115 results about "Bound water" patented technology

The invention discloses a nuclear magnetic T2 spectrum correction method for a shale reservoir, and relates to the field of object detection, and the nuclear magnetic T2 spectrum correction method for the shale reservoir comprises the following steps: 1, determining the gas logging porosity, saturated water porosity and main mineral components of the shale reservoir; compared with the prior art, the method disclosed by the invention has the beneficial effects that a drying-saturated water-centrifugal two-dimensional nuclear magnetic resonance experiment is carried out, and signals of crystal water, clay bound water and hydroxyl in a sample are preliminarily identified; through inversion of organic matter signals in the dry sample, signals of movable water are further determined; the relation between the difference value among the gas logging porosity, the saturated water porosity and the nuclear magnetic porosity and different mineral contents is discussed, and particularly the remarkable influence of iron-containing minerals on the porosity difference value is discussed; by eliminating the influence of diffusion relaxation caused by the magnetic susceptibility difference, the T2 spectrum correction method based on the mineral magnetic susceptibility is established, and the T2 spectrum accuracy obtained through nuclear magnetic resonance measurement is improved.

The invention relates to an automatic magnesium oxide coating analysis system and method, and belongs to the technical field of coating quality analysis. The method comprises the following steps: acquiring attributes of a magnesium oxide coating, an infrared spectrum and environment temperature and humidity data, and constructing a multi-source feature set; analyzing the distribution dispersion and local enrichment risk of free water based on a dynamic migration model, and analyzing the bonding weakening degree and dissociation risk of bound water based on a chemical stable state model; respectively generating free water treatment process parameters for inhibiting structural damage and combined water treatment process parameters for preventing performance degradation according to the abnormal analysis result and the coating attribute; by performing coupling influence analysis on the two types of process parameters, the balance requirements of the structural integrity and chemical stability of the coating are coordinated, an optimized process scheme is generated, and cooperative regulation is realized. According to the method, accurate identification, independent analysis and cooperative control of the free water and the bound water are realized, and the accuracy, reliability and quality consistency of coating water treatment are improved.

The invention discloses a novel dust falling material with strong wettability and high strength and toughness and a preparation method thereof. The novel dust falling material is prepared from the following raw materials in parts by weight: 1-3 parts of pectin, 10-35 parts of acrylamide, 1-2.5 parts of an initiator, 0.06-0.1 part of sodium periodate, 20-60 parts of bentonite, 8-12 parts of a wetting agent and 1000-3000 parts of water. According to the dust suppressant, the remarkable advantages of performance breakthrough, environment friendliness and economic optimization are achieved through the synergistic effect of multiple components, it is measured through experiments that the dust suppressant can form a solidified shell layer with toughness and strength on the surface of a coal sample, and the dust suppressant has the unique double-water-locking mechanism that polymer carboxyl chemical bonding water molecules and bound water physically adsorbed between bentonite layers are combined, so that the dust suppressant has the good dust suppressant effect on the surface of the coal sample. A good water loss rate can be maintained in a high-temperature drought environment, and the dust suppression efficiency can be improved due to the rapid film forming characteristic. A solidified layer with a complete structure is formed after drying, pulverized coal is effectively prevented from loosening, the inhibition rates of PM2.5 and PM10 both exceed 95%, and the efficient and lasting dust suppression effect is achieved.

The invention discloses a method and a device for determining water blocking damage degrees of different pore sizes of a rock core. Comprising the following steps: acquiring physical property data of a target rock core and simulated formation water; vacuumizing, pressurizing and saturating the target rock core to obtain a saturated water state rock core, and obtaining a first transverse relaxation spectrum and a first longitudinal and transverse relaxation correlation spectrum through nuclear magnetic resonance; performing displacement treatment on the rock core to obtain a water-bound state rock core, and obtaining a second transverse relaxation spectrum and a second longitudinal and transverse relaxation correlation spectrum; determining a pore size range, and establishing a water blocking damage identification chart to define a characteristic interval between bound water and saturated water; carrying out difference operation to obtain a difference spectrum matrix, extracting pore space areas of bound water and saturated water in the matrix, and calculating an area ratio; and determining the water blocking damage degrees of different pore sizes by combining the porosity, the permeability and the ratio. According to the method, the pore scale can be accurately divided, the damage of each scale can be quantified, the development efficiency can be optimized, and a reliable basis is provided for formulating a reservoir unblocking scheme.

