Geofluids
Volume 2021 (2021), Article ID 6688141, 19 pages
https://doi.org/10.1155/2021/6688141

Research Article

Evaluation of Favorable Shale Gas Intervals in Dawuba Formation of Ziyun Area, South Qian Depression

Kun Yuan,1,2 Wenhui Huang,¹ Xinxin Fang,³ Ting Wang,¹ Tuo Lin,¹ and Rong Chen¹

¹School of Energy Resources, China University of Geosciences (Beijing), Beijing 100083, China
²Oil and Gas Resources Survey, China Geological Survey, Ministry of Natural Resources, Beijing 100083, China
³Institute of Geomechanics, Chinese Academy of Geological Sciences, Beijing 100081, China

Correspondence should be addressed to Kun Yuan; kunyuanogscgs@sina.com and Xinxin Fang; freestarxin@163.com

Received 16 December 2020; Revised 10 January 2021; Accepted 20 May 2021; Published 8 June 2021

Academic Editor: Kun Zhang

Copyright © 2021 Kun Yuan et al. This is an open access article distributed under the Creative Commons Attribution License, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.

Abstract.

A series of qualitative descriptions and quantitative analyses was used to determine the lithofacies characteristics and recognize the favorable shale intervals of Dawuba Formation in the Ziyun area of South Qian Depression. The qualitative descriptions include core description and scanning electron microscope (SEM) observation. The quantitative analyses include X-ray diffraction, total organic content analysis, vitrinite reflectance, maceral composition, porosity, and permeability, as well as gas and element composition. The Dawuba Formation could be divided into four members. In general, the shale in the first and third members showed similarly high organic matter content with most samples in range of 2–2.5% and higher brittle mineral content with a content of quartz 40.53% and 33.21%, respectively, compared with the other two members, as well as high gas content. However, the first member shale samples exhibited much higher porosity and permeability than the third member shale samples. Furthermore, the shale gas in the first member was chiefly composed of methane (average: 83.63%), while that in the third member mainly consisted of nitrogen (average: 79.92%). Hence, the first member should be regarded as the most favorable target.

1. Introduction

In recent years, the success of shale oil and gas exploration and development in North America, such as the Barnett shale with tremendous cumulative gas production, has driven and promoted the development of shale oil and gas industry in China [1–8]. The industrial breakthroughs of shale gas exploration and development in China were achieved mainly in the Ordovician Wufeng and Silurian Longmaxi Formation marine shale reservoirs in Weiyuan, Zhaotong, and Jiaoshiba areas in the southern Sichuan Basin, where the shale gas output reached 10 billion cubic meters in 2019 [9–14]. Although the strata, pattern, mechanism, and geological factors for shale gas source and accumulation were different for different areas, such as in the Weiyuan block and Xiuwu basin [7, 8], the high-quality shale section is generally located at the top of Wufeng Formation and the bottom of Longmaxi Formation, in which the biogenic silica caused by frequent volcanic activities hugely developed [13, 15, 16]. However, in the Lower Cambrian shales, such as the shale in Xiuwu basin, the hydrothermal silica occupied a large proportion [13, 14]. Although the massively developed reverse faults in the complex geological structure areas outside the basin damaged the sealing property of the whole reservoir and induced the hydrocarbon loss and nitrogen entry [7], China Geological Survey firstly discovered that the Sinian and Cambrian systems in these areas also obtained high-yielding industrial shale gas airflow [6]. Shale oil exploration and development in China mainly focus on the widely developed continental shale in the north, including Ordos Basin, Songliao Basin, Tarim Basin, and Bohai Bay basin [17–22]. Shale oil exploration in the 2nd member of the Kondian Formation in Cangdong Sag of Bohai Bay Basin has made great breakthroughs, and industrial oil flows have been obtained in several wells such as KN9 and GD [23].

