648 results about "Shale oil" patented technology

The invention discloses a shale oil reservoir geology-engineering double-dessert compressibility comprehensive evaluation method, and relates to the technical field of petroleum and natural gas yield increase transformation and geotechnical engineering, in particular to a shale oil reservoir geology-engineering double-dessert compressibility comprehensive evaluation method, which comprises the following steps of performing normalization processing on a logging basic parameter standard deviation; geological dessert parameters are established by calculating the weight of each factor; influence factors influencing the longitudinal expansion capacity of the hydraulic fracture of the target reservoir are obtained; constructing a geological-engineering double-dessert compressibility comprehensive evaluation model of three types of lithofacies'reservoir performance-transformation potential 'synergistic mechanisms; and establishing a geological-engineering double-dessert compressibility kernel density estimation map, and dividing the reservoir compressibility on the premise of adaptive bandwidth. According to the method, the operability and prediction precision of an evaluation result are remarkably improved, and an innovative decision support tool is provided for horizon optimization and scheme design of shale oil reservoir fracturing transformation.

The invention relates to the field of oil well opening and killing fluid production, in particular to a solid-free well killing fluid for shale oil reservoir and a preparation method of the solid-free well killing fluid. The solid-free well killing fluid for the shale oil reservoir comprises the following raw materials in parts by mass: 50-70 parts of water, 10-30 parts of a density regulator, 3-6 parts of a copolymer tackifier, 1-3 parts of a dispersant, 3-7 parts of a filtrate reducer and 2-4 parts of a corrosion inhibitor. The copolymer tackifier is obtained by initiating copolymerization by taking acrylamide, a quaternary ammonium salt-containing monomer, an unsaturated silane coupling agent and polyethylene glycol diacrylamide as monomer free radicals, and the dispersing agent comprises gas-phase nano silicon dioxide and a fluorine-containing surfactant. Through reasonable compatibility of all the components in the formula, especially the copolymer tackifier, the effect that one agent has multiple functions is achieved, and meanwhile the high temperature resistance, the corrosion inhibition performance and the clay stability of the well killing fluid are improved.

Provided is a method for determining huff and puff fluid volumes in multi-scale spaces of shale oil reservoirs, including the following steps: rock sample pretreatment; porosity stress sensitivity testing; high pressure hg injection testing and nuclear magnetic resonance testing benchmarking; online nuclear magnetic resonance testing; data processing and analysis. Firstly, a changing law of multi-scale spaces of shale oil reservoirs with an effective stress is characterized through a pore stress sensitivity measurement and online nuclear magnetic resonance measurement combined experiment, and then the huff and puff fluid volumes of multi-scale spaces of shale oil reservoirs under a condition of a certain stimulated reservoir volume are calculated. A usage amount of a fracturing fluid for a fracturing horizontal well in the shale oil reservoir is determined from the perspective of giving full play to the imbibition replacement role of micro-nano pores.

The invention belongs to the technical field of shale oil development and research, and discloses a shale oil mobility evaluation method based on a two-dimensional nuclear magnetic resonance experiment, which comprises the following steps: dividing an oil-containing shale sample harvested by a closed coring well into three parts which are respectively marked as a sample 1, a sample 2 and a sample 3; carrying out a TOC determination experiment on the sample 1 to obtain the TOC content of the sample; carrying out a step-by-step pyrolysis experiment on the sample 2 to obtain the contents of the sample S1-1 and the sample S2-2; calculating to obtain a shale oil mobility evaluation factor which is marked as FMO; carrying out a two-dimensional nuclear magnetic resonance experiment on the sample 3 before and after centrifugation to obtain the movable oil content of the sample before and after centrifugation, calculating to obtain the percentage of two-nuclear magnetic resonance movable oil, and recording the percentage as MO2D-NMR; and shale oil mobility evaluation is realized through analysis of the relationship between MO2D-NMR and FMO. According to the method provided by the invention, nondestructive testing of the sample can be realized in the two-dimensional nuclear magnetic resonance experiment process, the loss of light hydrocarbon can be reduced to the greatest extent, and the mobility evaluation precision of shale oil is effectively improved.

