A method for identifying offshore continental transitional facies source rock type in a few-well area and a device thereof

Abstract

The present application relates to a kind of offshore sea-land transition phase little well area hydrocarbon source rock type identification method and its device, the identification method includes: S1, obtaining required data;S2, according to sporopollen facies analysis data, determine the hydrocarbon source rock division limit value based on sporopollen facies component content;S3, according to the hydrocarbon source rock division limit value based on sporopollen facies component content, determine the limit value of the biosignature compound of hydrocarbon source rock and condensate oil corresponding biosignature compound's source indicating parameter;S4, according to the limit value of the biosignature compound of condensate oil corresponding biosignature compound's source indicating parameter, determine the limit value of natural gas light hydrocarbon parameter;S5, according to natural gas light hydrocarbon parameter plot intersection figure, according to the limit value of natural gas light hydrocarbon parameter, the range corresponding to different types of hydrocarbon source rock is divided.The identification method and its device provided by the present application significantly improve the identification accuracy of offshore sea-land transition phase sedimentary environment little well area hydrocarbon source rock type, solve the problem of little well area sample limitation.

Description

TECHNICAL FIELD

[0001] The present application relates to the field of oil and gas exploration, in particular to a method for identifying source rock types in offshore land-ocean transitional facies and a device thereof. BACKGROUND

[0002] The land-ocean transitional facies is widely developed in the offshore of China, and is rich in oil and gas resources. Under the background of land-ocean transition, various types of sedimentary facies are developed, including delta, tidal flat, lagoon, and shore-shallow sea, etc. The understanding of source rock types and the distribution range of source rocks in the land-ocean transitional facies are of decisive significance for exploration deployment strategy.

[0003] At present, the identification of source rock types mainly uses rock pyrolysis and molecular geochemical indicators. A series of parameters are relatively mature in the application of terrigenous delta facies, lacustrine facies and marine source rocks. Based on the characteristic geochemical parameter values and the corresponding crossplot, different types of source rocks can be identified. However, the common indicators are difficult to distinguish because the sedimentary environment of the land-ocean transitional facies is different from the continental and marine facies. Moreover, the number of offshore drilling is small, and the discovery of oil and gas is the main purpose, so the source rock is limited, and it is difficult to collect enough source rock samples for testing and analysis.

[0004] Therefore, it is a technical problem in the present field to provide a method for identifying source rock types in offshore land-ocean transitional facies with few wells. SUMMARY

[0005] In view of the deficiencies in the prior art, the purpose of the present application is to provide a method for identifying source rock types in offshore land-ocean transitional facies with few wells. Compared with the prior art, the identification method provided by the present application comprehensively utilizes sporopollen facies analysis data, biomarker compound parameters and natural gas light hydrocarbon parameters, significantly improves the identification accuracy of source rock types in offshore land-ocean transitional facies with few wells, and solves the problem of limited samples in few-well areas.

[0006] To achieve the purpose of the present application, the following technical solutions are adopted:

[0007] In a first aspect, the present application provides a method for identifying source rock types in offshore land-ocean transitional facies with few wells, which comprises the following steps:

[0008] S1, obtaining sporopollen facies analysis data of source rocks, saturated hydrocarbon chromatography-mass spectrometry data of source rocks, saturated hydrocarbon chromatography-mass spectrometry data of condensate oil, and natural gas light hydrocarbon chromatography data in the study area;

[0009] S2, determining the source rock division limit value based on the sporopollen facies component content according to the sporopollen facies analysis data in step S1;

[0010] S3, determining the limit value of the biogenic indicator parameter of the biomarker compound corresponding to the condensate oil according to the limit value of the source rock based on the content of the sporopollen facies component in step S2;

[0011] S4, determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biogenic indicator parameter of the biomarker compound corresponding to the condensate oil in step S3;

[0012] S5, drawing an intersection diagram according to the natural gas light hydrocarbon parameter, and dividing the range corresponding to different types of source rocks according to the limit value of the natural gas light hydrocarbon parameter in step S4.

[0013] In the identification method provided by the present application, two types of source rocks, i.e., delta-swamp and tidal flat-lagoon, are divided according to the source rock sporopollen facies analysis data of the drilled well area, the limit value of the biogenic indicator parameter of the biomarker compound of the two types of source rocks is established on this basis, the limit value of the natural gas light hydrocarbon parameter is determined through the biogenic indicator parameter of the biomarker compound of the condensate oil, and finally the division range of the source rock type is obtained through the natural gas light hydrocarbon intersection diagram of the drilled well.

[0014] In the present application, the biogenic indicator parameter of the biomarker compound is mainly used to indicate the source and environment of organic matter.

[0015] Preferably, the source rock sporopollen facies analysis data in step S1 includes existing sporopollen facies data of the study area and / or sporopollen facies data collected from the source rock sample.

[0016] Preferably, the method for obtaining the sporopollen facies data collected from the source rock sample includes: obtaining sporopollen organic matter through acid treatment of the source rock sample, and obtaining sporopollen organic matter data through transmission light and fluorescence analysis under a microscope.

[0017] In the present application, the method for acid treatment is a conventional method in the field, for example, hydrochloric acid and hydrofluoric acid are used in sequence for treatment.

