164 results about "Fluid saturation" patented technology

The invention relates to a computed tomography (CT) scanning heterogeneous model testing system. The system comprises a CT scanning system, a displacement system, an overburden pressure system, a pressure measurement system, a heterogeneous multilayer core clamp holder and a metering system, wherein the heterogeneous multilayer core clamp holder consists of a shell, a rubber cylinder, a core left plug, a core right plug, a left fixing sleeve, a right fixing sleeve, a left fastening sleeve, a right fastening sleeve and a fixed bracket; the core right plug is provided with a plurality of liquid outlets; each liquid outlet is respectively aligned with one layer of core model; and a strip liquid outlet sealing gasket is formed on the core right plug, which correspond to a seam between two adjacent layers of core models, so that liquid flow passing through each layer of core model flows out from the corresponding liquid outlet of each layer of core model, and thus, intraformational heterogeneous water displacing oil layered measurement is realized. By the CT scanning system, the real-time on-line monitoring of the on-way distribution of saturation of fluid on each layer section in a heterosphere is realized so as to observe the interlayer communication phenomenon.

A method for estimating fluid saturation in a formation penetrated by a wellbore from nuclear magnetic resonance measurements made at a plurality of lateral depths into the formation from the wellbore includes estimating a bound water volume, a total porosity and a free water volume at each of the lateral depths from the nuclear magnetic resonance measurements. A minimum water saturation is estimated at each lateral depth from the total porosity, the free water volume and the bound water volume at each lateral depth. A value of water saturation is estimated at each lateral depth from the minimum water saturation at each lateral depth. A relationship between lateral depth and water saturation is determined. Water saturation is estimated at a selected lateral depth greater than the greatest lateral depth of the nuclear magnetic resonance measurements.

The invention relates to a multi-parameter logging method while drilling based on a controllable neutron source, which includes the steps of utilizing a multi-detector measuring system consisting of the D-T controllable neutron source, two thermal neutrons and two gamma detectors, sufficiently utilizing fast neutrons transmitted by the controllable neutron source to militate with atomic nucleuses of formation elements by means of special pulse and measuring timing sequence design, recording gamma energy spectrums, gamma time spectrums and thermal neutron time spectrums at different positions, and performing simultaneous measurement of multiple parameters such as formation density, formation porosity, formation fluid saturation, formation element content and the like with a nuclear logging instrument in a drilling process by means of different spectral resolution and data processing, so that valuation on formation lithology, formation porosity and formation fluid saturation while drilling are realized, the same parameter of the formation porosity and the formation fluid saturation can be measured by various methods, logging interpretation ambiguity is decreased, and accuracy and reliability of logging data interpretation are enhanced.

The invention provides a multi-scale rock physical charting method and device for detecting reservoir hydrocarbon. The method comprises the steps as follows: obtaining a reservoir rock matrix model and a reservoir rock framework model; acquiring a liquid-containing rock model according to the reservoir rock matrix model, the reservoir rock framework model and liquid parameters; obtaining a multi-scale initial reservoir rock physical chart according to the liquid-containing rock model; correcting the initial reservoir rock physical chart under a plurality of frequency bands according to the rock physical experimental data: correcting the initial reservoir rock physical chart under an acoustic logging frequency band based on the logging interpretation result; correcting the initial reservoir rock physical chart based on the seismic interpretation result; and outputting the final reservoir rock physical chart after the correction, so as to carry out inversion of a reservoir rock physical parameter. With the adoption of the method provided by the invention, the precision of the rock physical chart can be increased, and the quantitative inversion of the rock parameter and the saturation of the liquid can be realized.

Method for determining time-dependent changes [73] in the earth vertical and horizontal electrical resistivity and fluid saturations from offshore electromagnetic survey measurements. The method requires both online and offline data, which should include at least one electromagnetic field component sensitive at least predominantly to vertical resistivity and another component sensitive at least predominately to horizontal resistivity [62]. Using a horizontal electric dipole source, online Ez and offline Hz measurements are preferred. For a horizontal magnetic dipole source, online H2 and offline E2 data are preferred. Magnetotelluric data may be substituted for controlled source data sensitive at least predominantly to horizontal resistivity. Maxwell's equations are solved by forward modeling [64,65] or by inversion [66,67], using resistivity models of the subsurface that are either isotropic contrast, and [64,66] or anisotropic [65,67]. Fluid saturation is determined from the vertical and horizontal resistivities using empirical relations or rock physics models [70].

