427 results about "Source rock" patented technology

Method for assessing hydrocarbon source rock potential of a subsurface region without well log information. The method uses surface electromagnetic (121) and seismic (122) survey data to obtain vertical profiles of resistivity and velocity (123), which are then analyzed in the same way as well log data are analyzed by the well known DeltaLogR method (124).

Method for predicting physical properties of a source rock formation wherein an inclusion-based (103) mathematical rock physics model (101) is constructed that treats organic matter as solid inclusions, solid background, or both, and relates anisotropic elastic and electric properties of source rock to in-situ rock and fluid properties (102). The model is calibrated with well log data and may be used to forward model calculate effective anisotropic elastic (104.1) and electrical (104.2) properties of the source rock formation, or by inversion (441-442) of sonic and resistivity log data to calculate total organic carbon (423) in terms of a difference (421) between elastic and electrical properties of the source rock.

The present invention discloses a method for overall exploration of a mature exploration area of oil-rich sags, the method including the following steps: building an area-wide seismic sequence framework for a study area based on uniform 3D seismic data of the study area; determining the spatial distribution characteristics of sedimentary reservoirs in the study area by sequence based on the area-wide seismic sequence framework; grading source rocks in the study area by sequence based on the area-wide seismic sequence framework: counting the spatial distribution characteristics of caprocks in the study area; determining a transporting system for the study area based on the unified 3D seismic data of the study area; classifying potential trap areas in the study area based on the spatial distribution characteristics of the sedimentary reservoirs and the spatial distribution characteristics of the caprocks; and deploying the overall exploration of the study area based on the classification of the potential trap areas, grading of the source rocks and the transporting system of the study area.

The invention discloses a hydrocarbon source rock formation pore heat-pressing hydrocarbon-generation simulator and a use method thereof, pertaining to an experimental apparatus for simulating the process of heat-pressing hydrocarbon-generation for hydrocarbon source rocks in the field of geological research on petroleum and natural gas. The simulator is composed of such five parts as a high temperature high pressure reaction unit, a two-way hydraulic automation control unit 301, an automatic hydrocarbon expulsion product collecting and fluid supplementing unit, a data acquisition and automatic control unit, peripheral auxiliary equipment and apparatus casing. The invention can carry out heating and pressurizing closed and open or controllable hydrocarbon generation and expulsion simulated experiments with the reservation of original pores of a hydrocarbon source rock sample 518, within the limited pore spaces and in simultaneous consideration of lithostatic pressure, formation fluid pressure and confining pressure similar to the geological conditions, thereby improving a hydrocarbon source rock hydrocarbon generation and expulsion simulated experimental apparatus so as to provide an effective means for researches on the development of a hydrocarbon generation mechanism, oil-gas migration, oil and gas production quantity in basins as well as oil and gas resource prediction, and thus having wide application prospects.

The invention relates to an exploration method of faulted basin slope oil reservoir distribution and belongs to the field of oil exploration technology. In allusion to the later period of faulted basin exploration, through statistics of related information of source rock, fluid potential, sedimentary rock phase and fault in a target area and according to the principle of source potential conduction, the above information is comprehensively analyzed so as to determine a favorable oil reservoir distribution area in the target area. Forward oil control exploration limitations are broken and are shifted to negative structure and positive structure. Comprehensive analysis is carried out according to an oil source, fluid potential, sedimentary facies distribution and fault occurrence in the area, the slope is evaluated, and a favorable exploration target area is selected.

The invention provides a method for determining the content of organic carbon in hydrocarbon source rock. The method comprises the following steps: S1. experimentally measuring the content of organic carbon of a hydrocarbon source rock core; S2. acquiring the log values of uranium content, resistivity, compensated sonic time difference and compensated density in logging curves at rock core depths; S3. calculating delta lgR according to the log values of S2; S4. establishing the correspondence relation between the content value of organic carbon and the delta IgR as well as uranium log value according to the results of S1 to S3, and fitting into a function; S5. according to the fitted function, determining the content of organic carbon of hydrocarbon source rock at all positions of a log. The invention provides a device embodiment for determining the content of organic carbon in hydrocarbon source rock. According to the method and the device for determining the content of organic carbon in hydrocarbon source rock, the content of organic carbon is determined based on combination of uranium logging curves and delta lgR, the accuracy of the calculation results is high, and the method and the device have obviously practically application effects in the calculation on the content of organic carbon in the hydrocarbon source rock.

