Guanxiong Ren
Qirong Qin
Qiang Zhang3- 1School of Geosciences and Technology, Southwest Petroleum University, Chengdu, China
- 2State Key Laboratory of Oil and Gas Reservoirs Geology and Development Engineering, Chengdu, China
- 3PetroChina Southwest Oil and Gas Field CDB Operating Company, Dazhou, China
- 4Chongqing Gas Mine, PetroChina Southwest Oil and Gas Field Company, Chongqing, China
The origin and pore-throat structure of different lithofacies are key issues in exploration and development of tight oolitic reservoirs. Based on core and thin section observation, four types of lithofacies can be recognized in the Feixianguan Formation oolitic reservoir: 1) oolitic limestone with intergranular pores (Lithofacies A), 2) oolitic limestone with mold pores (Lithofacies B), 3) oolitic dolostone (Lithofacies C), and 4) silty crystalline dolomite and fine crystalline dolostone (Lithofacies D). The subsurface core samples from the different lithofacies were studied using mercury injection, 3D CT scanning, and nuclear magnetic resonance, indicating that Lithofacies D possesses the best pore-throat structure and reservoir connectivity. The pore-throat structure of Lithofacies C is very similar to that of D, but the heterogeneity is much stronger. By comparison, the pore-throat structure of Lithofacies A and B is relatively poor. Although the pore heterogeneity of Lithofacies B is weaker than that of Lithofacies A, there is no effective throat connection in Lithofacies B. On the basis of oolitic shoal deposition, the factors controlling the origin of different lithofacies are meteoric freshwater leaching and then dolomitization. Meteoric freshwater leaching dominates the origin of Lithofacies B but does not affect the origin of Lithofacies C. Lithofacies C is jointly controlled by seepage-reflux and hydrothermal dolomitization fluids. The origin of Lithofacies D is only controlled by seepage-reflux dolomitization. Some other diagenesis effects may also have an impact on petrophysical properties of different lithofacies, but they do not play a decisive role in the origin of different lithofacies.
1 Introduction
Oolitic shoal commonly possesses high primary interparticle porosity, as well as large cumulative thickness, and wide distribution range (Enos and Sawatsky, 1981; Schmoker and Hester, 1986). Therefore, oolitic shoal has always been the ideal target of oil and gas exploration since 1960s (Akin and Graves, 1969). At present, successful exploration cases have been obtained in the oolitic reservoir of the Carboniferous, Permian, Triassic, and Jurassic periods throughout the world, such as Walker Creek Oilfield in Arkansas (Swirydczuk, 1988; Bliefnick and Kaldi, 1996), Big Bow and Sand Arroyo Creek Oilfield in southwest Kansas (Qi et al., 2007), De Wijk and Wanneperveen Oilfield in the Netherlands (Palermo et al., 2008), South Pars Gas field and Balal Oilfield in Iran (Esrafili-Dizaji and Rahimpour-Bonab, 2014; Ebrahim et al., 2018), Villeperdue Oilfield in Paris Basin of France (Granier, 1995), and Puguang Gas field in Sichuan Basin of China (Li H et al., 2020; Li Y et al., 2020).
However, an oolitic reservoir shows strong heterogeneity in pore type, porosity, permeability, and pore-throat structure, which has great influence on exploration and development deployment. Swirydczuk (1988) first proposed that original mineralogy and diagenesis jointly control permeability and pore type in the oolitic reservoir. Bliefnick and Kaldi (1996) used high-pressure mercury injection (MICP) to compare the differences in pore structure of different lithofacies in oolitic limestone reservoirs. It is considered that mechanical compaction and calcite cementation are the negative factors of pore-throat structure, and the higher the degree of sorting, the better the pore structure. However, Makhloufi et al. (2013) argued that early compaction, with the development of grain interpenetration, permits better connectivity in the pore-throat structure, leading to better reservoir properties. Other researchers also noticed the differences in reservoir characteristics of different lithofacies in oolitic reservoirs (Palermo et al., 2008; Esrafili-Dizaji and Rahimpour-Bonab, 2014), but the research objects focus on geometry and distribution of oolitic shoal deposits (Qi et al., 2007; Qiao et al., 2016) and diagenetic evolution of porosity in different lithofacies (Esrafili-Dizaji and Rahimpour-Bonab, 2014; Li et al., 2017; Morad et al., 2019). At present, previous studies on pore-throat structure of oolitic reservoirs are rare, and only a few studies have discussed pore structure using MICP without lithofacies classification (Wang et al., 2018; Zhou et al., 2019). Lack of detailed comparison of pore-throat structure differences between different lithofacies leads to insufficient discussion on controlling factors.
