CN114109373B - Method for calculating oil content of shale oil reservoir by using logging data - Google Patents
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- 239000003079 shale oil Substances 0.000 title claims abstract description 60
- 238000000034 method Methods 0.000 title claims abstract description 30
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 57
- 239000011148 porous material Substances 0.000 claims description 42
- 238000005481 NMR spectroscopy Methods 0.000 claims description 7
- 238000002474 experimental method Methods 0.000 claims description 7
- 239000012530 fluid Substances 0.000 claims description 7
- 239000000706 filtrate Substances 0.000 claims description 6
- 238000011010 flushing procedure Methods 0.000 claims description 6
- 238000001228 spectrum Methods 0.000 claims description 4
- NAWXUBYGYWOOIX-SFHVURJKSA-N (2s)-2-[[4-[2-(2,4-diaminoquinazolin-6-yl)ethyl]benzoyl]amino]-4-methylidenepentanedioic acid Chemical compound C1=CC2=NC(N)=NC(N)=C2C=C1CCC1=CC=C(C(=O)N[C@@H](CC(=C)C(O)=O)C(O)=O)C=C1 NAWXUBYGYWOOIX-SFHVURJKSA-N 0.000 claims description 3
- 101100285518 Drosophila melanogaster how gene Proteins 0.000 claims description 3
- 238000012937 correction Methods 0.000 claims description 3
- 238000001514 detection method Methods 0.000 claims description 3
- 239000000523 sample Substances 0.000 claims description 3
- 230000008030 elimination Effects 0.000 claims description 2
- 238000003379 elimination reaction Methods 0.000 claims description 2
- 239000002002 slurry Substances 0.000 claims 2
- 238000001000 micrograph Methods 0.000 claims 1
- 238000011156 evaluation Methods 0.000 abstract description 8
- 238000011161 development Methods 0.000 abstract description 4
- 239000011435 rock Substances 0.000 description 4
- 238000004891 communication Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 229910052500 inorganic mineral Inorganic materials 0.000 description 2
- 239000011707 mineral Substances 0.000 description 2
- 238000004626 scanning electron microscopy Methods 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000013210 evaluation model Methods 0.000 description 1
- 238000011005 laboratory method Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000005416 organic matter Substances 0.000 description 1
- 238000000197 pyrolysis Methods 0.000 description 1
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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
- 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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- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
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Abstract
The invention belongs to the technical field of shale oil logging evaluation, and discloses a method for calculating oil content of a shale oil reservoir by using logging data. The method is strong in practicality of oil content calculation of the organic shale oil reservoir with large lithology change and strong heterogeneity, and enriches the technical means of shale oil reservoir exploration, development and logging evaluation.
Description
Technical Field
The invention belongs to the technical field of shale oil logging evaluation, and particularly relates to a method for calculating oil content of a shale oil reservoir by using logging data.
Background
The oil content of the shale oil reservoir is a key factor for determining the exploration and development economy, the productivity prediction result and the actual change rule of the shale oil reservoir. The current evaluation method for determining the oil content of shale oil by logging is determined based on rock experiments (Sunzhong, xue Haitao, jiang Qigui, etc.), or oil saturation is calculated based on an Alqi formula (Zhang Jinyan, wang Shaowei), so that the oil content is converted. However, laboratory methods do not allow continuous profiling of oil content, and oil content assessment based on the Alqi formula or modified Alqi is not applicable in shale oil reservoirs with complex pore structures, mineral compositions. For reservoirs with complex pore structures such as volcanic rock and carbonate rock, zhang Chaomo et al (2009) propose a saturation evaluation method for eliminating the influence of background conductive and nonconductive porosities. The method considers that even though the method is a dense layer without pores, the logging resistivity is not infinite, which indicates that the reservoir has a certain background conductivity factor, namely, the resistivity logging is the result of the combined action of the connected pore fluid, the water-containing micro-pores, the conductive minerals and the diversion of the well bore. The key parameter of the method, namely total nonconductive water saturation S wr, is that regression statistics is needed to be carried out on core experimental data of the reservoir, and each area or well section has only 1 fixed value and is not suitable for shale oil reservoirs with strong heterogeneity. In addition, the above method does not consider the influence of organic pores when calculating the oil saturation, and therefore is not fully applicable in shale oil reservoir evaluation. In view of the above, there is currently a lack of fully applicable, simple and rapid oil-based logging evaluation techniques in the art.