The invention provides a simulation experiment device and a simulation experiment method for hot-press hydrocarbon generation and discharge based on the basin evolution history, and belongs to the technical field of petroleum and gas geochemical experiment study. The experiment device comprises a hydrocarbon generation system and a discharged hydrocarbon collecting system which are connected through a multi-channel combined valve (139). The method comprises the steps of dividing different stages of basin evolution according to the construction evolution history of an actual geologic basin, automatically regulating the communicated state of the hydrocarbon generation system and a hydrocarbon discharge device, and simulating the hydrocarbon generation and discharge processes under a basin dynamic evolution condition. According to the invention, the hydrocarbon source rock hydrocarbon generation and discharge simulation experiment approximate to the construction evolution history of the basin containing petroleum and gas is achieved by combining with the construction evolution history of the basin and considering influences of paleo-fluid pressure fields of hydrocarbon source rock and reservoir rock to the generation and discharge of petroleum and gas, which are caused by basin evolution.

An empirical method of measuring water saturation in hydrocarbon bearing formations is described. The system described herein accurately calculates water saturation, formation volume, total organic carbon, and other formation parameters under a variety of formation conditions.

The invention discloses a method for evaluating hydrocarbon potential key parameters of high-quality hydrocarbon-source rock, and belongs to the technical field of oil and gas resource evaluation. The method includes the key steps of firstly, determining an immature and low-mature oil hydrocarbon expelling threshold, a normal hydrocarbon threshold and a normal hydrocarbon expelling threshold of high-quality hydrocarbon-source rock according to geochemistry data of hydrocarbon-source rock; secondly, establishing the hydrocarbon-source rock hydrocarbon amount and a hydrocarbon rate evaluating model; thirdly, establishing the hydrocarbon-source rock hydrocarbon expelling amount and a hydrocarbon expelling evaluating model, and evaluating the target level hydrocarbon-source rock hydrocarbon expelling amount and hydrocarbon expelling rate key parameters; fourthly, establishing a high-quality hydrocarbon-source rock organic carbon recovery coefficient evaluating model, and evaluating a target level hydrocarbon-source rock organic carbon recovery coefficient; fifthly, evaluating a research area target level high-quality hydrocarbon-source rock hydrocarbon potential plane graph, and analyzing the relation between the plane graph and tight oil hydrocarbon contribution. Immature and low-mature stage hydrocarbon potential key parameters of high-quality hydrocarbon-source rock are subjectively and accurately evaluated, and the blank, weakened by people in the past, of immature and low-mature stage hydrocarbon of high-quality hydrocarbon-source rock is filled in.

Elemental analysis of an earth formation is obtained using measurements from a gamma ray logging tool. From the elemental analysis, an estimate of the Calcium, Magnesium and Carbon content of the formation is determined. The amount of organic carbon in the formation is estimated from the total Carbon content and the inorganic carbon associated with minerals in the formation. An indication of source rock may be obtained from the Th/U ratio. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b)

The invention provides a determination method of oil sources of high-maturity condensate oil. The method comprises the following steps: (1) an oil sample undergoes analysis and detection so as to determine whether the oil sample contains a thioadamantane compound; (2) the oil sample containing the thioadamantane compound undergoes enrichment of the thioadamantane compound; and (3) the enriched thioadamantane compound undergoes sulfur isotope testing, and the test result is compared with known sulfur isotope data of source sequence sulfate so as to determine the oil source of the oil sample. By the determination method of oil sources of high-maturity condensate oil, oil sources of condensate oil at high maturity stage are determined by determining the unique factor in condensate oil at high maturity stage. Thus, the blank that oil sources of high-maturity condensate oil cannot be determined in the present petroleum industry is filled up. By determining oil sources of high-maturity condensate oil, major hydrocarbon source rocks can be truly and objectively found and key exploration target series of strata and resources potential are determined.

