# Geological Feasibility of Underground Oil Storage in Jintan Salt Mine of China

Authors: Xilin Shi; Wei Liu; Jie Chen; Chunhe Yang; Yinping Li; Hongling Ma; Huihua Peng; Tongtao Wang; Xuqiang Ma
Journal: Advances in Materials Science and Engineering
 (2017)

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## Abstract

A number of large underground oil storage spaces will be constructed in deep salt mines in China in the coming years. According to the general geological survey, the first salt cavern oil storage base of China is planned to be built in Jintan salt mine. In this research, the geological feasibility of the salt mine for oil storage is identified in detail as follows.(1) The characteristics of regional structure, strata sediment, and impermeable layer distribution of Jintan salt mine were evaluated and analyzed. (2) The tightness of cap rock was evaluated in reviews of macroscopic geology and microscopic measuring. (3) According to the geological characteristics of Jintan salt mine, the specific targeted formation for building underground oil storage was chosen, and the sealing of nonsalt interlayers was evaluated. (4) Based on the sonar measuring results of the salt caverns, the characteristics of solution mining salt caverns were analyzed. In addition, the preferred way of underground oil storage construction was determined. (5) Finally, the results of closed well observation in solution mining salt caverns were assessed. The research results indicated that Jintan salt mine has the basic geological conditions for building large-scale underground oil storage.


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## Body

## 1. Introduction

Strategic petroleum reserve (SPR) is a significant part of China’s energy structure, and perfecting China’s strategic oil reserve is also a necessary part of the 13th five-year plan for energy of China. In 2015, China’s dependence on imported oil increased to a record 63.7% [1], so it is urgent to construct more oil reserve. China’s strategic petroleum reserve has been planned to complete from 2003 to 2020, which is divided into three periods. Until 2020, oil reserve base construction will be completed, and then China’s petroleum reserve capacity will increase to about 85 × 109 t, equivalent to 90 days’ oil net imports. Currently, the second phase of China’s strategic petroleum reserve has been accomplished; however, most of reserve bases are located at offshore cities on the ground. Taking oil safety and regional economy harmonious development into account, the government has to switch reserve base from the offshore cities to inland, as well as from the construction of surface tanks to underground storage facilities.Rock salt has been recognized as having low permeability [2], low porosity [3], high ductility [4, 5], and water-soluble mining [6]. For these characteristics, rock salt is widely considered as the ideal host rock for hydrocarbon energy (gas or oil) storage [7–9]. Usually, salt cavern oil storage group is constructed in deep salt mine, hundred meters to thousand meters in depth, by water-solution mining method (see Figure 1). Salt cavern oil storage group is composed of many salt caverns, and the storage capacity of individual cavern is more than 20 × 104 m3. As a result, the total oil storable volume is up to millions or even tens of million cube meters. Nowadays, many countries have carried out large-scale oil reserves in underground salt caverns. For instance, in Germany, 42% of crude oil is stored in salt caverns. In the USA, the strategic oil reserves are mostly located in underground salt caverns. In addition, the construction cost on the ground is about $15~18 per barrel, while it is more than $30 per barrel in the digging rock cave. However, the construction cost is low, $1.5 per barrel, in underground salt caverns that are located in the Gulf of Mexico, USA. Therefore, the outstanding advantages of underground salt cavern oil storage include large storage capacity, high security, and remarkable economic benefits.Figure 1
Illustration of salt cavern oil storages in a bedded salt formation.In China, the formation conditions of many salt mines with wide range distribution are good enough to construct salt caverns [10]. The salt formations in China are mainly thin, bedded, and highly heterogeneous [11]. The geological tectonics, corrosion [12, 13], rock mechanics [14–17] and creep damage characteristics [18–20], gas storage tightness [21, 22], and risk assessment [23, 24] are thoroughly investigated. After more than ten years’ research and practice, China has begun to carry out the demonstration or construction of salt cavern oil storage in central and eastern regions.Owing to the outstanding advantages of salt cavern oil storage and abundant salt resources, China has made a preliminary plan of the third phase of the national petroleum reserve, which is going to be built in deep salt mine. In consideration of the distribution of Chinese salt mine [10], the construction of salt cavern oil storage can be considered in the economic developed districts of Middle East, such as Jintan salt mine, which is most likely to become the China’s first salt cavern oil storage. In this manuscript, the geological feasibility of underground oil storage in Jintan salt mine had been analyzed from the Jintan geological data and related rock parameters including the geological characters, tightness of cap rock, tightness of targeted strata, and sealing of existing salt caverns (Figure 2), from which we could judge whether Jintan salt mine strata was suitable for large-scale oil storage.Figure 2
Evaluation system of geological feasibility on underground oil storage.


## 2. Geological Evaluation of Jintan Salt Mine

### 2.1. Regional Structure Characteristics

Figure3 shows the tectonic map of Jintan salt mine which is a typical lacustrine fault cut halite subsag controlled by boundary faults and belongs to a lacustrine deposition. According to the characteristics of the base ups and downs and sedimentation development, as well as the spatial distribution law, the salt mine sag has one apophasis and two subsags along northeast. Thus it can be seen that the geological structure of the salt mine is simple and clear, which is advantageous to the tightness of underground oil storage group.Figure 3
Tectonic map and thickness of saliferous strata of Jintan salt mine.As shown in Figure3, there are four big faults, fault Fx, fault Fz, fault Fb, and fault Fg, and three small faults derived from fault Fz around the salt mine. Fortunately, there is no big fault found in the principal area of the salt mine. Importantly, the four big faults around the salt basin are all normal faults, which have been in inactive state since the Cenozoic. And the fault planes have also been in the state of sealing and tightness; the longitudinal direction of fault does not cut the salt rock. What is more, both sides of the faults are rock salt and mudstone with excellent plasticity and compact structure, resulting in remarkable sealing capacity. Therefore, a certain safe distance can ensure the security of oil caverns as long as the four big faults, Fx, Fz, Fb, and Fg, are avoided around the salt basin.As shown in Figure3, the area, thickness, and sedimentary center thickness of saliferous strata are 60.5 km2, 67.85~230.95 m, and 200 m, respectively, and the distribution of salt layers is relatively stable in plane and vertical direction in Jintan mining area. Besides, the distribution of salt layers is gentle and generally tilts towards the northwest with low dip angle (<10°). Such a small dip angle is beneficial to the shape control of oil storage during the salt cavern leaching process. It is suitable for the construction of underground oil storage by water leaching method.


### 2.2. Regional Earthquake Characteristics

According to the historical seismic data of Jintan salt mine and its adjacent area [25], there were a total of 26 earthquakes, which were greater than level 3, since AD 320. The maximum earthquake intensity was 6, and the common intensity was 3~5. However, only 7 quakes happened in Jintan area with the maximum magnitude of 3.5. According to the seismic ground motion parameter zonation map of China [26], the seismic peak ground acceleration and the characteristic period of the seismic response spectrum in engineering area are 0.05 g and 0.40 s, respectively. According to the seismic history of Jintan region, the seismic precautionary intensity of this region is VI. Therefore, there is little influence on the regional stability of Jintan area due to tectonic activities. In the engineering construction, the designed requirement for seismic resistance of VII can sufficiently guarantee the safety of oil storage against earthquake.


