CN112443322A - Hydrocarbon source rock logging evaluation method based on equivalent saturation - Google Patents
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- 239000011435 rock Substances 0.000 title claims abstract description 288
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 150
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 150
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 145
- 238000011156 evaluation Methods 0.000 title claims abstract description 32
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims abstract description 70
- 229910052799 carbon Inorganic materials 0.000 claims abstract description 70
- 238000000034 method Methods 0.000 claims abstract description 28
- 239000005416 organic matter Substances 0.000 claims abstract description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 20
- 150000001875 compounds Chemical class 0.000 claims description 8
- 238000004519 manufacturing process Methods 0.000 claims description 4
- 239000008398 formation water Substances 0.000 claims description 3
- 239000000203 mixture Substances 0.000 claims description 2
- 238000004458 analytical method Methods 0.000 description 10
- 239000011148 porous material Substances 0.000 description 7
- 238000004364 calculation method Methods 0.000 description 4
- 239000012530 fluid Substances 0.000 description 4
- 208000035126 Facies Diseases 0.000 description 3
- 238000013508 migration Methods 0.000 description 3
- 230000005012 migration Effects 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- 238000007796 conventional method Methods 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 230000007547 defect Effects 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 238000001730 gamma-ray spectroscopy Methods 0.000 description 2
- 229910052500 inorganic mineral Inorganic materials 0.000 description 2
- 239000011707 mineral Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 229910052770 Uranium Inorganic materials 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009933 burial Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000005056 compaction Methods 0.000 description 1
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- 239000000523 sample Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
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- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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Abstract
The invention discloses a hydrocarbon source rock logging evaluation method based on equivalent saturation, which comprises the following steps: obtaining the total porosity and the effective porosity of the source rock according to a neutron density intersection method; establishing a functional relation among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock to obtain the oil-gas saturation of the source rock; establishing a functional relation among the total porosity of the source rock, the oil-gas saturation of the source rock and the content of the residual hydrocarbon in the source rock to obtain the content of the residual hydrocarbon in the source rock; establishing a functional relation among the residual hydrocarbon content in the source rock, the kerogen of the source rock, the mixed density of oil gas, the rock density of the source rock and the total organic carbon of the source rock to obtain the total organic carbon of the source rock; and establishing a functional relation among the total organic carbon, the organic matter maturity, the oil-gas density and the hydrocarbon yield of the source rock to obtain the hydrocarbon yield of the source rock. The method improves the effectiveness and accuracy of conventional logging information for evaluating the organic carbon content of the hydrocarbon source rock.
Description
Technical Field
The invention relates to the technical field of geophysical exploration of argillaceous source rocks (including continental facies, marine facies and transition facies argillaceous source rocks). And more particularly, to a logging evaluation method for hydrocarbon source rocks based on equivalent saturation.
Background
The organic carbon content of the argillaceous source rock is the mass of organic carbon elements in a unit mass of rock, and is an important parameter which is used together with the hydrocarbon yield for evaluating the hydrocarbon generation potential of the source rock. Core analysis can provide high-precision organic carbon content of the source rock, but has the defects of high coring cost, limited samples, poor representativeness, long time consumption and the like, and the organic carbon content cannot be continuously characterized. According to the response characteristic of the organic matter on the logging curve, the quantitative relation between the organic carbon content and the logging response value can be established by using logging information, and the continuously distributed organic carbon content information can be obtained.
The currently common organic carbon content logging evaluation methods mainly include natural gamma-ray spectroscopy logging, density logging, acoustic logging, nuclear magnetic logging, a delta logR method, a multiparameter method and a multi-logging combination method. However, the method of natural gamma-ray spectroscopy logging is susceptible to uranium-containing minerals; both the density and acoustic logging methods require core analysis data to establish a relationship between a logging curve and the organic carbon content of the core; the nuclear magnetic logging method has limited detection depth, is greatly influenced by the borehole environment, has high logging cost and is not suitable for large-scale application; the delta logR method utilizes the relative values of the resistivity curve and the porosity curve to calculate the carbon content, but the calculation formula depends on the parameters such as a base line value, a thermal maturity index, a superposition coefficient and the like; the multi-parameter and multi-logging combined optimization method utilizes various logging information to reduce the influence of environmental factors, but still needs a large amount of core analysis data to be scaled so as to establish the relationship between logging values and organic carbon content; the geochemical well logging evaluation method utilizes an advanced element capture well logging technology, can directly output the content of organic carbon, and has the defects of complex calculation model of the content of the organic carbon, high uncertainty, high calculation difficulty of carbon of hydrocarbon fluid in pores and inorganic carbon in rock minerals and high well logging cost.