The invention discloses a shale oil geological engineering dessert evaluation method and device based on geological modeling, and the method comprises the steps: determining a shale oil facies classification scheme and shale oil dessert evaluation key parameter values according to the shale oil geological engineering logging interpretation data, determining the corresponding scores of different shale rocks, and obtaining the shale oil dessert evaluation key parameter values of the shale oil facies classification scheme and the shale oil dessert evaluation key parameter values of the shale oil facies classification scheme; and determining a target sweet spot evaluation parameter weight based on sweet spot evaluation attributes of the lithofacies three-dimensional model and actual well drilling productivity data, establishing a shale oil geological engineering integrated comprehensive sweet spot factor, and determining a shale oil geological engineering comprehensive sweet spot evaluation result based on the sweet spot factor and the target sweet spot evaluation parameter value. Through the technical scheme of the embodiment of the invention, comprehensive evaluation of shale oil geological engineering desserts is realized, complexity of shale oil geological features can be adapted, correlation between geological and engineering dessert evaluation parameters is improved, and fine evaluation of shale oil dessert space distribution is ensured.

The invention provides a shale oil pyrolysis adsorption oil and free oil correction method based on a nuclear magnetic experiment, and belongs to the field of exploration and development of unconventional oil and gas fields. According to the method, on the basis of a shale rock physical experiment and a shale nuclear magnetic resonance experiment, the occurrence space and content of adsorbed oil are determined by using multi-state nuclear magnetic resonance experiments such as original sample, saturated oil, washing oil and different temperatures, so that a nuclear magnetic adsorbed oil model is constructed, and the content of the adsorbed oil is determined by further combining a different-temperature-order parallel crushed sample lithologic pyrolysis experiment-nuclear magnetic combined measurement experiment. The content of the free oil and the content of the adsorbed oil are calculated through the two-dimensional nuclear magnetism T1-T2 spectrum semaphore, the content of the free oil and the content of the adsorbed oil are compared and analyzed, the difference between the nuclear magnetism adsorbed oil and the pyrolysis adsorbed oil is matched with a free hydrocarbon curve to achieve adsorbed oil correction, and the free oil and the adsorbed oil are obtained.

The invention discloses a complex lithofacies shale oil reservoir multi-scale productivity prediction method and system. The method comprises the following steps: establishing a complex lithofacies shale oil reservoir model with a multi-scale aperture structure; representing the complex lithofacies shale oil reservoir model by adopting a dual-medium model and an embedded discrete fracture model; establishing a complex lithofacies shale oil reservoir seepage model and a numerical solution algorithm considering the starting pressure gradient and the stress sensitive effect, and forming a complex lithofacies shale multi-scale numerical simulation method; the complex lithofacies shale multi-scale numerical simulation method is adopted to carry out complex lithofacies shale oil reservoir seepage numerical simulation, and the shale oil reservoir oil and gas yield is obtained through calculation. According to the method, the seepage simulation and productivity calculation of the complex lithofacies shale oil reservoir can be quickly and accurately realized by establishing the seepage numerical simulation method of the complex lithofacies shale oil reservoir considering the multi-scale aperture characteristics, the starting pressure gradient and the stress sensitive effect.

The invention belongs to the technical field of oil well paraffin removal and prevention, and relates to a paraffin removal and prevention agent for a shale oil shaft and a preparation method thereof. The paraffin remover and inhibitor for the shale oil wellbore comprises the following raw materials in percentage by mass: 40-55% of an oily solvent, 1-3% of a cosolvent, 1-2% of imidazole bis (trifluoromethanesulfonyl) imide salt, 10-20% of a wax crystal modifier, 3-5% of an emulsifier, 1-2% of an alkaline regulator and 25-35% of water, wherein the sum of the mass percentages of the raw materials is 100%. The wax crystal modifier is prepared by copolymerizing (methyl) acrylic acid C12-C16 ester, (methyl) acrylic acid C1-C3 ester and (methyl) acryloyl chloride and then reacting with C20-C30 alkyl alcohol. The wax crystal modifier provided by the invention has long-medium-short branched chains, and interacts with the imidazole bis (trifluoromethanesulfonimide) salt capable of improving the paraffin removal effect and low-temperature fluidity, so that the efficient paraffin removal and inhibition effect is realized, and the better paraffin removal and inhibition effect can still be kept at low temperature.

