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Article

A Method for Predicting the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults

by
Tianqi Zhou
,
Yachun Wang
,
Hongqi Yuan
*,
Yinghua Yu
and
Yunfeng Zhang
Heilongjiang Oil and Gas Reservoir Forming Mechanism and Resource Evaluation Key Laboratory, Northeast Petroleum University, Daqing 163318, China
*
Author to whom correspondence should be addressed.
Processes 2024, 12(9), 2055; https://doi.org/10.3390/pr12092055
Submission received: 1 August 2024 / Revised: 29 August 2024 / Accepted: 18 September 2024 / Published: 23 September 2024
(This article belongs to the Section Energy Systems)
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Abstract

:
Regional mudstone cap rock has an important influence on the oil and gas distribution of the oil source faults below it. Therefore, studying the influence of these mudstone cap rocks on the hydrocarbon distribution pattern is fundamental to understanding the oil and gas distribution of the lower generation and upper reservoir reservoirs in the Bohai Bay Basin. This study classified two types of hydrocarbon diversion from oil source faults: blockage diversion and seepage diversion. To locate them, we established a method to predict the areas with blockage diversion and seepage diversion separately by superimposing the sealing and leakage parts of the regional mudstone cap rock with the regions of the connected distribution of sand bodies and the favorable hydrocarbon transport sites of the oil source faults, respectively. We used this approach to predict the locations where hydrocarbons are diverted by the oil source faults under the regional mudstone cap rocks in the first and second sections of the Dongying Formation (E3d1-2) in the Liuchu area of the Raoyang Sag, Bohai Bay Basin. The results show that the regional mudstone cap rock’s blockage diversion occurs mainly in the south-central area of Liuchu, with a localized distribution in the northern part. The seepage diversion site is primarily located in the northeastern area and is also found locally in the west. Both diversions are beneficial for the accumulation of hydrocarbons from the source rocks of the first member of the Shahejie Formation (E3s1) to the upper second member of the Dongying Formation (E3d2U). The latter can also accumulate hydrocarbons in the Guantao Formation (N1g). The results align with the hydrocarbon distribution, demonstrating the feasibility of our method to predict various oil source fault diversion sites under the regional mudstone cap rock. This prediction method offers valuable guidance for exploring the lower generation and upper reservoir hydrocarbon accumulations in hydrocarbon-bearing basins.

