51 results about "Volume factor" patented technology

Method using <<Black Oil>> type modelling for predicting, as a function of time, the detailed composition of fluids produced by an underground reservoir under production, combined with a delumping stage allowing detailed thermodynamic representation of the reservoir fluids.The input data entered for the model are the thermodynamic parameters of the fluids such as viscosity, volume factor, density, gas-oil dissolution ratio, etc. (in form of charts, and / or by correlation, as a function of the pressure, of the temperature if it varies) and, if need be, an additional parameter keeping a memory of the composition of the gas such as, for example, the density of the gas), as well as data relative to the variations, as a function of the same <<abscissas>>, of the phase parameters required for delumping, without the latter being used during the <<Black Oil>> simulation of the flows.Application: predictive profiles of the detailed composition of hydrocarbons produced by a reservoir for example.

The invention belongs to the technical field of oil exploitation and particularly relates to a calculation method for predicating recovery percentage and water cut of an oil field. The method for predicting the recovery percentage and water cut of the oil field comprises the following steps of: (1) obtaining a water-oil mass ratio: Qw / Qo, i.e. Fg; (2) obtaining the initial oil saturation: Soi; (3) testing the irreducible water saturation: Swi; (4) obtaining a crude oil volume factor Bo; (5) putting the above parameters into a formula as shown in the specification so as to obtain a relationship between the water cut and the recovery percentage. According to the method for predicting the recovery percentage and water cut of the oil field provided by the invention, a universal method applicable to water-flooding development of reservoirs with high-permeability, low-permeability and ultra-low permeability is obtained, and the actual changing rule of the water cut and recovery percentage of reservoirs and the percolation characteristic representation of the oil reservoirs of different types can be reflected, therefore the method is fit for the practical situation better; furthermore, the development index prediction precision can be improved, therefore the method has an important practical significance on the production practice of the oil fields.

The invention discloses a method for predicting the well yield of sealed, unsaturated oil reservoirs through elastic driving water-flooding extraction. The method includes: measuring the initial volume coefficient Boi of crude oil and the volume coefficient Bo of the crude oil under different pressure conditions, measuring the initial oil saturation Soi and the initial water saturation Swc of the rock core, generally measuring the in-place oil compression coefficient Co, the formation water compression coefficient Cw and the rock compression coefficient Cp, obtaining the rock effective compression coefficient Ceff according to the above parameters; measuring the oil geological reserves N and the reservoir pressure under a certain injection condition according to a matter balance equation, and finally measuring the yield of an oil well according to a plane radial flow Darcy equation, wherein the yield includes oil yield and water yield. The method supplements the correspondence between injected water and oil reservoir pressure change under the water-flooding extraction condition, accordingly can predict the daily oil yield and the daily water yield under the water-flooding extraction condition, and provides reference value for oil field production cost.

The invention relates to the technical field of oil reservoir productivity prediction, in particular to a prediction method for volcanic rock oil reservoir productivity. The prediction method comprises the following steps: step one, collecting the oil reservoir basic parameters of oil reservoirs or similar oil reservoirs of tested oil wells in target blocks, including individual well productivity Q, perforation reservoir thickness h, crude oil volume factor B0, comprehensive skin factor s, perforation productivity ratio PR, starting pressure gradient lambda, after-pressing well testing permeability Ks, formation pressure pe, flowing pressure pw, wellbore radius rw, fluid viscosity u, and fracturing fracture length, wherein the unit of the after-pressing well testing permeability Ks is mD, the units of the formation pressure Pe and the flowing pressure Pw are MPa, the unit of the wellbore radius rw is m, and the unit of the fluid viscosity u is MPa*s. Compared with an existing analogy method, the prediction method is more targeted, and the precision is higher, the precision can be improved to 60% above through the method disclosed by the invention, and a good method is provided for exploration oil testing, layer selection and the like.

The invention discloses a sulfur deposition device based on a magnetic suspension balance. The sulfur deposition device comprises a displacement system, a stratum condition simulation system, a magnetic suspension balance measuring system and a data collecting and processing system. The sulfur deposition device based on the magnetic suspension balance has the beneficial effects that a high-temperature, high-pressure and high-sulfur-content stratum environment can be truly simulated, the measuring accuracy of the sulfur deposit amount is greatly improved, the viscosity, bulk coefficients and deviation factors of gas are calculated in real time, and the dynamic change of the rock core permeability due to sulfur deposition is measured online in real time. The sulfur deposition device based on the magnetic suspension balance has the advantages of good security, high measuring accuracy, high temperature resistance, high pressure resistance, strong corrosion resistance and the like and further has the important significance to the evaluation of the dynamic influence of the sulfur deposition of a high sulfur gas reservoir to the exploitation.