The invention relates to the technical field of shale oil phase state evaluation, in particular to a nanometer space shale oil in-situ phase state and shale oil reservoir type intelligent evaluation method which comprises the steps that a pressure maintaining rock core is obtained from a shale target layer series; the method comprises the following steps: taking out a blocky frozen-state pressure-maintaining rock core, quickly crushing, putting into a pyrolysis device sample boat, feeding into a pyrolysis furnace, acquiring pyrolysis data at each acquisition moment in a pyrolysis process, determining a comparison interval coefficient at the current moment, and constructing an accumulated comparison coefficient for adjusting control parameters so as to adjust the pyrolysis temperature; the method comprises the following steps: preparing a pressure-maintaining rock core, rapidly heating a heat release sample, separating the sample into various monomeric compounds to obtain a pressure-maintaining rock core pyrolysis gas chromatography spectrogram, calculating the content of each component, using simulation software and combining thermodynamic parameters of oil and gas components to obtain a shale oil P-T phase diagram, and further determining a nano space shale oil in-situ phase state and a shale oil reservoir type. The accuracy, efficiency and convenience of shale oil phase state and oil reservoir type evaluation are improved.

The invention relates to the field of oil and gas field exploration and development, in particular to a shale oil dessert well logging evaluation method and device based on source-reservoir coupling characteristics, and the method comprises the steps: determining the reservoir quality according to the effective porosity and effective thickness of a shale oil reservoir in a research area; the effective porosity is greater than a preset porosity lower limit threshold; evaluating the quality of each hydrocarbon source rock stratum section according to the effective points of the total organic carbon content of the kerogen in the research area, the effective thickness of the layer section corresponding to each effective point and the total organic carbon content of the kerogen of the effective point; according to the coupling relation between the reservoir quality and the quality of the hydrocarbon source rock stratum section within the estimated longitudinal distance range of the position of the effective point of the total organic carbon content of the kerogen; according to the coupling relation, shale oil desserts within the longitudinal distance range are evaluated and estimated. On the basis of hydrocarbon source rock quality classification, reservoir quality classification and a source-reservoir coupling relationship, a foundation is laid for accurate classification evaluation of shale oil dessert development sections.

The present description relates to the field of oil and gas field exploration and development, and in particular, to a shale oil sweet spot logging evaluation method and apparatus based on source-reservoir coupling characteristics. The method comprises: on the basis of the effective porosity and effective thickness of a shale oil reservoir in a research area, determining reservoir quality, wherein the effective porosity is greater than a preset porosity lower threshold; on the basis of effective points of kerogen total organic carbon content in the research area, the effective thickness of an interval corresponding to each effective point, and the kerogen total organic carbon content of each effective point, evaluating the quality of source rock intervals; on the basis of an estimated longitudinal distance range of the positions where the effective points of kerogen total organic carbon content are located, determining a coupling relationship between the reservoir quality and the quality of the source rock intervals; and on the basis of the coupling relationship, evaluating a shale oil sweet spot within the estimated longitudinal distance range.

The invention provides a shale oil reservoir dessert intelligent identification method and system, relates to the field of shale oil reservoirs, and aims to obtain original logging data and extract curve deep space-time coding features by fusing a hybrid model of a convolutional neural network and a recurrent neural network. Then, multi-source logging features are dynamically fused through a cross-curve feature fusion algorithm, and spatial compression is carried out through feature principal component analysis; thirdly, implicit features strongly related to the geological signs of the sweet spots are screened through semantic level selection based on feature principal components, sweet spot probability prediction is achieved based on a lightweight classification model, an intelligent recognition closed loop without manual intervention is formed, and the dependence of a traditional method on expert experience is broken through; in this way, non-linear correlation in the logging curve is automatically mined through deep learning, and the interpretability and generalization ability of complex reservoir dessert recognition are improved.

The invention relates to a method for treating shale oil crack wall surfaces by using carbon nanotubes to increase the heat transfer capacity of a reservoir, a plurality of horizontal wells are drilled from the ground, the horizontal sections of the horizontal wells form three parallel well rows, the uppermost well row and the lowermost well row are heating wells, and the middle well row is a production well. The fracturing fluid carrying the proppant is injected into the heating well and the production well with the displacement greatly exceeding the stratum absorption capacity, the bottom hole pressure is larger than the stratum fracture pressure, hydraulic fracturing is carried out, a tensional fracture area and a communication well group are generated, and meanwhile it is guaranteed that fractures are not closed after the proppant is filled. Under the condition that the pressure is lower than the formation fracture pressure, a weak acid solution is slowly squeezed into the heating well and the production well, the well wall and the crack wall face are treated, and a large number of corrosion micropores are formed. And under the condition that the pressure is lower than the stratum fracture pressure, a weak acid solution added with the carbon nano tubes is squeezed into the heating well and the production well, so that the carbon nano tubes are adsorbed or filled in the corrosion micropores, and the micropores where the carbon nano tubes are attached are formed. And high-temperature steam is circularly introduced into the heating well and the production well to heat the oil shale stratum. After heating for a certain time, stopping steam injection of the production well, and changing into production; and continuously injecting steam into the heating well. The method is suitable for an oil shale underground in-situ conversion exploitation technology, and is also suitable for geothermal exploitation and heavy oil thermal exploitation.