### 2.3. Strata Sediment Characteristics

Based on the investigations of the existing geological exploration data of Jintan salt mine, we chose the typical exploration Well M1# (the location was marked in Figure3) as the specific research object. As shown in Figure 3, Well M1# is located near the center of salt mine deposition, which has very good representativeness of the salt mine.The Paleogene stratum is covered by Quaternary in the Cenozoic of Jintan basin, which is revealed by drilling data inside the basin. Besides, the Tertiary is absent in this area, whereas the Quaternary loosely covers the entire area. Table1 shows the strata information of Jintan salt mine, according to the comprehensive salt mine strata histogram [10] and exploration well data [27]. As shown in Table 1, the Paleogene is composed of Funing, Dainan, and Sanduo group from bottom to top. The saliferous strata distribute in the upper part of the Funing group, that is, the 4th part (Ef4), which was deposited in shallow lake under the condition of static and dynamic water exchange environment in early sedimentary period. The profile structure of Ef4 is relatively simple. The bottom of Ef4 is mainly gypsum-containing glauberite mudstone; the top of Ef4 is mainly glauberite mudstone and mudstone. Comparatively, halite is included in the middle of Ef4. The thickness of halite layer with 80% salt content is high enough to ensure the efficiency of shape in the construction of oil storage. In addition, the moderate depth of Ef4 is 809.38~1045.57 m, which is also very suitable for the security and stable operation of underground oil storage.Table 1
Stratum information of Jintan salt mine.
Stratum M1# System Group Part Symbol Depth(m) Apparent thickness(m) Lithotype Quaternary Dongtai — Qd 17.0 17.0 Sandy clay, mudstone, glutenite  Paleogene Sanduo 2nd Es2 371.5 354.5 Top: conglomeratic sandstone, brown silty mudstone Middle: powder sandstone, silty sandstone, mudstone Bottom: mudstone, sandy mudstone 1st Es1 566.5 195.0 Top: basalt, metamorphic silty tuff Middle: gray silty mudstone Bottom: mudstone, gray mudstone Dainan 2nd Ed2 757.0 190.5 Silty powder sandstone, mudstone, conglomeratic mudstone 1st Ed1 832.5 75.5 Gray mudstone, sandy mudstone, mudstone, dolomitic mudstone Funing 4th Ef4 860.0 27.5 Top: gypsum mudstone, dolomitic mudstone, mudstone 1055.0 195.0 Middle: argillaceous rock salt, nitrate salt rock, thenardite salt rock, nitrate mudstone, salt mudstone, mudstone 1110.0 55.0 Bottom: mudstone


### 2.4. Water-Resisting Rock Layers

Owing to the good water-soluble property of salt rock, salt formation which is not connected with the underground water system is a necessary condition for contribution of oil storage.According to the hydrogeological characteristics of Jintan salt mine, there are effective water-resisting layers with considerable thickness along the longitudinal direction and above and below the salt layer, which are mainly reflected in the following three aspects:(1)
Basalt in the 1st part of Sanduo group: a wide distribution area, accumulated thickness of 50~120 m, stable thickness of 50 m in the center of basin, poor fracture, and good waterproof property(2)
The 2nd part of Sanduo group and Dainan group: located between basalt and the top of salt layers, containing mudstone, gray mudstone, and sandy mudstone, total thickness of 500 m, poor fracture, and argillaceous, calcareous, and nitrate-filled fracture(3)
The bottom of salt layer: dense-hard mudstone, silty mudstone, poor fracture, total thickness of about 100 m only below the salt layer in the 4th part of Funing group, and mudstone in the 3rd part of Funing groupFrom the above, it can be seen that the hydrogeological conditions of Jintan salt mine are so simple that they would not have bad influence on the salt layers of oil storage.


## 2.1. Regional Structure Characteristics

Figure3 shows the tectonic map of Jintan salt mine which is a typical lacustrine fault cut halite subsag controlled by boundary faults and belongs to a lacustrine deposition. According to the characteristics of the base ups and downs and sedimentation development, as well as the spatial distribution law, the salt mine sag has one apophasis and two subsags along northeast. Thus it can be seen that the geological structure of the salt mine is simple and clear, which is advantageous to the tightness of underground oil storage group.Figure 3
Tectonic map and thickness of saliferous strata of Jintan salt mine.As shown in Figure3, there are four big faults, fault Fx, fault Fz, fault Fb, and fault Fg, and three small faults derived from fault Fz around the salt mine. Fortunately, there is no big fault found in the principal area of the salt mine. Importantly, the four big faults around the salt basin are all normal faults, which have been in inactive state since the Cenozoic. And the fault planes have also been in the state of sealing and tightness; the longitudinal direction of fault does not cut the salt rock. What is more, both sides of the faults are rock salt and mudstone with excellent plasticity and compact structure, resulting in remarkable sealing capacity. Therefore, a certain safe distance can ensure the security of oil caverns as long as the four big faults, Fx, Fz, Fb, and Fg, are avoided around the salt basin.As shown in Figure3, the area, thickness, and sedimentary center thickness of saliferous strata are 60.5 km2, 67.85~230.95 m, and 200 m, respectively, and the distribution of salt layers is relatively stable in plane and vertical direction in Jintan mining area. Besides, the distribution of salt layers is gentle and generally tilts towards the northwest with low dip angle (<10°). Such a small dip angle is beneficial to the shape control of oil storage during the salt cavern leaching process. It is suitable for the construction of underground oil storage by water leaching method.


## 2.2. Regional Earthquake Characteristics

According to the historical seismic data of Jintan salt mine and its adjacent area [25], there were a total of 26 earthquakes, which were greater than level 3, since AD 320. The maximum earthquake intensity was 6, and the common intensity was 3~5. However, only 7 quakes happened in Jintan area with the maximum magnitude of 3.5. According to the seismic ground motion parameter zonation map of China [26], the seismic peak ground acceleration and the characteristic period of the seismic response spectrum in engineering area are 0.05 g and 0.40 s, respectively. According to the seismic history of Jintan region, the seismic precautionary intensity of this region is VI. Therefore, there is little influence on the regional stability of Jintan area due to tectonic activities. In the engineering construction, the designed requirement for seismic resistance of VII can sufficiently guarantee the safety of oil storage against earthquake.


## 2.3. Strata Sediment Characteristics

Based on the investigations of the existing geological exploration data of Jintan salt mine, we chose the typical exploration Well M1# (the location was marked in Figure3) as the specific research object. As shown in Figure 3, Well M1# is located near the center of salt mine deposition, which has very good representativeness of the salt mine.The Paleogene stratum is covered by Quaternary in the Cenozoic of Jintan basin, which is revealed by drilling data inside the basin. Besides, the Tertiary is absent in this area, whereas the Quaternary loosely covers the entire area. Table1 shows the strata information of Jintan salt mine, according to the comprehensive salt mine strata histogram [10] and exploration well data [27]. As shown in Table 1, the Paleogene is composed of Funing, Dainan, and Sanduo group from bottom to top. The saliferous strata distribute in the upper part of the Funing group, that is, the 4th part (Ef4), which was deposited in shallow lake under the condition of static and dynamic water exchange environment in early sedimentary period. The profile structure of Ef4 is relatively simple. The bottom of Ef4 is mainly gypsum-containing glauberite mudstone; the top of Ef4 is mainly glauberite mudstone and mudstone. Comparatively, halite is included in the middle of Ef4. The thickness of halite layer with 80% salt content is high enough to ensure the efficiency of shape in the construction of oil storage. In addition, the moderate depth of Ef4 is 809.38~1045.57 m, which is also very suitable for the security and stable operation of underground oil storage.Table 1
Stratum information of Jintan salt mine.
Stratum M1# System Group Part Symbol Depth(m) Apparent thickness(m) Lithotype Quaternary Dongtai — Qd 17.0 17.0 Sandy clay, mudstone, glutenite  Paleogene Sanduo 2nd Es2 371.5 354.5 Top: conglomeratic sandstone, brown silty mudstone Middle: powder sandstone, silty sandstone, mudstone Bottom: mudstone, sandy mudstone 1st Es1 566.5 195.0 Top: basalt, metamorphic silty tuff Middle: gray silty mudstone Bottom: mudstone, gray mudstone Dainan 2nd Ed2 757.0 190.5 Silty powder sandstone, mudstone, conglomeratic mudstone 1st Ed1 832.5 75.5 Gray mudstone, sandy mudstone, mudstone, dolomitic mudstone Funing 4th Ef4 860.0 27.5 Top: gypsum mudstone, dolomitic mudstone, mudstone 1055.0 195.0 Middle: argillaceous rock salt, nitrate salt rock, thenardite salt rock, nitrate mudstone, salt mudstone, mudstone 1110.0 55.0 Bottom: mudstone


## 2.4. Water-Resisting Rock Layers

Owing to the good water-soluble property of salt rock, salt formation which is not connected with the underground water system is a necessary condition for contribution of oil storage.According to the hydrogeological characteristics of Jintan salt mine, there are effective water-resisting layers with considerable thickness along the longitudinal direction and above and below the salt layer, which are mainly reflected in the following three aspects:(1)
Basalt in the 1st part of Sanduo group: a wide distribution area, accumulated thickness of 50~120 m, stable thickness of 50 m in the center of basin, poor fracture, and good waterproof property(2)
The 2nd part of Sanduo group and Dainan group: located between basalt and the top of salt layers, containing mudstone, gray mudstone, and sandy mudstone, total thickness of 500 m, poor fracture, and argillaceous, calcareous, and nitrate-filled fracture(3)
The bottom of salt layer: dense-hard mudstone, silty mudstone, poor fracture, total thickness of about 100 m only below the salt layer in the 4th part of Funing group, and mudstone in the 3rd part of Funing groupFrom the above, it can be seen that the hydrogeological conditions of Jintan salt mine are so simple that they would not have bad influence on the salt layers of oil storage.