A downhole tool is operated to pump fluid from a subterranean formation while obtaining fluid property measurements pertaining to the pumped fluid. The downhole tool is in communication with surface equipment located at the wellsite surface. The downhole tool and / or surface equipment is operated to estimate a first linear, exponential, logarithmic, and / or other relationship between compressibility and pressure of the pumped fluid based on the fluid property measurements. The downhole tool and / or surface equipment may also be operated to estimate a second linear, exponential, logarithmic, and / or other relationship between formation volume factor and pressure of the pumped fluid based on the first relationship. The downhole tool and / or surface equipment may also be operated to measure and correct optical density of the pumped fluid based on the first relationship.

The invention relates to a waterflood simulation recovery ratio test method considering energy flow in a low-permeability reservoir. The method is completed by means of a core displacement device. Thedevice is composed of a confining pressure pump, a core holder, a back pressure pump, a simulated oil intermediate container, a formation water intermediate container and the like. The method comprises the following steps that (1), simulated oil is prepared, and the volume factor B0 of the simulated oil is tested; (2), a plurality of blocks cores containing crack plungers are selected, and the diameter Di, the length Li, the mass Mi1 and the permeability Ki of the cores are tested; (3), the core bound water saturation is established; (4), the cores are saturated with the simulated oil; (5), the recovery ratio R0 of the failure development simulated oil is calculated; (6), the simulated oil intermediate container is opened, far-well zone energy flow is simulated, and a first round of waterflood simulation oil recovery cumulative recovery ratio R1 is obtained; and (7), the sixth step is repeated, and the i-th round of waterflood simulation oil recovery cumulative recovery ratio Ri is obtained. The method is reliable in principle, simple and applicable, can accurately evaluate the waterflood simulation recovery ratio under a real reservoir condition and has a wide market applicationprospect.

The invention discloses a shale reservoir free gas content earthquake predicating method and a system thereof. The method comprises the steps of respectively acquiring work area elastic parameters andtime domain well logging data based on a work area pre-stack seismic data volume and depth domain well logging data; establishing a rock physical model based on the work area elastic parameters, andobtaining porosity and gas saturation; based on seismic data and ground temperature gradient, respectively acquiring a stratum pressure and a stratum temperature, and furthermore obtaining a volume coefficient; and based on the porosity, the gas saturation, the volume coefficient and the stratum pressure, establishing a calculation model of the free gas content, thereby obtaining the free gas content, wherein the work area elastic parameters comprise longitudinal wave impedance, transverse wave impedance and density. According to the shale reservoir free gas content earthquake predicating method and the system, through restraining the factors such as the stratum temperature, the stratum pressure, porosity and gas saturation, high-precision predication for free gas content of the shale reservoir is realized.

The invention relates to ammunition for missile weapon and firearm. The cavitating core of the invention comprises a head part conjugated with a secant nose surface along the cavitating edge, a central part, and an aft part with a gliding surface, wherein the caliber of the core is defined by the maximum diameter of the circle describing the core cross-section. The contour line enveloping the cross-sections from the cavitating edge to the core caliber in the plane of the core axial longitudinal section is limited by the dependence:Dx=d×[1+(Lx / d)×(2×sin φ / π)1 / N]N, whereDx—is the current diameter of the core enveloping contour R, mm;d—is the cavitating edge diameter, mm;Lx—is the current distance from the cavitating edge to the core caliber, mm;φ=60° . . . 270°—is the apex angle of the tangents to the secant nose surface at the points of its conjugation with the cavitating edge measured from the side of the head part;N=(2π / φ)0.4 . . . (2π / φ)0.2—is the core volume factor, wherein the core caliber is equal to the current diameter of the core enveloping contour Dx.As a result the invention makes it possible to increase the effective distance for hitting underwater targets when shooting from the air to the water and / or during underwater shooting using arbalests, harpoon guns, artillery, small and sporting-and-hunting weapons.