The invention relates to the technical field of unconventional oil-gas exploration, in particular to a high-clay shale oil in-situ accumulation dynamics mechanism and mode evaluation method. The method comprises the following steps: collecting fluid pressure, temperature data, displacement pressure, oiliness, brittleness index, hydrostatic pressure, vitrinite reflectivity and density value of a shale sample at each depth position point of an exploratory well of each exploration point; calculating abnormal sensitivity; further acquiring ground temperature evaluation credibility; obtaining a self-adaptive fitting weight; acquiring the actual fluid pressure of the exploratory well of each survey point at each depth; acquiring the pressure coefficient of the shale sample at each depth position point of the exploratory well of each survey point; obtaining a self-sealing reservoir forming mode and a retention reservoir forming mode of shale oil; based on the vitrinite reflectivity, the oiliness, the brittleness index and the pressure coefficient, a shale oil enrichment area evaluation comprehensive index is constructed, and the in-situ flow of the high-clay shale is evaluated. According to the method, the accuracy of in-situ self-sealing reservoir formation, retention reservoir formation and dynamic mechanism evaluation of the high-clay shale is improved.

The invention provides a design method for dynamically regulating and controlling the reasonable oil nozzle size after shale oil horizontal well fracturing. The design method comprises the steps that 1, fracturing data, well bore structure data and well mouth production data are collected; 2, according to the collected data, the bottom hole flowing pressure and the bottom hole flowback speed are calculated; 3, calculating the sedimentation degree of the propping agent; 4, calculating the critical flow velocity of the proppant; 5, calculating preset oil nozzle bottom hole flowing pressure and bottom hole flow velocity; and 6, under different conditions, the oil nozzle is adjusted, and the current reasonable oil nozzle size is obtained. According to the design method for dynamically regulating and controlling the reasonable oil nozzle size after fracturing of the shale oil horizontal well, the conditions of propping agent sedimentation and propping agent backflow are considered, the condition that multiple cracks exist in multi-section fracturing of the horizontal well is fully considered, real-time regulation and control over the flow-back oil nozzle can be conducted according to the actual flow-back condition on site, and wide application prospects are achieved.

The invention relates to the technical field of fracturing fluid formulas and fracturing methods, in particular to a mixed-phase tackifying fracturing fluid system and a shale oil supercritical CO2 near-dry fracturing method, and the mixed-phase tackifying fracturing fluid system comprises a water-phase fracturing fluid and a CO2-phase fracturing fluid; the water-phase fracturing fluid comprises a water-phase thickening agent and water, and the CO2-phase fracturing fluid comprises a CO2-phase thickening agent and CO2. According to the invention, the net pressure at the bottom of the well during CO2 injection is greatly improved, the complexity of fracturing and crack forming is improved, the CO2 phase long-distance sand-carrying support function is realized through a CO2 tackifying technology, the CO2 acting distance is improved, and the water sensitivity, water locking and fracturing fluid residual gum damage of the water phase fracturing fluid to a reservoir are greatly reduced by reducing the water phase proportion, so that the fracturing efficiency is improved. And finally, the fracturing transformation effect and the recovery efficiency are greatly improved.

The invention provides a fracturing crack parameter evaluation method for a shale oil multi-section fracturing horizontal well. The shale oil multi-section fractured horizontal well post-fracturing crack parameter evaluation method comprises the following steps: multi-source data acquisition: acquiring fracturing construction data, logging data, production dynamic data and inter-well interference information of a target shale oil well; and monitoring the content of the osmotic adjusting substance: realizing real-time monitoring of the osmotic adjusting substance after pressure through a shaft sensor system. According to the method for evaluating the fractured fracture parameters of the shale oil multi-section fractured horizontal well, a systematic fracture parameter evaluation method is constructed by fusing key technical links such as multi-source data acquisition, osmotic regulation substance real-time monitoring, inter-section interference modeling inversion, phenotype-biochemical index coupling analysis and the like; and the bottlenecks of insufficient crack evaluation precision and difficult identification of inter-segment crack interference in the prior art are broken through. And the method has good engineering practical value and popularization prospect.