1. Introduction

For the source–reservoir–seal combination featured with a lower generation and upper reservoir in the hydrocarbon-bearing basins, oil source faults (i.e., the active faults in the hydrocarbon accumulation period connect the source rock and the target layer) have an important influence on oil and gas migration and accumulation, and hydrocarbons mainly gather in the vicinity of the oil source fault. The oil source fault must encounter the regional mudstone cap rock during upward hydrocarbon migration in the depression area. The different hydrocarbon diversion effects of the regional mudstone cap rocks on the oil source faults determine the pattern and position of hydrocarbon migration, which further affects the hydrocarbon accumulation and distribution [1]. The oil source faults are defined as the active faults in the hydrocarbon accumulation period that connect the source rock and the target layer [2,3,4,5]. It is essential to accurately predict the migration of hydrocarbons from oil source faults controlled by regional mudstone cap rock. This understanding is crucial for identifying the distribution pattern of hydrocarbons beneath the cap rocks and guiding exploration in hydrocarbon-bearing basins.
Scholars have previously studied and discussed to some extent the effect of the regional mudstone cap rock on hydrocarbon migration through oil source faults, most of which can be mainly summarized into three situations. The first is to research whether the regional mudstone cap rocks can terminate the upward migration of hydrocarbons by the oil source faults depending on the damage degree of the oil source fault to the cap rock [6,7,8,9,10]. When the oil source fault significantly damages the regional mudstone cap rock, the oil and gas will continue to migrate upwards through the oil source fault. However, suppose the cap rock is only slightly damaged (i.e., the oil source faults develop above and below the regional mudstone cap and are not interconnected [3]). In this case, the regional mudstone cap rock will prevent the oil source faults from transporting hydrocarbons upward. The second aspect is to study the hydrocarbon piercing area of the regional mudstone cap rock by identifying the regional mudstone cap rock’s leakage area and the preferred sites for transporting oil from the source fault [11,12]. The superimposed area for the leakage area and preferred sites is considered the cap rock’s piercing area with upward hydrocarbon migration through the oil source faults. The third aspect is to study the favorable area with the lateral hydrocarbon diversion migration from the oil source faults by stacking the confined area of the cap rocks and the favorable transport sites of the oil source fault [13,14,15,16]. These studies are essential for the accurate mapping of oil and gas distribution above and below the cap rocks in hydrocarbon-bearing basins, as well as for guiding hydrocarbon exploration.
However, these studies are all conducted from the perspective of hydrocarbon migration through oil source faults. Studies have been limited to the impact of cap rocks on the diversion migration of hydrocarbons from oil source faults and the associated controlling factors. As a result, more research on the hydrocarbon distribution pattern under the mudstone cap rocks is required, further restraining the in-depth hydrocarbon exploration under regional mudstone cap rocks. Therefore, this study’s method is highly significant for accurately understanding the distribution pattern of hydrocarbons under the regional mudstone cap rock in hydrocarbon-bearing basins, as well as for guiding hydrocarbon exploration.
This study analyzes various oil source fault diversion sites under the regional mudstone cap rock based on the configuration of oil source fractures and regional mudstone cap rock. We analyze drilling data to calculate the ratio of sand to mud in the reservoir. Then, we compare this ratio with the ratio required for the formation of continuous sand bodies. This helps us identify the accumulation area of continuous sand bodies. Afterward, the fault throw and sedimentary layer thickness are determined using logging and seismic data. Then, the sealing part of the regional mudstone cap rock, seepage area, and the favorable hydrocarbon transport sites of the oil source fault can be analyzed. By superimposing the set of contiguous sand bodies, the regional mudstone cap rock and the favorable hydrocarbon transport sites of the fault, we can identify the different diversion sites of the oil source fault under the regional mudstone cap rock. This method of prediction is simple and practical, and it serves as a useful guide for exploring similar hydrocarbon-bearing basins.

2. Geological Setting

The Liuchu area is located in the south-central part of the Raoyang Sag in the Jizhong Depression of the Bohai Bay Basin, China (Figure 1a), which is an asymmetric inherited anticline structure formed by the bi-directional compression at the eastern and western boundary faults [17,18]. It is an important area that has not been studied yet. It extends northeast for about 22 km and has a width of approximately 15 km, covering a total area of around 242 km2. The strata developed in this area from the bottom to the top are mainly Palaeogene (Kongdian Formation (E2k), Shahejie Formation (E3s), and Dongying Formation (E3d)), Neogene (Guantao Formation (N1g) and Minghuazhen Formation (N2m)), and a small amount of Quaternary (Q) [19]. Most hydrocarbons are discovered in the Dongying Formation, with a limited distribution in the Shahejie Formation, Guantao Formation, and Minghuazhen Formation. Hydrocarbons are mainly supplied from the underlying E3s1 source rock [18,20,21]. The source–reservoir–cap assemblage is classified as the lower source and upper reservoir type [22]. The E3s1 layer primarily consists of braided rivers, with mainly conglomerate and sandstone lithology. Occasionally, there are red mudstones at the bottom, indicating an oxidizing environment. The middle section comprises deep lake sedimentary rocks, predominantly mudstone with a general gray color and occasional thin limestone layers. The upper part shows delta deposition, characterized by mainly sandstone lithology with a thin layer of mudstone, and a gray color. The middle and lower parts of the Dongying Formation are shallow lake sediments, mainly mudstone. The bottom is dark red, the middle is gray siltstone, and the upper part is braided river deposition, which is composed of sandstone and mudstone interbeds (Figure 2) [23]. Figure 1c shows that the oil and gas discovered in the E3d2U Formation in the Liuchu area are primarily located in the north, with a small amount in the west-central part of the area, which is due to the effect of the E3d1-2 regional mudstone cap rocks on the diversion of oil and gas transported along the oil source faults. It is crucial to predict how the regional mudstone cap rocks affect the diversion of hydrocarbon migration through the oil source faults in the Liuchu area.