A method including analyzing seismic data relating to a producing hydrocarbon reservoir is disclosed. The seismic data includes first and second sets of seismic data obtained at different times. An interval composed substantially of hard rock is identified in the hydrocarbon reservoir. 4D seismic attributes for the region are calculated. Rock physics relationships are applied to seismic data related to the interval according to the permeability associated therewith. A fluid saturation change or a pressure change of the interval is inferred based on outputs of the first or second sets of rock physics relationships and the calculated 4D attributes for the interval. The inferred fluid saturation change or pressure change of the interval is outputted.

A borehole logging system for determining bulk density, porosity and formation gas/liquid fluid saturation of formation penetrated by a borehole. Measures of fast neutron radiation and inelastic scatter gamma radiation, induced by a pulsed neutron source, are combined with an iterative numerical solution of a two-group diffusion model to obtain the formation parameters of interest. Double-valued ambiguities in prior art measurements are removed by using the iterative solution of the inverted two-group diffusion model. The system requires two gamma ray detectors at different axial spacings from the source, and a single neutron detector axially spaced between the two gamma ray detectors. The system can be embodied as a wireline system or as a logging-while-drilling system.

The present invention relates to a constant gradient field nuclear magnetic resonance (NMR) rock sample analysis method and instrument. The method includes: in a constant gradient magnetic field, performing NMR measurement to acquire data; converting the measured NMR data into a two-dimensional NMR spectrum D-T₂; performing measurement and inversion on a standard sample of a constant gradient field to obtain a standard sample two-dimensional NMR spectrum D-T₂; measuring the sample to acquire a two-dimensional NMR spectrum D-T₂ of a fluid in the sample; identifying fluid types according to the practically measured two-dimensional NMR spectrum D-T₂; computing the fluid property and the petrophysical parameters according to the two-dimensional NMR spectrum D-T₂ of the fluid in the sample; performing single slice scanning on the sample to acquire partial oil and water saturation; performing continuous slice scanning to obtain axial oil and water saturation distribution and movable fluid saturation distribution of the sample.

The invention discloses a reservoir layer evaluation method by utilizing nuclear magnetic resonance logging interpretation parameters, relating to the geology logging interpretation evaluation technology field of petroleum geological exploration; oil saturation So and mobile fluid saturation BVM parameters are chosen, a formula M1=BVM*So is utilized to obtain the M1 parameter which reflects the oil characteristics of the reservoir layer and the total energy; by utilizing the formula SMo=BVM-SMw, the mobile oil saturation SMo parameter is calculated, and then the formula M2=SMO*phi is utilized to obtain the M2 parameter which reflects the recoverable oil volume of the recoverable oil volume, and then the fluid type is determined according to the numeric range of the M1 and M2 values; by adopting the method, different oil grades of the reservoir layer can be effectively and quantitatively divided in a refining way, the undetermined factors of the interpretation parameters caused by block, horizon and oil-containing characteristics are eliminated, and the reservoir layer evaluation method has general applicability to a clastic rock oil-containing bed series.

The invention provides a method for determining the nuclear magnetic resonance T2 cutoff value and the fluid saturation of tight oil, and an apparatus thereof. The method comprises the following steps: determining the carbon content of a sample to be measured to generate a carbon content determination result; determining the lower limit value of the pore throat radius of the sample to be measured according to the carbon content determination result; and determining the corresponding T2 cutoff value according to the lower limit value of the pore throat radius and the core relaxation rate of the sample to be measured. The T2 cutoff value is calculated by using the lower limit value of the pore throat radius of the tight oil movable fluid of the practical sample in the above scheme, and the lower limit value of the pore throat radius of the tight oil movable fluid of the practical sample is determined by adopting a course to fine pore throat carbon content gradual approximation technology, so the T2 cutoff value obtained in the invention is true.

A system and method for modeling fluid effects in a subsurface reservoir combines high quality shear modulus data from modern sonic logs with the inherent stability of VpVs ratio to derive more credible dry frame bulk modulus, in turn leading to improved fluid saturation modeling and improve fluid effect modeling. The system and model are designed primarily for low porosity and mixed lithology subsurface reservoirs although they may also be used with confidence in high porosity reservoirs.