Therefore, the invention provides a hydrocarbon source rock logging evaluation method based on equivalent saturation to solve the problems.
Disclosure of Invention
The invention aims to provide a hydrocarbon source rock logging evaluation method based on equivalent saturation; the method is a novel logging method for rapidly, continuously and accurately evaluating the organic carbon content and the hydrocarbon yield of the argillaceous hydrocarbon source rock by using conventional logging information, has the characteristics of low measurement cost and large data volume, and is easy to popularize and apply in a large scale.
In order to achieve the purpose, the invention adopts the following technical scheme:
a hydrocarbon source rock logging evaluation method based on equivalent saturation comprises the following steps:
1) obtaining the total porosity and the effective porosity of the source rock according to a neutron density intersection method;
2) establishing a functional relation among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock to obtain the oil-gas saturation of the source rock;
3) establishing a functional relation among the total porosity of the source rock, the oil-gas saturation of the source rock and the content of the residual hydrocarbon in the source rock to obtain the content of the residual hydrocarbon in the source rock;
4) establishing a functional relation among the residual hydrocarbon content in the source rock, the kerogen of the source rock, the mixed density of oil gas, the rock density of the source rock and the total organic carbon of the source rock to obtain the total organic carbon of the source rock;
5) and establishing a functional relation among the total organic carbon, the organic matter maturity, the oil-gas density and the hydrocarbon yield of the source rock to obtain the hydrocarbon yield of the source rock.
Preferably, the functional relationship among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock in the step 2) is established through a formula (I), a formula (II) and a formula (III);
Sog＝1-Swt (II)；
in the formulae (I), (II) and (III),
Swtrepresents the total water saturation of the source rock and has the unit of vol%;
Sogrepresenting the oil-gas saturation of the source rock, and the unit is vol%;
a. b, m and n represent empirical parameters and are dimensionless;
Rtthe unit of the true resistivity of the hydrocarbon source rock is omega-m;
Rzthe resistivity of mixed formation water is expressed and has the unit of omega.m;
Rwthe resistivity of a pure rock water layer is shown, and the unit is omega.m;
Rwcthe resistivity of a pure mud rock water layer is expressed and the unit is omega.m;
φtrepresents the total porosity of the source rock, and the unit is vol%;
φerepresenting the effective porosity of the source rock in vol%.
Preferably, for a new exploration area, the values of a, b, m and n may take empirical values of a-b-1 and m-n-2.
Preferably, the true resistivity of the source rock is obtained from a deep resistivity log.
Preferably, the functional relationship among the total porosity of the source rock, the hydrocarbon saturation and the residual hydrocarbon content in the source rock in the step 3) is established by a formula (IV);
VHC＝φt·Sog (IV)；
in the formula (IV), the compound is shown in the specification,
VHC represents the residual hydrocarbon content in the source rock in vol%;
φtrepresents the total porosity of the source rock, and the unit is vol%;
Sogthe hydrocarbon source rock oil-gas saturation is expressed in vol%.
Preferably, the functional relationship among the residual hydrocarbon content in the source rock, the kerogen and oil gas mixed density of the source rock, the rock density of the source rock and the total organic carbon of the source rock in the step 4) is established by a formula (V);
TOC＝VHC·ρgog/ρhr (V)；
in the formula (V), the compound represented by the formula (V),
TOC represents the total organic carbon of the source rock in wt%;
VHC represents the residual hydrocarbon content in the source rock in vol%;
ρgogthe mixed density of the kerogen and the oil gas of the source rock is expressed in g/cm3；
ρhrThe rock density of the source rock is expressed in g/cm3。
Preferably, the value of the mixed density of the kerogen of the source rock and the oil gas is 1.2g/cm of default value3。
Preferably, the rock density of the hydrocarbon source rock is 2.65g/cm in default value3。
Preferably, the functional relationship among the total organic carbon, organic matter maturity, oil gas density and hydrocarbon yield of the source rock in the step 5) is established by a formula (VI);
HCI＝TOC·Ro·ρog·10 (VI)；
in the formula (VI), the compound represented by the formula (VI),
HCI represents the hydrocarbon yield of the source rock and has the unit of kg/t;
ro represents organic matter maturity, dimensionless;
ρogrepresents the density of oil gas in g/cm3。
Preferably, the oil gas density is 0.8g/cm of default value3。
Preferably, the organic matter maturity is calculated by an arrhenius formula or obtained by geological analysis data.
