49 results about "Hydrogen index" patented technology

The invention discloses a shale organic porosity detection method, and belongs to the technical field of petroleum, geology and mining exploration and development. The shale organic porosity detection method comprises the steps of calculating chemical kinetic parameters of petroleum formation from kerogen, gas formation from kerogen and gas formation from crude oil pyrolysis by utilizing a chemical kinetic method based on the thermal simulation experiment of a shale sample and a crude oil sample with representativeness, and determining the conversion rate of the petroleum formation from kerogen, gas formation from kerogen and gas formation from crude oil pyrolysis of shale at the study layer section by combining with the burial history and thermal history of a target layer; recovering the original hydrogen index and the original organic carbon of shale of the target layer by utilizing residual hydrogen index and data of residual organic carbon of shale of the target layer and combining with the conversion rate of the petroleum formation from kerogen, gas formation from kerogen and gas formation from crude oil pyrolysis; analyzing the organic pore compressibility of shale by utilizing a Ar ion polishing thin sheet of a shale sample of the target layer; calculating the organic porosity of the shale sample of the target layer section. The shale organic porosity detection method has the effects that the organic porosity of the reservoir of shale can be calculated, and the shale organic porosity detection method is high in calculation accuracy, and is easy to operate.

A method and system for evaluation of a hydrocarbon-bearing shale formation employs a data processing system that defines a response model that relates first data representing measured petrophysical properties of the shale formation at a given location to second data representing volume fractions for a particular set of formation components at the given location. The first data includes hydrogen index at the given location, and the particular set of formation components of the second data include a number of mineral components and a number of hydrocarbon-bearing components. The hydrocarbon-bearing components include at least one kerogen component. A computation solver processes the response model along with the first data to solve for the second data. The solved second data representing the volume fraction of the at least one kerogen component is processed to derive at least one ratio that is indicative of kerogen maturity at the given location.

Systems, methods, and devices are provided to determine an accurate neutron-gamma density (NGD) measurement for a broad range of formations, including low-hydrogen-index or low-porosity formations and formations with heavy elements. For example, such an NGD measurement may be obtained by emitting neutrons into a formation such that some of the neutrons inelastically scatter off elements of the formation and generate inelastic gamma rays. The neutrons and inelastic gamma rays that return to the downhole tool may be detected. Some characteristics of certain formations are believed to affect the fast neutron transport of the formations. Thus, if a formation has one or more of such characteristics, a correction may be applied to the count rate of neutrons, the count rate of inelastic gamma rays, or the neutron transport correction function, upon which the neutron-gamma density (NGD) may be determined.

Methods are provided for improving the yield of aromatics during conversion of oxygenate feeds. An oxygenate feed can contain a mixture of oxygenate compounds, including one or more compounds with a hydrogen index of less than 2, so that an effective hydrogen index of the mixture of oxygenates is between about 1.4 and 1.9. Methods are also provided for converting a mixture of oxygenates with an effective hydrogen index greater than about 1 with a pyrolysis oil co-feed. The difficulties in co-processing a pyrolysis oil can be reduced or minimized by staging the introduction of pyrolysis oil into a reaction system. This can allow varying mixtures of pyrolysis oil and methanol, or another oxygenate feed, to be introduced into a reaction system at various feed entry points.

A method of formation evaluation using a pulsed neutron tool. The approach removes the effect of formation hydrogen index (HI) from the nuclear response of the tool. It can be used for gas detection and quantification, as well as for other fluids. It can also be used to improve a formation hydrogen index (HI) measurement.

The present invention relates to a method for exploitation of a sedimentary basin. Exploitation of the sedimentary basin is permitted by the choice of zones of interest within the basin, the zones being determined by means of maps of total organic carbon TOC and of hydrogen index HI of at least one sedimentary layer. According to the invention, the maps of total organic carbon TOC and of hydrogen index HI are obtained taking into account the current values of TOC_A(W) and HI_A(W) at the level of the well and taking into account the maps of bathymetry BM and of sedimentation rate SM.

The invention discloses a tight sandstone anhydrous gas reservoir gas-bearing capacity evaluation method, and solves the technical problem of low tight sandstone anhydrous gas reservoir gas-bearing capacity evaluation precision in the prior art. The method mainly comprises the following steps: sequentially calculating a shale content curve Vsh, an effective porosity curve phi e, a pure rock neutron curve CNL1, an apparent sandstone skeleton hydrogen content index curve CNL2 and a gas content evaluation index parameter GASFG curve, and finally carrying out gas content evaluation according to the gas content evaluation index parameter GASFG curve. According to the method, the excavation effect of the natural gas on the neutron logging curve is fully utilized to quantitatively characterize the gas-bearing index parameters, and the technical problem in the prior art that the tight sandstone anhydrous gas reservoir is difficult to accurately evaluate the gas-bearing property of the reservoir under the condition that stratum water and other data are lacked is effectively solved through classification evaluation. Practice proves that the technology not only can accurately evaluate the gasbearing capacity of the tight sandstone anhydrous gas reservoir, but also can effectively identify the high gamma reservoir, so that an accurate exploration method is provided for oil and gas exploration.