3. Method

3.1. The Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults

The type and position of the hydrocarbon diversion migration from the oil source fault conduit controlled by the regional mudstone cap rock is variable based on the destruction level of the cap rock by the fault. When the oil source fault damages the regional mudstone cap rock to a relatively small extent (the oil source fault grows in segments within the regional mudstone cap rock without a connection between the top and bottom), the regional mudstone cap rock has a blockage diversion effect on the hydrocarbon migration through the oil source fault. The regional mudstone cap rock blocks the upward migration of oil and gas from the oil source fault. The lateral migration into the underlying sand body occurs after diversion from the fault (Figure 3a). In areas where mudstone cap rocks are present and there is a blockage diversion, a closed portion of the caps connects to the distribution area of the sand body and the oil source faults. These areas are favorable for transporting oil and gas (Figure 4a).
In contrast, when the regional mudstone cap rock is seriously damaged by the oil source fault (the oil source fault segments are connected up and down after the independent growth within the regional mudstone cap rock), the regional mudstone cap rock has a seepage diversion effect on the hydrocarbon migration through the oil source fault. The hydrocarbons migrated through the oil source fault and continued upward across the regional mudstone cap rock. However, due to the blocking effect of the overlying regional mudstone seal, lateral diversion migration into the sand body also occurs below the regional mudstone cap rock (Figure 3b). Considering the top-most regional mudstone cap rock is sealing, the seepage diversion area of hydrocarbon migration should be the coupling of the seepage area of the regional mudstone cap rock and sand body connective distributed area, and the oil source fault contains favorable hydrocarbon transport sites developed in the reservoir under the regional mudstone cap rock (Figure 4b).

3.2. Prediction Method for the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbon Migration through the Oil Source Faults

In the preceding section, it was explained that the prediction method varies with the different types and locations of hydrocarbon diversion from oil source faults, influenced by the regional mudstone cap rock.

3.2.1. Prediction Method for Blockage Diversion Site

To predict the regional mudstone cap rock blockage diversion area, it is essential to determine the sealing part of the regional mudstone cap rocks, the area with connected distribution of sand bodies, and the dominant position of oil source fault upward migration.
The fault throw of the oil source faults in the regional mudstone cap rock and the thickness of the cap rocks can be determined by using drilling and seismic data. The paleo fault throw of the oil source fault is calculated by the maximum fault distance subtraction method [25,26,27,28,29], and the stratigraphic thickness recovery method is utilized [30,31,32,33] when recovering the paleo thickness of the mudstone cap rocks. Afterward, the latter is subtracted from the former to obtain the paleo thickness of the fault throw in the regional mudstone cap rocks. Using the method in [34], the maximum juxtaposition thickness required for the oil source faults to grow and shrink in the mudstone cap rock is determined (Figure 5a). The sealing ability of the regional mudstone cap rock is determined by comparing the relative size of the break thickness of the regional mudstone cap rock and the maximum juxtaposition thickness required to link the fault segments in the cap rock. The sealing area of the regional mudstone cap rock is defined where the paleo juxtaposition thickness is equal to or greater than the required maximum juxtaposition thickness for connecting the fault segments upward and downward within the regional mudstone cap rock, as illustrated in Figure 4a.
The minimum sand-to-shale ratio needed for the connected distribution of sand bodies in the reservoirs of the study area was determined based on the prediction method described in the literature [35] (Figure 5b). Drilling data are used for the calculation of the sand-to-shale ratio. The area of connected distribution of sand bodies under the regional mudstone cap rock is determined when the derived sand-to-shale ratio is greater than or equal to the minimum stratigraphic sand-to-shale ratio required for the continuous distribution of sand bodies (Figure 4a).
Seismic data are used to measure the current distance of faults in oil sources. We use the maximum fault throw subtraction method [36,37] to recover the paleo fault throw during the hydrocarbon accumulation period. The throw of the ancient fault is divided by the corresponding period to calculate the ancient activity velocity of the oil source fault in the reservoir beneath the regional mudstone cap rock. Furthermore, we identify the minimum activity rate required for hydrocarbon migration in our study area using the method described in the literature [3] (Figure 5c). The oil and gas migration path can be identified by calculating the historical activity rate of the oil source fault under the mudstone cap rock. The minimum activity rate is calculated, and if the historical activity rate is greater than or equal to the minimum activity rate, then the regional mudstone cap rock assists in the upward migration of oil and gas from the oil source fault below.
By superimposing the determined sealing part of the regional mudstone cap rock, the area of connected distribution of sand bodies, and the favorable sites for transporting hydrocarbons from the oil source fault in the reservoir under the regional mudstone cap rocks (Figure 4a), we can identify the sites with hydrocarbon blockage diversion from the oil source fault by the regional mudstone cap rocks.