The proven reserves of oolitic gas reservoirs in the Triassic Feixianguan Formation around the Kaijiang–Liangping Trough in the northeastern Sichuan Basin have exceeded 5,000 × 108 m3 (Zou et al., 2011). With the deepening of exploration and development, previous studies have illustrated that the oolitic reservoirs of different wells are composed of one lithofacies or multiple lithofacies combinations (Wang et al., 2018; Gu et al., 2021), and the gas production of each well varies greatly. The unclear understanding of reservoir characteristics, pore-throat structure, and controlling factors has become the decisive factor restricting the next exploration and development.
In this study, we first classify the lithofacies of oolitic reservoirs according to the macro–micro petrological characteristics. Then, pore type, throat type, and petrophysical property of different lithofacies are discussed using 3D CT scanning, low-field nuclear magnetic resonance (NMR), MICP, and scanning electron microscopy (SEM) (Fan et al., 2020). Finally, based on cathodoluminescence (CL), stable isotope, and rare Earth element (REE) data, factors controlling the origin of different lithofacies are studied, and a sedimentary-diagenetic evolution model is established. This study helps guide the further exploration and development of oolitic reservoirs.
2 Geological background
The Sichuan Basin lies on the relatively northwestern side of the Yangtze platform and is surrounded by the Daba and Micang mountains in the north, the Longmen Mountains in the west, Lou Mountain and the Daliang Mountains in the south, and Qiyue Mountain in the east (Wei et al., 2018; Jin et al., 2020; Ren et al., 2022).The basin in its geological history has experienced both tectonic evolution stages featuring tensile stress from the Sinian to Middle Triassic and horizontal compressive stress from the Late Triassic to Quaternary (Wang and Jin, 2002; Liu et al., 2011; Li et al., 2019a). Furthermore, it is divided into six tectonic cycles of Yangtze, Caledonian, Hercynian, Indosinian, Yanshan, and Himalayan (Deng, 1992; He et al., 2011). Based on the regional structural characteristics, the present structural features, and the previous research results, the basin is divided into three structural zones by the Huayingshan and Longquanshan faults, and subdivided into six secondary structural zones, namely, fault–fold belts of high steep in eastern Sichuan, low steep in southern Sichuan, low gentle in southwestern Sichuan, gentle in central Sichuan, gentle in northern Sichuan, and low gentle in western Sichuan (Zhou et al., 2016; Li et al., 2019a).
The study area is located in eastern Sichuan Basin (Figure 1A). Due to the combined effects of the “Emei” taphrogenesis and the formation and evolution of the Micangshan Fault Zone and the Guangwang Basin in the north, the study area is in the extensional tectonic setting during the Late Permian–Early Triassic, forming the Kaijiang–Liangping Trough (Xing et al., 2017). The trough is formed during the early Changxingian (Late Permian) due to rapid basement subsidence associated with the “Emei” taphrogenesis (Tan et al., 2012). As a result, a trough-platform sedimentary pattern comprising open platform facies, platform-margin facies, slope facies, ocean trough (basin) facies, and so on existed in both east and west sides of the trough (Zou et al., 2011). With the filling of sediments into the trough, the platform-margin facies gradually migrated to the center of the trough (Gu et al., 2021). Until the third member of Feixianguan Formation, the study area evolved into an open platform facies, which mainly consists of intra-platform oolitic shoal and inter-shoal sediments (Gu et al., 2020). At the end of the Feixianguan deposition (sedimentary period of the fourth member), the evaporation platform facies dominates the study area, which is comprised of gypsum rocks, gypsum-bearing dolomicrite, and mudstone (Figure 1B). Based on the evolution of sedimentary facies and lithology, the Feixianguan Formation can be divided into four members, namely, the first member (T1f1), the second member (T1f2), the third member (T1f3), and the fourth member (T1f4) (Figure 2).
FIGURE 1. Geological setting of Feixianguan Formation in the study area. (A) Location of the study area in China and locations of the representative wells; the numbers 1–2 represent Puguang and Luojiazhai–Gunziping gas fields, respectively. (B) Cross-well section of sedimentary facies and the stratigraphic framework.
FIGURE 2. Generalized stratigraphy and tectonic history of the study area (modified from Hao et al., 2008). Sym, symbol.