The invention discloses a shale oil reservoir CO2 huff and puff miscible-phase region dynamic discrimination method. The method comprises the steps that nuclear magnetic resonance testing is conducted on a target oil reservoir core sample; the method comprises the following steps: scanning a target oil reservoir core sample, constructing a three-dimensional core pore structure model, introducing nuclear magnetic resonance data to calibrate initial fluid saturation, and establishing a dynamic displacement numerical simulation model in combination with a CO2-crude oil phase equation, an interfacial tension model and a core permeability heterogeneity parameter; designing a plurality of groups of huff and puff experiments, simulating a CO2 injection process, monitoring nuclear magnetic resonance signal changes of the rock core in a displacement process in real time, correcting fluid saturation, a pressure field and interfacial tension parameters in a dynamic displacement numerical simulation model, and dividing a miscible-phase region; and selecting an optimal development parameter combination based on mixed-phase region distribution under different transfer injection opportunities, soaking time and throughput turns. According to the method, accurate division and dynamic discrimination of the CO2 huff and puff mixed-phase region are realized.

A method for evaluating contribution of each component to shale oil reservoir resistivity at high temperature and high pressure is applied to the field of oil exploration and development. The method comprises the following steps: (1) analyzing the volume percentage of each clay mineral, the pore water content and the mineralization degree of the shale oil reservoir pressure-maintaining closed core; (2) when the fluid pressure is greater than 23MPa, measuring the resistivity of the pressure-maintaining closed rock core at each temperature point; (3) carrying out water balance treatment on pure clay minerals, namely kaolinite, montmorillonite, illite and chlorite, and measuring the resistivity at each temperature point when the fluid pressure is greater than 23MPa; (4) when the fluid pressure is greater than 23MPa, measuring the resistivity of each temperature point of the solution consistent with the mineralization degree of the pore water; and (5) constructing a resistivity evaluation model, and evaluating the contribution of each component to the resistivity of the shale oil reservoir under the condition of high temperature pressure.

The invention discloses a shale oil content prediction method, device and equipment and a medium, and relates to the technical field of shale oil exploration and development. A high-quality model training sample data set is constructed by integrating shale oil content data actually measured by an oil field and associated logging data of the shale oil content data. And based on the data set, performing model training by adopting a long-short-term memory neural network enhanced based on an attention mechanism, constructing a high-precision shale oil content prediction model, and further performing oil content prediction by utilizing the trained shale oil content prediction model. Petroleum logging data and a deep learning technology are combined, accurate calculation of the oil content of the shale reservoir in the stratum in-situ state is achieved, and the reliability of a prediction result is remarkably improved. Compared with a traditional method, the method has the advantages that the analysis period is greatly shortened, the test cost is reduced, meanwhile, the method has excellent generalization ability, the oil content prediction requirements of different types of shale oil reservoirs can be met, and efficient and accurate technical support is provided for shale oil exploration and development.

The invention relates to the field of oil and gas reservoir exploration and development, and discloses a shale oil reservoir carbon dioxide injection exploitation effect prediction method and device, and the method comprises the steps: obtaining the characteristic parameters of a target core and the engineering parameters of a target block; constructing molecular dynamics models corresponding to different minerals in the target rock core according to the characteristic parameters and the engineering parameters; determining a target relational expression according to a simulation result of each molecular dynamics model; based on a target pore network model and the target relational expression, the exploitation effect of carbon dioxide injection of the shale oil reservoir is determined, and the target pore network model is obtained based on the characteristic parameters. Due to the fact that the flow rule of fluid in the nanoscale pores, nanoscale effect changes and differences among different mineral types are considered when the exploitation effect of the shale oil reservoir injected with the carbon dioxide is predicted, the accuracy of prediction of the exploitation effect of the shale oil reservoir injected with the carbon dioxide can be improved.