## 3. Tightness Evaluation of Cap Rock

In salt cavern oil storage, the crude oil may leak through the salt roof, the steel casings, or the cemented annulus. In geological aspects, the tightness of the cap rock is the basis to ensure the security of oil storage. The factors that influence the tightness of cap rock include the fault, homogeneity, and gas permeability of the cap rock.


### 3.1. Macroscopic Geological Evaluation

#### 3.1.1. Macroscopic Sealing Characteristic of Direct Cap Rock

The direct cap rock of the salt-bearing is located in Ed1 and the top of Ef4, with the depth and thickness being 800~1140 m and 96~150 m, respectively. From bottom to top, the direct cap rock consists of glauberite-containing mudstone, cloud gray mudstone, gypsum mudstone, glauberite-containing cloud mudstone, cloud mudstone, and ash black mudstone, which are all tight geomaterials with good sealing capacity. In addition, the distribution of the direct cap rock in the whole salt mine is stable and continuous, with a mean thickness over 120 m overlying the whole salt-bearing. Therefore, the direct cap rock is able to be the first effective barrier to prevent leakage of crude oil to the above strata.


#### 3.1.2. Macroscopic Sealing Characteristic of Indirect Cap Rock

The indirect cap rock is the strata overlying the direct cap rock, acting as the second barrier of the underground oil storages. The indirect cap rock of Jintan salt mine consists of thick mudstone stratum located between the top of direct cap rock and the bottom of Dainan group. From the thickness distribution map (Figure3), the maximum thickness is located in the north, whereas the thinnest is located in the southern edge of the tectonic uplift area. Despite that, the minimum thickness of indirect cap rock is up to 340 m, indicating that the whole indirect cap rock is thick enough, which is also beneficial to the tightness. Hence, these strata behave as the second effective barrier to prevent leakage of crude oil to the land surface.


#### 3.1.3. Sealing Characteristic Revealed by Drilling Data

According to the drilling data of Well M1# [28], there was no drilling mud leakage during the whole drilling process, illustrating that there are no big cracks in the entire drilled strata. Also, the bore diameter was not enlarged evidenced by logging, showing that the closure of filled seam was good under these geological conditions.Based on above analysis, the direct and indirect cap rocks of Jintan salt mine can act as effective overlying barriers to prevent the underground oil storage from groundwater erosion.


### 3.2. Microscopic Tightness Evaluation

The microscopic sealing capacity of cap rock mainly depends on the permeability of rock, that is, permeability and breakthrough pressure. Table2 shows the test results of permeability and breakthrough pressure of Well M1# carried out by the authors and our cooperators [27]. Considering the seepage direction of crude oil, the results show the sealing capacity of the cap rock in the vertical direction. For the cap rock cores with length of about 50 mm, it is found that the breakthrough pressure (1.36~5.71 MPa; mean value: 3.72 MPa) is high and the permeability (2.93~6.90 × 10−11 m2; average is 5.23 × 10−11 m2) is low. The data indicates that the cap rock can be used as effective overlying strata of oil storage.Table 2
The permeability and breakthrough pressure of Well M1#.
Number Depth Breakthrough pressure Permeability (m) (MPa) (×10−11 m2) PT-04 838.23 5.71 4.26 PT-06 840.28 1.64 6.23 PT-11 843.84 3.41 6.12 PT-13 846.23 1.36 6.56 PT-14 848.16 5.12 5.95 PT-17 851.44 3.70 6.90 PT-19 853.53 3.70 3.52 PT-22 855.99 5.12 2.93 Maximum 5.71 6.90 Minimum 1.36 2.93 Average 3.72 5.23


## 3.1. Macroscopic Geological Evaluation

### 3.1.1. Macroscopic Sealing Characteristic of Direct Cap Rock

The direct cap rock of the salt-bearing is located in Ed1 and the top of Ef4, with the depth and thickness being 800~1140 m and 96~150 m, respectively. From bottom to top, the direct cap rock consists of glauberite-containing mudstone, cloud gray mudstone, gypsum mudstone, glauberite-containing cloud mudstone, cloud mudstone, and ash black mudstone, which are all tight geomaterials with good sealing capacity. In addition, the distribution of the direct cap rock in the whole salt mine is stable and continuous, with a mean thickness over 120 m overlying the whole salt-bearing. Therefore, the direct cap rock is able to be the first effective barrier to prevent leakage of crude oil to the above strata.


### 3.1.2. Macroscopic Sealing Characteristic of Indirect Cap Rock

The indirect cap rock is the strata overlying the direct cap rock, acting as the second barrier of the underground oil storages. The indirect cap rock of Jintan salt mine consists of thick mudstone stratum located between the top of direct cap rock and the bottom of Dainan group. From the thickness distribution map (Figure3), the maximum thickness is located in the north, whereas the thinnest is located in the southern edge of the tectonic uplift area. Despite that, the minimum thickness of indirect cap rock is up to 340 m, indicating that the whole indirect cap rock is thick enough, which is also beneficial to the tightness. Hence, these strata behave as the second effective barrier to prevent leakage of crude oil to the land surface.


### 3.1.3. Sealing Characteristic Revealed by Drilling Data

According to the drilling data of Well M1# [28], there was no drilling mud leakage during the whole drilling process, illustrating that there are no big cracks in the entire drilled strata. Also, the bore diameter was not enlarged evidenced by logging, showing that the closure of filled seam was good under these geological conditions.Based on above analysis, the direct and indirect cap rocks of Jintan salt mine can act as effective overlying barriers to prevent the underground oil storage from groundwater erosion.


## 3.1.1. Macroscopic Sealing Characteristic of Direct Cap Rock

The direct cap rock of the salt-bearing is located in Ed1 and the top of Ef4, with the depth and thickness being 800~1140 m and 96~150 m, respectively. From bottom to top, the direct cap rock consists of glauberite-containing mudstone, cloud gray mudstone, gypsum mudstone, glauberite-containing cloud mudstone, cloud mudstone, and ash black mudstone, which are all tight geomaterials with good sealing capacity. In addition, the distribution of the direct cap rock in the whole salt mine is stable and continuous, with a mean thickness over 120 m overlying the whole salt-bearing. Therefore, the direct cap rock is able to be the first effective barrier to prevent leakage of crude oil to the above strata.


## 3.1.2. Macroscopic Sealing Characteristic of Indirect Cap Rock

The indirect cap rock is the strata overlying the direct cap rock, acting as the second barrier of the underground oil storages. The indirect cap rock of Jintan salt mine consists of thick mudstone stratum located between the top of direct cap rock and the bottom of Dainan group. From the thickness distribution map (Figure3), the maximum thickness is located in the north, whereas the thinnest is located in the southern edge of the tectonic uplift area. Despite that, the minimum thickness of indirect cap rock is up to 340 m, indicating that the whole indirect cap rock is thick enough, which is also beneficial to the tightness. Hence, these strata behave as the second effective barrier to prevent leakage of crude oil to the land surface.