Preferably, the organic matter maturity is 0.5.
Preferably, the organic matter maturity is calculated according to formula (VII) and formula (VIII),
Ro＝1-α (VII)；
in the formulae (VII) and (VIII),
ro represents organic matter maturity, dimensionless;
alpha represents the residual carbon of the hydrocarbon source rock and is dimensionless;
Tzthe mean annual absolute temperature of the paleo-geothermal field, which changes with the depth, is expressed in K;
T0representing the mean absolute temperature of the paleo-surface year as a function of depth, in units of K;
and t represents organic matter burying time and has a unit of Ma.
The invention has the following beneficial effects:
the invention utilizes the porosity and resistivity curve of the conventional logging series (namely, the logging series widely applied to various oil fields in China at present) to calculate the oil and gas saturation of the hydrocarbon source rock, and utilizes the total porosity, kerogen and the density of the hydrocarbon source rock to convert the oil and gas saturation of the hydrocarbon source rock into the organic carbon content and the hydrocarbon yield by a model equivalent method so as to achieve the aim of quantitatively evaluating the organic carbon content and the hydrocarbon yield of the hydrocarbon source rock by the conventional logging series. The method provides an evaluation idea of indirectly reflecting the organic carbon content and the hydrocarbon yield by utilizing the oil-gas saturation of the argillaceous source rock from the perspective of contribution degree of oil gas generated by organic carbon of the source rock to the current oil-gas reservoir, greatly improves effectiveness and accuracy of conventional logging information for evaluating the organic carbon content of the source rock, and further enriches and perfects a logging evaluation method for the organic carbon content of the source rock.
Drawings
The following describes embodiments of the present invention in further detail with reference to the accompanying drawings.
FIG. 1 shows a flow chart of a hydrocarbon source rock logging evaluation method based on equivalent saturation provided by the invention.
Fig. 2 shows a rock logging volume model rich in organic matter provided by the present invention.
FIG. 3 illustrates a non-hydrocarbon source rock log volume model provided by the present invention.
FIG. 4 illustrates a non-hydrocarbon source rock log interpretation conceptual model provided by the present invention.
FIG. 5 illustrates an explanation conceptual model of logging of an immature source rock provided by the present invention.
FIG. 6 shows an illustrative conceptual model of a well logging of a mature source rock provided by the present invention.
Fig. 7 shows a diagram of the well logging interpretation result of the M-well hydrocarbon source rock provided in embodiment 1 of the present invention.
Figure 8 shows a comparison of the M-well cuttings analyzed organic carbon and the log calculated organic carbon provided in example 1 of the present invention.
Detailed Description
In order to more clearly illustrate the invention, the invention is further described below in connection with preferred embodiments. It is to be understood by persons skilled in the art that the following detailed description is illustrative and not restrictive, and is not to be taken as limiting the scope of the invention.