However, the constant exploration and development of shale oil and gas in new areas is still necessary, because it still cannot meet the country’s energy demand at the present stage. The Permian transitional facies shale is widely distributed in China, and only a few shale gas discoveries have been made in it of some areas [24–26]. Hence, the industry has different opinions on whether the Permian transitional facies shale has commercial scale shale gas. In addition, the major breakthrough in Devonian and Carboniferous shale strata has not been made in south China. The main reason is that most areas in the south belonged to the paleogeographic environment alternative distribution of interplatform and basin during the Devonian-Carboniferous period [27]. Hence, the lithological association varies greatly, including the shale development thickness, distribution characteristics, organic geochemical characteristics, mineral composition, mechanical properties, and reservoir property of different layers [28].

In this paper, the Ziyun area of South Qian Depression is taken as the research area. Core samples of shale and mudstone in wells Qianziye 1, Changye 1, and Daiye 1, Guizhou, as well as samples collected from the surrounding outcrops, Manchang, Getuhe, Sidazhai, and Luogang, were taken as the research objects. The stratigraphic distribution characteristics, geochemical characteristics, reservoir characteristics, and gas bearing properties of Dawuba Formation were evaluated. On this basis, the sedimentary background and its effect on organic matter enrichment were discussed. Then, the favorable target layers for shale gas enrichment were optimized.

2. Geological Setting

The South Qian Depression is located in the southwest part of China (Figure 1(a)). It is a superimposed basin formed by the early Paleozoic Craton basin, the late Paleozoic passive continental margin basin, and the Mesozoic foreland basin [29–31]. The Guiyang-Zhenyuan fault zone and middle Qian uplift are the boundary in the northwest of the depression; the Tongren-Sandu fault zone and the Xuefengshan uplift are the boundary in the east and southeast; the Ziyun-Luodian fault zone is the boundary in the southwest of the depression (Figure 1(b)).

Figure 1: Location map of the research area (a, c, d), lithological characteristics of Dawuba Formation (b), tectonic characteristics of Ziyuan area (c), and location of samples from wells and outcrops (d). ① Xiaojiang fault; ② Shizong fault; ③ Pingxiang-Dali fault; ④ Yongfu fault; ⑤ Longsheng fault; ⑥ Tongren-Sandu fault; ⑦ Guiyang-Zhenyuan fault; ⑧ Zunyi fault; ⑨ Libo fault; ⑩ Ziyun-Luodian-Nandan-Duan fault. “Dian” means Yunnan province; “Qian” means Duizhou province; “Gui” means Guangxi province. The yellowish-brown section line crosses the wells and outcrops used in stratigraphic correlation and the green one used in comparison of total organic carbon (TOC).

The study area is located in the west part of South Qian Depression and confined by the Ziyun and Guiyang fault. Under the tectonic processes of multiple stresses, the Carboniferous, Permian, and Triassic strata have undergone strong structural deformation and denudation of different extent. In the Indosinian-Yanshan and Himalayan stages, strong folds and thrust nappes resulted in massive shortening deformation. The north-south compressional deformation dominated throughout the entire district (Figure 1(c)). The anticline was in box shape with mainly Devonian and Carboniferous strata. The syncline was in a groove shape with the axis being mostly destroyed by strike compressional faults and mainly consists of Triassic strata. In some areas, it was covered in unconformity with the upper Cretaceous strata.

The Dawuba Formation is about 150–250 m thick and is mainly composed of shale, silty shale with thin chert layer, and a small amount of silty sandstone, generally containing iron and phosphorus nodules and spore fossils (Figures 1(d) and 2). According to the lithological characteristics of wells Qianziye 1, Daiye 1, and Changye 1, as well as outcrops Manchang, Getuhe, Sidazhai, Luogang, and Kehun, the Dawuba Formation can be divided into four members. The fourth member of Dawuba Formation is approximate 100 m thick and lithologically composed of dark shale, black mudstone, and gray mudstone sandwiched with dark gray marl limestone and gray limestone (Figure 2(a)). The third member of the Dawuba Formation is 30 m thick and lithologically consists of black shale, gray mudstone with dark gray marl limestone, and gray dolomitic siltstone (Figure 2(b)). The second member is 75 m thick and lithologically interbedded with dark gray marl and gray dolomite (Figure 2(c)). The first section of Dawuba Formation is about 150 m thick and lithologically composed of dark shale, gray black mudstone, and gray limestone (Figures 1(d) and 2(d)).