3.2.2. Prediction Method for Seepage Diversion Site

Similarly, to predict the hydrocarbon seepage diversion area of regional mudstone cap rock to the oil source fault, the leakage area of regional mudstone cap rock, the location of the connected distribution of sand bodies, and the favorable sites for transporting hydrocarbons from the oil source fault in the reservoir under the regional mudstone cap rocks must be determined.
The seepage diversion area of the regional mudstone cap rock can be determined by identifying the location where the thickness of the faults in the regional mudstone cap rock is less than the maximum juxtaposition thickness required for the fault to penetrate upward and downward. This method is illustrated in Figure 4b.
By superimposing the seepage diversion area of regional mudstone cap rock, the area with connected distribution of sand bodies, and the favorable sites for transporting hydrocarbons from the oil source fault, we can obtain the sites of hydrocarbon seepage diversion from the oil source fault by the regional mudstone cap rock (Figure 4b).

4. Results and Discussion

Based on the drilling data, we obtained the distribution of the regional mudstone cap rocks of the E3d1-2 Formations in the Liuchu area. Figure 6 shows that the maximum thickness of the E3d1-2 regional mudstone cap rocks in the Liuchu area is over 550 m, mostly distributed in the southeast and north. The thickness gradually decreases from the two high-value areas to the surrounding area (i.e., 50 m in the southwest). The seismic data illustrate that many fault types exist in the regional E3d1-2 mudstone cap rocks in the Liuchu area. The faults originating from the E3s1 source rocks connect with the E3d1-2 formations and are active during the middle and late stages of deposition of the N2m. This is the period when hydrocarbons in the region start to accumulate. The drilling and seismic data were utilized to estimate the predominance of oil source faults in the northern part of the Liuchu area, with secondary development in the south-central area, as depicted in Figure 1. At the same time, using the data provided, we employed the maximum fault distance subtraction method to determine the paleo fault throw of oil source faults from the middle to the late stage of N2m deposition. Additionally, we utilized the ancient stratigraphic thickness recovery method to restore the paleo thickness of the mudstone cap rocks during the hydrocarbon accumulation period [38,39,40]. By subtracting the two, we obtained the ancient break thickness of the E3d1-2 cap rock. The maximum juxtaposition thickness of the segments of the oil source fault in the Liuchu area needed to connect both upward and downward within the E3d1-2 regional mudstone cap rock is about 275 m (see Figure 7). This information allows us to determine the blockage and seepage area of the cap rock in the Liuchu area. As shown in Figure 8, the seepage area of the E3d1-2 regional mudstone cap rocks in the Liuchu area is pervasively distributed in the northeastern and western parts. The rest of the area is the blockage area.
The sand-to-shale ratio of the E3d2U Formation can be obtained from the drilling data. Figure 9 shows that the maximum sand-to-shale ratio of the members in the Liuchu area is over 30%, dominantly in the north-central and southwestern parts. The sand-to-shale ratio of the E3d2U Formation gradually decreases from the three areas of high value to the surrounding areas. The ratio decreases to less than 10% in the northern part. Using the minimum cutoff value of the sand-to-shale ratio, at about 15%, we found that the area with connected distribution of sand bodies of the upper E3d2 member is mainly distributed in the south-central part of the Liuchu area and secondly distributed in the northern part (Figure 10).