A low value of Th/U ratio as determined from natural gamma radiation is indicative of deepwater sedimentation. This, together with estimates of total organic carbon from pulsed neutron measurements, is used to characterize source rocks. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understand that it will not be used to interpret or limit the scope or meaning of the claims.

The invention discloses a split-type source rock hydrocarbon generation simulation system and a source rock hydrocarbon generation kettle. The system comprises a plurality of kettles, a plurality of temperature controllers, a computer and at least one pressure pump, wherein each kettle is coupled with one corresponding temperature controller; the plurality of temperature controllers are connected with the computer; the plurality of kettles are connected with the pressure pump through connecting pipelines respectively; the pressure pump is coupled with the computer and used for providing pressure for the kettles; the computer controls the temperature and temperature rise programs of the corresponding kettles through the temperature controllers; each kettle comprises a kettle shell with clamping groove, a kettle cover with clamping groove and a sealing plug; the kettle cover is engaged with the kettle shell; the sealing plug is provided with a sealing conical surface; a sealing member which is matched with the sealing plug is annularly arranged outside the sealing plug; and the side wall of the sealing member is contacted with the inner wall of the kettle shell. The system can simulate the same sample at different temperature points and also simulate different samples at the same temperature point. Meanwhile, the pressure resistance of the kettle is improved, and the research on the influence of the pressure on the hydrocarbon generation is made possible.

A method for estimating a property of an earth formation, the method includes: conveying a carrier through a borehole penetrating the earth formation; performing a measurement of total organic carbon (TOC) within a region of investigation in the earth formation using a logging tool disposed at the carrier; and correlating the measured TOC to the property to estimate the property.

The invention provides a multivariate well logging computing method for the total organic carbon and the hydrocarbon generating potential of hydrocarbon source rocks in salt-lake facies. The method comprises the steps of conducting standardization and normalization on logging curves of different wells, conducting core proper-horizon restoration on hydrocarbon source rock total organic carbon data measured through experiments, classifying the hydrocarbon source rocks in the salt-lake facies, reading logging curve data, obtained after core proper-horizon restoration correction, of total organic carbon experimental points, conducting R-type hierarchical clustering analysis on the logging data and the total organic carbon of the rocks, establishing logging evaluation models of the TOC according to different lithological characters, and conducting computing to obtain TOC data so as to work out rock pyrolysis data. The multivariate well logging computing method for the total organic carbon and the hydrocarbon generating potential of the hydrocarbon source rocks in the salt-lake facies can be used for evaluating the mass and the hydrocarbon generating potential of the hydrocarbon source rocks, of special lithological characters, in the salt-lake facies, and the method can be applied to provide a great number of evaluation data for hydrocarbon source rock evaluation and oil and gas resource quantity evaluation.

The invention discloses a determining method of complex mountain-front effective source rock and a source rock structural model. The method includes the steps of implementing spatial distribution of potential source rock, restoring erosion thickness of different structural unit formations, restoring features of a paleo-geothermal field, determining hydrocarbon conversion type of the source rock by numerical simulation, and determining distribution of the complex mountain-front effective source rock according to the spatial distribution features of the source rock, the hydrocarbon conversion types of the source rocks at different positions of the different structural units and features of abundance of organic matters. Meanwhile, by means of the study based on the method of recovering hydrocarbon conversion of the source rocks in the study area, reliability of resource quantity evaluation is improved, the blank in determining the complex mountain-front effective source rocks is filled, and results help greatly boost the progress of next resource evaluation.