The invention relates to the technical field of oil exploration, in particular to a shale oil dessert evaluation system construction method and a shale oil dessert evaluation method.The shale oil dessert evaluation system construction method comprises the steps that geological characteristic parameters of a plurality of rock core samples are obtained; based on the geological characteristic parameters, determining main control influence factors of shale oil enrichment through a control variable method and correlation analysis; and establishing a dessert section quantitative evaluation system according to the master control influence factors. According to the method, on the basis of the geological parameter data of the sampled rock core, through the control variable method and the correlation analysis method, the sweet spot evaluation parameter system is established, the sweet spot section of the pure shale layer section is longitudinally divided, the favorable area can be further predicted, and the technical problem of the method faced by shale oil sweet spot selection is solved. The shale oil enrichment mechanism, dessert control factors and favorable zone evaluation in the research section are deeply understood; meanwhile, reference is provided for area selection, zone selection and exploration deployment of the pure shale type shale oil, and the field of exploration of the pure shale type shale oil is effectively expanded.

The invention relates to the technical field of shale oil exploitation, in particular to a shale oil working fluid displacement device and a reservoir physical property evaluation method. In the shale oil working fluid displacement process, dynamic pressure difference time sequence data corresponding to all moments are obtained, and due to the fact that the viscosity and flow characteristic difference of different fluid media is large, dynamic pressure difference fluctuation is remarkable during displacement; determining the fidelity of the displacement pressure at each moment by analyzing the frequency domain and linear regression characteristics; thirdly, all moments are clustered based on the dynamic pressure difference and the displacement pressure fidelity, and the moments in the same displacement state are clustered into one class; in view of the fact that fixed PID parameters are difficult to adapt to different working fluid medium characteristics and can cause control delay, in a cluster to which the current moment belongs, moment distribution characteristics and dynamic pressure difference time sequence data dynamic estimation characteristics are analyzed, the pressure instability degree and the observation uncertainty are reflected, a preset gain coefficient is adjusted accordingly, more accurate PID control is achieved, and the control precision is improved. And the reliability of subsequent reservoir physical property evaluation is ensured.

The invention provides a mobility evaluation method and device for shale oil, and the method comprises the steps: carrying out the multi-temperature-order pyrolysis operation of a shale oil core of a target work area, so as to obtain the pyrolysis hydrocarbon parameters of the shale oil components of the shale oil core; generating oil saturation corresponding to different transverse relaxation times according to the nuclear magnetic logging data of the target work area; and the oil saturation corresponding to the different transverse relaxation times is calibrated according to the pyrolysis hydrocarbon parameters of the shale oil components so as to evaluate the mobility of the shale oil in the target work area. According to the method, the real movable oil saturation and the maximum movable oil saturation can be accurately obtained, the shale oil occurrence state can be effectively identified, the oil content in different occurrence states can be represented, and the method has practical application value in shale oil sweet spot evaluation and prediction.

The invention discloses a shale oil reservoir volume fractured horizontal well'stuffiness-drainage-production 'integrated physical simulation method, which comprises the following steps: drilling a shale oil reservoir full-diameter plunger rock sample, and completing rock sample pretreatment; wax-sealing the pretreated rock sample, and vacuumizing and pressurizing to saturate heavy water; displacing the saturated heavy water rock sample with the compounded in-situ crude oil until a bound water state; wax seals are removed, quartz sand is laid on the end faces of the rock samples, the rock samples are spliced to form a volume fracturing horizontal well physical model, and the volume fracturing horizontal well physical model is loaded into a rock sample holder; heavy water is pumped into the inlet end of the rock sample holder and pressurized, the inlet end is closed, and the well closing process after fracturing is simulated; and opening the inlet end of the rock sample holder, and simulating flowback production after fracturing. According to the experimental method, the'stuffy-drainage-mining 'physical process of the shale oil volume fractured horizontal well can be restored, fluid imbibition, flowing and occurrence rules are researched, and efficient development of shale oil reservoirs is guided.

The invention discloses a shale oil reservoir multi-scale mechanical property prediction method. Comprising the following steps: S1, carrying out multi-scale structure characterization on a shale oil reservoir; s2, carrying out a microscopic mechanical test; s3, carrying out primary homogenization analysis to obtain an equivalent elastic modulus of the three-dimensional grain model; s4, carrying out a macroscopic physical experiment; s5, determining a mean value and a variance of lamina distribution; and S6, carrying out secondary homogenization analysis, and determining the equivalent elastic modulus of the lamina distribution model. The method has the advantages that the equivalent elastic modulus of the strata distribution model can be predicted in a cross-scale mode, and a more accurate mechanical basis is provided for shale oil reservoir development and engineering practice.