Firstly, the current fault throw of the upper E3d2 member is measured. The method of maximum fault throw subtraction is used to determine the distance of the ancient fault throw during the middle-late stage of the N2m oil and gas accumulation period. Then, the ancient fault throw is divided according to the active fault period, and the activity rate of the ancient fault distance for the oil source fault is calculated. It is estimated that the minimum activity rate required for oil and gas migration of oil source faults in the Liuchu area is about 6.5 m/Ma (Figure 11). Therefore, the distribution of the favorable transport sites of the oil source fault in the E3d2U reservoir under the E3d1-2 regional mudstone cap rock is delineated, as shown in Figure 12. We observed that in the E3d2U oil source fault under the mudstone cap rock in the E3d1-2 area, the favorable location of oil and gas migration is mainly distributed in the north of the Liuchu area, and secondarily in the southwestern part (Figure 12).
Based on the superposition of the mudstone cap rock sealing area in the E3d1-2 area of Liuchu area, according to the connected distribution of sand bodies in the E3d2U group and the favorable oil transportation place in the group, the sites of the blockage diversion of the mudstone cap rock in the E3d1-2 area of Liuchu area can be identified. This part acts as a barrier diverting the movement of hydrocarbons through the oil source fault, which is mainly situated in the south-central part and slightly developed in the northern area (Figure 13).
To find the area where the E3d1-2 regional mudstone cap rock in the Liuchu region diverts seepage and affects the movement of hydrocarbons through the oil source fault, repeat the previous step but input the seepage area of the E3d1-2 regional mudstone cap rock. Figure 13 shows that this diversion effect is mainly located in the northeastern part of the area and is also locally distributed in the western region.
Figure 13 illustrates that the hydrocarbon discovered in the E3d2U in the Liuchu area is mostly distributed in the north and locally in the west-central part of the area. The hydrocarbon in the northern part is situated near the area with the seepage diversion effect of the E3d1-2 regional mudstone cap rocks on the oil source faults. Hydrocarbons can be obtained from the source rock of the underlying E3s1 and can be transported upwards through the seepage diversion site. At the same time, they accumulate and form reservoirs in the E3d2 and the Guantao Formation.
Similarly, the hydrocarbon in the west-central parts is situated near the area with the blockage diversion effect of the E3d1-2 regional mudstone cap rocks on the oil source fault migration. The presence of reservoirs in the blockage diversion sites of the regional mudstone cap rock of E3d1-2, along with the reservoirs in the E3d2U Formation nearby, facilitates the obtainment of hydrocarbons from the source rocks of the underlying E3s1 through the favorable transport sites of the oil source faults. Blocked by the regional mudstone cap rocks of the E3d1-2, hydrocarbons divert, migrate, and accumulate in the E3d2U reservoir, bringing hope of discovery by drilling.