Disclosure of Invention
The invention aims at overcoming the defects of the prior art, and provides a method for calculating the oil content of a shale oil reservoir by using logging data. According to the invention, the organic holes and the inorganic holes are distinguished by establishing a new shale oil saturation evaluation model, and a new method for obtaining the total nonconductive water saturation S wr is provided, so that the oil saturation of the shale oil reservoir is accurately obtained, and the oil content of the shale oil reservoir is determined accordingly.
In order to achieve the above-mentioned purpose, the present invention provides a method for calculating oil content of shale oil reservoir, which uses core scanning electron microscope data, core oil content data and nuclear magnetic resonance logging data to calculate organic porosity phi ORG and inorganic porosity phi IN, and calculate organic hole oil content O corg of the whole well section, and calculate total non-conductive water saturation S wr of the whole well section, and then calculate inorganic hole oil content S oin of the whole well section by using background conductivity and non-conductive porosity elimination model, and calculate inorganic hole oil content O cin of the whole well section, and calculate total oil content O c of the whole well section according to the addition of the organic hole oil content O corg and the inorganic hole oil content O cin; wherein the total nonconductive water saturation S wr of the full wellbore section is the ratio of the porosity of the nonconductive water pores of the full wellbore section to the total porosity.
The technical scheme of the invention has the following beneficial effects:
(1) The invention provides a convenient means for determining the oil content of the shale oil reservoir by using logging data, and various parameters in the invention can be obtained according to the logging data and laboratory data. The oil content of the shale oil reservoir is calculated rapidly and accurately by using logging data, and the method has great practical value in shale oil exploration and development.
(2) The method is strong in practicality of oil content calculation of the organic shale oil reservoir with large lithology change and strong heterogeneity, and enriches the technical means of shale oil reservoir exploration, development and logging evaluation.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The foregoing and other objects, features and advantages of the invention will be apparent from the following more particular descriptions of exemplary embodiments of the invention as illustrated in the accompanying drawings wherein like reference numbers generally represent like parts throughout the exemplary embodiments of the invention.
Fig. 1 shows a schematic diagram of shale oil distribution in pore space of a method for calculating oil content of a shale oil reservoir.
FIG. 2 illustrates an example graph of oil content calculations for a Jiang Han oilfield Qianjiang recessed shale oil reservoir for a method of calculating oil content in a shale oil reservoir in accordance with an embodiment of the invention.
FIG. 3 shows a block diagram of main technical steps of a method for calculating oil content of a shale oil reservoir.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the preferred embodiments of the present invention are described below, it should be understood that the present invention may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
The invention provides a method for calculating oil content of a shale oil reservoir, which utilizes core scanning electron microscope data, core oil content data and nuclear magnetic resonance logging data to calculate organic porosity phi ORG and inorganic porosity phi IN, calculates organic hole oil content O corg of a whole well section, calculates total non-conductive water saturation S wr of the whole well section, calculates inorganic hole oil content S oin of the whole well section by utilizing a model for eliminating background conduction and non-conductive porosity, calculates inorganic hole oil content O cin of the whole well section, and calculates total oil content O c of the whole well section according to the sum of the organic hole oil content O corg and the inorganic hole oil content O cin; wherein the total nonconductive water saturation S wr of the full wellbore section is the ratio of the porosity of the nonconductive water pores of the full wellbore section to the total porosity.