The hydrocarbon source rock logging evaluation method based on equivalent saturation is researched according to the residual hydrocarbon concentration of generated hydrocarbons in the oil producing rock. Oil and gas are generated and then migrate from the oil and gas source rock to the outside in different phase states under the action of various geological stresses, but oil, gas and water migrate from the source rock in an early migration state or a late migration state, and in a water phase migration state or a free phase stateAfter some of the extrusions, the saturation level remaining in the source rock is constant, i.e., at some point the hydrocarbon saturation level of the fluid removed from the source rock is the same as the hydrocarbon saturation level of the fluid remaining in the pores of the source rock. Therefore, hydrocarbon expulsion does not reduce hydrocarbon saturation in the source rock. Furthermore, as the compaction and hydrocarbon expulsion progress, the oil and gas saturation of the source rock can only be increased and can not be reduced, because the maturity of the oil-bearing rock is increased along with the increase of the buried depth, the conversion is increased, the cumulative oil and gas generation amount is increased, and the pore space and the water content of the stratum are reduced along with the increase of the buried depth. Therefore, the oil-gas saturation in the pores of the source rock in the same layer is increased along with the increase of the burial depth. The oil gas content in the source rock is a product after organic matters are mature, so that the oil gas content is in direct proportion to the abundance of the organic matters and has a direct relation with the type and the maturity of the organic matters. Therefore, the hydrocarbon source rock has oil and gas saturation SogDirectly reflects the hydrocarbon generation potential of the source rock and is the basis for well logging and evaluation of the source rock. The method of the invention provides an evaluation idea for indirectly reflecting the organic carbon content and the hydrocarbon yield by utilizing the hydrocarbon saturation of the argillaceous source rock from the perspective of the contribution degree of oil gas generated by organic carbon of the source rock to the current oil and gas reservoir. The hydrocarbon source rock well logging explanation model is shown in fig. 2 to fig. 6. In FIGS. 4 to 6, φwRepresents the porosity of water in the source rock; phi is atRepresents the total porosity of the source rock; phi is aogRepresenting the porosity of the hydrocarbons in the source rock.
As can be seen from fig. 2 to 6, the non-hydrocarbon source rock volume model is composed of only mudstone framework particles and pore water; the immature source rock volume model rich in organic matters consists of mudstone framework particles, organic matters and pore water; the mature hydrocarbon source rock volume model consists of mudstone framework particles, residual organic matters, pore water and residual hydrocarbons. Therefore, the invention uses a logging method to calculate the total porosity and hydrocarbon saturation of the born source rock, thereby realizing the logging evaluation of the source rock.
Specifically, the hydrocarbon source rock logging evaluation method based on equivalent saturation comprises the following steps in combination with fig. 1:
s101, obtaining the total porosity and the effective porosity of the source rock according to a neutron density intersection method;
s102, establishing a functional relation among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock to obtain the oil-gas saturation of the source rock;
s103, establishing a functional relation among the total porosity of the source rock, the oil-gas saturation of the source rock and the content of the residual hydrocarbons in the source rock to obtain the content of the residual hydrocarbons in the source rock;
s104, establishing a functional relation among the residual hydrocarbon content in the source rock, the kerogen of the source rock, the mixed density of oil gas, the rock density of the source rock and the total organic carbon of the source rock to obtain the total organic carbon of the source rock;
s105, establishing a functional relation among the total organic carbon, organic matter maturity, oil gas density and hydrocarbon yield of the source rock to obtain the hydrocarbon yield of the source rock.
It should be understood by those skilled in the art that the neutron density intersection method in the present invention is a conventional technical method, and is not described herein; step S102, determining the oil and gas saturation of the source rock according to the functional relationship among the total porosity of the source rock, the effective porosity of the source rock and the oil and gas saturation of the source rock and by combining the total porosity of the source rock and the effective porosity of the source rock obtained in the step S101; step S103, determining the content of the residual hydrocarbon in the source rock according to the functional relationship among the total porosity of the source rock, the hydrocarbon saturation of the source rock and the content of the residual hydrocarbon in the source rock by combining the total porosity of the source rock obtained in the step S101 and the hydrocarbon saturation of the source rock obtained in the step S102; step S104, determining the total organic carbon of the source rock according to the functional relationship among the content of the residual hydrocarbon in the source rock, the kerogen and oil gas mixed density of the source rock, the rock density of the source rock and the total organic carbon of the source rock and by combining the content of the residual hydrocarbon in the source rock obtained in the step S103; and S105, determining the hydrocarbon production rate of the source rock according to the functional relation among the total organic carbon of the source rock, the organic matter maturity, the oil-gas density and the hydrocarbon production rate of the source rock and by combining the total organic carbon of the source rock obtained in the S104.
As a preferred embodiment of the present invention, the functional relationship among the total porosity of the source rock, the effective porosity of the source rock and the hydrocarbon saturation of the hydrocarbon gas in the source rock in S102 is established by formula (I), formula (II) and formula (III);
Sog＝1-Swt (II)；
in the formulae (I), (II) and (III),
Swtrepresents the total water saturation of the source rock and has the unit of vol%;
Sogrepresenting the oil-gas saturation of the source rock, and the unit is vol%;
a. b, m and n represent empirical parameters and are dimensionless;
Rtthe unit of the true resistivity of the hydrocarbon source rock is omega-m;
Rzthe resistivity of mixed formation water is expressed and has the unit of omega.m;
Rwthe resistivity of a pure rock water layer is shown, and the unit is omega.m;
Rwcthe resistivity of a pure mud rock water layer is expressed and the unit is omega.m;
φtrepresents the total porosity of the source rock, and the unit is vol%;
φerepresenting the effective porosity of the source rock in vol%.