(a)

(b)

(c)

(d)

Figure 2: Images of shale samples from Dawuba Formation: (a) black shale sample from the fourth member of Dawuba Formation; (b) black shale with argillaceous stripe sample from the third member of Dawuba Formation; (c) black shale sample from the second member of Dawuba Formation; (d) black shale sample from the first member of Dawuba Formation.

3. Sample Preparation and Methods

3.1. Lithology Analysis

Core observation and descriptions, including composition, texture, sedimentary structure, grain size, and color, were conducted to determine the lithofacies in Dawuba Formation. The mineral composition was measured by a Rigaku automated powder diffractometer (D/MAX-RA) equipped with a Cu X-ray source (40 kV, 35 mA). The samples from Dawuba shale were analyzed for whole-bulk and clay fraction mineralogy by quantitative X-ray diffraction following two independent processes. First, the bulk mineral composition of the powder sample was determined at this stage to only include the total clay content. The whole-rock samples were analyzed over an angular range of 4 to 70°2θ at a scanning speed of 1°2θ/min. Second, the individual clay mineral content of the clay fractions separated from the rock powder sample was determined. The clay minerals were analyzed over an angular range of 3 to 65°2θ at a scanning speed of 1.5°2θ/min. Quantification of the minerals was based on calculations of the integrated area using the Jade Five software.

3.2. Analysis of Geochemical Characteristics

The total organic carbon (TOC) analyses were conducted using laboratory apparatus Leco TOC (CS-230HC). The samples were immersed in 10% HCl solution for two days to remove the carbonate minerals and then washed with distilled water. Before measurement, the samples were dried in a stoving oven at 65°C for 1.5 days. The thermal maturity reflected by the experimental vitrinite reflectance () values and maceral composition of Dawuba Formation shale samples were acquired by using an oil-immersion lens and a full-automatic microscope photometer (a Leica MPV Compact II reflected-light microscope) in both reflected and fluorescent modes. Before the measurements, the equipment calibration was performed using two standard samples of known reflectance. Each represents the average of 20-30 measuring points. Each maceral analysis covered more than 30 points.

3.3. SEM Observation

Scanning electron microscopy (SEM) was performed to provide visualization of the minerals and micropores through FEI Quanta-200F apparatus with an energy-dispersive spectrometer (EDS). Fractured surfaces generated from slightly knock with a little hammer were used in SEM observation. Ar-ion polishing was applied in SEM observation. A thin layer of Au element was applied in gilding on the fractured surfaces before observation. The operating current must be maintained to be 15 kV for stable signal output of clear images.

3.4. Porosity and Permeability Analysis

The porosity of the dry samples was determined from the grain density obtained from helium pycnometry (skeletal density), and the bulk volume of the plugs was calculated from mercury immersion (bulk density) [32]. The total porosity was calculated from the difference between the bulk and skeletal densities. The permeability was calculated from measurements with helium expansion at a constant temperature of 30°C and a range of pressures from 5 MPa to 30 MPa in a stepwise increase [33, 34]. The cylinder samples of shale with diameters of 2.5 cm and lengths of 5 cm were analyzed for porosity and permeability. These 25 samples had no factitious fractures on the surface formed. But, it is hard to identify artificial microfractures that formed interior the sample, which explains the aberrant data points of porosity and permeability analysis.

3.5. Gas Content and Component Analysis

The shale gas was collected through gas gathering system, of which the principle was water gas displacing method. The water in it is saturated salt solution. When the core sample was taken out from the drilling borehole, they were put in an air collector as soon as possible. The shale gas gathered during the unheated stage was regarded as desorbed gas. When the desorbed gas content did not increase any more, the system was heated, and the gas gathered was regarded as residual gas. The shale gas component was determined through gas chromatographic method.