The invention discloses a viscous debris flow river-blocking calculation method and an application thereof, belonging to the technical field of debris flow prevention and treatment engineering. The viscous debris flow river-blocking calculation method comprises the following steps of: obtaining a confluence angle of a branch channel and a main river as shown in the specification by measurement; measuring the average width B1 of the main river and the flow Qm of the main river at the confluence position of the main river and the branch channel, and determining the flow per unit width Q1 of the main river; measuring the average width B2 of the branch channel and the flow of the debris flow as shown in the specification at the confluence position of the main river and the branch channel, determining the flow per unit width of the branch channel as shown in the specification, determining the ratio of the flow per unit width of the branch channel and the main river as shown in the specification, measuring water depth h of the main river at the confluence position of the main river and the branch channel, determining a volume factor yt, measuring the yield stress of the debris flow as shown in the specification, and the density of the debris flow as shown in the specification, and determining a yield stress factor x of the debris flow; and judging whether river blocking can be caused by the viscous debris flow or not according to a judgment factor y. A debris flow river-blocking calculation model established in the invention has the characteristics of being harmonious in dimension and high in calculation result accuracy, and is capable of accurately judging viscous debris flow river-blocking; and thus, the debris flow prevention and treatment effect is improved.

The invention discloses a device for online measurement of a gas injection crude oil volume factor and solubility.The device comprises a gas supply system, a buffer system, a testing system, a gas phase analysis system and a data collection system.The gas supply system comprises a gas cylinder.The buffer system comprises a high pressure buffer container.The buffer container is connected with a gas cylinder high pressure reaction container.The testing system comprises a high pressure reaction container and a temperature controller arranged on the high pressure reaction container.The gas phase analysis system comprises a gas chromatograph.The data collection system comprises a computer, a data collector and a temperature sensor, a pressure sensor and a liquid level sensor which are arranged on the high pressure reaction container.The invention further discloses a method for online measurement of the gas injection crude oil volume factor and solubility.Online testing of PVT data of crude oil before and after gas injection can be achieved, the measured PVT data is utilized for working out the crude oil volume factor and solubility parameters, and convenience and rapidness are achieved.

The invention provides a fluid phase analysis apparatus and a fluid phase analysis method. The fluid phase analysis apparatus includes at least one set of analysis units. Each analysis unit includes a first container, a second container and a sample transfer device. The sample transfer device achieves accurate transfer of a test sample through change of volume of inside space itself and meanwhile tests the changes of relative parameters of the test sample. Macroscopically, the apparatus allows single-phase and double-phase situations of crude oil to be observed directly, and microscopically, allows P-V relationship analysis and flash experiment test to be carried out under different phase conditions. By means of a plurality of fine measurements of volume change, bubble point pressure, gas-oil ratio, formation volume factor and the like stratum parameters of stratum oil are accurately obtained. The apparatus and the method solve a difficult problem of test of basic phase parameters of a micro-scale sample, thereby saving cost in on-site sampling and operations on an oil and gas field.

The invention provides a 3D object ink-jet printing method. The method includes the following steps that a, pixel points are printed one by one in the mode of spraying out ink droplets based on layer printing data of a target object to form a layer printing effect, the standard volume of the ink droplets sprayed out of a printing head is V0, the total volume of the ink droplets required by printing the single pixel points is V, the number of sorts of required forming materials is S, the volume factor F of the pixel points is equal to V / V0, and F is larger than or equal to S; and b, the step a is repeated to form a plurality of layer printing effects, and the multiple layer printing effects are overlaid to form the 3D object. The invention further provides a 3D object ink-jet printing system. The 3D object ink-jet printing system comprises a processing terminal, a driving controller which is provided with a driving voltage generating unit and a driving voltage applying unit and the printer head and is used for executing the printing method. By means of the 3D object ink-jet printing method and system, the printing head cost is reduced, the blocking danger of a printing head nozzle is lowered, the forming speed of the 3D object is increased, manufacturing cost of a printer is reduced, and miniaturization of the printer can be better achieved.

