LU102603A1 - Method for quantitatively evaluating natural gas diffusion rate - Google Patents
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- 235000016068 Berberis vulgaris Nutrition 0.000 description 1
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Abstract
The method includes the following steps: calculating a hydrocarbon generation intensity of a source rock; determining a hydrocarbon expulsion coefficient of the source rock applicable to a study area, and calculating a hydrocarbon expulsion intensity by multiplying the hydrocarbon generation intensity by the hydrocarbon expulsion coefficient; calculating a natural gas diffusion volume according to Pick's first law, and dividing the natural gas diffusion volume by a natural gas diffusion area to obtain a natural gas diffusion intensity; dividing the natural gas diffusion intensity by the hydrocarbon expulsion intensity of the source rock to obtain a natural gas diffusion rate; and determining a natural gas diffusion degree of a gas reservoir according to the natural gas diffusion rate.
Description
DESCRIPTION LU102603
TECHNICAL FIELD The present disclosure relates to a method for quantitatively evaluating a natural gas diffusion rate of a gas reservoir, which is particularly suitable for the quantitative evaluation of a natural gas diffusion degree and evaluation of a gas field preservation condition, and belongs to the technical field of natural gas diffusion.
BACKGROUND Natural gas has strong diffusivity underground due to its small molecules, light weight and strong mobility. The diffusion of natural gas is a migration process from concentration to dispersion. Although the diffusion of natural gas in underground rocks is very slow, it can proceed continuously in the long geological history, thus producing a very considerable cumulative diffusion volume. A large number of studies have shown that such diffusion is enough to destroy a natural gas reservoir with industrial exploitation value. Therefore, the establishment of a determination method for the natural gas diffusion degree is of great significance for the study of natural gas migration, accumulation and preservation, and for the evaluation of prospective resources.
Existing research mainly focuses on the calculation of the natural gas diffusion volume based on Fick's first law, but there is very little research on the natural gas diffusion degree. In order to quantitate the natural gas diffusion degrec of the gas reservoir, the present disclosure first proposes the concept of natural gas diffusion rate and a calculation method thereof. According to the present disclosure, the natural gas diffusion rate is a percentage of a natural gas diffusion volume to a natural gas reserve, which can be determined by dividing a natural gas diffusion intensity by a hydrocarbon expulsion intensity of a source rock.
SUMMARY An objective of the present disclosure is to provide a method for calculating a natural gas diffusion rate. The present disclosure realizes quantitative evaluation of a natural gas diffusion degree, and solves the problem that the current natural gas diffusion degree quantitative evaluation standard is scparated from the natural gas reserve.
To achieve the above objective, the present disclosure adopts a technical solution as follows: A method for quantitatively evaluating a natural gas diffusion rate, including the following steps: s1: calculating a hydrocarbon gencration intensity of a source rock per unit area;
s2: determining a hydrocarbon expulsion coefficient of the source rock applicable to a LU102603 target area, and calculating a hydrocarbon expulsion intensity of the source rock by multiplying the hydrocarbon generation intensity of the source rock by the hydrocarbon expulsion coefficient thereof; s3: deriving a calculation equation for a natural gas diffusion volume of a gas reservoir by a natural gas diffusion geological model according to Fick's first law, calculating the natural gas diffusion volume, and dividing the natural gas diffusion volume by a natural gas diffusion area to obtain a natural gas diffusion intensity; s4: dividing the natural gas diffusion intensity by the hydrocarbon expulsion intensity of the source rock to obtain a natural gas diffusion rate; and s5: determining a natural gas diffusion degree of the gas reservoir and evaluating a preservation condition of the gas reservoir according to the natural gas diffusion rate.
In step sl, a mathematical model of the hydrocarbon generation intensity of the source rock per unit area is Q,=Hep,*K*Cresidual*Dgas*10*, where H represents a thickness of the source rock (m); pr represents a density of the source rock (t/m*); K represents a recovery coefficient of original organic carbon; Cresidual represents a residual organic carbon content in the source rock (%); Deas represents a gaseous hydrocarbon yield of original organic matter (m*A.Toc); Q represents the hydrocarbon generation intensity (<10* m*/km?).
