A Fine Investigation on Geological Conditions for Oil Accumulation in the Paleogene Intersalt Shale Series in the Qianjiang Depression ()
1. Introduction
Shale oils often occur in effective hydrocarbon-generating shale series in free, adsorbed and dissolved states [1] [2] . They are in-situ retained oil and gas resources [2] [3] . The successful development of shale oils in North America attracted China to concern the shale oils in China. For example, the intersalt shale series of the Qianjiang Formation in the Qianjiang Depression of the Jianghan Basin in China is well-developed with oil and gas shows so abundant that oil immersions occur over the depression [4] [5] . Up to date, chromatography of the intersalt shale showed that a number of wells contributed commercial oil flows at initial rates of 0.9 - 66.75 t/d, indicative of a tremendous resource potential. However, the intersalt shale has been previously studied using the same methodologies as those used to deal with conventional reservoirs, thus obtaining unsatisfied results [6] . The insight conversion from “the conventional intersalt nonsandstone reservoir” to “the unconventional intersalt shale series” bought about a conclusion that the intersalt argillaceous dolomites did not only provide the main sources for oil and gas generation, but also the main spaces allowing oil and gas to be inhabited [7] [8] . Therefore, how to perform a systematical study on the intersalt shale oil regarding the geological conditions for oil accumulation is essential to boost the exploration and development of the shale oils in the Jianghan Basin. This paper presented an investigation on the rhythmic layer Qian 3410 of the intersalt shale series in the Qianjiang Depression, with respect to petro-minerology, hydrocarbon-generating conditions, reservoir conditions and oil/gas-bearing conditions, for the purpose of discussing the geological conditions for hydrocarbon accumulation, and revealing the interest in the depression.
2. Regional Geological Setting
The Qianjiang Depression is located in the center of the Jianghan Basin, which was an inland arid rift lake basin originated on the Paleozoic and basement, with an area of about 2500 km2. The depression is bounded by the Yuekou low relief on the east and by the Yajiao low relief on the west. It is controlled by the North Qianjiang Fault in the northwest, and by the Tonghaikou Fault in the south. Due to extensional shear, a NE-trending fracture system occurs in the study area (Figure 1), forming a tectonic framework with one concave between two slopes [6] [9] [10] [11] . In the depression, the Cretaceous-Paleogene strata were deposited, which ascendingly consist of the Cretaceous Yuyang Formation, the Paleogene Shashi, Xingouzui, Jingsha, Qianjian and Jinghezhen Formations, the Neocene Guanghuasi Formations, and the Quaternary Pingyuan Formation (Figure 1). Of them, Unconformities occur between the Pingyuan and Guanhuasi Formations and between the Guanhuasi and Jinghezhen Formations.
The late Eocene to early Oligocene represented the peak period for development of the Jianghan salt lake. The Qianjiang Depression in the center of the basin acted as a depocenter, catchment center and concentration center of the lake basin [12] . In the northern part, an environment with one-way provenance drainage, high salinity and strong evaporation, the Qianjiang Formation was deposited as thick as 6000 m [6] , forming rhythmic layers consisting of intersalt thin-layered, frequently interbedded mudstones, sandstones, carbonates and evaporates [13] . For each rhythmic layer, a roof plate is separated from the floor plate by a thick salt rock layer, forming a unique petroleum system. Laterally, from the northwest to southeast, sand-mudstone facies area, salt-fresh transition area and salt-lake sedimentary area are present successively. This study area is located in the belt of the Banghu, Wangchang, Zhouji and Guanghua regions. It is a transition belt from salt to fresh water. Vertically, the lithologic association consists of shales with carbonates or thin-layered sandstones, which represents a main area where intersalt shale series are present. The northwestern part is covered by deltaic sand and mudstone sediments, which is vertically characterized by frequent thin interbeds of sandstones and mudstones. The salt lake sedimentary area in the southeast is occupied by salt rocks, glauberites with mudstone sediments [6] . The Qianjiang Formation, in ascending order, can be divided into the Qian 4, 3, 2, and 1 Members. The target layer in the study area is located in the10th rhythmic layer of the 4th sublayer of the Qian 4 Member (thereafter simplified as the rhythmic layer Qian 3410). When it was deposited, the lake basin was characterized by subsidence of the fault depression with a weak faulting activity, and a gentle topography thinning to south from north, and to slope from center [14] .