## 3.1.3. Sealing Characteristic Revealed by Drilling Data

According to the drilling data of Well M1# [28], there was no drilling mud leakage during the whole drilling process, illustrating that there are no big cracks in the entire drilled strata. Also, the bore diameter was not enlarged evidenced by logging, showing that the closure of filled seam was good under these geological conditions.Based on above analysis, the direct and indirect cap rocks of Jintan salt mine can act as effective overlying barriers to prevent the underground oil storage from groundwater erosion.


## 3.2. Microscopic Tightness Evaluation

The microscopic sealing capacity of cap rock mainly depends on the permeability of rock, that is, permeability and breakthrough pressure. Table2 shows the test results of permeability and breakthrough pressure of Well M1# carried out by the authors and our cooperators [27]. Considering the seepage direction of crude oil, the results show the sealing capacity of the cap rock in the vertical direction. For the cap rock cores with length of about 50 mm, it is found that the breakthrough pressure (1.36~5.71 MPa; mean value: 3.72 MPa) is high and the permeability (2.93~6.90 × 10−11 m2; average is 5.23 × 10−11 m2) is low. The data indicates that the cap rock can be used as effective overlying strata of oil storage.Table 2
The permeability and breakthrough pressure of Well M1#.
Number Depth Breakthrough pressure Permeability (m) (MPa) (×10−11 m2) PT-04 838.23 5.71 4.26 PT-06 840.28 1.64 6.23 PT-11 843.84 3.41 6.12 PT-13 846.23 1.36 6.56 PT-14 848.16 5.12 5.95 PT-17 851.44 3.70 6.90 PT-19 853.53 3.70 3.52 PT-22 855.99 5.12 2.93 Maximum 5.71 6.90 Minimum 1.36 2.93 Average 3.72 5.23


## 4. Tightness Evaluation of Targeted Strata for Oil Storage

According to the analysis of strata information (Table1), the saliferous strata are located in Ef4. The targeted strata for oil storage constructed by solution mining method can be selected in the middle of Ef4.To further investigate the characteristics of rock cores in Ef4, the rock cores of well M1# were investigated, which were drilled from 834.86 to 1065.66 m (covering the entire Ef4), and the core recovery rate was 97.5%, suggesting that the targeted strata were fairly complete. Combining the drilling information of Well M1# with analytical tests of cores [27, 28], the tightness evaluation of targeted strata for oil storage will be evaluated below.


### 4.1. Lithologic Characteristics of Targeted Strata

According to the profile characteristics of salt layer revealed by Well M1#, Ef4 was divided into three sections from top to bottom, namely, top of salt bed, salt bed, and bottom of salt bed, as follows.


#### 4.1.1. Top of Salt Bed (Immediate Roof of Oil Storage)

In this section, the depth is 832.5~860.0 m and the apparent thickness is 27.5 m. The lithology is mainly gray gypsum mudstone, grey dolomitic mudstone, grey mudstone, and dark brown mudstone, which are all dense and hard and can be used as the ideal roof of salt cavern oil storage.


#### 4.1.2. Salt Bed (Targeted Strata of Oil Storage)

In this section, the depth is 860.0~1055.0 m and the apparent thickness is 195.0 m. The lithology is mainly grey argillaceous salt rock, nitrate salt rock, nitrate argillaceous salt rock, thenardite salt rock with celadon mudstone, nitrate mudstone, gray salt mudstone, mudstone, and dark brown mudstone, as shown in Table3. The thickness of single salt layer is very large (up to 49.0 m). Besides, this stratum is pure of salt, and the roof and bottom are all good enough to guarantee the sealing between layers.Table 3
Stratum distribution of Well M1# Ef4.
Number Lithotype Top depth Bottom depth Thickness Comment (m) (m) (m) 1 Rock salt 860.0 891.0 31.0 2 Mudstone 891.0 893.0 2.0 Interlayer 3 Rock salt 893.0 910.5 6.5 4 Mudstone 910.5 912.0 1.5 Interlayer 5 Rock salt 912.0 955.0 33.0 6 Mudstone 955.0 956.0 1.0 Interlayer 7 Rock salt 956.0 967.0 11.0 8 Mudstone 967.0 968.5 1.5 Interlayer 9 Rock salt 968.5 970.0 1.5 10 Mudstone 970.0 971.5 1.5 Interlayer 11 Rock salt 971.5 973.5 2.0 12 Mudstone 973.5 976.0 2.5 Interlayer 13 Rock salt 976.0 1025.0 49.0 14 Mudstone 1025.0 1027.0 2.0 Interlayer 15 Rock salt 1027.0 1055.0 28.0From Table3, we can see that this section contains seven mudstone interlayers with thickness of more than 1.0 m (the maximum is 2.5 m). The sealing capacity of the nonsalt interlayers is lower than salt. Therefore, the interlayers are the weak positions for tightness of oil storage (discussed in Sections 4.2 and 4.3).


#### 4.1.3. Bottom of Salt Bed (Immediate Bottom of Oil Storage)

In this section, the depth is 1055.0 to 1110.0 m and the apparent thickness is 55.0 m. The lithology is mainly interlayer of grey mudstone and dark brown mudstone, which is relatively hard and can be used as the excellent bottom of salt cavern storage.


### 4.2. Composition of Interlayers

#### 4.2.1. Thin Section Examination (TSE)

The mineral composition and types of the interlayers were measured by TSE under polarized light microscope using representative cores of Well M1#. The results are shown in Table4, from which we can see that the lithology of interlayers is all mudstone with 95.1% average mud content and little silt. As a result, the relative pure interlayers with good sealing ability are helpful to the tightness of oil storage.Table 4
TSE results of interlayers in Well M1#.
Number Depth Lithotype Mud Silt (m) (%) (%) TSE-38 891.0~893.0 Mudstone 95.0 0.5 TSE-41 910.5~912.0 Mudstone 97.0 0.5 TSE-47 955.0~956.0 Mudstone 95.5 2.0 TSE-49 967.0~968.5 Mudstone 95.0 4.0 TSE-52 973.5~976.0 Mudstone 92.0 8.0 TSE-53 973.5~976.0 Mudstone 96.0 3.0 Average 95.1 3.0


#### 4.2.2. X-Ray Diffraction (XRD)

Based on the above analysis, the main composition of interlayers is mudstone, which is mainly composed of clay minerals. The main types of clay minerals were carried out by X-ray diffraction analysis. As shown in Table5, the contents of glimmerton, illite/smectite mixed layer, and chlorite are 75.0%, 16.4%, and 8.2%, respectively. On one hand, it is well known that glimmerton is not easy to expand when immersed into water, which can effectively reduce the damage caused by the interlayers during the water-soluble mining process. Hence, it is good for the mechanics and sealing of surrounding rock. On the other hand, a small quantity of illite/smectite mixed layer that is easy to expand when immersed into water is beneficial to fill the microcracks in layers and improve the sealing ability of oil storage.Table 5
XRD analysis results of clay minerals in interlayers of Well M1#.
Number Depth Glimmerton Kaolinite Chlorite Illite/smectite mixed layer (m) (%) (%) (%) (%) XRD-37 891.0~893.0 80 0 10 10 XRD-38 891.0~893.0 74 0 6 20 XRD-39 891.0~893.0 71 0 7 22 XRD-47 955.0~956.0 75 0 10 15 XRD-49 967.0~968.5 72 0 8 20 XRD-51 970.0~971.5 85 3 7 5 XRD-52 973.5~976.0 68 0 12 20 XRD-53 973.5~976.0 75 0 6 19 Average 75.0 0.4 8.2 16.4According to the mineralogical analysis above, the main component of interlayers is mudstone (Table4) and the main clay mineral content of mudstone is glimmerton (Table 5). All relative minerals would not react obviously with the main ingredients of crude oil (hydrocarbon), which is indicative of stability and good quality of crude oil stored in the strata.


