Geofluids
Volume 2019 (2019), Article ID 1435892, 13 pages
https://doi.org/10.1155/2019/1435892

Research Article

A Cause Analysis of the High-Content Nitrogen and Low-Content Hydrocarbon in Shale Gas: A Case Study of the Early Cambrian in Xiuwu Basin, Yangtze Region

Yizhou Huang,1,2 Kun Zhang,1,2,3,4,5 Zhenxue Jiang,1,2 Yan Song,1,2,4 Shu Jiang,5,6,7 Chengzao Jia,⁴ Weiwei Liu,⁸ Ming Wen,1,2 Xuelian Xie,⁹ Tianlin Liu,1,2 Xin Li,1,2,3 Xin Wang,1,2 Xiaoxue Liu,1,2 Ye Zhang,¹⁰ and Ling Tang1,2,3

¹State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum, Beijing 102249, China
²Unconventional Natural Gas Institute, China University of Petroleum, Beijing 102249, China
³Unconventional Petroleum Collaborative Innovation Center, China University of Petroleum, Beijing 102249, China
⁴Research Institute of Petroleum Exploration and Development, Beijing 100083, China
⁵Key Laboratory of Tectonics and Petroleum Resources of Ministry of Education, Faculty of Earth Resources, China University of Geosciences, Wuhan 430074, China
⁶Research Institute of Unconventional Oil & Gas and Renewable Energy, China University of Petroleum (East China), Qingdao 266580, China
⁷Energy and Geoscience Institute, University of Utah, Salt Lake City, Utah 84108, USA
⁸Jiangxi Provincial Natural Gas Company Ltd., Nanchang 330000, China
⁹Guangzhou Marine Geological Survey, Guangzhou 510760, China
¹⁰National and Local Joint Engineering Research Center of Shale Gas Exploration and Development, Chongqing Institute of Geology and Mineral Resources, Chongqing 400042, China

Correspondence should be addressed to Zhenxue Jiang; zhenxuejiangedu@126.com, Yan Song; yansongpetrochina@126.com, and Shu Jiang; jiangsu@cug.edu.cn

Yizhou Huang and Kun Zhang contributed equally to this work.

Received 29 November 2018; Accepted 27 January 2019; Published 12 June 2019

Guest Editor: Giorgio Minelli

Copyright © 2019 Yizhou Huang 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.

There are successes and failures in the exploration of marine shale gas in South China. In some shale gas plays with great basis for hydrocarbon generation, a phenomenon exists that gas loggings reflect low gas bearing in some of the wells and the gas is dominated by nitrogen rather than hydrocarbon gas. The study of nitrogen concentration in shale gas contributes to solve the question that how shale gas diffuses in complex tectonic areas, which helps to figure out the preservation requirements and accumulation mechanisms of shale gas and avoid exploration crisis. This study focused on the lower Cambrian shale in Xiuwu Basin, Lower Yangtze Region, with emphasis on the well Jiangye-1, using gas component analysis, stable nitrogen isotope analysis, overburden permeability tests in parallel and perpendicular directions, and FIB-HIM experiments, also combining with core description, outcrop observation, and seismic interpretation to explore the causes of the high-content nitrogen and low-content hydrocarbon in the lower Cambrian shale gas. The results show that the nitrogen of the lower Cambrian shale in Xiuwu Basin is derived from the atmosphere and the deep crust-upper mantle. The bedding planes and the detachment layer at the bottom of the lower Cambrian compose the lateral pathways, and the widespread deep faults are the vertical pathways for shale gas migration and diffusion. Combining these two, an effective pathway network was built, favorable to gas exchange between the shale gas interval and the atmosphere, partly leading to the concentration of nitrogen and the diffusion of hydrocarbon gas. In the Jurassic, the magmatic activities occurred frequently in the surrounding areas, which not only brought nitrogen from the deep crust-upper mantle but also increased the value of paleo-heat flow even though the basin began to uplift, which promoted the graphitization of organic matter and the collapse of organic pores and accelerated the loss of shale gas. Based on the study above, an explanation model was summarized to expound the causes of high-content nitrogen and low-content hydrocarbon in shale gas plays near the plate-active region in Xiuwu Basin, Lower Yangtze Region.