3.6. Element Analysis

Trace element analysis can also be used in the study of the sedimentary environment, such as the reducibility or oxidability, salinity, and climate [35–39]. The shale samples of Dawuba Formation were used for the element analysis, which was determined with a laser-ablation microprobe linked to an inductively coupled plasma mass spectrometer (LAM–ICP–MS) at the Beijing Research Institute of Uranium Geology.

4. Results

4.1. Mineral Composition Characteristics

The Dawuba Formation shale is mainly composed of quartz and clay minerals (Figure 3). The third member shale exhibited the highest content of quartz (average 40.53%) but the lowest content of calcite (average 5.42%) (Figure 3(a)). For the shale of other three members, quartz was the dominated brittle minerals and then followed by calcite (Figure 3(a)). The contents of plagioclase, dolomite, and pyrite of all the four members were smaller than 10% (Figure 3(a)). The clay minerals were not much difference in content in shale of the four members. The clay minerals were mainly composed of illite, which reached larger than 70%, followed by illite/smectite mixed layers (average 16.78%) and chlorite (<10%) (Figure 3(b)). From the perspective of clay mineral composition, the shale of the four members in Dawuba Formation was similar to each other. Among the shale samples of Dawuba Formation, the third member shale exhibited the highest content of illite/smectite mixed layers (average 23.47%) but the lowest content of illite (average 70.21%) (Figure 3(b)).

(a)

(b)

Figure 3: Mineral composition of the Dawuba Formation shale samples: (a) mineral composition of bulk-rock; (b) clay mineral composition.

4.2. Organic Matter Characteristics

The TOC content of all the samples varies from 0.26% to 4.66%, while most samples are included in the range of 1–3% (Figure 4). Shale samples from the fourth member showed the lowest content of TOC values, while the TOC values did not show substantial difference among the shale sample from the other three members. Some shale samples in the third member show toc content larger than 3% (Figure 4). The measured vitrinite reflectance () of all the Dawuba Formation shale samples is in the range of 2.85–5.14% (Figure 4). The measured of most of the samples from all the four members ranged from 2.85% to 4.0%, which means most of Dawuba Formation shale samples were in the gas-generation stage at the present time. But some values of shale samples from the first and third members were larger than 4.5% (Figure 4), which means overmaturity stage. It was speculated that the high was caused by magmatic hydrothermal deposit, but there was no precise evidence. Approaching to the organic matter type from the point of view of maceral composition, exinite dominated the shale samples of Dawuba Formation, which means an incline to Type II₂ organic matter (Table 1). The exinite mainly consisted of homocollinite and alginite (Table 1). The vitrinite and inertinite were not widely developed. In general, the organic matter type did not show material difference among the shale samples from the four members (Table 1).

(a)

(b)

Figure 4: Histogram of TOC and of all the Dawuba Formation shale samples: (a) histogram of TOC; (b) value scope.

Table 1: The maceral composition of all the Dawuba Formation shale samples.

Sample ID
Depth/m
Member
Lithology
Sapropelinite %
Exinite %
Vitrinite %
Inertinite %
Types classification