### 4.3. Tightness of Interlayers

#### 4.3.1. Scanning Electron Microscope (SEM)

Some micropores were found in the interlayers by thin section examination. In order to further explore the microstructure characteristics of micropores, scanning electron microscope was measured. Figure4 shows the typical SEM images of mudstone interlayer at different magnification. At low magnification (Figure 4(a)), we can see the micropores and heterogeneous distribution of halite. However, the distribution of micropores is slightly directional with increase of magnification (Figure 4(b)). At high magnification (Figure 4(c)), we can see that the rich development micropores are filled with a large number of oil droplet-like and membrane-like rock salt crystals, which can effectively prevent the leakage of oil molecules from oil storage.Figure 4
SEM images of a mudstone interlayer at different magnification.
(a) (b) (c)


#### 4.3.2. Mercury Intrusion Porosimetry (MIP)

Furthermore, the MIP measurements were conducted to evaluate the characteristics of interlayer samples, and the results are shown in Table6. Deng et al. divided the cap rock of natural gas reservoirs cap rock into six grades by breakthrough pressure [29]. As seen in Table 6, the mean value of the breakthrough pressure is 7.69 MPa. Even as the cap rock of oil/gas reservoir, it is located within the second and third grades, which is an effective barrier. It is known that the geological history of the oil/gas reservoirs is much longer than the oil/gas storage. So, the sealing evaluating criteria of storage are higher and stricter than reservoirs. Thus, the interlayers are all effective sealing rock layers for oil storages.Table 6
MIP test results of interlayers in Well M1#.
Number Depth Breakthrough pressure Breakthrough radius Median pressure Median radius (m) (MPa) (nm) (MPa) (nm) MIP-37 891.0~893.0 6.87 20.380 22.22 6.301 MIP-38 891.0~893.0 6.25 21.430 31.69 4.418 MIP-39 891.0~893.0 3.91 35.840 23.13 6.052 MIP-47 955.0~956.0 10.64 13.160 42.88 3.265 MIP-49 967.0~968.5 12.86 10.890 51.06 2.742 MIP-51 970.0~971.5 4.17 33.540 15.72 8.907 MIP-52 973.5~976.0 7.27 18.710 46.76 2.994 MIP-53 973.5~976.0 9.55 14.670 47.76 2.931 Maximum 12.86 35.840 47.76 8.907 Minimum 3.91 10.890 15.72 2.742 Average 7.69 21.080 35.15 4.700


## 4.1. Lithologic Characteristics of Targeted Strata

According to the profile characteristics of salt layer revealed by Well M1#, Ef4 was divided into three sections from top to bottom, namely, top of salt bed, salt bed, and bottom of salt bed, as follows.


### 4.1.1. Top of Salt Bed (Immediate Roof of Oil Storage)

In this section, the depth is 832.5~860.0 m and the apparent thickness is 27.5 m. The lithology is mainly gray gypsum mudstone, grey dolomitic mudstone, grey mudstone, and dark brown mudstone, which are all dense and hard and can be used as the ideal roof of salt cavern oil storage.


### 4.1.2. Salt Bed (Targeted Strata of Oil Storage)

In this section, the depth is 860.0~1055.0 m and the apparent thickness is 195.0 m. The lithology is mainly grey argillaceous salt rock, nitrate salt rock, nitrate argillaceous salt rock, thenardite salt rock with celadon mudstone, nitrate mudstone, gray salt mudstone, mudstone, and dark brown mudstone, as shown in Table3. The thickness of single salt layer is very large (up to 49.0 m). Besides, this stratum is pure of salt, and the roof and bottom are all good enough to guarantee the sealing between layers.Table 3
Stratum distribution of Well M1# Ef4.
Number Lithotype Top depth Bottom depth Thickness Comment (m) (m) (m) 1 Rock salt 860.0 891.0 31.0 2 Mudstone 891.0 893.0 2.0 Interlayer 3 Rock salt 893.0 910.5 6.5 4 Mudstone 910.5 912.0 1.5 Interlayer 5 Rock salt 912.0 955.0 33.0 6 Mudstone 955.0 956.0 1.0 Interlayer 7 Rock salt 956.0 967.0 11.0 8 Mudstone 967.0 968.5 1.5 Interlayer 9 Rock salt 968.5 970.0 1.5 10 Mudstone 970.0 971.5 1.5 Interlayer 11 Rock salt 971.5 973.5 2.0 12 Mudstone 973.5 976.0 2.5 Interlayer 13 Rock salt 976.0 1025.0 49.0 14 Mudstone 1025.0 1027.0 2.0 Interlayer 15 Rock salt 1027.0 1055.0 28.0From Table3, we can see that this section contains seven mudstone interlayers with thickness of more than 1.0 m (the maximum is 2.5 m). The sealing capacity of the nonsalt interlayers is lower than salt. Therefore, the interlayers are the weak positions for tightness of oil storage (discussed in Sections 4.2 and 4.3).


### 4.1.3. Bottom of Salt Bed (Immediate Bottom of Oil Storage)

In this section, the depth is 1055.0 to 1110.0 m and the apparent thickness is 55.0 m. The lithology is mainly interlayer of grey mudstone and dark brown mudstone, which is relatively hard and can be used as the excellent bottom of salt cavern storage.


## 4.1.1. Top of Salt Bed (Immediate Roof of Oil Storage)

In this section, the depth is 832.5~860.0 m and the apparent thickness is 27.5 m. The lithology is mainly gray gypsum mudstone, grey dolomitic mudstone, grey mudstone, and dark brown mudstone, which are all dense and hard and can be used as the ideal roof of salt cavern oil storage.


## 4.1.2. Salt Bed (Targeted Strata of Oil Storage)

In this section, the depth is 860.0~1055.0 m and the apparent thickness is 195.0 m. The lithology is mainly grey argillaceous salt rock, nitrate salt rock, nitrate argillaceous salt rock, thenardite salt rock with celadon mudstone, nitrate mudstone, gray salt mudstone, mudstone, and dark brown mudstone, as shown in Table3. The thickness of single salt layer is very large (up to 49.0 m). Besides, this stratum is pure of salt, and the roof and bottom are all good enough to guarantee the sealing between layers.Table 3
Stratum distribution of Well M1# Ef4.
Number Lithotype Top depth Bottom depth Thickness Comment (m) (m) (m) 1 Rock salt 860.0 891.0 31.0 2 Mudstone 891.0 893.0 2.0 Interlayer 3 Rock salt 893.0 910.5 6.5 4 Mudstone 910.5 912.0 1.5 Interlayer 5 Rock salt 912.0 955.0 33.0 6 Mudstone 955.0 956.0 1.0 Interlayer 7 Rock salt 956.0 967.0 11.0 8 Mudstone 967.0 968.5 1.5 Interlayer 9 Rock salt 968.5 970.0 1.5 10 Mudstone 970.0 971.5 1.5 Interlayer 11 Rock salt 971.5 973.5 2.0 12 Mudstone 973.5 976.0 2.5 Interlayer 13 Rock salt 976.0 1025.0 49.0 14 Mudstone 1025.0 1027.0 2.0 Interlayer 15 Rock salt 1027.0 1055.0 28.0From Table3, we can see that this section contains seven mudstone interlayers with thickness of more than 1.0 m (the maximum is 2.5 m). The sealing capacity of the nonsalt interlayers is lower than salt. Therefore, the interlayers are the weak positions for tightness of oil storage (discussed in Sections 4.2 and 4.3).


## 4.1.3. Bottom of Salt Bed (Immediate Bottom of Oil Storage)

In this section, the depth is 1055.0 to 1110.0 m and the apparent thickness is 55.0 m. The lithology is mainly interlayer of grey mudstone and dark brown mudstone, which is relatively hard and can be used as the excellent bottom of salt cavern storage.