The invention provides a hydrocarbon source rock hydrocarbon expulsion efficiency calculation method and system based on a pyrolysis parameter diagram format. The method comprises the steps: firstly carrying out the pyrolysis and organic carbon analysis of a rock sample, and obtaining a current hydrogen index HI and a maximum pyrolysis peak temperature Tmax; further interpolating and subdividing an organic matter type boundary and a maturity trend line of the classic pyrolysis plate to obtain a subdivided pyrolysis plate; marking a data point consisting of HI and Tmax, and taking an ordinate value corresponding to an intersection point of an organic matter type line passing through the data point and a maturity line of which Ro is 0.2% as an original hydrogen index of the sample; and finally calculating the hydrocarbon expulsion efficiency according to the original hydrogen index. According to the method, the hydrocarbon expulsion efficiency of the hydrocarbon source rock can be simplyand accurately calculated; the original hydrogen index collection is relatively reasonable, and the calculation process is simple. Compared with a manual assignment method, the method has the advantages that the phenomena of negative values and hydrocarbon expulsion efficiency greater than 100% do not occur in the calculation process and result.

The invention discloses an excavation effect quantitative characterization and gas-bearing evaluation method for a compact sandstone low-resistance reservoir, belongs to the technical field of geophysical well logging evaluation, breaks through the difficulty that the excavation effect can only be qualitatively described for a long time, and solves the problems that in the prior art, the gas-bearing property evaluation effect of the compact sandstone low-resistance reservoir is not ideal, and the evaluation precision is difficult to meet the production requirements. The excavation effect quantitative characterization method for the compact sandstone low-resistance reservoir mainly comprises the steps that: the total hydrogen index Hgt of gaseous hydrocarbon is calculated according to gas logging data, and the shale content Vsh, the effective porosity phi e, the water saturation Sw and the total hydrogen index HNH in a stratum are calculated according to logging data; then an excavationeffect index Hex in the stratum is calculated by utilizing the parameters Hgt, Vsh, phi e, Sw and HNH; and then the gas-bearing property of the compact sandstone low-resistance reservoir is evaluatedaccording to Hex. According to the method, qualitative description to quantitative characterization of the excavation effect phenomenon is achieved, the precision and reliability problems of evaluation of the gas-bearing property of the compact sandstone low-resistance reservoir are solved, and a good application effect is achieved in Jinhua-Qiulin block jurassic Shaximiao formation.

The invention relates to a method for computing relative content of CO2 in a formation by using well-log information. The method comprises the following steps: (1) converting a gas volume ratio under the conditions of ground and gas reservoirs: converting relative CO2 content obtained through ground test into relative CO2 content under formation condition; (2) determining an average hydrogen index of gas: computing the average hydrogen index of the gas in pores; (3) correcting water-containing influence on well-logging counting rate: eliminating the influence on the well-logging counting rate caused by formation water, and highlighting the difference of response to CO2 and methane caused by the well-logging counting rate; (4) establishing a quantitative computation model for the relative CO2 content: computing the relative content of the CO2 under the formation condition. According to the method, through establishing a well-logging counting rate value, the average hydrogen index of the gas and the computation model for the CO2 content and predicting the relative content of the CO2 in the formation, the accuracy of the model is relatively high, the practicability is relatively high, and the popularization and application value is relatively good.

The invention provides a method and a device for predicting oil-gas quantity produced by in-situ development of shale oil, and the method comprises the following steps: obtaining an original total organic carbon content TOC value, a vitrinite reflectance Ro value and an original hydrogen index HI value of shale to be measured; obtaining the in-situ development output oil gas quantity of the to-be-measured shale according to the original TOC value, the Ro value and the original HI value of the to-be-measured shale, and a pre-established shale oil in-situ development output oil quantity prediction model and a shale oil in-situ development output gas quantity prediction model. The shale oil in-situ development output oil quantity prediction model and the shale oil in-situ development output gas quantity prediction model are pre-established according to output oil gas quantity data obtained by performing thermal simulation experiments on a plurality of different shale samples and originalTOC values, Ro values and original HI values of the shale samples. According to the technical scheme, quantitative prediction of the oil-gas quantity produced by in-situ development of the shale oil is realized, and the prediction precision and efficiency of the oil-gas quantity produced by in-situ development of the shale oil are improved.