The invention discloses a calculation method and application of river blocking by debris flow and belongs to the technical field of debris flow control engineering. The method includes the steps that a confluent angle theta between tributaries and a mainstream is measured; an average width B1 of the mainstream at the confluent with the tributaries is measured, a flow rate Qm of the mainstream is measured, and a discharge Q1 per unit width of the mainstream is determined; an average width B2 of the tributaries at the confluent with the mainstream is measured, and a flow rate Q of debris flow is measured, and a discharge Q2 per unit width of the tributaries is determined, a discharge ratio epsilon per unit width of the tributaries and the mainstream is determined, the depth h of the mainstream at the confluent with the tributaries is measured, a volume factor yt is determined, a yield stress T1 of debris flow is determined, a density Rho of debris flow is determined, and the yield stress factor x of debris flow is determined. The possibility of river blocking by debris flow can be judged according to the value of factory. The calculating model of river blocking by debris flow has the advantages of dimensional homogeneity, high accuracy in calculation and excellent universality. By means of the calculation method and application, river blocking by debris flow can be accurately judged and debris flow control efficiency can be improved.

A calculation method for determining high-pressure physical parameters of foamy oil is used to characterize the ability of heavy oil to capture gas in reduced pressure production of a foamy oil reservoir and reflect the magnitude of the ability of heavy oil to produce foamy oil. A series of calculation formulas for determining foamy oil dissolved gas-oil ratio, compression coefficient, volume coefficient, density and viscosity in balanced state are formed; high-pressure physical parameters of non-balanced foamy oil under bubble point pressure are determined by establishing function relationship between the high-pressure physical parameters and balance time in balanced state and the high-pressure physical parameters and different static times in non-balanced state; finally, foamy oil dissolved gas-oil ratio, compression coefficient, volume coefficient, density and viscosity under different static times and pressures are determined; therefore, the high-pressure physical parameters of foamy oil in balanced and non-balanced states are determined quickly and accurately. The calculation method according to the invention is significant to the calculation of heavy oil reservoir capacities, the selection of exploiting modes, gathering and transportation design of oil-gas well surface engineering, the formulation of exploitation schemes and the like.

The invention relates to a high-temperature and high-pressure unsteady-state equilibrium condensate oil gas-phase permeability test method. The method comprises the following steps: extracting, cleaning and drying a rock core; testing the maximum condensate oil saturation Som, the corresponding pressure PSom and the balance oil volume coefficient Bop of the constant volume failure; preparing a balanced oil gas sample; transferring the balanced oil gas sample; establishing bound water for the rock core; continuously performing balance oil displacement on the rock core under the pressure PSom and the formation temperature; carrying out balanced gas displacement on the rock core to obtain accumulated oil production O (t) and accumulated gas production G (t) on the ground; converting into accumulated oil production O '(t) and accumulated gas production G' (t) under stratum conditions; and calculating the oil-phase relative permeability Kro, the gas-phase relative permeability Krg and the gas saturation Sge of the outlet end surface of the rock core at each moment. The influence of rock and oil gas fluid under the stratum high-temperature and high-pressure conditions is considered, themeasurement result better conforms to production practice, and a simpler, more convenient, more accurate and more effective relative permeability curve testing method is provided for condensate gas reservoir development.

The invention discloses an online trace oil-water automatic metering system and a measuring method thereof. The system comprises an oil-water separation tube, a drain tube, a liquid inlet tube, a organic glass plate, a total liquid metering device, a flat panel light source, and a digital camera. By calibrating and calculating the volume factor, the digital camera dynamically recognizes the oil and gas interface and the oil-water interface in real time, and calculates the dynamic oil and water volume by measuring the total liquid discharge amount in real time. The invention has simple structure and small volume, and greatly reduces the volume of the core outlet to the identifiable area of the measuring tube -that is, the dead volume; The system can be directly connected to the core outlet,inheriting all the benefits of manual metering, and because of its small size, it can be placed directly in the incubator where the core holder is located, avoiding the thermostat that is separatelyprovided for the metering device, and also reduces the volume.