## 4.2. Composition of Interlayers

### 4.2.1. Thin Section Examination (TSE)

The mineral composition and types of the interlayers were measured by TSE under polarized light microscope using representative cores of Well M1#. The results are shown in Table4, from which we can see that the lithology of interlayers is all mudstone with 95.1% average mud content and little silt. As a result, the relative pure interlayers with good sealing ability are helpful to the tightness of oil storage.Table 4
TSE results of interlayers in Well M1#.
Number Depth Lithotype Mud Silt (m) (%) (%) TSE-38 891.0~893.0 Mudstone 95.0 0.5 TSE-41 910.5~912.0 Mudstone 97.0 0.5 TSE-47 955.0~956.0 Mudstone 95.5 2.0 TSE-49 967.0~968.5 Mudstone 95.0 4.0 TSE-52 973.5~976.0 Mudstone 92.0 8.0 TSE-53 973.5~976.0 Mudstone 96.0 3.0 Average 95.1 3.0


### 4.2.2. X-Ray Diffraction (XRD)

Based on the above analysis, the main composition of interlayers is mudstone, which is mainly composed of clay minerals. The main types of clay minerals were carried out by X-ray diffraction analysis. As shown in Table5, the contents of glimmerton, illite/smectite mixed layer, and chlorite are 75.0%, 16.4%, and 8.2%, respectively. On one hand, it is well known that glimmerton is not easy to expand when immersed into water, which can effectively reduce the damage caused by the interlayers during the water-soluble mining process. Hence, it is good for the mechanics and sealing of surrounding rock. On the other hand, a small quantity of illite/smectite mixed layer that is easy to expand when immersed into water is beneficial to fill the microcracks in layers and improve the sealing ability of oil storage.Table 5
XRD analysis results of clay minerals in interlayers of Well M1#.
Number Depth Glimmerton Kaolinite Chlorite Illite/smectite mixed layer (m) (%) (%) (%) (%) XRD-37 891.0~893.0 80 0 10 10 XRD-38 891.0~893.0 74 0 6 20 XRD-39 891.0~893.0 71 0 7 22 XRD-47 955.0~956.0 75 0 10 15 XRD-49 967.0~968.5 72 0 8 20 XRD-51 970.0~971.5 85 3 7 5 XRD-52 973.5~976.0 68 0 12 20 XRD-53 973.5~976.0 75 0 6 19 Average 75.0 0.4 8.2 16.4According to the mineralogical analysis above, the main component of interlayers is mudstone (Table4) and the main clay mineral content of mudstone is glimmerton (Table 5). All relative minerals would not react obviously with the main ingredients of crude oil (hydrocarbon), which is indicative of stability and good quality of crude oil stored in the strata.


## 4.2.1. Thin Section Examination (TSE)

The mineral composition and types of the interlayers were measured by TSE under polarized light microscope using representative cores of Well M1#. The results are shown in Table4, from which we can see that the lithology of interlayers is all mudstone with 95.1% average mud content and little silt. As a result, the relative pure interlayers with good sealing ability are helpful to the tightness of oil storage.Table 4
TSE results of interlayers in Well M1#.
Number Depth Lithotype Mud Silt (m) (%) (%) TSE-38 891.0~893.0 Mudstone 95.0 0.5 TSE-41 910.5~912.0 Mudstone 97.0 0.5 TSE-47 955.0~956.0 Mudstone 95.5 2.0 TSE-49 967.0~968.5 Mudstone 95.0 4.0 TSE-52 973.5~976.0 Mudstone 92.0 8.0 TSE-53 973.5~976.0 Mudstone 96.0 3.0 Average 95.1 3.0


## 4.2.2. X-Ray Diffraction (XRD)

Based on the above analysis, the main composition of interlayers is mudstone, which is mainly composed of clay minerals. The main types of clay minerals were carried out by X-ray diffraction analysis. As shown in Table5, the contents of glimmerton, illite/smectite mixed layer, and chlorite are 75.0%, 16.4%, and 8.2%, respectively. On one hand, it is well known that glimmerton is not easy to expand when immersed into water, which can effectively reduce the damage caused by the interlayers during the water-soluble mining process. Hence, it is good for the mechanics and sealing of surrounding rock. On the other hand, a small quantity of illite/smectite mixed layer that is easy to expand when immersed into water is beneficial to fill the microcracks in layers and improve the sealing ability of oil storage.Table 5
XRD analysis results of clay minerals in interlayers of Well M1#.
Number Depth Glimmerton Kaolinite Chlorite Illite/smectite mixed layer (m) (%) (%) (%) (%) XRD-37 891.0~893.0 80 0 10 10 XRD-38 891.0~893.0 74 0 6 20 XRD-39 891.0~893.0 71 0 7 22 XRD-47 955.0~956.0 75 0 10 15 XRD-49 967.0~968.5 72 0 8 20 XRD-51 970.0~971.5 85 3 7 5 XRD-52 973.5~976.0 68 0 12 20 XRD-53 973.5~976.0 75 0 6 19 Average 75.0 0.4 8.2 16.4According to the mineralogical analysis above, the main component of interlayers is mudstone (Table4) and the main clay mineral content of mudstone is glimmerton (Table 5). All relative minerals would not react obviously with the main ingredients of crude oil (hydrocarbon), which is indicative of stability and good quality of crude oil stored in the strata.


## 4.3. Tightness of Interlayers

### 4.3.1. Scanning Electron Microscope (SEM)

Some micropores were found in the interlayers by thin section examination. In order to further explore the microstructure characteristics of micropores, scanning electron microscope was measured. Figure4 shows the typical SEM images of mudstone interlayer at different magnification. At low magnification (Figure 4(a)), we can see the micropores and heterogeneous distribution of halite. However, the distribution of micropores is slightly directional with increase of magnification (Figure 4(b)). At high magnification (Figure 4(c)), we can see that the rich development micropores are filled with a large number of oil droplet-like and membrane-like rock salt crystals, which can effectively prevent the leakage of oil molecules from oil storage.Figure 4
SEM images of a mudstone interlayer at different magnification.
(a) (b) (c)


### 4.3.2. Mercury Intrusion Porosimetry (MIP)

Furthermore, the MIP measurements were conducted to evaluate the characteristics of interlayer samples, and the results are shown in Table6. Deng et al. divided the cap rock of natural gas reservoirs cap rock into six grades by breakthrough pressure [29]. As seen in Table 6, the mean value of the breakthrough pressure is 7.69 MPa. Even as the cap rock of oil/gas reservoir, it is located within the second and third grades, which is an effective barrier. It is known that the geological history of the oil/gas reservoirs is much longer than the oil/gas storage. So, the sealing evaluating criteria of storage are higher and stricter than reservoirs. Thus, the interlayers are all effective sealing rock layers for oil storages.Table 6
MIP test results of interlayers in Well M1#.
Number Depth Breakthrough pressure Breakthrough radius Median pressure Median radius (m) (MPa) (nm) (MPa) (nm) MIP-37 891.0~893.0 6.87 20.380 22.22 6.301 MIP-38 891.0~893.0 6.25 21.430 31.69 4.418 MIP-39 891.0~893.0 3.91 35.840 23.13 6.052 MIP-47 955.0~956.0 10.64 13.160 42.88 3.265 MIP-49 967.0~968.5 12.86 10.890 51.06 2.742 MIP-51 970.0~971.5 4.17 33.540 15.72 8.907 MIP-52 973.5~976.0 7.27 18.710 46.76 2.994 MIP-53 973.5~976.0 9.55 14.670 47.76 2.931 Maximum 12.86 35.840 47.76 8.907 Minimum 3.91 10.890 15.72 2.742 Average 7.69 21.080 35.15 4.700


## 4.3.1. Scanning Electron Microscope (SEM)

Some micropores were found in the interlayers by thin section examination. In order to further explore the microstructure characteristics of micropores, scanning electron microscope was measured. Figure4 shows the typical SEM images of mudstone interlayer at different magnification. At low magnification (Figure 4(a)), we can see the micropores and heterogeneous distribution of halite. However, the distribution of micropores is slightly directional with increase of magnification (Figure 4(b)). At high magnification (Figure 4(c)), we can see that the rich development micropores are filled with a large number of oil droplet-like and membrane-like rock salt crystals, which can effectively prevent the leakage of oil molecules from oil storage.Figure 4
SEM images of a mudstone interlayer at different magnification.
(a) (b) (c)