[0018] Preferably, the source rock saturated hydrocarbon chromatography-mass spectrometry data in step S1 includes existing source rock saturated hydrocarbon chromatography-mass spectrometry data of the study area and / or saturated hydrocarbon chromatography-mass spectrometry data collected from the source rock sample.

[0019] Preferably, the method for obtaining the saturated hydrocarbon chromatography-mass spectrometry data collected from the source rock sample includes: sequentially performing extraction and component separation on the source rock sample to obtain saturated hydrocarbons, and performing chromatography-mass spectrometry analysis on the saturated hydrocarbons.

[0020] Preferably, the condensate oil saturated hydrocarbon chromatography-mass spectrometry data includes existing condensate oil saturated hydrocarbon chromatography-mass spectrometry data of the study area and / or saturated hydrocarbon chromatography-mass spectrometry data collected from the condensate oil sample.

[0021] Preferably, the method for obtaining the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil sample comprises: separating components of the condensate oil sample to obtain saturated hydrocarbons, and performing chromatography-mass spectrometry analysis on the saturated hydrocarbons.

[0022] Preferably, the natural gas light hydrocarbon chromatography data in step S1 comprises existing natural gas light hydrocarbon chromatography data of the study area and / or light hydrocarbon chromatography data of the natural gas sample.

[0023] Preferably, the method for determining the division limit value of the source rock in step S2 comprises: determining types of each sporopollen component and content proportions of the sporopollen components in different types of source rocks according to sporopollen facies analysis data, comparing the content proportion data, and determining the division limit value of the source rock based on the content of the sporopollen component.

[0024] Preferably, the types of the sporopollen component include any one or a combination of at least two of coal component, wood component, grass component, or amorphous component.

[0025] Preferably, the method for obtaining the biosignature indicator parameter of the source rock corresponding biological marker compound in step S3 comprises: obtaining the biosignature indicator parameter by using integral area calculation of the biological marker compound according to saturated hydrocarbon chromatography-mass spectrometry data of the source rock.

[0026] Preferably, the biosignature indicator parameter of the source rock corresponding biological marker compound includes any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane.

[0027] Preferably, the method for obtaining the biosignature indicator parameter of the condensate oil corresponding biological marker compound comprises: obtaining the biosignature indicator parameter by using integral area calculation of the biological marker compound according to saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil.

[0028] Preferably, the biosignature indicator parameter of the condensate oil corresponding biological marker compound includes any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane.

[0029] In the present application, the sterane C27 / C29, Pr / Ph, Ts / Tm or gammacerane / C30 hopane are all the conventional biosignature compounds in the field, and specifically, the sterane C27 / C29 refers to the ratio of the content of 5α(H), 14α(H), 17α(H)-C27(20R) sterane and 24-ethyl-5α(H), 14α(H), 17α(H)-C29 sterane (20R) compounds in the chromatography-mass spectrometry data of condensate oil with mass ratio 217; Pr / Ph refers to the ratio of the content of pristane and phytane compounds in the saturated hydrocarbon chromatogram; Ts / Tm refers to the ratio of the content of 18α(H)-22, 29, 30-trisnorhopane and 17α(H)-22, 29, 30-trisnorhopane compounds in the chromatography-mass spectrometry data of condensate oil with mass ratio 191; gammacerane / C30 hopane refers to the ratio of the content of gammacerane and 17α(H), 21β(H)-C30 hopane compounds in the chromatography-mass spectrometry data of condensate oil with mass ratio 191.

[0030] Preferably, the method for determining the limit value of the biosignature parameter in step S3 comprises: drawing an intersection diagram according to the content of the sporopollen facies component and the biosignature parameter, and determining the limit value of the biosignature parameter of the biomarker corresponding to the hydrocarbon source rock according to the limit value of the hydrocarbon source rock classification based on the content of the sporopollen facies component, and the limit value of the biosignature parameter of the biomarker corresponding to the condensate oil is consistent with the limit value of the biosignature parameter of the biomarker corresponding to the hydrocarbon source rock.

[0031] In the present application, the main idea of determining the limit value of the biosignature parameter is that the type of the hydrocarbon source rock is determined by the organic matter, and the organic matter is directly composed of the sedimentary organic matter formed by the biological organic matter under the geological action, the content of the sporopollen facies component is the most intuitive parameter for indicating the composition of the biological organic matter, and the biosignature parameter determined by the relationship between the sporopollen facies component and the biomarker parameter can avoid the ambiguity of the empirical biosignature parameter, and the biosignature parameter of the hydrocarbon source rock and the condensate oil formed by the hydrocarbon source rock can more accurately indicate the type of the hydrocarbon source rock.

[0032] Preferably, the method for obtaining the natural gas light hydrocarbon parameter in step S4 comprises: calculating the integral area of the typical compounds to obtain the natural gas light hydrocarbon parameter, and the typical compounds include methylcyclohexane, toluene and benzene.

[0033] Preferably, the natural gas light hydrocarbon parameter comprises a methylcyclohexane index and a toluene / benzene.

[0034] In the present application, the methylcyclohexane index and toluene / benzene are both conventional natural gas light hydrocarbon parameters in the field, specifically, the methylcyclohexane index refers to the content ratio of methylcyclohexane / (methylcyclohexane+dimethylcyclopentane+normal heptane) in the natural gas light hydrocarbon chromatogram, and multiplied by 100%; toluene / benzene refers to the content ratio of toluene and benzene compounds in the natural gas light hydrocarbon chromatogram.