The hydrocarbon generation intensities of two types of source rocks, namely Permo- Carboniferous coal and dark mudstone, arc calculated and summed to obtain a total hydrocarbon generation intensity: a curve is plotted based on a cumulative oil and gas yield map of type III organic matter: an oil yield curve shows that after a peak of liquid hydrocarbon generation. a liquid hydrocarbon is continuously cracked into a gaseous hydrocarbon: by converting an oil production into a gas production by equating 1 ton of oil to about 700 m* of natural gas, the gaseous hydrocarbon yield of original organic matter is obtained.
In step s2, the hydrocarbon expulsion coefficient of the source rock refers to a ratio of a hydrocarbon expulsion volume of the source rock to a hydrocarbon generation volume thercof.
In step s2, the hydrocarbon expulsion coefficient of the source rock is 75%.
In step s3, the caleulation equation for the natural gas diffusion volume of the gas reservoir is Os = me , where Quirusea represents the natural gas diffusion volume of the gas reservoir (m?); C represents a gas concentration in the gas reservoir (m*/m*}; Co represents a gas concentration on a surface (mm); D represents a coefficient of natural gas diffusion in an overlying stratum of the gas reservoir (m“/s); t represents a LU102603 natural gas diffusion time of the gas reservoir (s); Z represents a natural gas diffusion distance of the gas reservoir (m).
In step s3, a gas-bearing area of the gas reservoir is taken as the natural gas diffusion area; in a zone where well drilling is completed, a boundary of the gas-bearing area is delineated according to well drilling data by comprehensive consideration based on a half well spacing and effective sandstone thickness distribution; in a zone where well drilling is not completed, the boundary of the gas-bearing area is delineated by a control area of a river channel based on a sedimentary characteristic research result.
In step s3. a buried depth of the gas reservoir is taken as the natural gas diffusion distance, and the natural gas diffusion time in the gas reservoir is 140 Ma.
The present disclosure has the following advantages. The present disclosure first proposes the concept of natural gas diffusion rate and a calculation method thercof. The present disclosure combines the natural gas diffusion intensity with the hydrocarbon expulsion intensity of the source rock, and uses the natural gas diffusion rate to quantitate the natural gas diffusion degrec of the gas reservoir. The present disclosure provides a new way lo quantitate the natural gas diffusion degree of the gas reservoir, and to evaluate the preservation condition of the gas reservoir.
BRIEF DESCRIPTION OF DRAWINGS FIG. 1 shows a cumulative hydrocarbon yield curve of type III organic matter.
FIG. 2 shows a contour map of a hydrocarbon generation intensity of a Permo- Carboniferous coal in the Su X block of the Sulige gas field.
FIG. 3 shows a contour map of a hydrocarbon generation intensity of a Permo- Carboniferous dark mudstone in the Su X block of the Sulige gas field.
FIG. 4 shows a contour map of a total hydrocarbon generation intensity of a Permo- Carboniferous source rock in the Su X block of the Sulige gas field.
FIG. 5 shows a contour map ol a hydrocarbon expulsion intensity of the Permo- Carboniferous source rock in the Su X block of the Sulige gas field.
FIG. 6 shows a natural gas diffusion geological model.
FIG. 7 shows a contour map of a diffusion rate of a Permo-Carboniferous gas reservoir in the Su X block of the Sulige gas field.
DETAILED DESCRIPTION The present disclosure is described in more detail below with reference to the accompanying drawings and specific implementations.
An embodiment of the present disclosure provides a method for quantitatively LU102603 evaluating a natural gas diffusion rate. In this embodiment. the Su X block in the Sugeli gas field is a target area. and the method includes the following steps: sl: Calculate a hydrocarbon generation intensity of a source rock per unit area.
A mathematical model of the hydrocarbon generation intensity of the source rock per unit arca is Q.—HepreKeCresigual*Deas* 1077, where H represents a thickness of the source rock (m}; pr represents a density of the source rock (Vm*); K represents a recovery coefficient of original organic carbon; Cresidual represents a residual organic carbon content in the source rock (%}: Deas represents a gascous hydrocarbon yield of original organic matter (m'/t. Toc); (u represents the hydrocarbon generation intensity (x 10% m*/km?).