The invention discloses a method for dividing the formation testing conclusion of a gas well. The method for dividing the formation testing conclusion of the gas well comprises the steps that a relative permeability curve and a log fluid saturation interpretation result are used for quantitatively characterizing the formation testing test-layer conclusion, and the flow partition of the relative permeability curve is finely partitioned to perform effective corresponding with formation testing test-layer conclusion, the formation testing test-layer conclusion is divided into seven layers, the division limit of each layer is quantified by the relationship between the water saturation of the relative permeability curve and the water-gas ratio, and meanwhile the water-gas ratio corresponding toa partition line point is calculated by using the partition line point in the relative permeability curve and a natural gas volume factor of a target stratum. The method for dividing the formation testing conclusion of the gas well considers the gas-water phase state change of the natural gas and the formation water, and combines the relative permeability curve theory and the log fluid saturationinterpretation result to realize the fine and accurate discrimination of the fluid property of a formation testing test-layer.

The invention discloses a method for calculating the critical condition of viscous debris flow river-blocking, and belongs to the technical field of debris flow prevention and treatment engineering. The method comprises the steps of: (a), calculating the per-unit-width flow ratio epsilon of a branch channel to a main river; (b), calculating a volume factor yt; (c), calculating a debris flow yield stress factor x and yield stress; (d), calculating a confluence angle factor as shown in the specification; and (e), judging the river-blocking occurrence probability, wherein when y is less than 0.16, river-blocking cannot occur; when y is greater than or equal to 0.16 and less than 0.3, local river-blocking possibly occurs; when y is greater than or equal to 0.3 and less than 0.46, most river-blocking possibly occurs; and, when y is greater than or equal to 0.46, complete river-blocking possibly occurs. By means of the method disclosed by the invention, in combination with indoor test and field data analysis, the debris flow yield stress and the per-unit-width flow ratio are sufficiently considered; debris flow river-blocking influence factors are nondimensionalized; the method can be suitable for field complex and changeable disaster conditions; the calculation result is accurate; the universality is high; and scientific guidance can be provided for preventing and treating debris flow river-blocking.

When a cylinder block is cast, a bearing housing is constituted by a preform integrally cast with the cylinder block. In order to raise the strength of the bearing housing, a metal matrix composite is formed around the preform. The preform is constituted by a high volume factor member having a relatively high volume factor and two low volume factor members having a relatively low volume factor connected with top and under surfaces of the high volume factor member respectively. The high volume factor member is made of solid metal and the low volume factor member is made of sintered metal filaments. Base material of the cylinder block infiltrates into the low volume factor member to form a metal matrix composite in the preform.

The invention relates to a method for determining the plugging length of a fractured water breakthrough oil well horizontal well and a plugging method, and belongs to the technical field of petroleum and natural gas exploration and development. The determination method comprises the following steps: 1) determining a main water outlet section of the oil well horizontal well; 2) predicting the comprehensive water content and the water drive volume sweep coefficient of the oil reservoir injection-production well group under different plugging schemes; various plugging schemes take the main water outlet section as the center, and the plugging length proportions of the well sections are different; the plugging section of each plugging scheme comprises a main water outlet section; and (3) weighted averaging is conducted on the comprehensive water content and the water flooding wave and volume coefficient of each plugging scheme, evaluation index parameters are obtained, and then the plugging length of the horizontal well of the oil well of the seamed reservoir is determined. The method can achieve the purposes of reducing water and increasing oil, reducing invalid displacement of injected water, guiding a fractured reservoir injection-production well group to carry out water plugging measures, improving the water injection wave and volume of the fractured reservoir and effectively supplementing stratum energy, and finally achieving the purpose of improving the development effect of the fractured reservoir.

The invention relates to a method for quantificationally measuring the stratum water producing rate. The method comprises the following steps that stratum sampling samples and slurry filter liquid samples are collected; the stratum sampling samples comprises crude oil, stratum water and slurry filter liquid, oil type samples and water type samples are obtained after the stratum sampling samples are separated, and the water type samples comprise stratum water and slurry filter liquid; the volume of the obtained oil type samples is the volume of the oil type samples under the ground condition, and the volume of the obtained water type samples is the volume of the water type samples under the ground condition; the volume factor of the oil type samples is obtained, the volume factor of the oil type samples is multiplied by the volume of the oil type samples under the ground condition, and the volume of the oil type samples under the stratum condition can be obtained; the volume of the stratum water in the water type samples is calculated on the basis of the concentration of K<+> in the slurry filter liquid samples and the concentration of K<+> in the water type samples; the volume factor of the stratum layer is obtained, the volume factor of the stratum water is multiplied with the volume of the stratum water in the water type samples, and the volume of the stratum water under the stratum condition is obtained; and the stratum water producing rate is obtained.