[0035] Preferably, the method for determining the limit value of the natural gas light hydrocarbon parameter comprises: drawing an intersection diagram according to the biogenic indicator parameters and the natural gas light hydrocarbon parameters of the corresponding biomarker compounds of the condensate oil, and determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biogenic indicator parameters of the corresponding biomarker compounds of the condensate oil.

[0036] In the present application, the main idea of determining the limit value of the natural gas light hydrocarbon parameter is that the natural gas and its associated condensate oil are generated at the condensate oil-gas-wet gas stage of the hydrocarbon source rock, and are the same hydrocarbon-forming parent material, based on this homology, the relationship between the condensate oil and the natural gas light hydrocarbon can determine the limit value of the natural gas light hydrocarbon parameter.

[0037] Preferably, the identification method further comprises a step S6: determining the type of the hydrocarbon source rock of the well to be measured according to the position of the natural gas light hydrocarbon parameter of the well to be measured in the intersection diagram in step S5.

[0038] In a second aspect, the present application provides a device for identifying the type of the hydrocarbon source rock in the offshore land-ocean transition phase and the few-well area, which is used for the method for identifying the type of the hydrocarbon source rock in the offshore land-ocean transition phase and the few-well area according to the first aspect of the present application, and the device comprises:

[0039] The acquisition module is used for acquiring the sporopollen facies analysis data, the saturated hydrocarbon chromatography-mass spectrometry data of the hydrocarbon source rock, the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil, and the natural gas light hydrocarbon chromatography data in the research area;

[0040] The sporopollen facies component content calculation module is used for determining the hydrocarbon source rock division limit value based on the sporopollen facies component content according to the sporopollen facies analysis data;

[0041] The biogenic indicator parameter calculation module is used for determining the limit value of the biogenic indicator parameter of the corresponding biomarker compounds of the hydrocarbon source rock and the condensate oil according to the hydrocarbon source rock division limit value based on the sporopollen facies component content;

[0042] The natural gas light hydrocarbon parameter calculation module is used for determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biogenic indicator parameter of the corresponding biomarker compounds of the condensate oil;

[0043] The hydrocarbon source rock intersection diagram division module is used for drawing an intersection diagram according to the natural gas light hydrocarbon parameter, and dividing the ranges corresponding to different types of hydrocarbon source rocks according to the limit value of the natural gas light hydrocarbon parameter.

[0044] Preferably, the identification device further comprises an identification module for determining the type of source rock of the well to be tested according to the position of the light hydrocarbon parameters of the natural gas of the well to be tested in the crossplot.

[0045] Compared with the prior art, the present application has the following beneficial effects:

[0046] In the identification method provided by the present application, the limit values of the biosignature compound of different types of source rock and the limit values of the light hydrocarbon parameters of natural gas are determined through the biosignature compound of the sporopollen phase of the source rock, the saturated hydrocarbon of the source rock and the saturated hydrocarbon of the condensate oil, the crossplot of the light hydrocarbon parameters of natural gas is drawn, the range corresponding to different types of source rock is divided according to the limit values of the light hydrocarbon parameters of natural gas, and key information is provided for the evaluation of the source rock of the oil and gas bearing basin and the calculation of the oil and gas resource quantity, which significantly improves the identification accuracy of the source rock type in the offshore sea-land transitional facies sedimentary environment with few wells and solves the problem of limited samples in the few well areas. BRIEF DESCRIPTION OF DRAWINGS

[0047] Figure 1 is a flowchart of the identification method provided by the present application embodiment 1 and embodiment 2;

[0048] Figure 2 is a diagram of the type and content of the sporopollen phase component of the source rock in the present application embodiment 2;

[0049] Figure 3 is the chromatography-mass spectrometry data of the tidal flat-lagoon source rock in the present application embodiment 2, wherein (a) is the chromatography-mass spectrometry data of the compound with a mass-to-charge ratio of 217, and (b) is the chromatography-mass spectrometry data of the compound with a mass-to-charge ratio of 191;

[0050] Figure 4 is the chromatography-mass spectrometry data of the delta-swamp source rock in the present application embodiment 2, wherein (a) is the chromatography-mass spectrometry data of the compound with a mass-to-charge ratio of 217, and (b) is the chromatography-mass spectrometry data of the compound with a mass-to-charge ratio of 191;

[0051] Figure 5 is the crossplot of the content of the coal component and the biosignature parameter sterane C27 / C29 in the present application embodiment 2;

[0052] Figure 6 is the crossplot of the content of the coal component and the biosignature parameter gammacerane / C30 hopane in the present application embodiment 2;

[0053] Figure 7 is the crossplot of the sterane C27 / C29 and the methylcyclohexane index in the present application embodiment 2;

[0054] Figure 8 is the crossplot of the sterane C27 / C29 and the toluene / benzene in the present application embodiment 2;

[0055] Figure 9 is a cross plot of natural gas light hydrocarbon parameters in embodiment 2 of the present application;

[0056] Figure 10 is a structural schematic diagram of the identification device provided in embodiment 3 of the present application. DETAILED DESCRIPTION

[0057] The technical solutions of the present application will be further described below through specific embodiments. Those skilled in the art should understand that the embodiments are only used to help understand the present application and should not be regarded as specific limitations on the present application.