1. Introduction

In recent years, because of the progress in geological theories and hydraulic fracturing technology, shale gas has drawn an increasing attention of exploration and development of oil and gas all over the world [1–3]. In China, since 2010, the well Wei-201 in Weiyuan Structure realized the industrialization of shale gas resources. Until 2018, shale gas plays like Weiyuan, Changning, Fushun-Yongchuan, Jiaoshiba, and Dingshan were continually established to achieve large-scale exploration and exploitation [4, 5]. Although successes are achieved, failures still exist that the gas content varies dramatically depends on plays [6, 7]. This makes further study on shale gas accumulation mechanism urgent to be carried out [8, 9]. Explorations on the accumulation mechanisms of shale gas have been carried out by previous works, including shale heterogeneity [10–12], shale pore connectivity [13–16], shale sedimentary environments [17], and structural styles [18, 19]. However, compared with North America, the Paleozoic marine shale in South China experienced a more complex, multistage tectonic and thermal evolution. Although the plays were equipped with similar materials basis, such as the similar total organic carbon (TOC) content and mineral composition, the gas-bearing properties are diverse under different preservation conditions. Thus, accurate selections of favorable intervals and areas are important for shale gas exploration [20].

Methods have been applied to previous studies about preservation conditions of shale gas. Cheng et al. [21] researched shale gas preservation conditions of the lower Cambrian Niutitang formation in the Enshi-Lichuan Play. From material basis, tectonic effects, and evolution history, they proposed a comprehensive evaluation index system of shale gas preservation. Guo et al. [22] put forward “accumulation controlling production” theory which considered preservation conditions crucial for shale gas accumulation. Quality roof and floor effectively prevent hydrocarbon from diffusing vertically and strand hydrocarbon right after its generation. The strength and duration of tectonic effects determine the preservation conditions, which are key geological factors in the theory. A shale reservoir, with quality gas-bearing properties, large porosity, and high formation pressure, is inclined to be a prolific area enriched by natural gas. Zhai et al. [23] demonstrated the main controlling factors of production of marine shale gas reservoir in South China which include quality organic-rich shale deposited in deep-water shelf (favorable for hydrocarbon generation) and appropriate tectonic uplift time and structural styles (keys of shale gas accumulation and preservation). They summarized three major types of shale gas structural styles: the complete, the residual, and the destructive styles. Also, overpressure is considered as a necessary prerequisite for high production.

Many shale gas plays of the lower Cambrian located outside the Sichuan Basin, represented by Xiuwu Basin, are blessed with great material basis but no considerable commercial discoveries, only slightly gas bore. Among the wells, a phenomenon is shown in common that the nitrogen content is distinguished, reflecting the complexity of the preservation conditions of shale gas in the lower Cambrian [24–29]. Since nitrogen is an indicator, directly reflecting the preservation conditions of oil and gas plays, the study of nitrogen in shale gas promotes the clarification of the preservation regulations and shale gas accumulation mechanism [30–33], which are important for accurately selecting favorable intervals and areas and avoiding crisis during the shale gas exploitation.

Therefore, based on the detailed components of the lower Cambrian shale gas, this paper combined stable nitrogen isotopes and previous works to determine the sources of nitrogen and then figured out the causes of high-content nitrogen and low-content hydrocarbon in the lower Cambrian shale gas by the comprehensive analysis of regional geological settings, tectonic characteristics, and thermal evolution history. Finally, a shale gas accumulation model was established to explain the causes, significant to the exploration and exploitation of shale gas in highly matured shale in complex tectonic zones.