The method of the present invention is based on the following assumptions, as shown in fig. 1, which are as follows:
Oil in the shale oil reservoir is produced from kerogen, and the kerogen organic pores are filled with oil; the rest oil is transported in a short distance to displace the stratum water which is easy to flow in the central part of the inorganic macropores, and the stratum water in the pore space with complex macropore edges is reserved; the isolated pores are filled with water; thus, the non-conductive pores include organic matter pores, isolated pores, and bifurcated portions (aqueous) in the communicating pores; nonconductive aqueous pores include isolated pores and portions (water) of communication pores that are bifurcated (since the nonconductive aqueous pores are nonconductive as organic pores, the nonconductive aqueous pores are often also calculated into the oil-containing pores when oil content is calculated, resulting in a calculated oil content that is greater than actual), and the organic pores, isolated pores, and portions of communication pores that are bifurcated are small pores; the non-conductive aqueous pores are associated with a cut-off interval of the T2 spectrum of the nmr log.
According to the invention, preferably, the method comprises the steps of:
s1: two kerogen volumes were calculated separately And/>Taking the smaller value of the calculated two types of kerogen volumes as the kerogen volume v KEROGEN, and calculating the organic porosity phi ORG and the inorganic porosity phi IN; further calculating the oil content O corg of the organic hole of the whole well section;
S2: obtaining a porosity ratio from a minimum T2 relaxation time to a different T2 relaxation time cutoff interval;
S3: according to the oil content S t of all the selected cores, calculating nonconductive water-containing porosity S wrin in the inorganic holes with the depths corresponding to the core taking points of all the cores;
s4: calculating total nonconductive water saturation S wr of corresponding depths of all core coring points by utilizing nonconductive water porosity S wrin and organic porosity phi ORG in the inorganic holes;
s5: determining a proper cut-off value interval of the depth corresponding to all core coring points according to the proportion relation between the total nonconductive water saturation S wr of the depth corresponding to all core coring points and the step S2, calculating the ratio of the porosity in the proper cut-off value interval to the total porosity, and determining an S wr input curve of a whole well section with a similar pore structure;
S6: calculating nonconductive water-containing porosity in the inorganic hole of the whole well section by using the S wr input curve S All-around wrin;
S7: calculating the water saturation of inorganic holes of a shale oil reservoir layer of the whole well section S win, the oil saturation of inorganic holes of the whole well section S oin and the oil content of inorganic holes of the whole well section O cin; and further calculate the total oil content O c of the whole well section.
According to the present invention, preferably, in step S1, the formulas for calculating the two types of kerogen volumes are formula (1) and formula (2), respectively:
in the formula (1) and the formula (2):
Phi NMR is the fluid-containing porosity of the shale oil reservoir as determined by nuclear magnetic resonance log T2 spectrum of the shale oil reservoir;
ρ ma is the skeletal density of the shale oil reservoir obtained by lithology scanning logging;
Phi N is the neutron porosity of the shale oil reservoir obtained by compensated neutron logging;
DEN is a density curve of the shale oil reservoir determined by a density logging instrument;
k 1 and k 2 are quantitative calculation correction coefficients obtained from the kerogen content scales of all the selected cores;
ρ f is the fluid density, taken as 1;
ρ KEROGEN is the kerogen density, obtained by core experiments with all cores selected.
The calculation formulas of the organic porosity Φ ORG and the inorganic porosity Φ IN are formula (3) and formula (4):
φORG＝vKEROGEN×φKEROGEN(3)；
φIN＝φNMR-φORG(4)；
In the above-mentioned formula (3),
Phi KEROGEN is the face rate of kerogen determined from the core scanning electron microscopy image.
The formula for calculating the oil content O corg of the organic hole is shown as formula (5):
In the formula (5), ρ o is shale oil density.