## 4.3.2. Mercury Intrusion Porosimetry (MIP)

Furthermore, the MIP measurements were conducted to evaluate the characteristics of interlayer samples, and the results are shown in Table6. Deng et al. divided the cap rock of natural gas reservoirs cap rock into six grades by breakthrough pressure [29]. As seen in Table 6, the mean value of the breakthrough pressure is 7.69 MPa. Even as the cap rock of oil/gas reservoir, it is located within the second and third grades, which is an effective barrier. It is known that the geological history of the oil/gas reservoirs is much longer than the oil/gas storage. So, the sealing evaluating criteria of storage are higher and stricter than reservoirs. Thus, the interlayers are all effective sealing rock layers for oil storages.Table 6
MIP test results of interlayers in Well M1#.
Number Depth Breakthrough pressure Breakthrough radius Median pressure Median radius (m) (MPa) (nm) (MPa) (nm) MIP-37 891.0~893.0 6.87 20.380 22.22 6.301 MIP-38 891.0~893.0 6.25 21.430 31.69 4.418 MIP-39 891.0~893.0 3.91 35.840 23.13 6.052 MIP-47 955.0~956.0 10.64 13.160 42.88 3.265 MIP-49 967.0~968.5 12.86 10.890 51.06 2.742 MIP-51 970.0~971.5 4.17 33.540 15.72 8.907 MIP-52 973.5~976.0 7.27 18.710 46.76 2.994 MIP-53 973.5~976.0 9.55 14.670 47.76 2.931 Maximum 12.86 35.840 47.76 8.907 Minimum 3.91 10.890 15.72 2.742 Average 7.69 21.080 35.15 4.700


## 5. Evaluation of Existing Salt Caverns

### 5.1. Volume and Shape Characteristics

Figure5 and Table 7 show the salt cavern shapes and data measured by sonar in Jintan salt mine [30]. The effective volume of a single salt cavern can be up to 19 × 104 m3, which is a very large storage volume, by single-well water solution mining. It is inferred that the salt formation is suitable to build large-scale underground oil storage.Table 7
Data results of sonar surveys.
Salt cavern Nadir Peak Height Maximum radius Cavern volume Number (m) (m) (m) (m) (×104 m3) X1 1013.4 959.5 53.9 52.6 15.6 X2 1007.4 937.4 70.0 44.4 15.9 D1 1016.9 955.1 61.8 45.6 18.7 D2 1012.3 958.4 53.9 47.1 18.9 G1 1020.1 966.4 53.7 41.9 14.0 G2 1015.3 955.8 59.5 46.1 15.4Figure 5
Sonar surveys of several existing salt caverns.However, as we can see from Figure5, some shapes of salt cavities in Jintan salt mine are irregular, which are unfavorable to the mechanical stability of oil storage. Meanwhile, the roofs were unprotected during the water-soluble mining, so the salt roof and even cap rock might be eroded or penetrated by water, resulting in reduction of sealing ability. Therefore, to effectively control the cavern shape and protect the salt roof, the suggested construction technology of salt cavern oil storage is illustrated in Figure 6, referring to overseas experience of salt cavern construction. Importantly, diesel oil is selected as cushion to protect the cavern roof.Figure 6
Suggested construction technology of salt cavern oil storage.


### 5.2. Salt Cavern Tightness Tests

All tightness tests mentioned above are in laboratory scale except for the geological evaluation. So, it is necessary to ascertain the macroscopic sealing characteristics through field tests in Jintan salt mine. The tightness tests of existing salt caverns were analyzed based on the shut in sealing tests of salt caverns in Jintan salt mine [31]. The two salt caverns are located at in the south (Cavern Mao-1 in Figure 3) and north (Cavern Rong-1 in Figure 3) of the salt basin. So, their characteristics have good representativeness for the whole salt mine.Based on the principle of liquid pressure balance in a salt cavern well, an equation is established:(1)PCavern=PWellhead+ρgh,where PCavern is the pressure of brine or oil at depth h in a salt cavern; PWellhead is the wellhead pressure; ρ is the density of brine or oil (ρbrine is 1.20 × 103 kg/m3 and ρoil is 0.85 × 103 kg/m3); g is the acceleration of gravity which is 9.8 m/s2; h is the depth.


#### 5.2.1. Cavern Mao-1

The saliferous strata depth of this cavern is between 858.00 m and 1029.97 m. The depth of cavern peak is located at 879.57 m. The bottom of the cemented casings was located at 1008.38 m at the beginning of cavern leaching.After this well was shut for 3 months, the wellhead pressure was stable at 3.95 MPa (PWellhead in (1)). It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 975.5 m (h in (1)). The brine pressure at this depth is 15.42 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.08 MPa (PCavern in (1)) under the same wellhead pressure (3.95 MPa). It is obvious that 12.08 MPa is lower than 15.42 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.


#### 5.2.2. Cavern Rong-1

The saliferous strata depth of this cavern is between 932.00 m and 1064.21 m. The depth of cavern peak is located at 979.30 m. The bottom of the cemented casings was located at 1016.91 m at the beginning of cavern leaching.Similarly, the wellhead pressure was stable at 4.30 MPa (PWellhead in (1)) after this well was shut for 3 months. It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 998.0 m (h in (1)). The brine pressure at this depth is 16.04 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.61 MPa (PCavern in (1)) under the same wellhead pressure (4.30 MPa). It is obvious that 12.61 MPa is lower than 16.04 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.It can be inferred that there is no serious leakage in the two salt caverns because the wellhead pressure can reach stable values (3.95 MPa and 4.30 MPa). However, the wellhead pressure may be influenced by creep closure of a salt cavern, thermal expansion of brine, and permeation loss of brine. So, the tightness tests for the two existing caverns are preliminary. In the further in-depth research, several more detailed tightness tests will be carried out. For example, fill the annular space with nitrogen or diesel oil to develop an interface below the last cemented casing and measure interface depth changes during a couple of days.


## 5.1. Volume and Shape Characteristics

Figure5 and Table 7 show the salt cavern shapes and data measured by sonar in Jintan salt mine [30]. The effective volume of a single salt cavern can be up to 19 × 104 m3, which is a very large storage volume, by single-well water solution mining. It is inferred that the salt formation is suitable to build large-scale underground oil storage.Table 7
Data results of sonar surveys.
Salt cavern Nadir Peak Height Maximum radius Cavern volume Number (m) (m) (m) (m) (×104 m3) X1 1013.4 959.5 53.9 52.6 15.6 X2 1007.4 937.4 70.0 44.4 15.9 D1 1016.9 955.1 61.8 45.6 18.7 D2 1012.3 958.4 53.9 47.1 18.9 G1 1020.1 966.4 53.7 41.9 14.0 G2 1015.3 955.8 59.5 46.1 15.4Figure 5
Sonar surveys of several existing salt caverns.However, as we can see from Figure5, some shapes of salt cavities in Jintan salt mine are irregular, which are unfavorable to the mechanical stability of oil storage. Meanwhile, the roofs were unprotected during the water-soluble mining, so the salt roof and even cap rock might be eroded or penetrated by water, resulting in reduction of sealing ability. Therefore, to effectively control the cavern shape and protect the salt roof, the suggested construction technology of salt cavern oil storage is illustrated in Figure 6, referring to overseas experience of salt cavern construction. Importantly, diesel oil is selected as cushion to protect the cavern roof.Figure 6
Suggested construction technology of salt cavern oil storage.