![]()
Figure 1. Map showing the location of the study area, distribution of wells, sedimentary environment, with the stratigraphic sketch for the Qianjiang Depression.
3. Sampling and Analysis Experiment
A total of 106 samples for this study were cored from the Paleogene rhythmic layer Qian 3410 in 3 wells across the Banghu-Wangchang area, including 52 samples from 99 wells, 20 from Well BYY2, and 5 from Well WY11. Thin sections of the all samples were identified under the conventional SEM, in order to ensure a reliable classification and analysis. On this basis, the residual samples were selected for SEM, microscopic analysis of kerogen compositions, vitrinite reflectance, X-ray diffraction, and rock pyrolysis tests. Plunger samples were obtained by drilling on-site for mercury injection, with a diameter of 2.5 cm and a length of 10 cm. The distribution of the sampling wells is shown in Figure 1.
For this study, analysis and tests, such as thin section identification and sample SEM were performed by the Geological Laboratory of Exploration and Development Institute of the Southwest Oil and Gas Field Company of CNPC. For the conventional thin section identification, the lycra polarizing three-eye microscope (DM2700P) was used. Prior to identification, the samples were treated with the solution mixture of alizarin red and potassium ferricyanide. SEM was perfomed with a field emission environmental scanning electron microscope (JSM-5500).
Additional analyses and tests, such as for kerogen compositions and maturity with SEM, x-diffraction, rock pyrolysis and mercury injection were performed by the Exploration and Development Institute of the SINOPEC Jianghan Oilfield Company and SINOPEC Wuxi Petroleum Geology Institute. The microscopic kerogen compositions were detected with Leica transmission light and reflected light fluorescence microscope (Leica AF6000) at a 24˚C temperature and humidity of 65% RH. The vitrinite reflectance was measured with the microphotometer Leica MSP200 at 23˚C and humidity of 60% RH. The X-ray diffraction analysis was performed with Phillips Xpert-MPD-typed X-ray diffractometer to determine the mineral spacies and contents in terms of 2θ angles (a scanning range of 20˚ - 40˚) and spectral peak intensity. The pyrolysis analysis was conducted to detecte by using Rock-Eval6 (rock pyrolysis unit) according to the standard for rock pyrolysis analysis (GB/T18602-2012). The mercury injection was performed with a unit named PoreMaster 33 with an aperture measuring range from 6.4 nm to 950 μm.
4. Experimental Results and Discussion
4.1. Characteristics of Lithofacies and Brittleness
The full rock XRD test indicated that the rhythmic layer Qian 3410 in the study area is complicated in mineral composition, which is compound of terrigenous debris, carbonate and evaporite minerals. Vertically, the layer is characterized by a variety of mineral types and high heterogeneity. In order to investigate its vertical minerological variation, the layer can be subdivided into secondary lithofacies consisting of argillaceous dolomite, dolomitic mudstone, argillaceous limestone and glauberite-filling dolomitic mudstone facies, in terms of content and attitude of the rock constituents (Figure 2). The development characteristics of these lithofacies are described as follows.
![]()
Figure 2. Generalized stratigraphic column for the rhythmic layer Qian 3410 in well W99.
Argillaceous dolomite facies: This facies is in yellowish-brown color, with obvious oil immersions (Figure 3(a)). Under the microscope, the dolomite is observed to be in a micritic structure, which is xenotopic, with a large quantity of carbon debris (Figure 3(b) and Figure 3(c)). Its mineral compositions are compound of dolomite as high as 20% - 42% (averaging 30.5%), clay minerals, 18% - 33% (averaging 25.4%), quartz and feldspar, 9% - 20% (averaging 13.3%), as well as evaporite minerals (gypsum and calcium mirabilite as dominant) as low as 1% - 6% (averaging 2.3%), and brittle minerals (quartz, feldspar, dolomite and calcite) as high as 50% - 71% (averaging 61.1%).