According to the present invention, preferably, in step S3, the oil content S t of the depth point where the core is located is obtained by a core experiment performed using the core; the formula for calculating the nonconductive water-containing porosity S wrin in the inorganic holes with the corresponding depths of all core coring points is as formula (6):
In the formula (6) and the formula (7):
s IN is the oil content in the inorganic hole of the depth point, and is obtained by calculation according to the formula (7);
C w is the conductivity of water;
C BG is the conductivity minimum of the depth corresponding to all core coring points, R BG is the maximum value found in the deep detection resistivity log of the depth corresponding to all core coring points,
C Log logging conductivity of the corresponding depth of all core coring points; c Log100 is the full water conductivity of the depth corresponding to all core coring points, and is obtained by reading the flushing zone resistivity R xo of the depth corresponding to all core coring points and combining the resistivity of the borehole mud filtrate.
According to the present invention, preferably, in step S4, the formula for calculating the total nonconductive water saturation S wr of the depth corresponding to the coring point of all the cores is formula (9):
according to the invention, preferably, in step S6, the non-conductive aqueous porosity S All-around wrin in the inorganic pores of the full interval is back-deduced from formula (9).
In accordance with the present invention, preferably, in step S7, the formula for calculating the water saturation of inorganic pores of the shale oil reservoir of the full interval S win is formula (10):
Wherein a=c w;B＝-(CwS All-around wrin+C All-around BG);
Alpha stru is a pore structure factor, and the calculation formula is formula (11):
in the formulas (10) and (11):
c All-around BG is the conductivity minimum for the full interval, R All-around BG is the maximum found in the deep-probe resistivity log through the full interval,
C All-around Log is the logging conductivity of the whole well section;
C All-around Log100 is the full water conductivity of the full interval, obtained by reading the flushing zone resistivity R All-around xo of the full interval, in combination with the wellbore mud filtrate resistivity.
The formula for calculating the inorganic hole oil saturation S oin of the whole well section is shown as formula (13):
Soin＝1-Swin(13)。
The formula for calculating the inorganic hole oil content O cin of the whole well section is shown as formula (14):
The formula for calculating the total oil content O c of the whole well section is formula (15): o c＝Ocin+Ocorg (15).
The invention is further illustrated by the following examples:
Examples
The embodiment provides a method for calculating the oil content of a shale oil reservoir, which is used for calculating the oil content of a Jiang Han oilfield Qianjiang concave shale oil reservoir. Specifically, the method utilizes logging data of a shale oil well of a Qianjiang sunken shale oil reservoir of the Jiang Han oilfield, the logging data comprise core scanning electron microscope data, core oil content data and nuclear magnetic resonance logging data, the organic porosity phi ORG and the inorganic porosity phi IN are calculated, the organic hole oil content O corg of the whole well section is calculated, the total non-conductive water saturation S wr of the whole well section is calculated, the inorganic hole oil content S oin of the whole well section is calculated by utilizing a model for eliminating background conductivity and non-conductive porosity, the inorganic hole oil content O cin of the whole well section is calculated, and the total oil content O c of the whole well section is calculated according to the sum of the organic hole oil content O corg and the inorganic hole oil content O cin, as shown in fig. 2, and the 1 st track on the right of fig. 2 is the total oil content O c of the whole well section; wherein the total nonconductive water saturation S wr of the full wellbore section is the ratio of the porosity of the nonconductive water pores of the full wellbore section to the total porosity.
The method comprises the following steps:
s1: two kerogen volumes were calculated separately And/>Taking the smaller value of the calculated two types of kerogen volumes as the kerogen volume v KEROGEN, and calculating the organic porosity phi ORG and the inorganic porosity phi IN; further calculating the oil content O corg of the organic hole of the whole well section;
S2: obtaining a porosity ratio from a minimum T2 relaxation time to a different T2 relaxation time cutoff interval;
S3: according to the oil content S t of all the selected cores, calculating nonconductive water-containing porosity S wrin in the inorganic holes with the depths corresponding to the core taking points of all the cores;
s4: calculating total nonconductive water saturation S wr of corresponding depths of all core coring points by utilizing nonconductive water porosity S wrin and organic porosity phi ORG in the inorganic holes;
s5: determining a proper cut-off value interval of the depth corresponding to all core coring points according to the proportion relation between the total nonconductive water saturation S wr of the depth corresponding to all core coring points and the step S2, calculating the ratio of the porosity in the proper cut-off value interval to the total porosity, and determining an S wr input curve of a whole well section with a similar pore structure;
S6: calculating nonconductive water-containing porosity in the inorganic hole of the whole well section by using the S wr input curve S All-around wrin;
S7: calculating the water saturation of inorganic holes of a shale oil reservoir layer of the whole well section S win, the oil saturation of inorganic holes of the whole well section S oin and the oil content of inorganic holes of the whole well section O cin; and further calculate the total oil content O c of the whole well section.