The invention provides a method for quickly identifying a favorable interval of shale oil based on rock pyrolysis parameters. The method comprises the steps of acquiring a shale sample of a shale stratum, and respectively carrying out rock pyrolysis analysis and total organic carbon content measurement; acquiring a first organic geochemical parameter of the shale formation by adopting a rock pyrolysis analysis measurement method; determining the organic matter maturity and the organic matter type of the shale sample according to the highest pyrolysis peak temperature or the highest pyrolysis peak temperature and hydrogen index plate; solving the hydrocarbon expulsion amount; dividing the shale into an E type, an M type and an R type on the basis of the hydrocarbon expulsion amount in the unit mass of the low-maturity-maturity sample; and determining a favorable interval of the shale oil by combining analysis and description of different types of shale. According to the method, a new index for representing the hydrocarbon expulsion amount of the shale is established, the shale oiliness is predicted, and then the favorable interval of shale oil exploration is determined.

The invention provides a high-over mature decayed mud type marine shale original hydrogen index and organic carbon recovery method, which belongs to the technical field of oil and gas geochemistry research, and realizes the high-over mature decayed mud type marine shale original hydrogen index and organic carbon content recovery under the condition of considering the influence of the paleo-productivity and land source input. The method comprises the steps of selecting the high-over mature rotten mud type marine shale in a research area as a target shale sample, determining the content of organic carbon, the content of free hydrocarbon and the content of pyrolytic hydrocarbon at present, and calculating the potential of hydrocarbon generation; determining the total phosphorus content and the aluminum content, and calculating the autogenous organic phosphorus content; selecting a shale sample in an immature-low mature stage in the same layer system as a target shale sample as a referenceshale sample; and obtaining the lowest hydrogen index and the highest hydrogen index of the reference shale sample, and recovering the original hydrogen index and the original organic carbon contentby taking the lowest hydrogen index and the highest hydrogen index as references and utilizing the ratio of the content of the autogenous organic phosphorus to the content of the total phosphorus.

The invention relates to a shale oil saturation determination method and device, electronic equipment and a storage medium, and relates to the technical field of shale oil saturation. The invention discloses the shale oil saturation determination method comprising the following steps: acquiring first signal intensity corresponding to first two-dimensional nuclear magnetic resonance distribution of shale, fourth signal intensity corresponding to second two-dimensional nuclear magnetic resonance distribution of the shale without water, and setting a hydrogen-containing index of formation water and a hydrogen-containing index of an oil sample; and determining the oil saturation of the shale based on the first signal intensity, the fourth signal intensity, the hydrogen-containing index of the set formation water and the hydrogen-containing index of the set oil sample. According to the embodiment of the invention, the oil saturation of shale can be determined.

The invention provides a prediction method and device for physical property parameters of effective hydrocarbon source rock. The method comprises the following steps: acquiring the total organic carbon content, vitrinite reflectivity and hydrogen index of to-be-detected effective hydrocarbon source rocks; establishing an original hydrocarbon generation capability prediction model, and obtaining the original hydrocarbon generation capability of the effective hydrocarbon source rock to be tested by utilizing the original hydrocarbon generation capability prediction model according to the total organic carbon content, the vitrinite reflectivity and the hydrogen index of the effective hydrocarbon source rock to be tested; and establishing an effective hydrocarbon source rock physical property parameter prediction model, and obtaining physical property parameters of the effective hydrocarbon source rock to be measured according to the original hydrocarbon generation capacity of the effective hydrocarbon source rock to be measured and the effective hydrocarbon source rock physical property parameter prediction model, wherein the physical property parameters comprise the oil gas discharge amount and/or the total organic carbon content lower limit value. The method and device provided by the invention can realize quantitative prediction of the oil and gas discharge amount of the effective hydrocarbon source rock and/or quantitative evaluation of the TOC lower limit value of the effective hydrocarbon source rock, and improve the prediction precision and efficiency of oil and gas resources and favorable zones.

The invention discloses a metamorphic rock component logging identification method based on a relative hydrogen-containing index. The method comprises the following steps: constructing a relative hydrogen-containing index curve sensitive to the content of dark minerals by using a neutron and density curve; establishing a quantitative calculation formula of the relative hydrogen-containing index and the total content of the non-long quartz minerals; according to the igneous rock component classification standard, solving the relative hydrogen-containing index limit range corresponding to various component metamorphic rocks through a forward modeling method, calibrating and verifying the rock component limit of various metamorphic rocks through an inversion method, and establishing a metamorphic rock component classification model; and calculating the relative hydrogen-containing index of unknown lithology by using the proposed curve construction method, and performing square wave display according to the established metamorphic rock component classification model to realize semi-quantitative logging identification of the unknown lithology rock components of the metamorphic rock. The method can be used for conveniently and accurately quantitatively calculating the sum of the contents of the non-macromineral in the metamorphic rock, semi-quantitatively identifying the rock components, and providing a reliable basis for subsequent logging comprehensive interpretation, rock naming and the like.