[0058] Embodiment 1

[0059] The present embodiment provides a method for identifying source rock types in a nearshore paralic facies and a few well areas, which comprehensively utilizes sporopollen facies analysis data, biomarker compound parameters and natural gas light hydrocarbon parameters to identify source rock types in a nearshore paralic facies and a few well areas. The identification method can be performed by an identification device for source rock types in a nearshore paralic facies and a few well areas, which can be realized in the form of hardware and / or software.

[0060] As shown in Figure 1 The identification method provided by the present embodiment includes:

[0061] S1, obtaining sporopollen facies analysis data of source rock, saturated hydrocarbon chromatography-mass spectrometry data of source rock, saturated hydrocarbon chromatography-mass spectrometry data of condensate oil and light hydrocarbon chromatography data in the study area;

[0062] In step S1, the sporopollen facies analysis data of source rock includes existing sporopollen facies data in the study area and / or sporopollen facies data collected from source rock samples. The method for obtaining the sporopollen facies data collected from source rock samples includes: obtaining sporopollen organic matter by acid treatment of source rock samples, and obtaining sporopollen organic matter data by transmission light and fluorescence analysis under a microscope;

[0063] In step S1, the saturated hydrocarbon chromatography-mass spectrometry data of source rock includes existing saturated hydrocarbon chromatography-mass spectrometry data of source rock in the study area and / or saturated hydrocarbon chromatography-mass spectrometry data collected from source rock samples. The method for obtaining the saturated hydrocarbon chromatography-mass spectrometry data collected from source rock samples includes: sequentially extracting and separating components from source rock samples to obtain saturated hydrocarbons, and performing chromatography-mass spectrometry analysis on the saturated hydrocarbons;

[0064] In step S1, the condensate saturated hydrocarbon chromatogram-mass spectrum data includes existing condensate saturated hydrocarbon chromatogram-mass spectrum data of the study area and / or condensate sample collected saturated hydrocarbon chromatogram-mass spectrum data, and the method for obtaining the condensate sample collected saturated hydrocarbon chromatogram-mass spectrum data includes: separating components of the condensate sample to obtain saturated hydrocarbons, and performing chromatogram-mass spectrum analysis on the saturated hydrocarbons;

[0065] In step S1, the natural gas light hydrocarbon chromatogram data includes existing natural gas light hydrocarbon chromatogram data of the study area and / or natural gas sample collected light hydrocarbon chromatogram data.

[0066] S2, determining a source rock division limit value based on the content of the sporopollen facies components according to the sporopollen facies analysis data of step S1;

[0067] In step S2, the method for determining the source rock division limit value includes: determining the types of the sporopollen facies components and the content proportion of each sporopollen facies component in different types of source rocks according to the sporopollen facies analysis data, comparing the content proportion data, and determining the source rock division limit value based on the content of the sporopollen facies components;

[0068] Specifically, the types of the sporopollen facies components include any one or a combination of at least two of coal components, wood components, grass components, or amorphous components.

[0069] S3, determining a limit value of a biosignature parameter of a biomarker corresponding to the condensate oil and the source rock according to the source rock division limit value based on the content of the sporopollen facies components of step S2;

[0070] In step S3, the method for obtaining the biosignature parameter of the biomarker corresponding to the source rock includes: calculating the biosignature parameter of the biomarker by using integral areas of the biomarker according to source rock saturated hydrocarbon chromatogram-mass spectrum data;

[0071] Specifically, the biosignature parameter of the biomarker corresponding to the source rock includes any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane.

[0072] In step S3, the method for obtaining the biosignature parameter of the biomarker corresponding to the condensate oil includes: calculating the biosignature parameter of the biomarker by using integral areas of the biomarker according to condensate saturated hydrocarbon chromatogram-mass spectrum data;

[0073] Specifically, the biosignature parameter of the biomarker corresponding to the condensate oil includes any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane.

[0074] In step S3, the method for determining the limit value of the biosignature compound biogenic indicator parameter comprises: drawing an intersection diagram according to the sporopollen facies component content and the biosignature compound biogenic indicator parameter, determining the limit value of the biosignature compound biogenic indicator parameter corresponding to the hydrocarbon source rock according to the limit value of the hydrocarbon source rock classification based on the sporopollen facies component content, and the limit value of the biosignature compound biogenic indicator parameter corresponding to the condensate oil is consistent with the limit value of the biosignature compound biogenic indicator parameter corresponding to the hydrocarbon source rock.

[0075] S4, determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biosignature compound biogenic indicator parameter of the condensate oil in step S3;

[0076] In step S4, the method for obtaining the natural gas light hydrocarbon parameter comprises: calculating the integral area of the typical compound to obtain the natural gas light hydrocarbon parameter according to the natural gas light hydrocarbon chromatographic data, wherein the typical compound includes methylcyclohexane, toluene and benzene.

[0077] Specifically, the natural gas light hydrocarbon parameter includes a methylcyclohexane index and a toluene / benzene ratio.

[0078] In step S4, the method for determining the limit value of the natural gas light hydrocarbon parameter comprises: drawing an intersection diagram according to the biosignature compound biogenic indicator parameter corresponding to the condensate oil and the natural gas light hydrocarbon parameter, and determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biosignature compound biogenic indicator parameter corresponding to the condensate oil.