3 Samples and methods
The results obtained by the comprehensive study on Feixianguan Formation tight oolitic reservoir were based on core analysis data from 12 cored wells, including TS5, TS11, TS14, TD110, TD102, and TD100 (Figure 1A). To ensure the reliability of this study, samples should be collected and selected in accordance with the following principles: 1) samples shall not be collected from the development parts such as structurally crushed and weathered zones; 2) the structure and state of the sample should be collected as undamaged as possible. The thin sections of drilling cuttings were prepared from the non-cored wells, in order to establish a complete lithology column. First, all core samples involved in the experiments were used for thin sections and SEM analysis individually. The polarized light microscope, CL, and SEM were used to classify lithofacies. In addition to these studies, two core plugs and one full-diameter core sample were drilled from different lithofacies. Under the test conditions of an injection pressure of 50 MPa and confining pressure range of 0–100 MPa, the porosimeter–permeameter HKGP-3 was used to determine porosity and permeability of core plug samples. Then, the core plug samples were fully saturated with brine. The NMR T2 spectrum of the core plug samples was acquired by using NUMAG’s C12–010V low-field NMR spectrometer under 100% water saturation (Shen et al., 2019; Li 2022). A 3D CT scanning of core samples was then performed using a nanoVoxel-4000 3D X-ray microscope (XRM). Finally, the core plug samples were tested using MICP. The capillary pressure curves and the histogram graphs of the pore-throat radius were obtained (He et al., 2021; Kang 2021; Li H et al., 2022; Li J et al., 2022). Meanwhile, the critical parameters are the following: threshold pressure (Pcd), median radius (r50), maximum throat radius (rmax), maximum mercury saturation (Smax), and mercury extrusion efficiency (Ew).
The remaining samples were used to select fresh sections by avoiding calcite veins and organic matter and grounded to 200 mesh size for rare Earth element (REE) and carbon–oxygen isotope analysis. REE (n = 25 samples) measurements were carried out by inductively coupled plasma-mass spectrometry (ICP-MS). Considering the relationship between carbonate diagenetic fluids and normal seawater, this study selected REE content of seawater published by Kawabe et al. (1998) as the standard. Because REE content of seawater is very low, the REE content of seawater is magnified by 104 times before standardization. Eu, Ce, and Pr anomaly values were calculated as follows: δCe=2CeN/(LaN+PrN); δEu=2EuN/(SmN+GdN); δPr=2PrN/(CeN+NdN) (Shields and Stile, 2001).
The samples for isotopic analysis were microdrilled from the cores. Stable isotopes (δ18O and δ13C) (n = 48 samples) of different rock fabrics were carried out by using the carbonate reaction method. These test samples reacted in the phosphoric acid bath method at 90°C, and the CO2 generated was examined using Elementar IsoPrime GC5. Standard isobaric corrections were adopted, while strontium was separated using the Eichrom Sr-Spec resin and measured on a Triton Plus thermal ionization mass spectrometer. All stable isotope data are converted to permille (‰) relative to Vienna Pee Dee Belemnite (VPDB) and corrected by fractionation factors supplied by Fairchild and Spiro (1987). Precision of the δ18O and δ13C ratio data is greater than ±.1‰.
4 Results and discussion
4.1 Reservoir characterization of tight oolitic reservoirs
4.1.1 Lithofacies, pore, and throat types
The rock fabrics, depositional structure, and diagenesis of carbonate reservoirs are extremely complex, which lead to complexity in the reservoir space (Guo et al., 2016; Kiani et al., 2021; Abraham-A et al., 2022; Forstner and Laubach, 2022). Typically, the primary pore types are hard to preserve through the late-stage diagenetic environment. Therefore, carbonate reservoirs often possess the characteristics, such as abrupt changes in lithology, various pore types, and unpredictable petrophysical properties. Based on observation of cores and thin sections, the lithofacies of the oolitic reservoir in Feixianguan Formation were classified into four types, namely, Lithofacies A, Lithofacies B, Lithofacies C, and Lithofacies D.
Lithofacies A is oolitic limestone featured by gray colors in the core (Figure 3A). Microscopically, Lithofacies A is composed of ooids and sparry calcite cement (Figure 3B), and the size of each ooid ranged from 500 μm–900 μm and was fabric-selectively replaced by very fine crystalline dolomite (Figure 3C). The main pore type of Lithofacies A is intergranular pores (100–240 μm in diameter) developing between ooids (Figure 3C). The intergranular pores are mainly connected by the tube-shaped throat (50 μm–80 μm in diameter) (Figure 3D).