The invention discloses a method for evaluating a reservoir stratum with a nuclear magnetic resonance logging interpretation chart, relating to the technical field of evaluation of petroleum geology exploration geological logging interpretation. The method comprises the steps of: selecting two parameters such as an oil saturation So and a movable fluid saturation BVM; obtaining a parameter M1 with the formulation M1=BVM*So; building Phi-M1 interpretation chart; computing the movable oil saturation Smo parameter with the formulation Smo=BVM-Smw; obtaining a parameter M2 with the formulation M2=Smo*phi; building So-M2 interpretation chart; and visually evaluating the classification of the reservoir stratum liquid with the two interpretation charts. The method can solve the problem for evaluating whether the reservoir stratum can generate liquid and the character of the fluid, can solve the problem for evaluating the oil content of the reservoir stratum and the oil capacity, removes uncertain factors of interpretation parameters caused by factors such as block, stratum position and oil content character, and the like, and has universal applicability in oil-containing bed series of clastic rocks.

A method for designing an absorbent article. The steps of the method are generating a physical spatial map of saturation of a fluid within an absorbent in a physical test environment, generating a virtual spatial map of saturation of a fluid within an absorbent in a virtual test environment, identifying absorbent-fluid interaction properties for the absorbent such that the virtual spatial map of saturation approximates the physical spatial map of saturation, inputting the absorbent-fluid interaction properties into a virtual model of the absorbent article to produce a representation of at least one feature of the absorbent article, evaluating the virtual model of the absorbent article to determine the performance of the at least one feature of the absorbent article, modifying the design of the absorbent article in response to the performance of the at least one feature of the absorbent article determined from the virtual model of the absorbent article.

A method for determining fluid saturation in a formation at a plurality of radial depths near a wellbore, the method including: obtaining multi-frequency nuclear magnetic resonance (NMR) response data for the formation; and processing the data to determine simultaneously the fluid saturation at each radial depth. A computer program product is provided.

The invention provides a reservoir capillary pressure curve determinator under a high temperature and a pressure. The determinator comprises a ring pressure system, an injection system, a core clamping system, a semi-permeable baffle plate, a back pressure system, a measuring system, a data automatically collecting and processing system, and a thermostat which are connected through pipelines. A semi-permeable baffle plate method is adopted to measure capillary pressure curves under a stratum condition, and the basic rationale is that a principle of balance between an impressed pressure and the capillary pressure is used to measure the capillary pressure curves under the high temperature and the pressure. Core saturated wetting phase fluid displaces a wetting phase with a nonwetting phase under a certain displacement pressure. When the impressed pressure overcomes the capillary pressure of a certain capillary in the core, the wetting phase fluid in the capillary is discharged gradually, and the wetting phase fluid saturation in the core is reduced. Pressure is increased stepwise, accumulated discharged quantity of the wetting phase fluid when the wetting phase fluid is no longer discharged and an injection pressure are measured, and the capillary pressure curves can be solved.

The invention provides a three-phase relative permeability testing method based on CT (computed tomography) scanning, the method is applied to a three-phase relative permeability testing system based on CT scanning; the system comprises a CT scanner, a rock core holder, a confining pressure system, a filling system and a return pressure control system, wherein the filling system comprises an oil filling system, a water filling system and a gas filling system which are respectively connected with an inlet end of the rock core holder; the method comprises the following steps: an inlet pressure gauge (7) is arranged at the inlet of the rock core holder (6); an outlet pressure gauge (4) is arranged at the outlet of the rock core holder (6); a confining pressure interface of the rock core holder (6) is connected with the confining pressure system; and the outlet end of the rock core holder (6) is connected with the return pressure control system. The system and the method are used for carrying out CT scanning on a whole three-phase displacement process and acquiring the pressure of the inlet and the outlet throughout the whole process so as to obtain fluid saturation data of the whole process; and the system and the method are visual and accurate in result, simple in structure and convenient to operate.

The invention discloses a method for assessing a classification standard of a tight reservoir pore structure based on nuclear magnetic resonance. The method comprises the following steps of 1, measuring the porosity and permeability of each rock center; 2, measuring the displacement pressure, mid-value pressure, sorting coefficient, pore throat radius and maximum mercury saturability of each rockcenter; 3, analyzing the petrologic feature of each rock center, and the pore throat combination and pore type of the rock center; 4, testing the movable fluid saturation and the movable fluid porosity parameter of each rock center; and 5, based on the abovementioned parameters, dividing the rock centers into I, II and III three types according to the good, middle and bad comprehensive assessmentof reservoirs, and building a classification assessment standard of the three kinds of reservoirs. The invention firstly provides the method for assessing the classification standard of the tight reservoir pore structure based on nuclear magnetic resonance; the reservoir types divided by the method are more accurate and scientific, and the basis is provided for subsequent exploration and development of the tight reservoirs.