Resinite
Homocollinite
Alginite
Sum
Normal vitrinite
Fusinite
Index
Type

CY1-1
751
Fourth
Black shale
0
—
59
28
87
10
3
33
II₂

DY1-5
450
Fourth
Black shale
0
2
63
20
85
13
2
30.8
II₂

MC-1
2750
Fourth
Black shale
0
—
63
22
85
12
3
30.5
II₂

ZY1-1
2668
Fourth
Black shale
0
2
67
13
82
14
4
26.5
II₂

ZY1-3
2688
Fourth
Black shale
0
4
56
18
78
17
5
21.3
II₂

ZY1-4
2759
Fourth
Black shale
0
3
56
17
76
16
8
18
II₂

ZY1-9
2738
Fourth
Black shale
0
—
64
17
81
16
3
25.5
II₂

GTH-1
Outcrop
Third
Black shale
0
5
47
24
76
18
6
18.5
II₂

LG-1
Outcrop
Third
Black shale
0
—
58
26
84
11
5
28.8
II₂

ZY1-2
2806.50
Third
Black shale
0
—
72
13
85
11
4
30.3
II₂

ZY1-6
2796
Third
Black shale
0
0
74
12
86
13
1
32.3
II₂

ZY1-7
2802.60
Third
Black shale
0
—
73
11
84
14
2
29.5
II₂

ZY1-8
2812.5
Third
Black shale
0
—
64
15
79
16
5
22.5
II₂

GTH-2
Outcrop
Second
Black shale
0
0
55
26
81
16
3
31.8
II₂

LG-2
Outcrop
Second
Black shale
0
1
53
29
83
14
3
31.8
II₂

ZY1-10
2857
Second
Black shale
0
0
54
28
82
15
3
31.8
II₂

ZY1-12
2858
Second
Black shale
0
4
53
29
86
11
3
31.8
II₂

ZY1-13
2858.5
Second
Black shale
0
0
50
28
78
17
5
31.8
II₂

CY1-2
880
First
Black shale
0
4
57
14
75
17
8
16.8
II₂

CY1-3
881
First
Black shale
0
4
59
8
71
22
7
12
II₂

DY1-1
633
First
Black shale
0
0
62
22
84
12
4
29
II₂

DY1-2
634
First
Black shale
0
—
74
16
90
8
2
37
II₂

KH-1
Outcrop
First
Black shale
0
—
69
16
85
11
4
30.3
II₂

SDZ-1
Outcrop
First
Black shale
0
0
75
12
87
11
2
33.3
II₂

SDZ-2
Outcrop
First
Black shale
0
—
80
12
92
6
2
39.5
II₂

ZY1-14
2871
First
Black shale
0
—
65
20
85
12
3
30.5
II₂

ZY1-15
2877.40
First
Black shale
0
—
63
19
82
14
4
26.5
II₂

ZY1-16
2931.95
First
Black shale
0
5
61
14
80
15
5
23.8
II₂

ZY1-17
2882.50
First
Black shale
0
—
76
16
92
5
3
39.3
II₂

4.3. Characterization of Pores

Compared with marine shale, organic matter pores did not hugely develop in Dawuba Formation shale (Figures 5(a)–5(c)). Cracks can be observed between organic matter and mineral particles under high magnification (Figure 5(c)). Some organic matter developed pores, which were not subrotund or elliptical as usual but elongated and irregular (Figures 5(d) and 5(e)). The organic matter symbiotic with minerals, such as pyrite and quartz, always developed pores (Figures 5(f)–5(h) and 5(p)). Interparticle pores always appear along the rims of quartz and plagioclase, as well as in the pyrite framboids (Figures 5(i)–5(l)). Rims of detrital quartzes and plagioclase are always jagged, which leads to inter particle pores surviving consolidation and compaction. Pyrites were abundant in Dawuba Formation shale and occurred mostly as pyrite framboids (Figures 5(k) and 5(l)). Interparticle pores exist in pyrite framboids (Figure 5(l)). Many of interparticle pores and cracks occurred among clay minerals (Figures 5(m)–5(p)). Some clay minerals exhibited sheet-like shapes because of compaction. Gaps occurred between these sheet-like clay minerals. For the Ar-ion polished samples, clay mineral pore types cannot be further identified and classified, because most clay minerals are not authigenic minerals of diagenetic genesis.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

(o)

(p)

(q)

(r)

Figure 5: Images of SEM observation for the Dawuba Formation shale. The red arrows point to the organic matter and organic matter pores. The yellow arrows point to the pores related to quartz and pyrite. The blue arrows point to the pores among clay minerals. (a) 2946 m, the 1st member, black shale; (b, j) 2929 m, the 1st member, black shale; (c) 2811.5 m, the 4th member, black shale; (d) 2942.15 m, the 1st member, black shale; (e) 2950 m, the 1st member, black shale; (f, g) 2946.6 m, the 1st member, black shale; (h, i) 2983.3 m, the 1st member, black shale; (k, m) 2950.1 m, the 1st member, black shale; (l) 2932.95 m, the 1st member, black shale; (n, o) 2946.6 m, the 1st member, black shale; (p) 2883.5 m, the 2nd member, black shale; (q) EDS spectrum of red “+” in image (h); (r) EDS spectrum of red “+” in image (l).