5. Conclusions

(1)
The regional mudstone cap rock has two types of effects on the hydrocarbon migration through the oil source fault: (1) Blockage diversion effect: the site is the coupling of the enclosed area of the regional mudstone cap rock, the position with connected distributed sand bodies and the advantageous locations for transporting oil from the source fault. (2) Seepage diversion effect: the site is the coupling of the regional mudstone cap rock seepage area, the area with connected distributed sand bodies, and the advantageous locations for transporting oil from the source fault.
(2)
By identifying the sealing part of the regional mudstone cap rock, the area with connected distributed sand bodies, and the favorable transport sites of the oil source fault, the place where the regional mudstone cap rock has a blockage diversion effect on oil source fault migration is determined. In contrast, by identifying the leakage area of the regional mudstone cap rock, the parts with connected distributed sand bodies, and the favorable transport sites of the oil source fault, the place where the regional mudstone cap rock has a seepage diversion effect on oil source fault migration is determined. Integrating the two, we establish a prediction method for different diversion migration sites of oil source faults affected by the regional mudstone cap rock. Our case study has demonstrated the method’s validity for predicting different diversion sites of regional mudstone cap rock on oil source fault migration.
(3)
In the Raoyang Sag of the Jizhong depression of the Bohai Bay Basin, we found that the blockage diversion area is mostly located in the south-central area and has limited development in the northern part. The seepage diversion is primarily located in the northeastern and western parts. Both are favorable to migrating underlying hydrocarbon of the E3s1 Formation into the E3d2U reservoir to form hydrocarbon accumulations. The latter can also accumulate hydrocarbons in the Guantao Formation (N1g). The predicted results agree with the current hydrocarbon discoveries in the Liuchu area.
(4)
This method mainly applies to predicting the different hydrocarbon diversion effects of the regional mudstone cap rock on oil source fault migration in the clastic hydrocarbon-bearing basin.

Author Contributions

Conceptualization, T.Z. and Y.W.; methodology, T.Z.; software, T.Z.; validation, T.Z., Y.W. and H.Y.; formal analysis, Y.W.; investigation, T.Z.; resources, H.Y.; data curation, Y.Y.; writing—original draft, T.Z.; writing—review and editing, T.Z.; visualization, T.Z.; supervision, Y.W. and Y.Y.; project administration, Y.Z.; funding acquisition, H.Y. and Y.Z. All authors have read and agreed to the published version of the manuscript.

Funding

This research was funded by the Natural Science Foundation of Heilongjiang Province, item numbers LH2022D013 and LH2023D005. The Natural Science Foundation of Central Support Project for Young Talents in Local Universities in Heilongjiang Province (14011202101), and Financially supported by the Key Research and Development Plan Program of Heilongjiang Province (JD22A022).

Data Availability Statement

The original contributions presented in this study are included in the article; further inquiries can be directed to the corresponding author.

Acknowledgments

We are very grateful to the reviewers and editors for their contributions to improving this manuscript.

Conflicts of Interest

The authors declare no conflicts of interest.