2. Geological Settings

2.1. Tectonic and Sedimentary Characteristics

The study area is located in Xiuwu Basin, Lower Yangtze Region (Figure 1). Xiuwu Basin was a stable cratonic basin in the Cryogenian and then experienced a regression in the late Cryogenian, when the Piyuancun formation was deposited. A massive transgression occurred in the early Cambrian, leading to the deposition of the Wangyinpu formation in a deep-water basin (Figure 2), which is a set of black organic-rich siliceous shale of 45-60 m thick. Afterwards, the seawater was gradually shallower and the upper part of the Guanyintang formation formed in shallow-water shelf facies [34]. Subsequently, the sedimentary environments transformed from a clastic sedimentary system in early Cambrian to a carbonate system in the middle-late Cambrian and further to a detrital sedimentary system in the early-middle Ordovician [35]. In the late Ordovician-early Silurian, due to the plate collision, the study area changed to a deep-water basin when the Xinkailing-Lishuwo shale was deposited. Since the middle Silurian, the seawater became shallower and the study area began to uplift to ancient lands in the late Silurian [36, 37]. In the Devonian-Carboniferous, sedimentation and uplift interlaced with little deposition. The Permian and the early-middle Triassic welcomed another major sedimentary period. The late Triassic was affected by the collision between the North China and the Southern China plates; thus, the study area was uplifted [27, 38] and ended up a syncline with lots of thrust faults in the early-middle Jurassic by extrusion [39].

Figure 1: Locations of the study area and wells and outcrop mentioned.

Figure 2: A map of the regional sedimentary characteristics of the lower Cambrian in the Lower Yangtze, South China.

2.2. Stratigraphic Characteristic

The research target is the lower Cambrian Wangyinpu and Guanyintang formations. Wangyinpu formation is underlain by the late Ediacaran Piyuancun formation, which is dominated by gray siliceous dolomite. The Wangyinpu formation is black siliceous shale, and Guanyintang formation is dark gray siliceous shale. Guanyintang formation is the middle Cambrian Yangliugang formation, a set of gray micrite limestone (Figure 3(b)). These strata are all conformly contacted.

(a)

(b)

Figure 3: A stratigraphic column and core photos of the late Ediacaran and the lower-middle Cambrian of Jiangye-1. (A) The late Ediacaran Piyuancun formation (depth: 2675 m). (B) The lower Cambrian Wangyinpu formation (depth: 2638 m). (C) The lower Cambrian Guanyintang formation (depth: 2546 m). (D) The middle Cambrian Yangliugang formation (depth: 2511 m). The data of gamma ray log and total gas content were from Schlumberger. See Figure 1 for the well location. Fm. = formation; GR = gamma ray log; TOC = total organic carbon content; GAS = total gas content.

2.3. Present Conditions of Exploration

According to the exploration history, there are two shale gas wells named Jiangye-1 and Jiangye-2 (Figure 1). The lower Cambrian shale of Jiangye-1 is around 58 m thick and equipped with sapropel-type kerogen. The TOC content is generally larger than 2 wt% (Figure 3(a)), and the average porosity is about 2.1%. Based on the previous study of storage potential, the theoretical gas content of the lower Cambrian shale is 2.29-5.73 m³/t. Therefore, it tells that the study area is theoretically favorable for hydrocarbon generation.

However, the gas logging of Jiangye-1 reflects a weak gas bearing with a decreasing downwards gas content of 0.01-1.23 m³/t (Figure 3(a)) and the adsorbed gas on field of Jiangye-2 is dominated by nitrogen. This contrast leads to the target problem of this paper why there is high-content nitrogen rather than hydrocarbon gas in the shale gas in an area theoretically favorable for hydrocarbon generation.

3. Methodology

3.1. TOC Content Test and Gas Content Test

From the lower Cambrian shale in Jiangye-1, fifty-one core samples were selected in total. Present-day TOC content tests were carried out by an OG-2000v analyzer and gas content tests were operated by LH-2 shale gas content analyzer.

3.2. Gas Component Analysis and Nitrogen Isotope Analysis

Using the AD-RJ-150-6-type shale gas field analytical instrument, there are sixteen gas samples of different depths collected from the cores of the lower Cambrian Guanyintang and Wangyinpu formations in Jiangye-1 (Table 1). The cores were taken on field. The gas samples underwent gas component analysis by the GC-2014C Gas Chromatograph and stable nitrogen isotope analysis by the EA IsoLink™ 253 Plus™ IRMS.

Table 1: Information of gas samples from Jiangye-1. See Figure 1 for the well location.

No.
Well
Depth (m)
Fm.