[0079] S5, drawing an intersection diagram according to the natural gas light hydrocarbon parameter, and dividing the ranges corresponding to different types of hydrocarbon source rocks according to the limit value of the natural gas light hydrocarbon parameter in step S4.

[0080] S6, determining the type of the hydrocarbon source rock of the well to be tested according to the position of the natural gas light hydrocarbon parameter of the well to be tested in the intersection diagram in step S5.

[0081] Embodiment 2

[0082] This embodiment takes the XH sag of the East China Sea Basin where the marine-terrestrial transitional facies hydrocarbon source rock is widely distributed as an example to identify the type of the hydrocarbon source rock therein, so as to further explain the composition of the specific technical solution.

[0083] As shown in Figure 1 The prediction method provided by the embodiment comprises:

[0084] S1, obtaining sporopollen facies analysis data of the hydrocarbon source rock, saturated hydrocarbon chromatography-mass spectrometry data of the hydrocarbon source rock, saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil and natural gas light hydrocarbon chromatography data in the study area;

[0085] In the embodiment, the hydrocarbon source rock sporopollen facies analysis data includes existing sporopollen facies analysis data of the study area, and sporopollen organic matter is obtained by treating hydrocarbon source rock samples with hydrochloric acid, hydrofluoric acid and the like, and the sporopollen organic matter data is obtained by classification and identification under a microscope through transmitted light and fluorescence. Specifically, sporopollen facies analysis data of 30 hydrocarbon source rock samples of wells such as XH-3 is collected and supplemented in the embodiment, and sample wells cover the slope zone with more drilling to the depression zone with less drilling.

[0086] In the embodiment, the hydrocarbon source rock saturated hydrocarbon chromatography-mass spectrometry data includes existing hydrocarbon source rock saturated hydrocarbon chromatography-mass spectrometry data of the study area, and data obtained by chromatography-mass spectrometry analysis after saturated hydrocarbons are obtained by sequentially extracting and separating components of hydrocarbon source rock samples. Specifically, saturated hydrocarbon chromatography-mass spectrometry data of 30 hydrocarbon source rock samples of wells such as XH-3 is collected and supplemented in the embodiment, and sample wells cover the main hydrocarbon generation intervals of the XH sag.

[0087] In the embodiment, the condensate saturated hydrocarbon chromatography-mass spectrometry data includes existing condensate saturated hydrocarbon chromatography-mass spectrometry data of the study area, and data obtained by chromatography-mass spectrometry analysis after saturated hydrocarbons are obtained by separating components of condensate samples. Specifically, saturated hydrocarbon chromatography-mass spectrometry data of 15 condensate samples of wells such as XH-7 is collected and supplemented in the embodiment, and sample wells cover the main structures and intervals of discovered oil and gas in the XH sag.

[0088] In the embodiment, the natural gas light hydrocarbon chromatography data includes existing natural gas light hydrocarbon chromatography data of the study area, and data obtained by light hydrocarbon chromatography analysis of collected natural gas samples. Specifically, light hydrocarbon chromatography data of 24 natural gas samples of wells such as XH-1 is collected and supplemented in the embodiment, and sample wells cover the main structures and intervals of discovered natural gas in the XH sag.

[0089] S2, determining a hydrocarbon source rock division limit value based on sporopollen facies component content according to the sporopollen facies analysis data of step S1;

[0090] In the embodiment, the content of each component such as coal component, wood component, grass component and amorphous component in the slope zone and near-depression zone is respectively counted according to the sporopollen facies analysis data, the content ratio data is compared, and the hydrocarbon source rock division limit value based on the sporopollen facies component content is determined. Specifically, taking the slope zone hydrocarbon source rock (specifically delta-swamp in the embodiment) as an example, the content of coal component is more than 60%, and 60% is the hydrocarbon source rock division limit value based on the content of coal component (the same below), and the contents of grass component and amorphous component are less than 30%. Taking the near-depression zone hydrocarbon source rock as an example (specifically tidal flat-lagoon in the embodiment), the content of coal component is less than 60%, and the contents of grass component and amorphous component are more than 30%, as shown in FIG. 1. Figure 2

[0091] ​S3, determining the limit value of the biosignature indicator parameter of the biomarker corresponding to the condensate oil according to the limit value of the source rock classification based on the content of the sporopollen facies component;

[0092] In this embodiment, the biosignature indicator parameters of the biomarker are calculated according to the saturated hydrocarbon chromatography-mass spectrometry data of the source rock by using the integral area of the biomarker, including the sterane C27 / C29, Pr / Ph, Ts / Tm and gammacerane / C30 hopane; as shown in Figure 3 and Figure 4 as shown in Figure 3 (a) and Figure 4 (a) is the chromatography-mass spectrometry data of the compound with mass-to-charge ratio 217, which is used to calculate the sterane C27 / C29, Figure 3 (b) and Figure 4 (b) is the chromatography-mass spectrometry data of the compound with mass-to-charge ratio 191, which is used to calculate the Ts / Tm;

[0093] In this embodiment, the biosignature indicator parameters of the biomarker are calculated according to the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil by using the integral area of the biomarker, including the sterane C27 / C29, Pr / Ph, Ts / Tm and gammacerane / C30 hopane;