The invention relates to the technical field of soil physical parameter in-situ measurement, and discloses a soil layer natural water content portable intelligent measuring instrument based on multi-source sensing fusion, which comprises a composite probe assembly and an intelligent measurement and control host which are physically connected, the composite probe assembly is configured to be inserted into a soil layer to be tested to construct a multi-physical field test environment, and an electrical transceiving unit and an acoustic transceiving unit are integrated in the composite probe assembly. By constructing a cross physical field excitation and multiphase parameter collaborative decoupling mechanism, a multidimensional dynamic correlation model is established by using the thermosensitive drift characteristic of the sound velocity of a mixed medium during thermal disturbance and the transient step response of a dielectric constant under an acoustic radiation force field; the problems that the coupling influence of the water content and the volume weight cannot be distinguished and the conductivity of bound water and the conductivity of free water are difficult to separate in a traditional means are effectively solved, and four independent physical quantities including the volumetric water content, the in-situ dry volume weight, the bound water content and the actual conductivity of pore water are synchronously inverted through a single probe. And the decoupling precision of the equipment on complex multi-phase soil medium parameters is improved.

The invention discloses a laboratory adsorption gas calculation method based on isothermal adsorption-nuclear magnetic resonance combined measurement, and relates to the technical field of exploration geophysics. According to the invention, on the basis of isothermal adsorption-nuclear magnetic resonance combined measurement experiment, 23MHz nuclear magnetic resonance experiment is utilized; nuclear magnetic signal conversion of bound water-adsorbed state methane is carried out through nuclear magnetic resonance T2 spectrums of coal rocks with different water saturations and T2 spectrums measured through a coal rock isothermal adsorption-nuclear magnetic resonance combined measurement experiment to obtain the hydrogen content of the adsorbed state methane, then the amount of substance of the adsorbed state methane is obtained, and finally the volume of the adsorbed state methane is obtained. The method comprises the following steps: firstly, measuring and determining the content of bound water in the coal rock by adopting a 25mm sample tube and the current minimum nuclear magnetism callback interval, then carrying out bound water-adsorbed gas nuclear magnetism signal conversion on the sample tube used in an isothermal adsorption-nuclear magnetism combined measurement experiment to obtain the hydrogen content of the adsorbed gas, further obtaining the amount of substance of the adsorbed gas, and finally obtaining the volume of the adsorbed gas.

The invention belongs to the technical field of cerium-based rare earth oxide dispersibility testing, and particularly relates to a method for evaluating cerium-based rare earth oxide particle surface characteristics and slurry dispersion stability. Comprising the following steps: when cerium-based rare earth oxide particles are synthesized, adding a paramagnetic element as a probe, and mixing the synthesized particles with a dispersing agent and water to obtain mixed slurry; nuclear magnetic resonance scanning is adopted, the body water relaxation peak and the particle surface bound water and body water exchange dynamic relaxation peak of the mixed slurry in each stage of the process from uniform mixing to standing layering are measured, and the particle surface characteristics are evaluated based on the relaxation efficiency; meanwhile, a linear relation between the relaxation peak area proportion and the sedimentation time in the standing layering process is constructed, a fitting slope value is obtained, and the dispersion stability of the mixed slurry is evaluated. According to the method, non-intrusive in-situ detection of the dispersion stability of the cerium-based rare earth oxide particle slurry is realized by innovatively using a low-field nuclear magnetic resonance mode, and accurate comparison and evaluation of the dispersion stability can be realized.

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 present application relates to the technical field of hygroscopic materials, and specifically to a composite hygroscopic material and preparation method, a composite hygroscopic agent and preparation method, and applications. The composite hygroscopic material comprises a substrate and an organic substance loaded on the substrate; wherein the organic substance is an organic substance containing amino or sulfonic acid groups; the substrate comprises a molecular sieve; the hygroscopic material is a composite of organic and inorganic materials, which adsorbs water molecules to form bound water, thereby effectively preventing water molecules from condensing into liquid water in the pores, thereby achieving desorption of the hygroscopic material at 70°C, an adsorption depth below 40°C, and an adsorption capacity of more than 300g / kg.

A treatment solution for a food product may include water, salt, and ground substrate of the food product being treated. The water, salt, and ground substrate are emulsified together to define an emulsified treatment solution, and protein of the ground substrate is activated to bind water to the food product when is treated with the treatment solution. The treatment solution remains at a substantially constant viscosity after emulsification.