Wherein:
In step S1, the formulas for calculating the volumes of the two types of kerogen are formula (1) and formula (2), respectively:
in the formula (1) and the formula (2):
Phi NMR is the fluid-containing porosity of the shale oil reservoir as determined by nuclear magnetic resonance log T2 spectrum of the shale oil reservoir;
ρ ma is the skeletal density of the shale oil reservoir obtained by lithology scanning logging;
Phi N is the neutron porosity of the shale oil reservoir obtained by compensated neutron logging;
DEN is a density curve of the shale oil reservoir determined by a density logging instrument;
k 1 and k 2 are quantitative calculation correction coefficients obtained from the kerogen content scales of all the selected cores;
ρ f is the fluid density, taken as 1;
ρ KEROGEN is the kerogen density, obtained by core experiments with all cores selected.
The calculation formulas of the organic porosity Φ ORG and the inorganic porosity Φ IN are formula (3) and formula (4):
φORG＝vKEROGEN×φKEROGEN(3)；
φIN＝φNMR-φORG(4)；
In the above-mentioned formula (3),
Phi KEROGEN is the face rate of kerogen determined from the core scanning electron microscopy image.
The formula for calculating the oil content O corg of the organic hole is shown as formula (5):
In the formula (5), ρ o is shale oil density.
According to the present invention, preferably, in step S3, the oil content S t of the depth point where the core is located is obtained by a core experiment performed using the core; the formula for calculating the nonconductive water-containing porosity S wrin in the inorganic holes with the corresponding depths of all core coring points is as formula (6):
In the formula (6) and the formula (7):
s IN is the oil content in the inorganic hole of the depth point, and is obtained by calculation according to the formula (7);
C w is the conductivity of water;
C BG is the conductivity minimum of the depth corresponding to all core coring points, R BG is the maximum value found in the deep detection resistivity log of the depth corresponding to all core coring points,
C Log logging conductivity of the corresponding depth of all core coring points; c Log100 is the full water conductivity of the depth corresponding to all core coring points, and is obtained by reading the flushing zone resistivity R xo of the depth corresponding to all core coring points and combining the resistivity of the borehole mud filtrate.
According to the present invention, preferably, in step S4, the formula for calculating the total nonconductive water saturation S wr of the depth corresponding to the coring point of all the cores is formula (9):
In step S6, the non-conductive water-containing porosity S All-around wrin in the inorganic pores of the whole well section is obtained by the reverse of the formula (9).
In step S7, the formula for calculating the water saturation of inorganic pores of the shale oil reservoir of the full interval S win is formula (10):
Wherein a=c w;B＝-(CwS All-around wrin+C All-around BG);
Alpha stru is a pore structure factor, and the calculation formula is formula (11):
in the formulas (10) and (11):
c All-around BG is the conductivity minimum for the full interval, R All-around BG is the maximum found in the deep-probe resistivity log through the full interval,
C All-around Log is the logging conductivity of the whole well section;
C All-around Log100 is the full water conductivity of the full interval, obtained by reading the flushing zone resistivity R All-around xo of the full interval, in combination with the wellbore mud filtrate resistivity.
The formula for calculating the inorganic hole oil saturation S oin of the whole well section is shown as formula (13):
Soin＝1-Swin(13)。
The formula for calculating the inorganic hole oil content O cin of the whole well section is shown as formula (14):
The formula for calculating the total oil content O c of the whole well section is formula (15): o c＝Ocin+Ocorg (15).