[0094] In this embodiment, the intersection diagram is drawn according to the content of the sporopollen facies component and the biosignature indicator parameter of the biomarker of the ramp zone and the near-depression zone, the limit value of the biosignature indicator parameter of the biomarker corresponding to the source rock is determined according to the limit value of the source rock classification based on the content of the sporopollen facies component, and the limit value of the biosignature indicator parameter of the biomarker corresponding to the condensate oil is consistent with the limit value of the biosignature indicator parameter of the biomarker corresponding to the source rock; specifically, in this embodiment, the limit value of the sterane C27 / C29 of the ramp zone and the near-depression zone is 1.2, the limit value of Pr / Ph is 3.0, the limit value of Ts / Tm is 0.6, and the limit value of gammacerane / C30 hopane is 0.2; taking the determination of the limit value of the biosignature indicator parameter such as the sterane C27 / C29 and the gammacerane / C30 hopane as an example, as shown in Figures 5-6 the limit value of the sterane C27 / C29 ( Figure 5 ) and the limit value of the gammacerane / C30 hopane ( Figure 6 ) are determined according to the limit value of the coal component content of the source rock.

[0095] S4, determining the limit value of the natural gas light hydrocarbon parameter according to the limit value of the biomarker corresponding to the condensate oil according to the limit value of the biomarker corresponding to the condensate oil according to the limit value of the source rock classification based on the content of the sporopollen facies component;

[0096] In this embodiment, according to the natural gas light hydrocarbon chromatographic data, the integral area of the typical compound is used to calculate the natural gas light hydrocarbon parameters, methylcyclohexane index and toluene / benzene, the crossplot is drawn according to the biosignature parameters of the condensate oil corresponding biomarker compounds and the natural gas light hydrocarbon parameters, and the limit value of the natural gas light hydrocarbon parameters is determined according to the limit value of the biosignature parameters of the condensate oil corresponding biomarker compounds; specifically, as shown in Figure 7 and Figure 8 In this embodiment, the limit value of the methylcyclohexane index of the ramp zone and the mid-sag is calculated to be 60 Figure 7 , and the limit value of the toluene / benzene parameter is calculated to be 3.0 Figure 8 .

[0097] S5, the crossplot is drawn according to the natural gas light hydrocarbon parameters, as shown in Figure 9 , the range corresponding to different types of source rocks is divided according to the limit value of the natural gas light hydrocarbon parameters in step S4.

[0098] S6, the type of the source rock of the well to be measured is determined according to the position of the natural gas light hydrocarbon parameters of the well to be measured in the crossplot in step S5.

[0099] In this embodiment, it can be seen from Figure 9 that the limit value of the natural gas light hydrocarbon parameters calculated by the foregoing method divides the crossplot area, and the delta-swamp-method data and the tidal flat-lagoon-method data in the figure refer to the natural gas light hydrocarbon parameter data used in the foregoing step S4 and step S5, and the delta-swamp-division result and the tidal flat-lagoon-division result refer to the natural gas light hydrocarbon parameter data of the well to be measured, the method data indicates that the type of the source rock at the lower left corner is a delta-swamp type source rock, and the type of the source rock at the upper right corner is a tidal flat-lagoon type source rock, and the type of the source rock of the well to be measured is determined according to the parameters of the well to be measured.

[0100] Embodiment 3

[0101] This embodiment provides a device for identifying the type of source rock in a nearshore sea-land transitional facies and a few well area, as shown in Figure 10 , the device comprises an acquisition module 110, a sporopollen facies component content calculation module 120, a biosignature parameter calculation module 130, a natural gas light hydrocarbon parameter calculation module 140, a source rock crossplot division module 150, and an identification module 160. Wherein:

[0102] The acquisition module 110 is used to acquire the sporopollen facies analysis data of the source rock in the study area, the saturated hydrocarbon chromatography-mass spectrometry data of the source rock, the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil, and the natural gas light hydrocarbon chromatographic data;

[0103] The sporopollen facies component content calculation module 120 is configured to determine a hydrocarbon source rock division limit value based on sporopollen facies component content according to sporopollen facies analysis data.

[0104] The biogenic indicator parameter calculation module 130 is configured to determine a biogenic indicator parameter limit value of a biomarker corresponding to condensate oil of a hydrocarbon source rock according to the hydrocarbon source rock division limit value based on sporopollen facies component content.

[0105] The natural gas light hydrocarbon parameter calculation module 140 is configured to determine a natural gas light hydrocarbon parameter limit value according to the biogenic indicator parameter limit value of the biomarker corresponding to the condensate oil.

[0106] The hydrocarbon source rock crossplot division module 150 is configured to draw a crossplot according to the natural gas light hydrocarbon parameter, and divide ranges corresponding to different types of hydrocarbon source rocks according to the natural gas light hydrocarbon parameter limit value.

[0107] The identification module 160 is configured to determine the type of hydrocarbon source rock of the well to be tested according to the position of the natural gas light hydrocarbon parameter of the well to be tested in the crossplot.

[0108] In the acquisition module 110, the sporopollen facies analysis data of the hydrocarbon source rock, the saturated hydrocarbon chromatography-mass spectrometry data of the hydrocarbon source rock, the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil, and the natural gas light hydrocarbon chromatography data each independently include existing data and sample collection data of the study area.