4.4. Porosity and Permeability

Samples with drilling orientation perpendicular to sedimentary stratification displayed relatively lower permeability than samples with drilling orientation parallel to sedimentary stratification, which explained the largest data point of the first member (Figure 6). In general, the first member shale samples possessed the inconspicuous highest porosity and permeability. Although one sample from the third member shale displayed lower permeability and porosity, totally speaking, no apparent difference of permeability and porosity occurred among the other three member shales (Figure 6). The abnormally higher permeability value for the first member shale sample may be reduced by factitious microfracture formed in sample interior during drilling process. Porosity displayed a positive correlation with the permeability for all the samples (Figure 6).

Figure 6: The cross plot of porosity and permeability.

4.5. Gas-Containing Property

Through shale gas gathering system, the desorbed gas in Dawuba Formation shale ranged from 0.07 cm³/g to 1.28 cm³/g, while the residual gas varied from 0.09 cm³/g to 0.44 cm³/g. Some samples did not contain residual gas. The total shale gas content was in the scope of 0.07 cm³/g to 1.28 cm³/g (Figure 7). The first and third member shale samples presented much higher content of shale gas (Figure 7). It seems that these two member shales were favorable for development. However, the shale gas component showed different opinion through gas chromatographic method. Only the shale gas gathered from the first member contained a large abundant of methane (83.63%), followed by the second member shale samples (36.88%) (Figure 7). The major component of shale gas in the other three member samples was nitrogen, which means no commercial production value.

(a)

(b)

Figure 7: The shale gas content and components of the Dawuba Formation.

4.6. Element Characteristics

The Sr/Ba is a parameter sensitively reflecting the salinity of sedimentary water because of much stronger migration ability of Sr than Ba [39, 40]. It represents fresh water sedimentary environment when the Sr/Ba value is less than 1 [38–41], which is exactly describing most of the Dawuba Formation shale samples (Figure 8). The Sr/Cu is a parameter employed to express the dry-humid degree of sedimentary environment. The Sr/Cu values ranging from 1 to 10 represent warm-moist climate and larger than 10 reflect hot-dry climate [37, 39, 42, 43]. Sr/Cu values of most Dawuba Formation shale samples are larger than 10, which indicates hot-dry climate. However, some samples of the first member shale showed Sr/Ba and Sr/Cu values much larger than 1 and 40, respectively, which means relatively higher salinity of sedimentary water for the first member shale (Figure 8). A large quantity of parameters have been used to reflect the reducibility or oxidability of sedimentary environment, such as Ce/La, Th/U, Cr/Cu, and V/Sc [36, 38, 44–46]. Compared with the other three member shales, the first member shale presented obviously much lower Ce/La, Th/U, Cr/Cu, and V/Sc values, which represented a stronger reducing environment (Figure 9). The first member shale might develop under much deeper and stratified water. Water below with more mineral ions cannot be mixed with the fresh water on top in view of density differences.

Figure 8: The relationship between Sr/Ba and Sr/Cu.

(a)

(b)

(c)

(d)

Figure 9: The resolution comparison of reducing environment exquisite changes for variety of parameters: (a) cross plot of Ce/La values and depth for the four member shale samples; (b) cross plot of Cr/Cu values and depth for the four member shale samples; (c) cross plot of Th/U values and depth for the four member shale samples; (d) cross plot of V/Sc values and depth for the four member shale samples.