There are two types of source rocks. Permo-Carboniterous coal and dark mudstone. In the Su X block of the Sulige gas field. the density of the Permo-Carboniferous dark mudstone is generally 2.5-2.65 (t/m°). and an average of 2.6 t/m° is taken for calculation; the density of the Permo-Carboniferous coal is taken as 1.55 t/m* for calculation.
Table 1 is available from a literature published by Zheng Haigiao in 2016. As shown in Table 1, the average organic carbon contents of the Permo-Carboniferous coal and dark mudstone are taken for calculation, which are about 73.423% and about 2.707%. respectively.
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FIG. 1 is available from a literature published by Wang Bo in 2010. It shows a cumulative Lu102603 oil and gas yield map of type III organic matter, which was established based on simulation results of Upper Triassic lignite in the Sichuan Basin, À curve was plotted according to the cumulative oil and gas yicld map of type HI organic matter. The vitrinite reflectance Rs of the coal in the Su X block is between 1.3% and 2.0%, and calculating by a median value of
1.6% leads to a gas yield of 135 m*t TOC and an oil yield of 7.5 kg/t TOC. An oil yield curve shows that after a peak of liquid hydrocarbon generation. a liquid hydrocarbon is continuously cracked into a gaseous hydrocarbon. By converting an oil production into a gas production by equating 1 ton of oil to about 700 m* of natural gas. a gaseous hydrocarbon yield of the original organic matter is calculated as ga, =140.25 m*/t TOC, According to a classification standard derived by Tissot et al., a recovery coefficient of original organic carbon in the Su X block of the Sulige gas field is K=1.57.
The hydrocarbon generation intensities of the Permo-Carboniferous coal and dark mudstone are calculated and summed to obtain a total hydrocarbon generation intensity, as shown in Table. 2.
Table 2 shows a thickness of the source rock in the Su X block of the Sugeli gas field.
FIGS. 2. 3 and 4 respectively show the hydrocarbon generation intensity and total hydrocarbon generation intensity of different source rocks. The total hydrocarbon generation intensity of the Su X block in the Sugeli gas field is 20x10® m*/km? to 36x10® m*/km?, and the maximum hydrocarbon generation intensity of well S173 reaches 36x 10° m*/km?.
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L | | | | | | | s2: Determine a hydrocarbon expulsion coefficient of the source rock applicable to the LU102603 study areu. and calculate a hydrocarbon expulsion intensity of the source rock by multiplying the hydrocarbon generation intensity of the source rock by the hydrocarbon expulsion coefficient thereof, The hydrocarbon expulsion coefficient of the source rock refers to a ratio of a hydrocarbon expulsion volume of the source rock to a hydrocarbon generation volume thereof.
The organic matter of the Permo-Carboniferous source rock is mainly type III; its thermal evolution reaches a mature to high mature stage, and its abundance is generally high. The natural gas in the source rock is mainly expulsed through gas expansion. micro- fractures, etc.. and the hydrocarbon expulsion coefficient is determined as 75%.
The hydrocarbon gencration intensity of the source rock is multiplied by the hydrocarbon expulsion coefficient thereof to obtain the hydrocarbon expulsion intensity of the source rock. as shown in Table 3.
FIG. 5 shows a contour map of the hydrocarbon expulsion intensity of the Permo- Carboniferous source rock in the Su X block of the Sulige gas field. The hydrocarbon expulsion intensity of the source rock in the Su X block of the Sulige gas field is between 15<10* m¥km” and 27<10* m°/km°, and is higher than 27x10* m¥km® in some well (well S193).
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$3: Derive a calculation equation tor a natural gas diffusion volume of a gas reservoir by LU102603 a natural gas diffusion geological model according to Fick's first law. calculate the natural gas diffusion volume. and divide the natural gas diffusion volume by a natural gas diffusion area to obtain a natural gas diffusion intensity.
Due to the difference in the gas concentration between the gas reservoir and an overlying stratum. the natural pas can diffuse to the surface through rock pores of the overlying stratum. This process is shown by the geological model in FIG. 6.