1
Jiangye-1
2540
Guanyintang

2
Jiangye-1
2545
Guanyintang

3
Jiangye-1
2562
Guanyintang

4
Jiangye-1
2568
Guanyintang

5
Jiangye-1
2574
Guanyintang

6
Jiangye-1
2580
Guanyintang

7
Jiangye-1
2585
Guanyintang

8
Jiangye-1
2590
Guanyintang

9
Jiangye-1
2595
Guanyintang

10
Jiangye-1
2602
Guanyintang

11
Jiangye-1
2612
Wangyinpu

12
Jiangye-1
2620
Wangyinpu

13
Jiangye-1
2635
Wangyinpu

14
Jiangye-1
2641
Wangyinpu

15
Jiangye-1
2655
Wangyinpu

16
Jiangye-1
2669
Wangyinpu

No. = sample number; Fm. = formation.

3.3. Overburden Permeability Test

From the lower Cambrian Wangyinpu formation in the Lower Yangtze, there were ten samples selected, among which 2 were from Jiangye-1 and the other 8 were from Jiangye-2 (Table 2). The overburden permeability analyzer PDP-200 was adopted in the tests in both directions of parallel (for lateral permeability) and perpendicular (for vertical permeability) to bedding planes. The pressure of the permeability test and the confining pressure was 1000 and 1500 psi, respectively.

Table 2: Information of samples for permeability tests. See Figure 1 for the well locations.

No.
Well
Depth (m)
Fm.

1
Jiangye-1
2635
Wangyinpu

2
Jiangye-1
2641
Wangyinpu

3
Jiangye-2
3090
Wangyinpu

4
Jiangye-2
3095
Wangyinpu

5
Jiangye-2
3101
Wangyinpu

6
Jiangye-2
3108
Wangyinpu

7
Jiangye-2
3115
Wangyinpu

8
Jiangye-2
3122
Wangyinpu

9
Jiangye-2
3129
Wangyinpu

10
Jiangye-2
3135
Wangyinpu

No. = sample number; Fm. = formation.

3.4. FIB-HIM Experiment

FIB-HIM is suitable for shale micropore reorganization for its high resolution, which makes it possible to achieve a resolution of 0.5 nm under 45 kV. An ORION NanoFab microscope is used to identify organic pores. Additionally, grinding and Ar-ion polishing were involved in a sample preparation.

In this paper, samples were chosen from the organic-rich shale of the lower Cambrian Wangyinpu formation in Jiangye-1 at a depth of 2630 m. The data of the experimental results of the lower Silurian Longmaxi formation shale of the Jiaoye-1 in Sichuan Basin, South China, were from Wang et al. [13, 14, 40].

4. Results and Discussion

4.1. Gas Components

The results of gas components analysis are shown in Figure 4. It supposes that the shale gas is dominated by nitrogen and oxygen with the percentage of volume of 80% and 17%, respectively, which is close to the content in the air (78% and 21%, respectively). The average methane content is only 0.22%.

Figure 4: Gas components of the lower Cambrian Guanyintang and Wangyinpu formations of Jiangye-1. See Figure 1 for the location of the well location.

In comparison, the average nitrogen content in natural gas is about 3% in the United States and less than 8% in most plays of China [30]. The nitrogen content is 10%~30% in natural gas of the Tarim Basin, where nitrogen is highly concentrated [31, 33], less than 10% in Northeast Chongqing shale gas and almost 0 in Jiaoshiba shale gas play, Fuling [28, 30, 32]. The nitrogen content of the study area is far higher than average and reflects its unique accumulation characteristics.

4.2. Nitrogen Sources

From the tests of stable nitrogen isotope, the δ¹⁵N of all the sixteen samples ranges from -0.8‰ to 0‰ (Figure 5). It is summarized from the previous researches that the content of stable nitrogen isotope depends on its sources, and based on Krooss et al. [41], Zeng [42], and Liu et al. [43], nitrogen sources, genesis mechanisms, and corresponding isotopic content are summarized in Table 3. The δ¹⁵N of the study area falls in two sources. Therefore, it indicates the mixed origins of nitrogen, the atmosphere, and the deep crust-upper mantle.

Figure 5: δ¹⁵N content of the lower Cambrian Guanyintang and Wangyinpu formation shale gas of Jiangye-1. See Figure 1 for the location of the well location.

Table 3: Summarized characteristics of stable nitrogen isotope of nitrogen in natural gas of different sources (modified from Zeng [42] and Liu et al. [43]).