![]()
Figure 3. Core and SEM characteristics of petrologic facies for the rhythmic layer Qian 3410 in Wells W99, BYY2 and WY11. a. Yellowish-brown argillaceous dolomite facies, Well W99, 1676.9 m; b. Micritite-structured dolomite, with much dispersed carbon debris, Well W99, 1675.8 m; c. Dolomite crystals, in micritic structure, xenomorphic, with irregular contact surface, Well WY11, 1749.3 m; d. Argillaceous limestone facies, Well W99, 1678 m; e. Dolomitic mudstone facies, Well W99, 1679.5 m; f. Dolomitic mudstone facies, Well BYY2, 2821.4 m; g. Glauberite-filling dolomitic mudstone facies, Well W99, 1682.4 m; h. Carbon-rich glauberite-filling dolomitic mudstone facies, BYY2 well, 2823.4 m.
Argillaceous limestone facies: This facies is in greyish brown color, with grayish black mudstones non-isopachous interbedded with yellowish brown limestones (Figure 3(d)). Its mineral compositions are compound of calcite as high as 23% - 41% (averaging 34%), clay minerals, 5% - 39% (averaging 28.4%), quartz and feldspar, 79% - 21% (averaging 16.7%), as well as evaporite minerals (gypsum and calcium mirabilite as dominant) as low as 1% - 3% (averaging 2.4%), and brittle minerals (quartz, feldspar, dolomite and calcite) as high as 48% - 76% (averaging 58%).
Dolomitic mudstone facies: This facies is in greyish brown or yellow brown color. Core observation indicates that it is a non-isopachous interbed of yellowish brown dolomicrite with yellowish brown limestones (Figure 3(d)). Its mineral compositions are compound of calcite as high as 23% - 41% (averaging 34%), clay minerals, 5% - 39% (averaging 28.4%), quartz and feldspar, 79% - 21% (averaging 16.7%), as well as evaporite minerals (gypsum and calcium mirabilite as dominant) as low as 1% - 3% (averaging 2.4%), and brittle minerals (quartz, feldspar, dolomite and calcite) as high as 48% - 76% (averaging 58%).
Glauberite-filling dolomitic mudstone facies: This facies is in grey-light gray color, and mostly occurs at the bottom and top of the 10th rhythimc layer (Figure 3(g) and Figure 3(h)). Its mineral compositions are compound of glauberite rocks in a range of 5% - 54% (averaging 33.3%), dolomites, 11% - 35% (averaging 22.5%), clay minerals equivalent to dolomites in content, 13% - 29% (averaging 22.5%), as well as quartz and feldspar, 6% - 23%, (averaging 12%), and calcite as low as 0% - 4%, (averaging 2%). This facies contains the lowest content of brittle minerals among the all facies, in a range of 24% - 49% (averaging 34.8%) (Figure 2).
In comparison with North America and other parts of China, the intersalt shale series of the Qianjiang Formation is characterized by lower clay minerals, lower quartz and feldspar and higher carbonates [14] . In brittle mineral content, the rhythmic target layer Qian 3410 tends to descend from argillaceous dolomite facies → argillaceous limestone facies → dolomitic mudstone facies → glauberite filling dolomitic mudstone facies. Owing to a good brittleness and fractibility, the argillaceous dolomite facies provides a favorable target zone of the rhythmic layer Qian 3410 for hydrocarbon exploration.
4.2. Development of Source Rocks
In this paper, the development of the shale source rocks of the intersalt shale series was studied regarding organic abundance, type and maturity, so as to ascertain which type(s) of lithofacies can accomodate excellent source rock reservoirs.
4.2.1. Organic Abundances
In general, the organic abundance cannot only control the physical and chemical properties of shales, but also development of fractures in the shales, and more importantly, the oil content of the shales [15] . The dark shales of the intersalt shale series have high organic abundances, but which are different between different types of lithofacies, from in a range of 4.23% - 6.38% (averaging 4.23%) for the argillaceous dolomites (limestones), to 0.44% - 5.71% (averaging 3.08%) for the dolomitic mudstone facies, and even to 0.35% - 5.06% (averaging 1.81%) (Figure 2).