The invention provides a method and device for acquiring oil-reservoir geologic reserves with a gravitational differentiation phenomenon, and belongs to the technical field of petroleum exploration and development. The method for acquiring the oil-reservoir geologic reserves with the gravitational differentiation phenomenon comprises the steps that preset parameters of N subregions are obtained, specifically, the preset parameters of the subregions comprise subregion oil-bearing areas, subregion effective thicknesses, subregion effective porosities, subregion oil saturation and subregion crudeoil volume factors; and the crude oil geologic reserves of the volume unit of a preset area are acquired according to the preset parameters of the N subregions, and the preset area is divided into the N subregions, wherein N is an integer greater than or equal to 2. According to the method and device for acquiring the oil-reservoir geologic reserves with the gravitational differentiation phenomenon, the accuracy degree of the crude oil geologic reserves is improved.

The invention relates to a rapid calculation method for the reconstruction volume of a compact oil reservoir volume fractured horizontal well, which comprises the following steps: step 1, collecting production data and calculating required basic parameters, the production data comprising a pressure history and a flow history, wherein the basic parameters comprise the original pressure, the comprehensive compression coefficient, the porosity and the fluid volume coefficient of the stratum; 2, drawing a relation curve of the regularized yield and the material balance time; and 3, calculating the transformation volume by using a depletion flow stage pressure change formula. Linear regression is carried out by utilizing production data in a linear flow stage, and the permeability is determined by combining a linear flow equation. According to the invention, the relation curve is drawn by directly utilizing the existing production dynamic data, the transformation volume is determined in combination with the depletion flow stage pressure change formula, well shut-in and curve fitting are not needed, and the calculation method is simple and rapid.

This engine consists of an inlet one-way valve, an outlet one-way valve, solenoids, a sealed body and a pump cover. Some electromagnetic factors are uniformly arranged in the sealed chamber of the said body and are actuated by electromagnetic force generated by varied electromagnetic fields, which are caused by some controlled power currents are induced into a movable coil and a static coil. The electric energy is directly converted into fluid energy efficiently. The heat generated by the electromagnetic elements is taken away by fluid. The fluid is heated while radiation of the electromagnetic elements is carried out. The engine has good sealing performance and can be used for dangerous fluid with good security and without environment pollution.

The invention discloses a method for analyzing the saturation degree of residual oil, which comprises the following steps of: injecting two inert distribution type tracers into a water injection well in a pulse input manner, sampling in a peripheral production well, and analyzing the accumulated mass of the output of the tracers according to the concentration data of the two tracers in the sample. The statistical law of the communication process is studied according to the mass ratio of tracers accumulatively produced by a production well, the average value of analysis volume factors, the saturation degree of remaining oil and the like. According to the method adopted by the invention, only two inert tracers are injected to determine the relative remaining oil saturation of the communication channel, and a reactive tracer is not needed, so that interference and loss caused by the fact that the reactive tracer is difficult to store and prepare on the ground can be avoided, and the accuracy of an analysis result is improved; by adopting the method, the saturation of the remaining oil can be more economically, quickly and accurately obtained, and an important basis can be provided for secondary oil recovery or tertiary oil recovery.

The invention discloses a crude oil cracking gas reservoir ancient oil reservoir area calculation method and device. The method comprises the steps that the formation temperature and the formation pressure of a crude oil cracking gas reservoir ancient oil reservoir are obtained; obtaining the density of the same type of crude oil in the ancient oil reservoir of the crude oil cracking gas reservoir under the ground standard condition; calculating the volume coefficient of crude oil in the crude oil cracking gas reservoir ancient oil reservoir according to the burial depth of the crude oil cracking gas reservoir ancient oil reservoir; calculating the cracking rate of crude oil in the ancient oil reservoir of the crude oil cracking gas reservoir; obtaining a deviation coefficient of original gas in the ancient oil reservoir of the crude oil cracking gas reservoir; and calculating the area of the ancient oil reservoir of the crude oil cracking gas reservoir according to the formation temperature, the formation pressure, the density of the crude oil under the ground standard condition, the volume coefficient of the crude oil, the cracking rate of the crude oil and the deviation coefficient of the original gas. The method is simple in calculation, high in accuracy and high in practicability.