Sources
Genesis mechanism
Nitrogen isotope (δ¹⁵N≈)

Atmosphere
Carried by surface water, diffused underground
0‰

Deep crust-upper mantle
Thermal reactions and radiation effects in the Earth’s core
-2‰~+1‰

Sedimentation
Metamorphism
High temperature metamorphism of nitrogenous minerals
+1‰~+3.5‰

Microbial denitrification
Generated by interactions between organisms and organic matter
-17‰~-10‰

Thermal evolution
Evolutionary stages of organic matter
Immature
<-10‰

Mature-highly mature
-10‰~-1‰

Overmature
+5‰~+20‰

4.3. Causes of Nitrogen Concentration

4.3.1. Effective Pathway Network to Atmosphere

(1) Lateral Pathway. In the overburden permeability tests, the lateral permeability and the vertical permeability were obtained by samples being tested in parallel and perpendicular, respectively, to the bedding planes. As Figure 6 shows, generally, the lateral is larger than the vertical and the ratio of these two reflects that the lateral permeability is more than 1~40 times higher than the vertical, indicating a dominant migration pathway along the bedding planes (Figure 7).

Figure 6: Lateral and vertical permeability of the lower Cambrian shale of Jiangye-1 and Jiangye-2. See Figure 1 for the well locations.

Figure 7: The ratio of lateral and vertical permeability of the lower Cambrian of Jiangye-1 and Jiangye-2. See Figure 1 for the well locations.

Cores were from the bottom of the lower Cambrian shale in Jiangye-1 and Jiangye-2. The observation revealed obvious characteristics of the bedding slip deformation (Figures 8(a) and 8(b)). Furthermore, apparent slippage and crinkle phenomenon (Figure 8(c)) are presented in the Laozhuang Outcrop. These obvious deformation structures are widely developed at the bottom of the Wangyinpu formation in the study area, reflecting the general existence of a detachment layer at the bottom of the lower Cambrian in Xiuwu Basin, which resulted from the relative slipping between the soft shales of the Wangyinpu formation and the hard siliceous dolomite of Piyuancun formation under the North-South extrusion influencing the whole basin. The gas content of the Wangyinpu formation decreased when it is near the bottom, from 0.93 m³/t in the lower part to 0.73 m³/t at the bottom of the formation. The detachment layer at the bottom of the lower Cambrian greatly accelerated the diffusion process of shale gas.

(a)

(b)

(c)

Figure 8: A detachment layer widely developed at the bottom of the lower Cambrian Wangyinpu formation shale in Xiuwu Basin. Core photos at the bottom of the lower Cambrian Wangyinpu formation: (a) in Jiangye-1 (depth: 2670 m) and (b) in Jiangye-2 (depth: 3135 m). (c) A photo of Laozhuang Outcrop at the bottom of the lower Cambrian Wangyinpu formation. See Figure 1 for the well locations.

From the analysis above, the bedding surface and the detachment layer comprise the migration pathways in the lateral direction to communicate with the atmosphere, partly leading to the concentration of nitrogen and the diffusion of hydrocarbon gas.

(2) Vertical Pathway. Physical sealing is the main mechanism that roof and floor seal the natural gas within organic-rich shale in vertical direction. A quality seal on organic-rich shale requires a large thickness of roof and floor and a lower porosity than shale gas interval. The burial depth, the thickness of the organic-rich shale, and the average TOC content control the self-sealing property of the shale. As Table 4 tells, the roof of Guangyintang formation and the floor of Piyuancun formation are equipped with a large thickness and much lower porosity than the shale gas interval. In the meanwhile, the shale gas interval of Wangyinpu formation is buried at a moderate depth (2609.5~2672 m) with a large thickness of organic-rich shale (62.5 m). Its TOC content is higher than the roof and the floor reflecting a stronger adsorption capability of shale gas and a strong self-sealing property. Therefore, it reveals that the lower Cambrian shale should have a favorable physical sealing.

Table 4: The sealing parameters of shale and its roof and floor in Jiangye-1 of the lower Cambrian Wangyinpu formation. The data of average TOC content and average porosity is referred to Liu et al. [24]. See Figure 1 for the well locations.