The embodiment of the invention provides a rock irreducible oil saturation determination method, which comprises the following steps: carrying out nuclear magnetic resonance T1-T2 test on a to-be-tested rock sample without a movable fluid to obtain first test data; determining a first content relative value of bound oil in the to-be-tested rock sample based on the first test data, and determining a second content relative value of bound fluid in the to-be-tested rock sample based on the first test data, the bound fluid comprising bound oil and bound water; performing nuclear magnetic resonance T2 test on the rock sample to be tested to obtain second test data; determining the bound oil porosity of the rock sample to be tested based on the second test data, the first content relative value and the second content relative value; and determining the irreducible oil saturation of the to-be-measured rock sample based on the total porosity of the to-be-measured rock sample and the irreducible oil porosity. According to the technical scheme provided by the embodiment of the invention, the accuracy of determining the rock irreducible oil saturation can be improved.

The application discloses a shale oil reservoir core micro-percolation model and a preparation method and application thereof, and belongs to the technical field of oilfield development experiment researches.The core micro-percolation model comprises a rock sample and adhesive glass sheets used on two surfaces of the rock sample, and according to the oil-water flow direction in the rock sample, the side surface of the rock sample is set as an inflow end, an outflow end, a first end and a second end respectively, one or two needle heads are arranged close to the inflow end, one needle head is arranged close to the outflow end, and the core micro-percolation model is packaged through glue.The single-needle head and double-needle head micro-percolation models are prepared for different types of shale oil reservoir cores, and oil-water two-phase percolation experiments are carried out on typical rock samples; through the experiments, more accurate understanding of the percolation channels of oil and water in the shale reservoir core is obtained, the distribution states of residual oil and bound water in the core are accurately characterized in a visualized mode, and important references can be provided for the research on percolation curves, the understanding of percolation rules and the compilation of development schemes.

This invention provides a fluid identification method, device, processor, and machine-readable storage medium, relating to the field of oil and gas reservoir evaluation. The method includes: determining the porosity correction coefficient for escaping fluids in multiple full-diameter core sections; determining the apparent total porosity, two-dimensional nuclear magnetic resonance T1-T2 spectra, and porosity of each fluid component in the full-diameter core; determining the porosity of the fluid distribution range, the porosity of the bound fluid distribution range, the porosity of the movable fluid in vacuum-saturated water, and the total porosity; determining the escaping fluid porosity correction coefficient based on the total porosity, apparent total porosity, and bound water porosity of the full-diameter core, and establishing a porosity correction coefficient model based on the correction coefficients of multiple core sections, and determining the total porosity based on the model; and determining the oil and gas saturation and water cut of the entire well section core using the apparent total porosity, total porosity, water saturation, and porosity of each fluid component. Through this invention, the porosity of gas reservoir cores can be accurately measured, fluid properties can be accurately identified, and quantitative evaluation can be performed.

The invention discloses a closed coring saturation correction system, which relates to the technical field of oil and gas reservoir evaluation and comprises a movable water degassing correction model based on a nuclear magnetic simulation experiment and a bound water volatilization correction model based on a volatilization experiment. The method comprises the following steps: determining movable water loss through a nuclear magnetic simulation experiment, and establishing a movable water degassing correction model with permeability, movable water saturation and time; determining irreducible water loss through a volatilization experiment, and establishing an irreducible water volatilization correction model with permeability, irreducible water saturation and time; through combination of the movable water degassing correction model and the irreducible water volatilization correction model, more accurate correction of the closed coring water saturation is realized.

The present application relates to oil and gas geology evaluation technical field, specifically to a kind of construction method of resistivity model for evaluating the adsorbed oil content of shale oil reservoir.The method includes: based on effective medium symmetric conduction theory, establish the shale adsorbed oil resistivity model consisting of rock skeleton, adsorbed oil, free oil, free water and clay bound water five components;According to well logging data, determine the mineral skeleton content, argillaceous content and porosity in the model;Using the whole rock XRD of core sample, porosity determination and rock pyrolysis experimental data, the model geometric parameters are determined by using Powell optimization algorithm;Finally, the adsorbed oil component content is solved according to dichotomy iteration algorithm and converted into adsorbed oil mass.The present application overcomes the problem that traditional step pyrolysis experiment is limited by core sample and is difficult to realize continuous evaluation of whole well section, realizes continuous and quantitative evaluation of the adsorbed oil content of shale oil reservoir, and provides technical support for the evaluation of adsorbed oil content of shale oil reservoir.