The present application belongs to the technical field of oil well wax removal and prevention, and relates to a shale oil well shaft wax removal and prevention agent and a preparation method thereof. The shale oil well shaft wax removal and prevention agent comprises the following raw materials in percentage by mass: 40-55% of an oily solvent, 1-3% of a cosolvent, 1-2% of an imidazole double-trifluoromethylsulfonylimide salt, 10-20% of a wax crystal modifier, 3-5% of an emulsifier, 1-2% of an alkaline adjusting agent, and 25-35% of water, with the sum of the percentage by mass of each raw material being 100%; the wax crystal modifier is prepared by copolymerizing (methyl) acrylic C12-C16 ester, (methyl) acrylic C1-C3 ester and (methyl) acryloyl chloride, and then reacting with C20-C30 alkyl alcohol. The wax crystal modifier in the present application has long-mid-short branched chains, and cooperates with the imidazole double-trifluoromethylsulfonylimide salt to improve the wax removal effect and low-temperature fluidity, thereby achieving high-efficiency wax removal and prevention effect and still maintaining good wax removal and prevention effect at low temperatures.

The application discloses a multifunctional biological imbibition agent and a preparation method and application thereof. The preparation method of the multifunctional biological imbibition agent comprises the following steps: (S1), alkylization reaction to obtain alkyl naphthalene; (S2), chloromethylation reaction to obtain halomethyl alkyl naphthalene; (S3), halogen alkyl nucleophilic substitution reaction to obtain hydroxymethyl alkyl naphthalene; and (S4), esterification reaction to obtain the multifunctional biological imbibition agent. The application further discloses application of the multifunctional biological imbibition agent as an imbibition agent in shale oil reservoir oil extraction. The application has the following advantages: (1) the reservoir adsorption amount is small, but the good wetting reversal characteristic is still maintained, and the emulsification is weak; (2) the high-temperature resistance is strong, and the temperature resistance reaches above 200 DEG C; (3) the preparation process is simple, and the yield is high; (4) the dosage is small, the cost is low, and the economic benefit is remarkable.

The present application provides a kind of shale oil saturation quantitative determination method and system, quantitative determination method includes: preparation shale plug sample;The shale plug sample is washed oil, dried, vacuum pressurized saturated deionized water, carries out one-dimensional nuclear magnetic resonance test, obtains shale plug sample pore volume;Step 3: the shale plug sample is dried again, and the dynamic change characteristics of the one-dimensional and two-dimensional nuclear magnetic resonance test results of the shale plug sample are obtained, and the oil output at the end of the displacement device is measured by measuring cylinder;According to the shale plug sample, the oil and water distribution area is determined, and the limit value of the two is divided;The oil saturation of different displacement stages of the displacement oil and the displacement non-oil shale plug sample is calculated respectively;According to the characteristic parameters of shale plug sample, an oil saturation calculation model is established based on least square method, and a chart is constructed.A shale oil saturation interpretation chart based on different displacement stages of nuclear magnetic characteristics is provided.

The utility model relates to the field of oilfield development, and discloses a shale oil high-sulfur flowing well ground desulfurization device which comprises a mixing tank, a support frame, a desulfurizer spraying mechanism, a transition pipeline, an S-shaped distributed ground desulfurization pipeline group and a buffer pool, the S-shaped arrangement ground desulfurization pipeline group comprises a plurality of desulfurization pipelines which are laid on the ground and are parallel to one another and pipe bending mechanisms which are connected with corresponding position ports of the adjacent desulfurization pipelines. The device is simple in structure, small in equipment fixing investment and low in operation cost, and has good economic benefits; the flow velocity is delayed through gravity oil discharge, the flow in the pipeline is increased and the time is prolonged by additionally arranging the S-shaped distributed ground desulfurization pipeline group formed by the bent pipes, and homogenization is performed through the buffer pool, so that shale oil and a desulfurizer are fully and uniformly mixed, the desulfurization effect is better, and the safety production is better guaranteed; the S-shaped arrangement mode of the ground desulfurization pipelines is small in occupied area, land space is saved, and good resource utilization benefits are achieved.