5. Discussion

5.1. Sedimentary Environment and Shale Thickness

The whole Dawuba Formation is characterized by a set of platform edge slope facies and platform basin facies deposits. The content of sand in the strata near the platform increased, while the content of silica in the strata near the basin increased [47–49]. In the early Carboniferous period, the seawater of Qinfang basin and Ailaoshan basin in the Tethys domain invaded along the sedimentary basin from southeast to northwest. The Ziyun area was stretched into a rifting basin under the action of NE-NW stress [50]. Due to the rapid transgression and insufficient material supply, the first member of the Dawuba Formation in deep water was deposited in the basin and mainly consisted of black shale and siliceous rock (Figure 10). At this time, the southwest of Ziyun area was the sedimentary center, and the shale thickness in the Ziyun area represented by Sidazhai outcrop was the largest (Figure 10). In the north, there was no deposit of shale strata because it was not within the range of the rift basin. During Ziyun tectonic movement, transgression gradually increased, and water body became shallow gradually from the trough internal to both sides. Material continued in supplying from the north and north east of Ziyun area. A thin layer of silty sand rock with gray, silty mudstones, colored marl of the lithologic combination was formed, which was called the upper strata of Dawuba Formation (Figure 10). Subsequently, with the continuous uplift of the structure, the water body continued to become shallower. The thick carbonate rocks of the Nandan Formation were formed and covered over the Dawuba Formation.

Figure 10: Columnar contrast map of the Dawuba Formation in Ziyun area. The section line of wells and outcrops connecting was shown in Figure 1 (the yellowish-brown one).

The shale thickness in Ziyun area was obviously affected by sedimentary facies and gradually thickened from northeast to southwest (Figure 11), with the maximum sedimentary thickness of nearly 400 m [51]. The first and third members of the Dawuba Formation in the north of Ziyun area were dominated by organic-enriched shale, which was about 40–170 m in in the first member and less than 50 m in the third member. However, the changes of sedimentary facies occurred in the north of Maoying, and the Dawaba Formation changed from mud-shale system to limestone-marl system. To the south of Ziyun area, the thickness of the Dawuba Formation increased significantly, reaching over 300 m. The first and third members of Dawuba Formation were still intensively compose of black shale, while the second and fourth members changed from sandstone combined with mudstone and marl in the north to gray marl with thin layer siliceous rock. The thickness of Dawuba Formation in the eastern Ziyun area gradually decreased, and the stratification characteristic was fuzzy. But, the organic-enriched shale was still developed in the first and third members, and in the first member was about 70 m thick; the third member was about 20 m thick. The second member was composed of only a few meters of black shale with grey black lens marl, and the fourth member consisted of a set of grey black and dark grey silty mudstone with mud shale. It is generally concluded that the first and third members of the Dawuba Formation were the most intensively and consistently organic-rich shale layers. From the perspective of lithologic characteristics, limestone and marl mostly developed at the bottom of the first member, and then, shale widely developed. In the third member, mudstone and shale developed with marl strips. The proportion of black shale in the second and fourth members of the Dawuba Formation is relatively small. Except for sandstone and siliceous rocks with continuous thickness of more than 3 meters, the proportion of shale is less than 50%.

Figure 11: Stratum thickness contour map of Dawuba Formation.

In fact, the Dawuba Formation was deposited during a transgressive–regressive cycle, which included several sea level eustacy of small scale. The transgression began during the first member deposition period and reached its climax. During most of this transgression, the bottom waters of the first member were oxygen poor (anoxic to euxinic), allowing for preservation of the abundant organic matter. During the third member deposition period, a transgressive of smaller scale happened, but the redox conditions never fully returned to the anoxic conditions of the first member, so in general, organic-matter abundances are lower in black shale from the Upper Dawuba Formation than in black shale from the Lower Dawuba Formation.

5.2. Comparative Evaluation of the Dawuba Formation Shale

As an important shale gas survey target in the southern Guizhou depression, the Carboniferous Dawuba Formation shale was characterized by large thickness, high TOC, and high gas-bearing content. By comparing and analyzing the shale thickness, sedimentary environment, organic geochemical characteristics, reservoir characteristics, and gas-bearing property, the four members of the Dawuba Formation in Ziyun area were evaluated.