It will be understood by those skilled in the art that the true resistivity R of the source rock in the present inventiontObtaining the resistivity R of the water layer of the pure rock through logging informationwAnd the pure mudstone water layer resistivity RwcThe resistivity of the pure rock section water layer and the resistivity of the pure mudstone section water layer are obtained respectively, and the obtaining method is a conventional method and is not described herein any more.
In a preferred embodiment of the present invention, the empirical values a, b, m, and n for the new probe area are a-b-1 and m-n-2. It should be understood by those skilled in the art that the values of a, b, m, and n for the old exploration area in the present invention are conventional values or obtained by a rock-electricity experiment, and are not described herein in detail.
In a preferred embodiment of the present invention, the true resistivity of the source rock is obtained from a deep resistivity log. It should be understood by those skilled in the art that the deep resistivity well log according to the present invention is obtained according to well log data, and the obtaining method of the deep resistivity well log is a conventional technical means, and is not described herein.
As a preferred embodiment of the present invention, the functional relationship among the residual hydrocarbon content in the source rock, the kerogen and hydrocarbon gas mixture density of the source rock, the rock density of the source rock and the total organic carbon of the source rock in S104 is established by formula (V);
TOC＝VHC·ρgog/ρhr (V)；
in the formula (V), the compound represented by the formula (V),
TOC represents the total organic carbon of the source rock in wt%;
VHC represents the residual hydrocarbon content in the source rock in vol%;
ρgogthe mixed density of the kerogen and the oil gas of the source rock is expressed in g/cm3；
ρhrThe rock density of the source rock is expressed in g/cm3。
In a preferred embodiment of the invention, the mixed density of the kerogen and the oil gas in the source rock is 1.2g/cm of default value3。
As a preferred embodiment of the invention, the rock density of the hydrocarbon source rock is a default value of 2.65g/cm3。
As a preferred embodiment of the present invention, the functional relationship among the total organic carbon, organic matter maturity, hydrocarbon gas density and hydrocarbon yield of the source rock in S105 is established by formula (VI);
HCI＝TOC·Ro·ρog·10 (VI)；
in the formula (VI), the compound represented by the formula (VI),
HCI represents the hydrocarbon yield of the source rock and has the unit of kg/t;
ro represents organic matter maturity, dimensionless;
ρogrepresents the density of oil gas in g/cm3。
As a preferred embodiment of the invention, the oil gas density is set to be 0.8g/cm as a default value3。
In a preferred embodiment of the present invention, the organic matter maturity is calculated by the arrhenius formula or obtained from geological analysis data. It should be understood by those skilled in the art that the method for obtaining the localization analysis data of the present invention is a conventional technical means, and is not described herein in detail.
In a preferred embodiment of the present invention, the organic matter maturity is 0.5.
As a preferred embodiment of the present invention, the organic matter maturity is calculated according to formula (VII) and formula (VIII),
Ro＝1-α (VII)；
in the formulae (VII) and (VIII),
ro represents organic matter maturity, dimensionless;
alpha represents the residual carbon of the hydrocarbon source rock and is dimensionless;
Tzthe mean annual absolute temperature of the paleo-geothermal field, which changes with the depth, is expressed in K;
T0representing the mean absolute temperature of the paleo-surface year as a function of depth, in units of K;
and t represents organic matter burying time and has a unit of Ma. It will be understood by those skilled in the art that the ancient geothermal annual average absolute temperature T as a function of depth as described in the present inventionzAnd the annual mean absolute temperature T of the paleo-surface as a function of depth0The obtaining method is a conventional method and is not described herein.
The present invention will be further described with reference to the following examples.