[0109] In the sporopollen facies component content calculation module 120, the type and content proportion of each sporopollen facies component in different types of hydrocarbon source rocks are determined according to the sporopollen facies analysis data, the content proportion data is compared, and the hydrocarbon source rock division limit value based on the sporopollen facies component content is determined. The type of the sporopollen facies component includes any one or a combination of at least two of coal component, wood component, grass component, or amorphous component.

[0110] In the biogenic indicator parameter calculation module 130, the biogenic indicator parameter is calculated by using the integral area of the biomarker according to the saturated hydrocarbon chromatography-mass spectrometry data of the hydrocarbon source rock, and the biogenic indicator parameter is calculated by using the integral area of the biomarker according to the saturated hydrocarbon chromatography-mass spectrometry data of the condensate oil. The biogenic indicator parameter includes any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane. The crossplot is drawn according to the sporopollen facies component content and the biogenic indicator parameter, and the biogenic indicator parameter limit value of the biomarker corresponding to the hydrocarbon source rock is determined according to the hydrocarbon source rock division limit value based on the sporopollen facies component content. The biogenic indicator parameter limit value of the biomarker corresponding to the condensate oil is consistent with the biogenic indicator parameter limit value of the biomarker corresponding to the hydrocarbon source rock.

[0111] In the natural gas light hydrocarbon parameter calculation module 140, the natural gas light hydrocarbon parameters are calculated according to the integral area of typical compounds including methylcyclohexane, toluene and benzene based on the natural gas light hydrocarbon chromatographic data, the crossplot is drawn according to the biogenic indicator parameters of the biomarker compounds corresponding to the condensate oil and the natural gas light hydrocarbon parameters, and the limit value of the natural gas light hydrocarbon parameters is determined according to the limit value of the biogenic indicator parameters of the biomarker compounds corresponding to the condensate oil.

[0112] The device provided in the embodiment can execute the offshore sea-land transitional facies few-well area hydrocarbon source rock type identification method provided in any embodiment of the application, has the function modules and beneficial effects corresponding to the execution method.

[0113] The applicant declares that the above description is only a specific embodiment of the application, but the protection scope of the application is not limited to this, and the skilled in the art should understand that any change or replacement within the technical range disclosed by the application can be easily thought by any person skilled in the art in this technical field, which falls within the protection scope and disclosure range of the application.

Claims

1. A method for identifying source rock types in nearshore transitional marine-continental areas with few wells, characterized in that, The identification method includes the following steps: S1, acquire data on pollen phase analysis of source rocks, chromatographic-mass spectrometry data of saturated hydrocarbons in source rocks, chromatographic-mass spectrometry data of condensate oil saturated hydrocarbons, and chromatographic data of light hydrocarbons in natural gas within the study area; S2, Based on the pollen analysis data described in step S1, determine the boundary value for the classification of source rocks based on the content of pollen components; The method for determining the boundary value of source rocks in step S2 includes: determining the type and content ratio of each pollen phase component in different types of source rocks based on pollen phase analysis data, comparing the content ratio data, and determining the boundary value of source rocks based on the content of pollen phase components. S3, Based on the boundary value of source rock division based on pollen phase component content described in step S2, determine the boundary value of the biomarker compound corresponding to the source rock and condensate oil. The biomarker parameters of the source rocks corresponding to the source rocks include any one or a combination of at least two of the following: sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane. The biomarker parameters of the condensate oil corresponding to the biomarker compound include any one or a combination of at least two of the following: sterane C27 / C29, Pr / Ph, Ts / Tm, or gammacerane / C30 hopane. The method for determining the limit value of the biomarker parameter in step S3 includes: drawing an intersection diagram based on the content of pollen phase components and the biomarker parameter; determining the limit value of the biomarker parameter of the biomarker compound corresponding to the source rock based on the limit value of the source rock division based on the content of pollen phase components; and the limit value of the biomarker parameter of the biomarker compound corresponding to the condensate oil is consistent with the limit value of the biomarker parameter of the biomarker compound corresponding to the source rock. S4. Determine the limit value of the light hydrocarbon parameter of natural gas based on the limit value of the biomarker compound corresponding to the condensate oil described in step S3. The light hydrocarbon parameters of the natural gas include the methylcyclohexane index and the toluene / benzene ratio; S5. Draw an intersection diagram based on the light hydrocarbon parameters of natural gas, and divide the range corresponding to different types of source rocks according to the boundary values ​​of the light hydrocarbon parameters of natural gas described in step S4. The identification method further includes step S6: determining the source rock type of the well based on the position of the light hydrocarbon parameters of the natural gas in the well to be logged falling into the intersection diagram described in step S5.

2. The identification method according to claim 1, characterized in that, The source rock pollen phase analysis data in step S1 includes existing pollen phase data in the study area and / or pollen phase data collected from source rock samples.

3. The identification method according to claim 2, characterized in that, The method for obtaining pollen phase data from the source rock sample includes: treating the source rock sample with acid to obtain pollen organic matter, and then analyzing the pollen organic matter data under a microscope using transmitted light and fluorescence.

4. The identification method according to claim 1, characterized in that, The saturated hydrocarbon chromatographic-mass spectrometry data of the source rocks mentioned in step S1 includes existing saturated hydrocarbon chromatographic-mass spectrometry data of source rocks in the study area and / or saturated hydrocarbon chromatographic-mass spectrometry data collected from source rock samples.