The application discloses a method for determining the lower limit of movable fluid in water drive gas reservoirs and a preparation method thereof, and belongs to the technical field of oilfield development. T 2The conversion relationship between the relaxation time and the pore throat radius is derived and established by considering the bound water film thickness, the bound water film thickness, the maximum pore throat radius and the minimum pore throat radius of the rock sample are calculated and obtained; the change characteristics of the nuclear magnetic resonance T 2The residual gas saturation of the rock sample after water drive gas is calculated and obtained by using the fractal theory, the theoretical expression of the lower limit of the movable fluid pore diameter, the lower limit of the movable fluid porosity and the lower limit of the movable fluid permeability considering the bound water film thickness is respectively derived and established; the lower limits of the movable fluid pore diameter, the porosity and the permeability in the water drive gas process are respectively calculated and evaluated by using the Newton iteration algorithm and the numerical integration algorithm in combination with the theoretical expression and the related parameters.

The invention relates to the field of rock and soil testing, and particularly discloses a nuclear magnetic resonance detection method for the pore water state of cohesive soil, which comprises the following steps: optimizing a nuclear magnetic resonance echo parameter acquisition scheme, and adjusting acquisition parameters such as echo interval time (Time Echo) and polarization wait time (Time Wait) and a signal processing strategy; and a low-field nuclear magnetic resonance echo acquisition and partition inversion method for needle bound water, capillary water and gravity water is formed. According to the method, relaxation distribution of bound water, capillary water and gravity water can be effectively separated, the problem of quantitative identification of water in different occurrence states such as gravity water, capillary water and bound water in rock and soil media is solved, the quantitative and qualitative analysis precision is improved, and the method is suitable for the fields of soil, hydrogeology, oil and gas exploration and the like.

This application provides a method, apparatus, and device for obtaining bound water saturation. The method includes: acquiring reservoir parameters of a rock sample to be tested, and calculating the bound water saturation of the rock sample based on the reservoir parameters and a bound water saturation formula. The bound water saturation formula is pre-established based on the bound water saturation of multiple first rock samples and reservoir parameters, through multiple linear regression analysis. The bound water saturation of the multiple first rock samples is calculated based on the cumulative permeability contribution rate corresponding to the category to which the first rock sample belongs under porosity and pore structure index. Different cumulative permeability contribution rates are used to calculate the bound water saturation of different categories of rock samples, thereby ensuring the accuracy of the bound water saturation of the multiple first rock samples and the established bound water saturation formula. Therefore, the accurate bound water saturation of the rock sample to be tested can be obtained based on this formula.

The invention discloses a method for predicting the performance of a GO separation membrane based on molecular simulation and a preparation method of the GO separation membrane. Based on a molecular dynamics simulation technology, revealing a relationship among a GO interlayer water distribution state, an interlayer spacing and a chemical environment, and obtaining an interlayer water distribution state beneficial to ion transmission and corresponding geometric and chemical parameters of the membrane; the GO ion separation membrane is prepared under the guidance, a suspension of single-layer GO is prepared, a polyethersulfone membrane is adopted as a substrate, and thermal reduction treatment is performed after vacuum filtration and membrane formation. By reasonably regulating and controlling the interlayer spacing and the chemical environment of the GO membrane, fine regulation and control are carried out on the distribution state of water molecules containing interface bound water and non-interface free water in a confinement channel, and selective transmission of Li < + > relative to Na < + > and Mg < 2 + > by the GO membrane can be realized.

The invention discloses a condensate gas reservoir horizontal well reverse condensation multiphase flow pseudo-pressure determination method. The method comprises the following steps: determining relative permeability of a gas phase and an oil phase under different pressures based on well flow component data of a condensate gas reservoir horizontal well; determining the gas phase relative permeability under irreducible water saturation based on the relative permeability curve of the condensate gas reservoir horizontal well; correcting the gas phase relative permeability under different pressures and the gas phase relative permeability under irreducible water saturation based on a capillary number effect and a high-speed non-Darcy effect generated by the seepage velocity of condensate gas in the condensate gas well; and based on the oil phase relative permeability under the different pressures, the corrected gas phase relative permeability under the different pressures and the corrected gas phase relative permeability under the irreducible water saturation, utilizing a three-region pseudo-pressure equation to determine the pseudo-pressure of the three regions of the condensate gas well. The pseudo-pressure of the condensate gas reservoir can be calculated more accurately, and a necessary basis is provided for subsequent productivity evaluation and reasonable and efficient development of the condensate gas reservoir.