Part
Fm.
Lith.
Depth (m)
Avg. TOC (%)
Avg. porosity (%)
Thk. (m)

Roof
Guanyintang
Silty shale
2520~2609.5
2~4
1.2
89.5

Shale gas interval
Wangyinpu
Organic-rich siliceous shale
2609.5~2672
7~14
2.2
62.5

Floor
Piyuanchun
Silty shale
>2672
0.1~0.6
0.7
>50

Fm. = formation; Lith. = lithology; Avg. = average; TOC = total organic carbon; Thk. = thickness.

However, things changed when it comes to the tectonic evolution and seismic interpretation.

As mentioned in geological settings, tectonic evolution history shows that, influenced by the collision between the Southern China and the North China plates, study area was squeezed into a syncline with a large number of thrust faults in the early-middle Jurassic [39]. After that, in the Late Cretaceous to the Paleogene, the stress of the whole basin changed from extrusion to tension forcing the faults reopened due to the tension effects from the subduction of the Pacific Plate to the Eurasian Plate [44]. The stress did not change back to extrusion from tension until the Neogene [13, 14].

According to the seismic inter of the section through the study area, deep and large faults developed massively going through the roof, the shale gas interval, and even the floor (Figure 9). These faults destroyed the physical sealing in vertical direction, forming the vertical pathways, composing the pathway network with the lateral ones and made it more effective for gas exchange with the atmosphere. Furthermore, the reopening of the faults in Late Cretaceous to the Paleogene contributes to a large loss of shale gas.

Figure 9: Hydrocarbon gas diffuses and nitrogen from atmosphere entrances through bedding planes, the detachment layer, and deep faults in section of EW303.4 through Xiuwu Basin. See Figure 1 for the well locations.

4.3.2. Frequent Magmatic Activities Brought Nitrogen

According to the previous studies [45], the value of paleo-heat flow changed greatly since the early Cambrian. The value of paleo-heat flows increased slowly at first (the Cambrian to the Late Triassic: 543 Ma~205 Ma) and then began a rapid increase since the Late Triassic (around 205 Ma). According to regional tectonic evolution, it was when the plates of the North China and the South China collided leading to frequent magmatic activities in surrounding areas. At the turn of the Jurassic and the Cretaceous (around 137 Ma), it reached a maximum. It gradually cooled down during the early Cretaceous (137 Ma~96 Ma). In the Late Cretaceous to the Paleogene (96 Ma~23.3 Ma), it reached another high point due to the tectonic movements (Figure 10). It slowly cooled down to the present value afterwards.

Figure 10: Value of the paleo-heat flows in Xiuwu Basin. Data is referred to Li et al. [45].

The frequent magmatic activities brought nitrogen from the deep crust and upper mantle to the basin basement. In the process of magma cooling, nitrogen was vaporized into the lower Cambrian shale reservoir.

4.3.3. Overmaturity Accelerated Diffusion

The thermal evolution of organic matter is mainly controlled by paleo-geotemperature, while paleo-geotemperature is related to buried depth and value of paleo-heat flows. According to the previous researches [39, 45–48], Xiuwu Basin reached the maximum burial depth when the North China plate collided with the South China plate in the Triassic. As it can be told from the burial and thermal evolution history (Figure 11), even though it uplifted after reaching the maximum depth, the geotemperatue continued to increase as the value of paleo-heat flows increased rapidly and reached 270°C at the turn of the Jurassic and the Cretaceous (137 Ma). The organic matter was consequently overcooked with the vitrinite reflection () of 3.8% and evolved into graphitization stage [45].

Figure 11: The burial history and the thermal evolution history of Jiangye-1 in Xiuwu Basin. See Figure 1 for the well location (modified from Li et al. [45]).

Generally, organic pores are more developed in moderate maturity (). The graphitization of organic matter may collapse the organic pores and lead to the decrease of the adsorption capacity of organic matter to natural gas, and, therefore, reducing of gas bearing potential of shale [49–54]. The low-mature Longmaxi shale and the overmature Wangyinpu shale were compared. Figures 12(a) and 12(b) are FIB-HIM photos of the Longmaxi shale in Jiaoye-1 and the Wangyinpu shale in Jiangye-1. It shows much fewer organic pores observed in the Wangyinpu shale. This resulted in the diminishment of storage ability of shale and promoted the loss of hydrocarbon gas and relatively increased the nitrogen content.