The calculation equation for the natural gas diffusion volume of the gas reservoir is Os = PL where Quifused represents the natural gas dillusion volume of the gas reservoir (m*); © represents a gas concentration in the gas reservoir (m*/m*}; Cu represents a gas concentration on a surface (m*/m?); S represents a natural gas diffusion area of the gas reservoir (m7): D represents a coefficient of natural gas diffusion in an overlying stratum of the gas reservoir (m*/s); t represents a natural gas diffusion time of the gas reservoir (s): Z represents a natural gas diffusion distance of the gas reservoir (m).
According to a literature published by Li Jianmin in 2009, in the Su X block of the Sulige gas field, the gas concentration difference (C-Co) between the gas reservoir and the surface and the coefficient (D) of natural gas diffusion in the overlying stratum are 2.66 m*/m’ and 0.8x 1079 m* /s respectively.
A gas-bearing area of the gas reservoir 1s taken as the natural gas diffusion area. In a zone where well drilling is completed, a boundary of the gas-bearing area is delincated according to well drilling data by comprehensive consideration based on a half well spacing and effective sandstone thickness distribution. In à zone where well drilling is not completed, the boundary of the gas-bearing area is delincated by a control arca of a river channel based on a sedimentary characteristic research result. The gas-bearing area of the gas reservoir is
1773.788 km? according to statistics.
As the natural gas diffuses from the gas reservoir to the surface. a buried depth of the gas reservoir can be regarded as the natural gas diffusion distance. For a gas reservoir in the Shan and Hes members, its average buried depth is 3579 m. The natural gas accumulation period is mainly concentrated in the Late Jurassic to Early Cretaceous. and the natural gas diffusion time of the gas reservoir is 140 Ma.
The natural gas diffusion volume Quittuseu is calculated as 4656.4 10° m°. and dividing it by the gas-bearing area of the gas reservoir, namely 1.773.788 km“, leads to a natural gas diffusion intensity of 2.63* 10% m*/km7.
s4: Divide the natural gas diffusion intensity by the hydrocarbon expulsion intensity of LU102603 the source rock to obtain a natural gas diffusion rate. The natural gas diffusion rates of different wells are shown in Table 4. $a — st — — Fa — fot Tt m] | = ia] &| | ©] wf Ja SI 2 Fa Lu at a ~~] ~J ta > Zl = Sl ®
F nd ao 4 bre à =
LG [= © = ol = =| | Bw] 6 = S = = w| © Ww of Ww La] =| w| Ww = o wy
2.1 © 8 = 8 mn = & oo = — ao — —
LA bo wml wn UN] LA] LA) wl LA] unl wl LA = a — —| —| pt | | | pe | pet | peek [ND A| æ| of oof cof of al la] a] a S| OQ Cas A | Lei DD) Ww ee | OWA NO > zZ ps past pou Jo oi — Jd. — — — m >| of | | 2 NN | = = La] bb] of La] I | wol Ww bi] ta Sr wv Z. — 8 nm >
E FIG. 7 shows a contour map of the diffusion rate of the Permo-Carboniferous gas reservoir in the Su X block of the Sulige gas field, which indicates that the natural gas diffusion rate in the Su X block of the Sulige gas field is dominated by 11% to 17%. $5: Determine a natural gas diffusion degree of the gas reservoir and evaluate a preservation condition of the gas reservoir according to the natural gas diffusion rate.
According to the calculation and analysis above. the natural gas diffusion rate in the Su LU102603 X block of the Sulige gas field is small and dominated by 11% to 17%. indicating that the gas reservoir has a low diffusion degree and a good preservation condition.
Fach embodiment of the present specification is described in a related manner, each embodiment focuses on the difference from other embodiments, and the same and similar parts between the embodiments may refer to each other. For a system embodiment, since it corresponds to the method embodiment. the description is relatively simple, and reference can be made to the description of the method embodiment.
Any modifications, equivalent substitutions and improvements made within the spirit and scope of the present disclosure should fall within the protection scope of the present disclosure. Any modifications. equivalent substitutions and improvements made within the spirit and scope of the present disclosure should fall within the protection scope of the present disclosure.