5. The identification method according to claim 4, characterized in that, The method for acquiring saturated hydrocarbon chromatographic-mass spectrometry data from source rock samples includes: sequentially extracting and separating components from the source rock sample to obtain saturated hydrocarbons, and then performing chromatographic-mass spectrometry analysis on the saturated hydrocarbons.

6. The identification method according to claim 1, characterized in that, The saturated hydrocarbon chromatographic-mass spectrometry data of condensate oil includes existing saturated hydrocarbon chromatographic-mass spectrometry data of condensate oil in the study area and / or saturated hydrocarbon chromatographic-mass spectrometry data of condensate oil samples.

7. The identification method according to claim 6, characterized in that, The method for acquiring saturated hydrocarbon chromatographic-mass spectrometry data from condensate oil samples includes: separating the components of the condensate oil sample to obtain saturated hydrocarbons, and performing chromatographic-mass spectrometry analysis on the saturated hydrocarbons.

8. The identification method according to claim 1, characterized in that, The chromatographic data of light hydrocarbons in natural gas mentioned in step S1 includes existing chromatographic data of light hydrocarbons in natural gas in the study area and / or chromatographic data of light hydrocarbons collected from natural gas samples.

9. The identification method according to claim 1, characterized in that, The pollen phase components include any one or a combination of at least two of the following: coal-based components, woody components, herbaceous components, or amorphous components.

10. The identification method according to claim 1, characterized in that, The method for obtaining the biomarker parameters of the source rock corresponding to the source rock in step S3 includes: calculating the parameters based on the integral area of ​​the biomarker compound using saturated hydrocarbon chromatography-mass spectrometry data of the source rock.

11. The identification method according to claim 1, characterized in that, The method for obtaining the biomarker parameters of the biomarker compounds corresponding to the condensate oil includes: calculating the parameters based on the integral area of ​​the biomarker compounds using saturated hydrocarbon chromatographic-mass spectrometry data of the condensate oil.

12. The identification method according to claim 1, characterized in that, The method for obtaining the parameters of light hydrocarbons in natural gas in step S4 includes: calculating the parameters based on the integral area of ​​typical compounds, including methylcyclohexane, toluene, and benzene, according to the chromatographic data of light hydrocarbons in natural gas.

13. The identification method according to claim 1, characterized in that, The method for determining the limit values ​​of the natural gas light hydrocarbon parameters includes: drawing an intersection diagram based on the biomarker indicator parameters of the biomarker compounds corresponding to condensate oil and the natural gas light hydrocarbon parameters, and determining the limit values ​​of the natural gas light hydrocarbon parameters based on the limit values ​​of the biomarker indicator parameters of the biomarker compounds corresponding to condensate oil.

14. A device for identifying source rock types in nearshore transitional marine-continental areas with few wells, characterized in that, The identification device includes: The acquisition module is used to acquire pollen phase analysis data of source rocks, saturated hydrocarbon chromatographic-mass spectrometry data of source rocks, saturated hydrocarbon chromatographic-mass spectrometry data of condensate oil, and chromatographic data of light hydrocarbons of natural gas in the study area. The pollen phase component content calculation module is used to determine the boundary values ​​for source rocks based on pollen phase component content according to pollen phase analysis data. The method for determining the boundary value of source rocks includes: determining the type and content ratio of each pollen phase component in different types of source rocks based on pollen phase analysis data, comparing the content ratio data, and determining the boundary value of source rocks based on the content of pollen phase components. The biomarker parameter calculation module is used to determine the boundary values ​​of biomarker parameters of biomarker compounds corresponding to source rocks and condensate oil based on the boundary values ​​of source rock classification based on pollen phase component content; the biomarker parameters include any one or a combination of at least two of sterane C27 / C29, Pr / Ph, Ts / Tm or gammacerane / C30 hopane. The method for determining the limit value of the biomarker parameter includes: drawing an intersection diagram based on the content of pollen phase components and the biomarker parameter; determining the limit value of the biomarker parameter of the biomarker compound corresponding to the source rock based on the limit value of the source rock division based on the content of pollen phase components; and the limit value of the biomarker parameter of the biomarker compound corresponding to the condensate oil is consistent with the limit value of the biomarker parameter of the biomarker compound corresponding to the source rock. The natural gas light hydrocarbon parameter calculation module is used to determine the limit values ​​of natural gas light hydrocarbon parameters based on the limit values ​​of the biomarker compound biomarker parameter corresponding to condensate oil. The method for obtaining the parameters of light hydrocarbons in natural gas includes: calculating them based on the integral area of ​​typical compounds, including methylcyclohexane, toluene, and benzene, according to the chromatographic data of light hydrocarbons in natural gas. The method for determining the limit values ​​of the natural gas light hydrocarbon parameters includes: drawing an intersection diagram based on the biomarker indicator parameters of the biomarker compounds corresponding to condensate oil and the natural gas light hydrocarbon parameters, and determining the limit values ​​of the natural gas light hydrocarbon parameters based on the limit values ​​of the biomarker indicator parameters of the biomarker compounds corresponding to condensate oil. The source rock intersection map division module is used to draw intersection maps based on natural gas light hydrocarbon parameters and to divide the range corresponding to different types of source rocks according to the boundary values ​​of natural gas light hydrocarbon parameters. The identification device also includes an identification module, used to determine the source rock type of the well based on the location of the light hydrocarbon parameters of the natural gas in the well falling into the cross-sectional diagram.

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