The invention relates to a method for identifying a clastic rock low-resistivity oil layer in a salt lake sedimentary environment, and belongs to the technical field of oil exploration and development. The identification method for the clastic rock low-resistivity oil layer in the salt lake sedimentary environment comprises the following steps: determining an identification standard of a dry layer and a production layer in a target layer of a research area based on a corresponding relation of porosity data, permeability data and reservoir types of the target layer encountered by a standard well in the low-resistivity research area; based on the corresponding relation of the irreducible water saturation, the movable water saturation and the reservoir type of the standard well drilling encountering target layer in the research area, the identification standards of the oil layer, the same oil-water layer and the water layer in the production layer in the target layer in the research area are determined. According to the method for identifying the clastic rock low-resistivity oil reservoir in the salt lake sedimentary environment, the reservoir seepage characteristics are considered, the Archie formula is corrected, and the movable water saturation is introduced, so that the identification accuracy of the low-resistivity oil reservoir can be effectively improved.

This application discloses a method for calculating the adsorption capacity of coal shale gas based on the nuclear magnetic resonance (NMR) T2 cutoff value. The method includes: acquiring multiple coal shale samples and determining their ash content; performing NMR testing on the coal shale samples to obtain the NMR T2 spectrum under saturated water conditions; centrifuging the saturated coal shale samples to obtain the NMR T2 spectrum under bound water conditions; obtaining the NMR T2 cutoff value of the coal shale samples based on the NMR T2 spectrum; testing the adsorbed gas content of the coal shale samples to obtain their adsorbed gas content; establishing an adsorbed gas content calculation model through regression analysis; and inputting the ash content and NMR T2 cutoff value of the coal shale sample into the adsorbed gas content calculation model to obtain the adsorbed gas content of the coal shale sample. This invention reduces the high cost of experiments and significantly improves the efficiency of coal shale gas exploration and development.

This invention discloses a drying agent, its preparation method, and its application method for converting water-bearing gas reservoirs into gas storage facilities. This invention belongs to the field of underground gas storage facility construction technology. The drying agent is prepared by mixing a desorbent, sodium dodecylbenzenesulfonate, a capillary force neutralizer, and supercritical carbon dioxide. The desorbent causes the aqueous phase to detach from the reservoir pore throats; sodium dodecylbenzenesulfonate acts as an interface modifier, weakening the binding force of the rock on the water film, causing the water film to rupture and converge into water droplets; the capillary force neutralizer is miscible with water, reducing the interfacial tension of the fluid within the pores and converting the bound water trapped in the micropores into flowing water; supercritical carbon dioxide, with its low viscosity and high diffusivity, can flow in the complex and fine pore throat system of the reservoir, and can also carry components such as the desorbent, sodium dodecylbenzenesulfonate, and capillary force neutralizer to the depths of the reservoir's micropores, allowing the components of the drying agent to function in a wider range of reservoir areas.

The invention relates to the technical field of oil exploration and development, and discloses a high-argillaceous loose stratum clay bound water porosity evaluation method and device, and the method comprises the steps: measuring the nuclear magnetic porosity of a saturated water core, and weighing the saturated water core; drying the saturated water rock core and weighing the dried rock core; calculating the clay bound water porosity of the rock core according to the mass of the saturated water rock core, the nuclear magnetic porosity of the saturated water rock core and the mass of the dried rock core; calculating a clay bound water nuclear magnetism T2 cutoff value according to the clay bound water porosity; establishing a corresponding relation between the clay bound water nuclear magnetism T2 cutoff value and the clay content; and calculating the formation clay bound water porosity according to the continuous depth of the corresponding relation. The method is designed according to the characteristics of the high-argillaceous loose rock, and compared with a previous high-argillaceous loose stratum clay bound water porosity evaluation method, the method has better applicability and precision.

The application discloses a kind of sandy conglomerate fluid property identification method based on bound water saturation model, belong to complex lithology reservoir comprehensive evaluation technical field, solve the technical problem that although the existing technique comprehensive identification method can identify fluid property to some extent, but because reservoir structure is complex, strong heterogeneity, oil-water identification is difficult, lack of systematicness when evaluating.The method disclosed in the application obtains single well average J type function by laboratory mercury injection experiment, obtains bound water saturation S wi From function, corrected porosity physical value φ is established with bound water saturation S wi Fitting, obtain the bound water saturation model based on corrected porosity physical value, then recalculate water saturation, bound water saturation, then and well logging data establish fluid identification chart, with reliable theoretical basis, easy to operate and the like.