Claims (8)
1. A method for quantitatively evaluating a natural gas diffusion rate. comprising the following steps: sl: calculating a hydrocarbon generation intensity of a source rock per unit area: s2: determining a hydrocarbon expulsion coefficient of the source rock applicable to a target arca. and calculating a hydrocarbon expulsion intensity of the source rock by multiplying the hydrocarbon gencration intensity of the source rock by the hydrocarbon expulsion coefficient thereol: s3: deriving a calculation equation for a natural gas diffusion volume of à gas reservoir by a natural gas diffusion geological model according to Fick's first law. calculating the natural gas diffusion volume. and dividing the natural gas diffusion volume by a natural gas diffusion area to obtain a natural gas diffusion intensity: s4: dividing the natural gas diffusion intensity by the hydrocarbon expulsion intensity of the source rock to obtain a natural gas diffusion rate: and s5: determining a natural gas diffusion degree of the gas reservoir and evaluating a preservation condition of the gas reservoir according to the natural gas diffusion rate.
2. The method for quantitatively evaluating a natural gas diffusion rate according to claim |. wherein in step s1. a mathematical model of the hydrocarbon generation intensity of the source rock per unit area is Q:=HepreKeCresidual*Deast 104. wherein H represents a thickness of the source rock (m); pr represents a density of the source rock (Um): K represents a recovery coefficient of original organic carbon; Cresidual represents a residual organic carbon content in the source rock (%); Deas represents a gascous hydrocarbon yield of original organic matter (mt. Toc): Qe represents the hydrocarbon generation intensity (<10* m°*/km7).
3. The method for quantitatively evaluating à natural gas diffusion rate according to claim 2. wherein in the mathematical model of the hydrocarbon generation intensity of the source rock per unit area, the hydrocarbon generation intensities of two types of source rocks. namely Permo-Carboniferous coal and dark mudstone. are calculated and summed to obtain a total hydrocarbon generation intensity: a curve is plotted based on a cumulative oil and gas yield map of type III organic matter; an oil yield curve shows that after a peak of liquid hydrocarbon generation. a liquid hydrocarbon is continuously cracked into a gaseous hydrocarbon; by converting an oil production into a gas production by cquating | ton of oil to about 700 m* of natural gas. the gascous hydrocarbon yield of original organic matter is obtained.
4. The method for quantitatively cvaluating a natural gas diffusion rate according to LU102603 claim 1. wherein in step $2. the hydrocarbon expulsion coefficient of the source rock refers to a ratio of a hydrocarbon expulsion volume of the source rock to a hydrocarbon generation volume thereof.
5. The method lor quantitatively evaluating a natural gas diffusion rate according to claim 1. wherein in step s2. the hydrocarbon expulsion coefficient of the source rock is 75%.
6. The method for quantitatively evaluating a natural gas diffusion rate according to claim 1. wherein in step s3. the calculation equation for the natural gas diffusion volume of the gas reservoir is Oued PAC CO wherein Qaitlused represents the natural gas He Zz diffusion volume of the gas reservoir (m*); C represents a gas concentration in the gas reservoir (m/m°); Co represents a gas concentration on a surface (m*Ym*); D represents a coefficient of natural gas diffusion in an overlying stratum of the gas reservoir (m°/s): t represents a natural gas diffusion time of the gas reservoir (s): 7 represents a natural gas diffusion distance of the gas reservoir (m).
7. The method for quantitatively evaluating a natural gas diffusion rate according to claim 1. wherein in step s3, a gas-bearing arca of the gas reservoir is taken as the natural gas diffusion area: in à zone where well drilling is completed, à boundary of the gas-bearing area is delineated according to wel! drilling data by comprehensive consideration based on a half well spacing and effective sandstone thickness distribution: in a zone where well drilling is not completed. the boundary of the gas-bearing area is delineated by a control area of a river channel based on a sedimentary characteristic rescarch result.
8. The method for quantitatively evaluating a natural gas diffusion rate according to claim 1. wherein in step s3. a buried depth of the gas reservoir is taken as the natural gas diffusion distance. and the natural gas diffusion time in the gas reservoir is 140 Ma.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010672286.3A CN111915447B (en) | 2020-07-14 | 2020-07-14 | Quantitative evaluation method for natural gas diffusion dissipation rate |
Publications (2)
| Publication Number | Publication Date |
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| LU102603A1 true LU102603A1 (en) | 2021-08-26 |
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