And comparing the total oil content O c of the whole well section calculated by the method of the embodiment with the core pyrolysis oil content result of the shale oil well. The comparison result shows that the calculation result of the method disclosed by the invention is very well matched with the rock core data, and the method is feasible.
The foregoing description of embodiments of the invention has been presented for purposes of illustration and description, and is not intended to be exhaustive or limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the various embodiments described.
Claims (1)
1. The method is characterized in that core scanning electron microscope data, lithology scanning logging data and nuclear magnetic resonance logging data are utilized to calculate organic porosity phi ORG and inorganic porosity phi IN, the organic hole oil content O corg of the whole well section is calculated, the total non-conductive water saturation S wr of the whole well section is calculated, the inorganic hole oil saturation S oin of the whole well section is calculated by utilizing a background conductive and non-conductive porosity elimination model, the inorganic hole oil content O cin of the whole well section is calculated, and the total oil content O c of the whole well section is calculated according to the sum of the organic hole oil content O corg and the inorganic hole oil content O cin; wherein the total nonconductive water saturation S wr of the full wellbore section is the ratio of the porosity of the nonconductive water pores of the full wellbore section to the total porosity;
The method comprises the following steps:
s1: two kerogen volumes were calculated separately And/>Taking the smaller value of the calculated two types of kerogen volumes as the kerogen volume v KEROGEN, and calculating the organic porosity phi ORG and the inorganic porosity phi IN; further calculating the oil content O corg of the organic hole of the whole well section;
S2: obtaining a porosity ratio from a minimum T2 relaxation time to a different T2 relaxation time cutoff interval;
S3: according to the oil content S t of all the selected cores, calculating nonconductive water-containing porosity S wrin in the inorganic holes with the depths corresponding to the core taking points of all the cores;
s4: calculating total nonconductive water saturation S wr of the depth corresponding to all core coring points by using the nonconductive water porosity S wrin and the organic porosity phi ORG in the inorganic holes of the depth corresponding to all core coring points;
s5: determining a proper cut-off value interval of the depth corresponding to all core coring points according to the proportion relation between the total nonconductive water saturation S wr of the depth corresponding to all core coring points and the step S2, calculating the ratio of the porosity in the proper cut-off value interval to the total porosity, and determining an S wr input curve of a whole well section with a similar pore structure;
S6: calculating nonconductive water-containing porosity in the inorganic hole of the whole well section by using the S wr input curve S All-around wrin;
S7: calculating the water saturation of inorganic holes of a shale oil reservoir layer of the whole well section S win, the oil saturation of inorganic holes of the whole well section S oin and the oil content of inorganic holes of the whole well section O cin; further calculating the total oil content O c of the whole well section;
In step S1, the formulas for calculating the volumes of the two types of kerogen are formula (1) and formula (2), respectively:
in the formula (1) and the formula (2):
Phi NMR is the fluid-containing porosity of the shale oil reservoir as determined by nuclear magnetic resonance log T2 spectrum of the shale oil reservoir;
ρ ma is the skeletal density of the shale oil reservoir obtained by lithology scanning logging;
Phi N is the neutron porosity of the shale oil reservoir obtained by compensated neutron logging;
DEN is a density curve of the shale oil reservoir determined by a density logging instrument;
k 1 and k 2 are quantitative calculation correction coefficients obtained from the kerogen content scales of all the selected cores;
ρ f is the fluid density, taken as 1;
ρ KEROGEN is kerogen density, obtained by core experiments with all cores selected;
In step S1, the calculation formulas of the organic porosity Φ ORG and the inorganic porosity Φ IN are formula (3) and formula (4):
φORG＝vKEROGEN×φKEROGEN(3)；
φIN＝φNMR-φORG(4)；