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Figure 1. Regional geological map and study area map of the Liuchu area in Raoyang Sag, Jizhong Depression [24]. (a) The situation of Raoyang Sag, China; (b) the situation of Liuchu area in Bohai Bay Basin; (c) the situation of the study area.
Figure 1. Regional geological map and study area map of the Liuchu area in Raoyang Sag, Jizhong Depression [24]. (a) The situation of Raoyang Sag, China; (b) the situation of Liuchu area in Bohai Bay Basin; (c) the situation of the study area.
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Figure 2. Stratigraphic sequence division of the Liuchu area [23].
Figure 2. Stratigraphic sequence division of the Liuchu area [23].
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Figure 3. Schematic diagram of the types of regional mudstone cap rock effects on hydrocarbon diversion from the oil source fault: (a) blockage diversion effect; (b) seepage diversion effect.
Figure 3. Schematic diagram of the types of regional mudstone cap rock effects on hydrocarbon diversion from the oil source fault: (a) blockage diversion effect; (b) seepage diversion effect.
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Figure 4. Schematic drawing illustrating the hydrocarbon migration sites of the oil source fault affected by the regional mudstone cap rock: (a) blockage diversion site; (b) seepage diversion site.
Figure 4. Schematic drawing illustrating the hydrocarbon migration sites of the oil source fault affected by the regional mudstone cap rock: (a) blockage diversion site; (b) seepage diversion site.
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Figure 5. Schematic diagram defining the lower cutoff values of the parameters used to predict the oil source fault’s different hydrocarbon diversion migration sites controlled by the regional mudstone cap rock: (a) maximum juxtaposition thickness required for the fault to grow up and down in the regional mudstone cap rock; (b) maximum stratigraphic sand ratio required for the sand bodies to connect; (c) minimum activity rate required to transport hydrocarbons on a fault.
Figure 5. Schematic diagram defining the lower cutoff values of the parameters used to predict the oil source fault’s different hydrocarbon diversion migration sites controlled by the regional mudstone cap rock: (a) maximum juxtaposition thickness required for the fault to grow up and down in the regional mudstone cap rock; (b) maximum stratigraphic sand ratio required for the sand bodies to connect; (c) minimum activity rate required to transport hydrocarbons on a fault.
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Figure 6. Thickness map of the E3d1-2 regional cap rock in the Liuchu area.
Figure 6. Thickness map of the E3d1-2 regional cap rock in the Liuchu area.
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Figure 7. Tables defining the maximum juxtaposition thickness of fault required for the separately developed fault segments to connect upward and downward in the E3d1-2 regional cap rocks of the Liuchu area.
Figure 7. Tables defining the maximum juxtaposition thickness of fault required for the separately developed fault segments to connect upward and downward in the E3d1-2 regional cap rocks of the Liuchu area.
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Figure 8. The distribution map of the blockage and seepage area of the E3d1-2 regional cap rocks in the Liuchu area.
Figure 8. The distribution map of the blockage and seepage area of the E3d1-2 regional cap rocks in the Liuchu area.
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Figure 9. The map of the connected distribution of sand bodies in the E3d2U Formation in the Liuchu area.
Figure 9. The map of the connected distribution of sand bodies in the E3d2U Formation in the Liuchu area.
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Figure 10. The histogram determines the minimum sand-to-shale ratio required for the connected distribution of E3d2U sand bodies in the Liuchu area.
Figure 10. The histogram determines the minimum sand-to-shale ratio required for the connected distribution of E3d2U sand bodies in the Liuchu area.
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Figure 11. Histogram determining the minimum fault activity rate required for the oil and gas migration through a fault in the Liuchu area.
Figure 11. Histogram determining the minimum fault activity rate required for the oil and gas migration through a fault in the Liuchu area.
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Figure 12. The distribution map of the favorable transport sites of the oil source fault in the E3d2U reservoir under the E3d1-2 regional mudstone cap rock in the Liuchu area.
Figure 12. The distribution map of the favorable transport sites of the oil source fault in the E3d2U reservoir under the E3d1-2 regional mudstone cap rock in the Liuchu area.
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Figure 13. The relationship map between the distribution of hydrocarbons in the E3d2U Formation and the different hydrocarbon diversion migration sites of oil source faults by the E3d1-2 regional mudstone cap rocks.
Figure 13. The relationship map between the distribution of hydrocarbons in the E3d2U Formation and the different hydrocarbon diversion migration sites of oil source faults by the E3d1-2 regional mudstone cap rocks.
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MDPI and ACS Style

Zhou, T.; Wang, Y.; Yuan, H.; Yu, Y.; Zhang, Y. A Method for Predicting the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults. Processes 2024, 12, 2055. https://doi.org/10.3390/pr12092055

AMA Style

Zhou T, Wang Y, Yuan H, Yu Y, Zhang Y. A Method for Predicting the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults. Processes. 2024; 12(9):2055. https://doi.org/10.3390/pr12092055

Chicago/Turabian Style

Zhou, Tianqi, Yachun Wang, Hongqi Yuan, Yinghua Yu, and Yunfeng Zhang. 2024. "A Method for Predicting the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults" Processes 12, no. 9: 2055. https://doi.org/10.3390/pr12092055

APA Style

Zhou, T., Wang, Y., Yuan, H., Yu, Y., & Zhang, Y. (2024). A Method for Predicting the Action Sites of Regional Mudstone Cap Rock Affecting the Diversion of Hydrocarbons Transported along Oil Source Faults. Processes, 12(9), 2055. https://doi.org/10.3390/pr12092055

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