A method for determining content of uranium and organic carbon in uranium-rich hydrocarbon-source rocks comprises steps as follows: firstly, hydrocarbon-source rock core samples obtained through multi-hole drilling coring is acquired in a certain area, a radioactive uranium content value and an organic carbon content value of each hydrocarbon-source rock core are measured through an experiment, logging values of a natural gamma curve and a natural gamma-spectrum curve in logging curves, as well as resistivity, compensating sonic differential time and compensating density of the depth position of each rock core are acquired, a corresponding relation between the uranium content and the natural gamma curve as well as the natural gamma-spectrum curve is established and fitted to form a function, the corresponding relation between the organic carbon content values and related logging curve values is established and fitted to form a function, and the uranium content in each depth position and the hydrocarbon-source rock organic carbon content in each depth position in a well are determined according to the fitted function. Response of the uranium-rich hydrocarbon-source rocks in logging information is sufficiently considered, various logging information is comprehensively utilized to quantify and determine the content of uranium and organic carbon in the uranium-rich hydrocarbon-source rocks, and an obtained result is more accurate.

The invention relates to a method and device for determining the oil and gas accumulation period of a complex superimposed basin. The method comprises the steps that a mode chart showing changes of the hydrocarbon generation potential index of a source rock along with the burial depth is made; the hydrocarbon expulsion threshold and the hydrocarbon expulsion rate of the source rock are determined according to the mode chart showing the changes of the hydrocarbon generation potential index of the source rock along with the burial depth; the hydrocarbon expulsion intensities are determined according to the hydrocarbon expulsion threshold and the hydrocarbon expulsion rate of the source rock; the hydrocarbon expulsion amounts are determined according to the hydrocarbon expulsion intensities; peak periods for discharging oil and gas are determined according to hydrocarbon expulsion amounts of different earth history periods; the planar hydrocarbon expulsion ranges of the source rock are determined according to the distribution areas and the hydrocarbon expulsion intensities of the source rocks at the different peak periods for discharging oil and gas; the oil and gas accumulation period is determined through superposition of the planar hydrocarbon expulsion ranges at the different peak periods for discharging oil and gas. The method and device solve the problem that the oil and gas accumulation period of a basin with oil and gas, especially of the complex superimposed basin, is difficult to determine, lower the risk of oil-gas exploration, indicate the oil-gas exploration direction, and have a wide application range.

The invention provides a quantitative evaluation method for hydrocarbon generation quantity, hydrocarbon expulsion quantity and hydrocarbon retention quantity of source rock. The quantitative evaluation method comprises the following steps that TOC (Total Organic Carbon) of a source rock sample of a research region target layer is acquired; thermal simulation experiments are performed on the source rock sample of the research region target layer; the thermal simulation experiments are a set of semi-opened system simulation experiments of hydrocarbon generation and expulsion with different preset temperatures; the preset temperatures are temperature rising end points of the simulation experiments of the hydrocarbon generation and expulsion; a first parameter at different preset temperature is acquired according to the result of each semi-opened system simulation experiment of the hydrocarbon generation and expulsion; a first model and a second model are built according to the TOC of the source rock sample and the first parameter; the hydrocarbon generation quantity, the hydrocarbon expulsion quantity and the hydrocarbon retention quantity of the source rock are quantitatively evaluated by means of combining the first model and the second model.

The invention discloses a chromatograph on-line analysis method for source rock by closed ball milling, heating analysis and cold trap trapping, which is used for analyzing light fraction compound and percentage composition thereof in the dispersed organic matter of the source rock, and is characterized by comprising the following steps: carrying out vacuum sealing and ball milling on a source rock sample, carrying out ball milling, crushing, then heating to 300DEG C, and carrying out thermal desorption; blowing the pyrolysed hydrocarbon to a liquid helium cold trap by utilizing helium; placing the cold trap into a chromatograph furnace; and trapping, then carrying out chromatograph or Chromatographic-MS on-line analysis to obtain the qualitative data of chromatograph fine separation and/or Chromatographic-MS analysis of the light fraction in the source rock. The separation degree of the sample can approximate to the separation effect of the light dydrocarbon chromatograph separation of crude oil; the invention has good repeatability, reduces the volatilization loss of the light fraction in the crushing process because of the large volume of the sample before being put in a ball milling tank; and the qualitative analysis result can be used for researching the maturity and the environment of sedimentation of the source rock and carrying out oil source comparison.