In the above-mentioned formula (3),
Phi KEROGEN is the face rate of kerogen determined according to the core scanning electron microscope image;
In step S1, the formula for calculating the oil content O corg in the organic hole is formula (5):
in the formula (5), ρ o is shale oil density;
In step S3, the oil content S t is obtained through a core experiment; the formula for calculating the nonconductive water-containing porosity S wrin in the inorganic holes with the corresponding depths of all core coring points is as formula (6):
In the formula (6) and the formula (7):
s IN is the oil content in the inorganic pores, and is calculated by the formula (7);
C w is the conductivity of water;
C BG is the conductivity minimum of the depth corresponding to all core coring points, R BG is the maximum value found in the deep detection resistivity log of the depth corresponding to all core coring points,
C Log is the logging conductivity of the depth corresponding to the coring point of all the cores; c Log100 is the full water conductivity of the depth corresponding to the core coring points of all the cores, and is obtained by reading the flushing band resistivity R xo of the depth corresponding to the core coring points of all the cores and combining the resistivity of the slurry filtrate of the well bore;
in step S4, the formula for calculating the total nonconductive water saturation S wr of the depth corresponding to the coring point of the core is formula (9):
In the step S6, the non-conductive water-containing porosity S All-around wrin in the inorganic hole of the whole well section is obtained by the reverse thrust of the formula (9);
In step S7, the formula for calculating the water saturation of inorganic pores of the shale oil reservoir of the full interval S win is formula (10):
Wherein a=c w;B＝-(CwS All-around wrin+C All-around BG);
Alpha stru is a pore structure factor, and the calculation formula is formula (11):
in the formulas (10) and (11):
c All-around BG is the conductivity minimum for the full interval, R All-around BG is the maximum found in the deep-probe resistivity log through the full interval,
C All-around Log is the logging conductivity of the whole well section;
C All-around Log100 is the full water conductivity of the full well section, and is obtained by reading the resistivity R All-around xo of the flushing zone of the full well section and combining the resistivity of the slurry filtrate of the well bore;
In the step S7 of the process,
The formula for calculating the inorganic hole oil saturation S oin of the whole well section is shown as formula (13): s oin＝1-Swin (13);
The formula for calculating the inorganic hole oil content O cin of the whole well section is shown as formula (14):
The formula for calculating the total oil content O c of the whole well section is formula (15): o c＝Ocin+Ocorg (15).
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| CN202010897610.1A CN114109373B (en) | 2020-08-31 | 2020-08-31 | Method for calculating oil content of shale oil reservoir by using logging data |
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| US4548071A (en) * | 1983-09-01 | 1985-10-22 | Phillips Petroleum Company | Determination of oil shale yield from well log data |
| CN104712329A (en) * | 2015-01-29 | 2015-06-17 | 中国石油大学(华东) | Computing model of mud shale oil gas saturability |
| CN107808032A (en) * | 2017-09-28 | 2018-03-16 | 中国石油化工股份有限公司 | Shale gas reservoir water saturation computational methods and system |
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| WO2015021088A1 (en) * | 2013-08-06 | 2015-02-12 | Schlumberger Canada Limited | Methods for determining a saturation-height function in oil and gas reservoirs |
| US11187825B2 (en) * | 2015-11-12 | 2021-11-30 | Schlumberger Technology Corporation | Method for formation evaluation of organic shale reservoirs using well logging data |
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| US4548071A (en) * | 1983-09-01 | 1985-10-22 | Phillips Petroleum Company | Determination of oil shale yield from well log data |
| CN104712329A (en) * | 2015-01-29 | 2015-06-17 | 中国石油大学(华东) | Computing model of mud shale oil gas saturability |
| CN107808032A (en) * | 2017-09-28 | 2018-03-16 | 中国石油化工股份有限公司 | Shale gas reservoir water saturation computational methods and system |
| CN110687612A (en) * | 2019-09-17 | 2020-01-14 | 中国石油天然气股份有限公司 | Shale oil analysis method and device for continuously representing content of adsorbed oil and free oil |
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