(a)

(b)

Figure 12: FIB-HIM photos of organic-rich shale: (a) the lower Silurian Longmaxi shale in Jiaoye-1, Jiaoshiba Play (depth: 2402 m, TOC: 4.44%, : 2.58%) (from Wang et al. [13]) and (b) the lower Silurian Wangyinpu shale in Jiangye-1, Xiuwu Basin (depth: 2402 m, TOC: 11.27%, : 3.8%). See Figure 1 for the well locations.

4.4. Explanation Model Summarization

After all the studies above, a model was summarized to explain the destruction of shale gas reservoirs and the causes of high-content nitrogen and low-content hydrocarbon in shale gas of the study area, which affected by active plate movements. As presented in Figure 13, the effective network of migration pathways made the gas exchange possible between the shale gas reservoir and the atmosphere. The network is composed of the lateral pathways including the bedding surface and the detachment layer and the vertical ones which are the trust faults. The magmatic activities not only brought the nitrogen from the deep crust and upper mantle but also overcooked the organic matter and accelerated the loss of shale gas, which increased the relative content of nitrogen.

Figure 13: An explanation model for the destruction of shale gas reservoirs and the nitrogen concentration in the study area.

As a shale gas play, which was favorable for hydrocarbon generation but experienced complex tectonic evolution and affected by plate movements, the study area represents areas near the plate conjecture in the Lower Yangtze Region. The summarized model is applicable to explain the causes of the destruction of shale gas reservoirs and the widespread phenomenon where nitrogen concentrates and hydrocarbon diffuses in tectonic-complex areas in the Lower Yangtze Region and even in the some plate-active areas.

5. Conclusions

To solve the problem why a general phenomenon exists that nitrogen is highly concentrated and hydrocarbon diffuses in the lower Cambrian shale gas play in Xiuwu Basin, this paper takes two shale gas exploration wells, Jiangye-1 and Jiangye-2, as examples. After determining the detailed shale gas composition through the on-field gas component analysis, stable nitrogen isotopes were applied to identify the sources of the nitrogen. Then the overburden permeability tests in different directions reflected the existence of migration pathways and the FIB-HIM photos revealed the negative impact of overmaturity on organic pores, which, combined with the comprehensive analysis of the geological settings, the description of cores and outcrop, the interpretation of seismic section, and the history of thermal and tectonic evolution reveal the causes of the phenomenon which was the result of the effects of the effective pathway network, the magmatic activities, and the consequent overmaturity of organic matter. The explanation model of the destruction of shale gas reservoir in study area was summarized, and the conclusion was drawn as follows:

(i)With the gas component analysis on the field, it revealed that the nitrogen accounts for 80 vol.% in the lower Cambrian shale gas. The value of δ¹⁵N ranges from -0.8‰ to 0‰, which reflects that the nitrogen is mainly from the atmosphere and the deep crust and upper mantle according to the summary of previous works(ii)Effective network of migration pathways partly led to the high content of nitrogen. The shale bedding surface and the detachment layer at the bottom of the lower Cambrian compose of the lateral pathways to atmosphere. In vertical, massively developed trust faults damaged the quality sealing, forming the pathway network with the lateral ones(iii)The frequent magmatic activities in the Jurassic brought nitrogen from deep crust and upper mantle and caused the organic matter highly overmatured to the graphitization stage, consequently reducing the storage capability and accelerating the methane loss, which increased the relative content of nitrogen in shale gas

Data Availability

Some of the data are contained in a published source cited in the References. All the data in this article is accessible to readers.

Disclosure

An earlier version of this study was presented as an abstract in GSA Annual Meeting in Indianapolis, Indiana, USA—2018.

Conflicts of Interest

There are no conflicts of interest with respect to the results of this paper.

Authors’ Contributions

Yizhou Huang and Kun Zhang contributed equally to this work.

Acknowledgments

Thanks are due to all the financings supporting the research, which are the National Science and Technology Major Project, the Science Foundation of the Ministry of Land and Resources of China, the National Natural Science Foundation of China, the Performance Incentive and Guidance of Chongqing Scientific Research Institute, and the Sinopec Key Laboratory of Shale Oil/Gas Exploration and Production Technology. Also, thanks are due to all coauthors who worked with me through the whole research.

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