4.2.2. Organic Types
The organic type can somewhat determine the hydrocarbon-generating potential of the organic matter, and also affect the occurrence pattern and content of shale oil [15] . The microscopic kerogen compositions of the intersalt series consist of amorphous bacteria and lower biogenic algae organic matter [7] . The plots of pyrolytic peak temperature Tmax vs HI and HI vs OI indicate that the data points are mostly concentrated in the Types I and II1 interval (Figure 4), which
![]()
![]()
Figure 4. Plots of HI-Tmax and HI-OI for source rocks of the rhythmic layer Qian 3410 in Well W99.
is consistent with the microscopic identification result. Various analysis results indicate that the Types I (sapropel type) and II 1 (sapropelic-humus type) represent the main kerogen types of the intersalt shale series, indicative of a great oil-generating potential.
4.2.3. Organic Maturity
The organic maturity is an important parameter to characterize its hydrocarbon-forming effectiveness and hydrocarbon properties. A number of methods can be used to evaluate the organic maturity, among which the vitrinite reflectance method is one of the most common and effective methods [15] . The rhythmic Qian 3410 shale has Ro values in a range of 0.48% - 0.83%, averaging 0.63%, indicative of an entire thermal evolution degree as low as immature to undermature level. Laterally, Ro values tend to increase toward the Banghu Depression, and decrease to the Wangchang Anticline Belt. In addition, Tmax ranges from 300˚C to 436˚C, averaging 418.7˚C, indicative of immature source rocks.
The above metioned parameters for evaluation of the development of the source rocks indicate that the intersalt shale series in the study area is characterized by high organic abundance, moderate organic types and thermal evolution degrees, indicative of a potential to generate a large volume of immature oils.
4.3. Petrophysic Properties and Spaces of the Reservoir
The comprehensive analysis on 18 core samples from Wells W99 and BYY2 pore, regrading porosity, permeability and structure data indicated that the intersalt shale series represented a superior type of lithofacies. In combination with observation and analyses with cathode luminescence, SEM and ordinary thin sections, the reservoir space types and development characteristics of intersalt shale were ascertained.
Petrophysic characteristics: Generally speaking, a great difference in porosity and less difference in permeability occur between different lithofacies types of the intersalt shale series in the study area (Figure 5), from argillaceous dolomites (limestones) as the best reservoir with porosities in a range of 10.78% - 26.3% (averaging 15.96%), and permeabilities, 0.05 - 23.68 md (averaging 4.25 md) indicative of moderate porosity-extrolow permeability reservoir, to dolomitic mudstone facies as the moderate reservoir, with porosities in a range of 5.21% - 23.83% (averaging 10.98%) and permeabilities 1.33 - 9.89 md (averaging 3.65 md), indicative of low-porosity, extrolow-permeability reservoir, and to grauberite-filling dolomitic mudstone facies as the poorest reservoir, with porosities in a range of 3.58% - 5.25% (averaging 4.42%), indicative of extrolow-porosity reservoir (Figure 1 and Figure 5). In addition, the plot of porosity vs permeability shown in Figure 5 indicates that a poor function occurs between porosity and permeability for the dolomite reservoirs in the study area, indicative of a pore structure too poor to form a good-connectivity pore network.
![]()
Figure 5. Plot of porosity vs permeability for the rhythmic layer Qian 3410 of the inter-salt shale series in Wells W99 and BYY2.
Reservoir space types and characteristics: With respect to the reservoir space types of the argillaceous dolomite facies and dolomite mudstone facies in the study area, pores are dominant, apart from few fractures. The pores consist of secondary intercrystalline pores as dominant, as well as rare intercrystalline dissolved pores. The intercrystalline pores are those occurring between xenomorphic micritic dolomite crystals, which belong to fabric selectivity pores. This type of rocks are mostly supported by crystal particles, and the intercrystalline spaces unfilled with cements provide good reservoir spaces, with pore sizes 2 - 4 um, in an irregular polyhedron shape and a poor structure (Figure 6(a) and Figure 6(b)). They contribute major reservoirs to the study area. The dissolution
![]()
Figure 6. Shows the spatial types and characteristics of the dolomite reservoirs in the di3410 rhythmic strata in the study area. a. Intercrystalline pores, Well W99, carbon-rich dolomitic mudstone facies, 1679.7 m, SEM; b. Intercrystalline pores, Well WY11, carbon-rich argillaceous dolomite facies, 1749.3 m, SEM; c. Dissolution pores, Well W99, carbon-rich argillaceous dolomite facies, 1675.8 m, SEM; d. Dissolution pores, Well WY11, carbon-rich argillaceous dolomite facies, 1749.3 m, SEM; e. Structural fractures, Well W99, carbon-rich dolomitic mudstone facies, 1678.9 m, SEM; f. Dissolution fractures, Well BYY2, carbon-rich argillaceous dolomite facies, 2821.3 m, SEM.