## 5.2. Salt Cavern Tightness Tests

All tightness tests mentioned above are in laboratory scale except for the geological evaluation. So, it is necessary to ascertain the macroscopic sealing characteristics through field tests in Jintan salt mine. The tightness tests of existing salt caverns were analyzed based on the shut in sealing tests of salt caverns in Jintan salt mine [31]. The two salt caverns are located at in the south (Cavern Mao-1 in Figure 3) and north (Cavern Rong-1 in Figure 3) of the salt basin. So, their characteristics have good representativeness for the whole salt mine.Based on the principle of liquid pressure balance in a salt cavern well, an equation is established:(1)PCavern=PWellhead+ρgh,where PCavern is the pressure of brine or oil at depth h in a salt cavern; PWellhead is the wellhead pressure; ρ is the density of brine or oil (ρbrine is 1.20 × 103 kg/m3 and ρoil is 0.85 × 103 kg/m3); g is the acceleration of gravity which is 9.8 m/s2; h is the depth.


### 5.2.1. Cavern Mao-1

The saliferous strata depth of this cavern is between 858.00 m and 1029.97 m. The depth of cavern peak is located at 879.57 m. The bottom of the cemented casings was located at 1008.38 m at the beginning of cavern leaching.After this well was shut for 3 months, the wellhead pressure was stable at 3.95 MPa (PWellhead in (1)). It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 975.5 m (h in (1)). The brine pressure at this depth is 15.42 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.08 MPa (PCavern in (1)) under the same wellhead pressure (3.95 MPa). It is obvious that 12.08 MPa is lower than 15.42 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.


### 5.2.2. Cavern Rong-1

The saliferous strata depth of this cavern is between 932.00 m and 1064.21 m. The depth of cavern peak is located at 979.30 m. The bottom of the cemented casings was located at 1016.91 m at the beginning of cavern leaching.Similarly, the wellhead pressure was stable at 4.30 MPa (PWellhead in (1)) after this well was shut for 3 months. It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 998.0 m (h in (1)). The brine pressure at this depth is 16.04 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.61 MPa (PCavern in (1)) under the same wellhead pressure (4.30 MPa). It is obvious that 12.61 MPa is lower than 16.04 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.It can be inferred that there is no serious leakage in the two salt caverns because the wellhead pressure can reach stable values (3.95 MPa and 4.30 MPa). However, the wellhead pressure may be influenced by creep closure of a salt cavern, thermal expansion of brine, and permeation loss of brine. So, the tightness tests for the two existing caverns are preliminary. In the further in-depth research, several more detailed tightness tests will be carried out. For example, fill the annular space with nitrogen or diesel oil to develop an interface below the last cemented casing and measure interface depth changes during a couple of days.


## 5.2.1. Cavern Mao-1

The saliferous strata depth of this cavern is between 858.00 m and 1029.97 m. The depth of cavern peak is located at 879.57 m. The bottom of the cemented casings was located at 1008.38 m at the beginning of cavern leaching.After this well was shut for 3 months, the wellhead pressure was stable at 3.95 MPa (PWellhead in (1)). It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 975.5 m (h in (1)). The brine pressure at this depth is 15.42 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.08 MPa (PCavern in (1)) under the same wellhead pressure (3.95 MPa). It is obvious that 12.08 MPa is lower than 15.42 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.


## 5.2.2. Cavern Rong-1

The saliferous strata depth of this cavern is between 932.00 m and 1064.21 m. The depth of cavern peak is located at 979.30 m. The bottom of the cemented casings was located at 1016.91 m at the beginning of cavern leaching.Similarly, the wellhead pressure was stable at 4.30 MPa (PWellhead in (1)) after this well was shut for 3 months. It is indicated that the tightness of cemented casings is well under this wellhead pressure. The middle depth of this salt cavern is located at 998.0 m (h in (1)). The brine pressure at this depth is 16.04 MPa (PCavern in (1)). It is indicated that the tightness of cavern is under this cavern pressure.If oil is stored in this cavern, the oil pressure in the middle depth of the cavern will be only 12.61 MPa (PCavern in (1)) under the same wellhead pressure (4.30 MPa). It is obvious that 12.61 MPa is lower than 16.04 MPa. Therefore, the above analysis indicated that the Cavern Mao-1 and its cemented casings can reach the tightness requirements for oil storage.It can be inferred that there is no serious leakage in the two salt caverns because the wellhead pressure can reach stable values (3.95 MPa and 4.30 MPa). However, the wellhead pressure may be influenced by creep closure of a salt cavern, thermal expansion of brine, and permeation loss of brine. So, the tightness tests for the two existing caverns are preliminary. In the further in-depth research, several more detailed tightness tests will be carried out. For example, fill the annular space with nitrogen or diesel oil to develop an interface below the last cemented casing and measure interface depth changes during a couple of days.


## 6. Conclusions

In conclusion, the following favorable geological conditions are good for the construction of underground oil storage in Jintan salt mine of China.


### 6.1. Simple Geological Structure and Clear Strata Sedimentary Characteristics

The distribution of salt layers is relatively stable in plane and vertical direction in Jintan mining area, and the large faults are located in the mining boundary with clear distribution. Besides, the regional earthquake seldom happens and the waterproof condition of strata is good enough to guarantee the security of oil storage.


### 6.2. Wide Distribution and Large Thickness

The saliferous strata are located in the 4th part of Funing group (Ef4) with large area of 60.5 km2, great thickness of 67.85–230.95 m, and sedimentary center thickness of at least 200 m. Additionally, the depth of Ef4 is 809.38~1045.57 m, which is also very suitable for the security and stable operation of underground oil storage.


### 6.3. Excellent Strata Sealing Condition

The immediate roof and cap rock of salt strata are mainly composed of mudstone with excellent sealing ability. The results by microscopic tests revealed that the high breakthrough pressure (1.36~5.71 MPa) and low permeability (2.93~6.90 × 10−11 m2) were beneficial to the tightness of cap rock. From the analysis of rock cores, the composition of nonhalite interlayers was mainly mudstone, which was dense and hard evidenced by SEM images.


### 6.4. Large Volume and Good Tightness of the Salt Caverns

The results measured by sonar showed that the effective volume of a single salt cavern is up to 19 × 104 m3 by single-well water solution mining. Moreover, the volume of single salt cavern could be larger if the suggested construction technology of salt cavern oil storage would be applied. Finally, the tightness tests on existing salt caverns (Cavern Mao-1 and Cavern Rong-1) illustrated that the two caverns and their cemented casings can reach the tightness requirements for oil storage.To sum up, Jintan salt mine has the basic geological conditions for constructing the large-scale underground oil storage, which could become the first salt cavern oil storage group base in China.


## 6.1. Simple Geological Structure and Clear Strata Sedimentary Characteristics

The distribution of salt layers is relatively stable in plane and vertical direction in Jintan mining area, and the large faults are located in the mining boundary with clear distribution. Besides, the regional earthquake seldom happens and the waterproof condition of strata is good enough to guarantee the security of oil storage.


## 6.2. Wide Distribution and Large Thickness

The saliferous strata are located in the 4th part of Funing group (Ef4) with large area of 60.5 km2, great thickness of 67.85–230.95 m, and sedimentary center thickness of at least 200 m. Additionally, the depth of Ef4 is 809.38~1045.57 m, which is also very suitable for the security and stable operation of underground oil storage.


## 6.3. Excellent Strata Sealing Condition

The immediate roof and cap rock of salt strata are mainly composed of mudstone with excellent sealing ability. The results by microscopic tests revealed that the high breakthrough pressure (1.36~5.71 MPa) and low permeability (2.93~6.90 × 10−11 m2) were beneficial to the tightness of cap rock. From the analysis of rock cores, the composition of nonhalite interlayers was mainly mudstone, which was dense and hard evidenced by SEM images.


## 6.4. Large Volume and Good Tightness of the Salt Caverns

The results measured by sonar showed that the effective volume of a single salt cavern is up to 19 × 104 m3 by single-well water solution mining. Moreover, the volume of single salt cavern could be larger if the suggested construction technology of salt cavern oil storage would be applied. Finally, the tightness tests on existing salt caverns (Cavern Mao-1 and Cavern Rong-1) illustrated that the two caverns and their cemented casings can reach the tightness requirements for oil storage.To sum up, Jintan salt mine has the basic geological conditions for constructing the large-scale underground oil storage, which could become the first salt cavern oil storage group base in China.



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*Source: 3159152-2017-06-14.xml*