The invention provides a method for judging a gas source of high-to-over mature natural gas. The method comprises the following steps: testing and analyzing geochemistry characteristics of natural gas, reservoir stratum asphalt and a hydrocarbon source rock, and establishing a natural gas-reservoir stratum asphalt-hydrocarbon source rock factor relation; and judging the gas source of the high-to-over mature natural gas. According to the method for judging the gas source of the high-to-over mature natural gas, the reservoir stratum asphalt is taken as a core entry point and the stored asphalt is used as a bond and a bridge for connecting gas and a source, so that the natural gas-reservoir stratum asphalt-hydrocarbon source rock three-end-member factor relation is established, and the comprehensive judgment of the gas source of the high-to-over mature natural gas is realized; and the situation that a corresponding available application does not exist is solved, and the actual production requirements on comparison of the gas source of the high-to-over mature natural gas, recovery of a complicated reservoir forming process, potential evaluation of high-to-over mature region resources, old marine facies seismic exploration and district selection and the like in superimposed basin deep-layer oil-gas exploration are met.

The invention discloses a GC*GC (comprehensive two-dimensional gas chromatography) method for hydrocarbons in crude oil or sedimentary organic matters. The method is implemented through directly carrying out analysis on crude oil or sedimentary organic matter samples by using GC*GC-FID (GC*GC-flame ionization detection) so as to obtain data of hydrocarbons (saturated hydrocarbons, aromatic hydrocarbons and the like); and by using GC*GC-TOFMS (GC*GC-time-off-flight mass spectrometer) software and methods and comprehensive two-dimensional gas chromatographic hydrocarbon separation characteristic determinations, carrying out calculation on the data so as to obtain the localization parameters of saturated hydrocarbons and aromatic hydrocarbons. The method disclosed by the invention is validated through taking the GC*GC on crude oil and sedimentary organic matter samples in the Saertu Oilfield in Daqing, the fangzheng fault depression of the peripheral basin, and the Hailer-Tamtsag Basin as examples. The GC*GC method for hydrocarbons in crude oil or sedimentary organic matters disclosed by the invention creates a new method for analyzing hydrocarbons in crude oil or sedimentary organic matters, and has important significances in deep understanding of the oil pool forming process, migration, accumulation, preservation, oil and source rock correlation of crude oil and the geochemical researches on oil pools, exploration of new geochemical indicators of crude oil and the exploration and development of crude oil.

The invention provides a method and a device of testing a mercury isotope in an oil gas source. The device comprises at least a set of enrichment absorption system (1) of mercury in crude oil/ hydrocarbon source rocks, an enrichment absorption system (2) of mercury in natural gas and at least a set of secondary purification enrichment system (3) of mercury; the enrichment absorption system (1) ofmercury in crude oil/ hydrocarbon source rocks comprises three air absorption flasks, a pyrolysis/cracking system (12), five hitting flasks and a vacuum pump (14), which are connected sequentially inseries by using pipelines; the enrichment absorption system (2) of mercury in natural gas comprises five sequentially connected hitting flasks; the first hitting flask is connected with the natural gas outlet of the natural gas well; and the last hitting flask is connected with a gas accumulated flow meter (26).

The invention discloses a trap evaluation method for a heterogeneous thin sandstone interbed oil reservoir. The method comprises the steps of (a), carrying out stratum correlation and classification and sedimentation environment research through combination of well logging information, well drilling and logging information, coring information and seismic inversion data, and moreover, obtaining hydrocarbon source rock evolution data through utilization of geochemistry information; (b), obtaining reservoir characteristics through combination of the stratum correlation and classification, sedimentation environment research and the hydrocarbon source rock evolution data; (c), carrying out seismogeology comprehensive calibration, fracture explanation and growth period analysis, tectonic level tracking, tectonic evolution analysis and tectonic trap analysis in sequence according to seismic data; (d), carrying out hydrocarbon accumulation research through combination of the reservoir characteristics according to a tectonic evolution analysis result; and (e), carrying out final favorable trap evaluation. According to the method, the problem that in the prior art, later period reserve volume recalculation and exploratory well deployment work of a heterogeneous interbed old oil field are difficult to develop effectively is solved, and a purpose of providing a heterogeneous trap later period evaluation method for the old oil field is realized.