Example 1
The embodiment provides a hydrocarbon source rock logging evaluation method based on equivalent saturation, which is used for evaluation of an M well and comprises the following steps:
1) obtaining the total porosity phi of the hydrocarbon source rock according to a neutron density intersection methodtAnd effective porosity phi of source rockeFIG. 7 shows a log interpretation achievement plot for M wells, in which:
the 1 st channel is a depth channel;
the 2 nd channel is a lithologic section channel;
the 4 th pass is permeability and crack
the 6 th channel is a fluid analysis channel;
comparing the logging evaluation results of the source rock (including logging and calculating the content of residual hydrocarbon, the content of organic carbon, the hydrocarbon yield and the content of organic carbon analyzed by rock debris);
the 8 th path is a storage cover combination;
the 9 th to the 11 th paths are respectively a mud logging curve, a resistivity logging curve and a porosity logging curve;
2) establishing a functional relation among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock according to a formula (I), a formula (II) and a formula (III), and calculating to obtain the oil-gas saturation of the source rock according to the total porosity of the source rock and the effective porosity of the source rock obtained in the step 1);
3) establishing a functional relation among the total porosity of the source rock, the oil and gas saturation of the source rock and the residual hydrocarbon content in the source rock according to a formula (IV), and calculating to obtain the residual hydrocarbon content in the source rock according to the total porosity of the source rock obtained in the step 1) and the oil and gas saturation of the source rock obtained in the step 2);
4) establishing a functional relation among the content of the residual hydrocarbon in the source rock, the kerogen of the source rock and the mixed density of oil gas, the rock density of the source rock and the total organic carbon of the source rock through a formula (V), and calculating to obtain the total organic carbon of the source rock according to the content of the residual hydrocarbon in the source rock obtained in the step 3);
5) and (3) establishing a functional relation among the total organic carbon, the organic matter maturity, the oil-gas density and the hydrocarbon yield of the source rock according to a formula (VI), and calculating the hydrocarbon yield of the source rock according to the total organic carbon of the source rock obtained in the step 4).
The results of the logging calculations of this example were compared with the results of the cuttings analysis, and the results are shown in fig. 7 and 8.
As can be seen from FIG. 7, the calculated organic carbon content of the log of this embodiment in the 6 th trace has better consistency with the analyzed organic carbon content of the debris, both in terms of the magnitude and the trend of the change.
As can be seen from FIG. 8, the organic carbon content of the source rock calculated by logging in this embodiment has a good correlation with the organic carbon content of the debris analysis, and the correlation coefficient reaches 0.83. The method can better reflect the organic carbon content and hydrocarbon generation potential of the actual source rock, can be used for source rock evaluation, reduces the cost and expands the scale application.
According to the residual hydrocarbon content, the organic carbon content, the hydrocarbon yield and the like obtained by the hydrocarbon source rock logging evaluation method, parameters in the 7 th path in the attached figure 7 can be obtained, and the graph shows that the organic carbon content calculated by logging has good correlation with the organic carbon content analyzed by experiments, which shows that the method for evaluating the organic carbon content of the hydrocarbon source rock by logging is feasible and can reflect the development degree and the organic carbon size of the hydrocarbon source rock of the stratum, and the hydrocarbon production potential of the hydrocarbon source rock can be further evaluated through the calculated hydrocarbon yield.
It should be understood that the above-mentioned embodiments of the present invention are only examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention, and it will be obvious to those skilled in the art that other variations or modifications may be made on the basis of the above description, and all embodiments may not be exhaustive, and all obvious variations or modifications may be included within the scope of the present invention.
Claims (10)
1. A hydrocarbon source rock logging evaluation method based on equivalent saturation is characterized by comprising the following steps:
1) obtaining the total porosity and the effective porosity of the source rock according to a neutron density intersection method;
2) establishing a functional relation among the total porosity of the source rock, the effective porosity of the source rock and the oil-gas saturation of the source rock to obtain the oil-gas saturation of the source rock;
3) establishing a functional relation among the total porosity of the source rock, the oil-gas saturation of the source rock and the content of the residual hydrocarbon in the source rock to obtain the content of the residual hydrocarbon in the source rock;
4) establishing a functional relation among the residual hydrocarbon content in the source rock, the kerogen of the source rock, the mixed density of oil gas, the rock density of the source rock and the total organic carbon of the source rock to obtain the total organic carbon of the source rock;
5) and establishing a functional relation among the total organic carbon, the organic matter maturity, the oil-gas density and the hydrocarbon yield of the source rock to obtain the hydrocarbon yield of the source rock.
2. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 1, wherein the functional relationship among the total porosity of the hydrocarbon source rock, the effective porosity of the hydrocarbon source rock and the hydrocarbon source rock hydrocarbon saturation in the step 2) is established through formula (I), formula (II) and formula (III);
Sog＝1-Swt(II)；
in the formulae (I), (II) and (III),
Swtrepresenting a hydrocarbon sourceThe total rock water saturation in vol%;
Sogrepresenting the oil-gas saturation of the source rock, and the unit is vol%;
a. b, m and n represent empirical parameters and are dimensionless;
Rtthe unit of the true resistivity of the hydrocarbon source rock is omega-m;
Rzthe resistivity of mixed formation water is expressed and has the unit of omega.m;
Rwthe resistivity of a pure rock water layer is shown, and the unit is omega.m;
Rwcthe resistivity of a pure mud rock water layer is expressed and the unit is omega.m;
φtrepresents the total porosity of the source rock, and the unit is vol%;
φerepresenting the effective porosity of the source rock in vol%.
3. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 2, wherein for a new exploration area, the values of a, b, m and n are a-b-1 and m-n-2; and the true resistivity of the hydrocarbon source rock is obtained according to a deep resistivity logging curve.
4. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 1, wherein the functional relationship among the total porosity of the hydrocarbon source rock, the hydrocarbon source rock hydrocarbon saturation and the residual hydrocarbon content in the hydrocarbon source rock in the step 3) is established through a formula (IV);
VHC＝φt·Sog (IV)；
in the formula (IV), the compound is shown in the specification,
VHC represents the residual hydrocarbon content in the source rock in vol%;
φtrepresents the total porosity of the source rock, and the unit is vol%;
Sogthe hydrocarbon source rock oil-gas saturation is expressed in vol%.
5. The hydrocarbon source rock logging evaluation method based on equivalent saturation degree as claimed in claim 1, wherein the functional relationship among the residual hydrocarbon content in the hydrocarbon source rock, the kerogen and oil gas mixture density of the hydrocarbon source rock, the rock density of the hydrocarbon source rock and the total organic carbon of the hydrocarbon source rock in the step 4) is established by a formula (V);
TOC＝VHC·ρgog/ρhr (V)；
in the formula (V), the compound represented by the formula (V),
TOC represents the total organic carbon of the source rock in wt%;
VHC represents the residual hydrocarbon content in the source rock in vol%;
ρgogthe mixed density of the kerogen and the oil gas of the source rock is expressed in g/cm3；
ρhrThe rock density of the source rock is expressed in g/cm3。
6. The hydrocarbon source rock logging evaluation method based on equivalent saturation of claim 5, wherein the mixed density of kerogen and oil gas of the hydrocarbon source rock is 1.2g/cm of default value3(ii) a The rock density of the hydrocarbon source rock is taken as a default value of 2.65g/cm3。
7. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 1, wherein the functional relationship among the total organic carbon, organic matter maturity, hydrocarbon gas density and hydrocarbon production rate of the hydrocarbon source rock in the step 5) is established by formula (VI);
HCI＝TOC·Ro·ρog·10 (VI)；
in the formula (VI), the compound represented by the formula (VI),
HCI represents the hydrocarbon yield of the source rock and has the unit of kg/t;
ro represents organic matter maturity, dimensionless;
ρogrepresents the density of oil gas in g/cm3。
8. The hydrocarbon source rock logging evaluation method based on equivalent saturation of claim 7, wherein the hydrocarbon density is a default value of 0.8g/cm3。
9. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 7, wherein the organic matter maturity is 0.5.
10. The hydrocarbon source rock logging evaluation method based on equivalent saturation according to claim 7, wherein the organic matter maturity is calculated according to formula (VII) and formula (VIII),
Ro＝1-α (VII)；
in the formulae (VII) and (VIII),
ro represents organic matter maturity, dimensionless;
alpha represents the residual carbon of the hydrocarbon source rock and is dimensionless;
Tzthe mean annual absolute temperature of the paleo-geothermal field, which changes with the depth, is expressed in K;
T0representing the mean absolute temperature of the paleo-surface year as a function of depth, in units of K;
and t represents organic matter burying time and has a unit of Ma.
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