The application discloses a method and system for overpressure formation rock physics modeling considering multiple pore media, and the method comprises the following steps: constructing a rock skeleton; adding a bound water pore to the rock skeleton; adding a bound water modulus to the rock skeleton containing the bound water pore; calculating a flexible pore ratio and a flexible porosity, and then adding a flexible pore to the rock skeleton containing the bound water modulus; adding a rigid pore to the rock skeleton containing the flexible pore; adding movable fluid to the double-pore rock skeleton; determining the volume modulus and shear modulus of each type of mineral in a saturated fluid equivalent model; and optimizing and adjusting the length-width ratio of the bound water pore and the length-width ratio of the rigid pore based on the volume modulus and shear modulus of each type of mineral in the saturated fluid equivalent model. The method adds the bound water pore and modulus to the rock skeleton on the basis of predicting formation pore pressure, adds fluid under consideration of different pore conditions, and thus improves the accuracy and reliability of the prediction result of the model velocity.

This application discloses a method, apparatus, and equipment for determining the pore-throat characteristics of shale. The method includes: obtaining a first water content, a second water content, and a third water content from a core sample of a target shale reservoir; wherein the first water content is used to characterize the water content of a dried core sample, the second water content is used to characterize the water content of a core sample saturated with fluid, and the third water content is used to characterize the water content of a centrifuged core sample; determining the movable water volume of the core sample based on the second and third water contents; determining the throat-bound water volume of the core sample based on the first and third water contents; and determining the pore-throat volume ratio of the target shale reservoir based on the movable water volume and the throat-bound water volume. This method allows for the quantitative characterization of shale pore-throat characteristics and yields more accurate and reliable measurement results.

The invention relates to the technical field of oil field oil reservoir development models, in particular to a dry rock model building method for a high-water-cut-period reservoir of an oil field. According to the dry rock model building method for the high-water-cut-period reservoir of the oil field, well drilling and well logging work is carried out on a target reservoir, data are collected, a curve is drawn through the data, consistency correction is carried out, total porosity is calculated according to the corrected data curve, and irreducible water porosity is obtained by subtracting effective porosity. And adding the obtained bound water porosity into dry clay data to obtain wet clay data, then combining the wet clay data with core data to establish a rock skeleton model, and then combining the rock skeleton model with the effective porosity to form a new dry rock model. According to the dry rock model building method for the high-water-cut-period reservoir of the oil field, the bound water porosity is calculated and added into the dry clay data to obtain the wet clay data, and the influence of long-time water injection exploitation on the structure in the reservoir is considered; and the reservoir sand body prediction precision and the fluid identification capability by using the longitudinal and transverse wave curves are improved.

This invention discloses a sludge conditioner comprising a nanoscale hydrophobic material loaded with a polynuclear metal chelate. The conditioner, by weight percentage, comprises the following components: 10-20% hydrophobic material, 30-35% chelated iron solution, 10-15% polynuclear metal salt, 5-10% dispersant, 2-5% pH adjuster, and the balance being deionized water. This sludge conditioner can disrupt the EPS (expanded saline solution) of the sludge system, dissolve microbial cells in the sludge, release bound water within the sludge, reduce electrostatic repulsion, improve the hydrophobicity of microbial cells in the sludge, and release free water and surface water, thereby significantly improving the dewatering performance of the sludge.

The application discloses a low-resistance oil layer sweet spot identification method based on nuclear magnetic logging, which comprises the following steps: determining the bound water saturation and the bound mineralization degree of a research area according to the specific conditions of the research area, discussing the influence of the above-mentioned content on the oil layer resistivity, and analyzing the formation mechanism of the low-resistance oil layer; determining the movable porosity of the low-resistance oil layer of the research area, and then analyzing the relationship between the movable porosity and the initial daily production of a single well, and demarcating the threshold value of the movable porosity; discussing the relationship between the movable porosity and seismic attributes, and performing nonlinear analysis on the movable porosity and sensitive seismic attributes through a neural network algorithm to realize the sweet spot identification of the low-resistance oil layer. The method considers the influence of the bound water saturation and the mineralization degree on the oil layer resistivity, and on this basis, analyzes the movable porosity development characteristics of the low-resistance oil layer through nuclear magnetic logging, and then analyzes the relationship between the movable porosity and the seismic attributes, so that the sweet spot identification of the low-resistance oil layer is realized.