pores are resulted from dissolution and enlargement of the intergranular pores, in a highly irregular shape, with pore sizes 5 - 10 um usually greater than those of the dolomite crystals (Figure 6(c) and Figure 6(d)). The dissolution pores are rarely seen in the study area, providing less reservoir contribution due to a poor connectivity. Fractures in the study area are rarely seen, which can be divided into structural and dissolution ones, in terms of origin. The structural fractures are rarely seen and in a simplex type, such as high-angle straight fractures, with the internal fillings locally undissolved to form effective reservoir spaces (Figure 6(e)), so the structural fractures provide a less contribution to the reservoirs in the study area. The dissolution fractures are caused from dissolution and enlargement of the earlier structural fractures by fluids, with rugged walls, and in a wide range of widths. Their interiors are unfilled (Figure 6(f)). Their presences can often improve the local connectivity, but in a limited extent, so providing a limited contribution to the reservoirs.
4.4. Characterization of Oil-Bearing Properties
The intersalt shale seires are evaluated with respect to oil-bearing property by using both parameters S1 and S1/TOC. The parameter S1 obtained from the pyrolysis chromatographic analysis means the total hydrocarbon volume volatilzing from heated sample not exceeding 300˚C. The total hydrocarbons generally contain C7 - C33 hydrocarbons. The parameter S1/TOC may reflect the volume of free hydrocarbons. As indicated by the related research results in North America, a high oil saturation (S1/TOC) represents the shale oil resources with a productivity. S1/TOC greater than 100 mg oil/g TOC means oil-productive [16] . In a whole, the intersalt shale series have a good oil-bearing property, with the S1/TOC values all over 100 mg oil/g, but due to high internal heterogeneity, a great difference occurs between different lithofacies. The argillaceous dolomite facies was the best in oil-bearing property, with S1 values in a range of 3.48 - 5.64 mg/g (averaging 4.49 mg/g) and S1/TOC values 348 - 564 mg oil/g (averaging 449 mg oil/g). The argillaceous limestone facies are less different from the argillaceous dolomite facies, with S1 values in a range of 3.22 - 5.22 mg/g (averaging 4.45 mg/g) and S1/TOC values 322 - 522 mg oil/g (averaging 445 mg oil/g).
The dolomitic mudstone facies is the secondary, with S1 values 2.25 - 4.99 mg/g (averaging 3.69 mg/g) and S1/TOC values 225 - 498 mg oil/g (averaging 369 mg oil/g). The glauberite-filling dolomitic mudstone facies is the poorest in oil-bearing property, with S1 values 0.85 - 6.82 mg/g (averaging 3.41 mg/g) and S1/TOC values 125 - 508 mg oil/g (averaging 336 mg oil/g).
In summary, the argillaceous dolomite facies of the intersalt shale series in the Qianjiang Depression is considered the most favorable facies type, which is characterized by good brittleness, hydrocarbon source rock characteristics, reservoir characteristics and oil-bearing property, and provide a key target interval for the coming exploration and development.
5. Conclusions
1) The intersalt shale series in the Qianjiang Depression is characterized by high organic abundance, as well as fair organic matter type and thermal evolution level, indicative of potential generating a great volume of immature oil.
2) The rhythmic layer Qian 3410 in the Qianjiang Depression consists of argillaceous dolomite facies, argillaceous limestone facies, dolomitic mudstone facies, and calcium-mirabilite filling mudstone facies in terms of rock facies.
3) The argillaceous dolomite facies is the most contributory, with the reservoir spaces consisting of intercrystalline pores as dominant, as well as few dissolution pores and fractures. Owing to high content of brittle minerals, high organic abundance, high porosity and good oil-bearing properties, the argillaceous dolomite facies is considered the key target in the coming exploration and development efforts in the study area.
Funded
This paper is funded by the 2018 Undergraduate Training Program for Innovation and Entrepreneurship of Yangtze University, the project number is 2018267.