The fourth member of Dawuba Formation was mainly black carbonaceous mudstone mixed with siliceous rocks and limestone deposited in half deep water, and gray mudstone was developed locally. The strata thickness of the fourth member was about 20–105 m. The organic-enriched shale strata was relatively thin, merely about 2–30 m, and the continuous thickness of shale is small. The TOC was in the range of 0.38–2.26% with an average of 0.99%. The major gas component was nitrogen. The third member was one of the major shale strata with thickness of 10–70 m. It was mainly composed of black carbonaceous shale with siliceous rocks with thickness for 5–45 m. The thickness thinned gradually from south west to north east. It was deposited under semideep water and reductive environment. The TOC was in the scope of 0.97–4.25% with an average of 2.44%. The third member contained a large scale of shale gas, but the major component was nitrogen, which is the similar component as the gas in the Lower Cambrian shale of Xiuwu Basin in the Lower Yangtze [7]. It was obvious that the third member of the Carboniferous Dawuba Formation shale in the southern Guizhou depression was not sealed well as the Wufeng-Longmaxi Formation shale in Sichuan Basin [12]. The second member of the Dawuba Formation had a thin thickness, generally less than 20 m. The obvious feature is mudstone interbedded with limestone and was formed under the oxidation environment of semideep water. The shale was thin, with a thickness of less than 5 m and the single layer of shale much thinner. The content of organic carbon is relatively low, with an average TOC of 1.59%. The shale in this member basically contains no gas. The first member of Dawuba Formation was mainly composed of organic-enriched shale with silty sand a small amount of marl limestone at the bottom. The formation thickness was usually more than 100 m, and the proportion of shale in the formation is relatively high. The elemental analysis indicated that the shale strata in the first member was formed in a relatively stagnant and reducing environment. The TOC was in the range of 0.96–4.66%, with an average of 1.92%. Moreover, the shale gas content was higher, and the shale gas mainly consisted of methane.

In general, the TOC vertically increased gradually from the fourth member to the first member of Dawuba Formation. On the plane, the organic carbon content increased gradually from north to south (Figure 12). The southern part of Ziyun area in early Carboniferous period is near the center of the rift basin, and the water is relatively deep, which is conducive to the accumulation of organic matter.

Figure 12: The TOC comparison of typical stratigraphic section of Dawuba Formation in Ziyun area. The section line of wells and outcrops connecting was shown in Figure 1 (the green one).

6. Conclusion

The shale intervals of the Dawuba Formation in Ziyun area of South Qian Depression were evaluated through mineral composition, organic matter character, pores, porosity, and permeability, as well as gas-containing property.

(1)The Dawuba Formation had a stable distribution in Ziyun area and was mainly composed of platform and basin facies deposits. According to the stratigraphic development characteristics and lithofacies association law of Dawuba Formation, the Dawuba Formation was divided into four members, among which the first and third members were organic-rich shale strata(2)The type of shale organic matter in Dawuba Formation in Ziyun area was mostly II₂ kerogen. The TOC content ranged from 0.38 to 4.66%, with an average of 1.73%. Ro was in the range of 2.85% and 5.14%, which indicated a stage of overmature evolution. The mineral composition is mainly quartz and clay minerals, and the brittle mineral content is more than 45%, which has good compressibility. The shale gas content was in the scope of 0.07–1.68 cm³/g(3)The shale in the first and third members of Dawuba Formation was characterized by high TOC, high evolution degree, and high brittle mineral content, which indicated favorable shale strata. However, the shale gas in the third member mainly consisted of nitrogen, while that in the first member was chiefly composed of methane. Hence, the first member should be regarded as the most favorable target

Data Availability

The data has been included in the manuscript.

Conflicts of Interest

The authors declare that they have no conflicts of interest.

Acknowledgments

This study was supported by the China Geological Survey Projects “Geological survey of shale gas in Guizhong-Nanpanjiang area” (grant no. DD20190088). We thank Guoheng Liu at China University of Petroleum (East China) for his help in these experiments.

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