FIGURE 3. Petrological characteristics of different lithofacies in Feixianguan Formation tight oolitic reservoir. (A) Intergranular pores (P1) present as clearly visible pinholes in the drill core, Lithofacies A, Well TB101, 2957.47 m–2957.57 m; (B) several intergranular pores (P1) are connected through tube-shaped throats (T1), Lithofacies A, Well TB101, 2,956.84 m (PPL); (C) intergranular pores (P1) are connected through tube-shaped throats (T1), Lithofacies A, Well TD110, 3,457.3 m (PPL); (D) intergranular pores (P1), Lithofacies A, Well TD110, 3,457.3 m (SEM); (E) mold pores (P2) without throats, Lithofacies B, Well C10; (F) mold pores (P2), Lithofacies B, Well C14, 1,678.33 m (PPL); (G) mold pores (P2), Lithofacies B, Well C10 (PPL); (H) mold pores (P2), Lithofacies B, Well X13, 3,297.94 m (PPL); (I) intergranular dissolution pores (P3) present as clearly visible pinholes in drill cores, Lithofacies C, Well TS5, 2,863.32 m; (J) intergranular dissolution pores (P3) are connected by the necking throat (T2), Lithofacies C, Well TS5, 2,853.36 m (PPL) (Wang et al., 2018); (K) intergranular dissolution pores (P3) are connected by the necking throat (T2), Lithofacies C, Well TS5, 2,867.34 m (PPL); (L) intergranular dissolution pores (P3) are connected by necking throat (T2), Lithofacies C, Well TS5, 2,867.34 m (SEM); (M) intercrystalline pores (P4) in the drill core, Lithofacies D, Well TD100, 3,823.41 m; (N) intercrystalline pores (P4) are connected by the flaky throat (T3), Lithofacies D, Well TD100, 3,823.41 m (PPL); (O) intercrystalline pores (P4), Lithofacies D, Well TD110, 3,448.85 m (PPL); (P) intercrystalline pores (P4) and flaky throat (T3), Lithofacies D, Well TD110, 3,448.85 m (SEM).
Lithofacies B is oolitic limestone featured by greyish white color in the core (Figure 3E). Microscopically, most of the ooids in Lithofacies B are fabric-selectively dissolved (Figure 3F), but outermost concentric laminations are well-preserved (Figures 3G, H). The only pore type of Lithofacies B is mold pore (250–500 μm in diameter), and the throat is not developed (Figure 3H).
Lithofacies C is oolitic dolostone featured by white color in the core (Figure 3I). Microscopically, Lithofacies C is composed by subhedral silty crystalline dolomite (Figure 3J) and is characterized by signs of shadowy ooid outlines due to intense dolomitization (Figure 3K). The major pore type of Lithofacies C is intergranular dissolution pore (250 μm–500 μm in diameter) connected by a necking throat (Figure 3L). Very often, the difference between the pores and throats does not become obvious, and this necking throat mainly appears in the intergranular dissolution pores (Figure 3L).
Lithofacies D is oolitic dolostone composed of euhedral silty crystalline dolomite and fine crystalline dolomite (Figures 3M, N). The pore type of Lithofacies D is the intercrystalline pore (100 μm–150 μm in diameter) connected by a flaky throat (15 μm–40 μm in diameter) (Figures 3O, P).
4.1.2 Petrophysical property
Porosity and permeability are measured on 744 core plugs collected from 1) Lithofacies A (n = 480), 2) Lithofacies B (n = 26), 3) Lithofacies C (n = 85), and 4) Lithofacies D (n = 153). The average porosity of these four lithofacies is 2.7%, 2.6%, 7.0%, and 7.5%, respectively (Figure 4).
FIGURE 4. Petrophysical property of Feixianguan Formation tight oolitic reservoir.
According to the Oil and Gas Industry Standard of the People’s Republic of China (No. SY/T 6285-2011), Lithofacies A is characterized by ultra-low porosity and ultra-low permeability (Kralikova et al., 2016; Gao, 2019; Liu et al., 2022). The porosity distribution of Lithofacies A ranges from 2.00% to 8.90%, with an average value of 2.72%, mainly concentrated in 2.00%–4.00% (accounting for 93.21%) (Figure 4C). The permeability distribution of Lithofacies A ranges from less than .001 mD to 19.80 mD, with an average value of .20 mD, mainly concentrated in the two intervals of less than .001 mD (account for 52.43%) and .001 mD–.01 mD (accounting for 33.48%) (Figure 4D). Lithofacies B is characterized by ultra-low porosity and ultra-low permeability. The porosity distribution of Lithofacies B ranges from 2.05% to 4.08%, with an average value of 2.59%, mainly concentrated in 2.00%–4.00% (account for 96.15%) (Figure 4C). The permeability of Lithofacies B is less than .0100 mD with an average of .0076 mD (Figure 4D).
Lithofacies C is characterized by low porosity and medium permeability, with porosity distribution ranging from 2.00% to 23.85%, with an average of 7.03% (Figure 4E). The permeability distribution of Lithofacies C ranges from less than .001 mD to 423.000 mD, with an average value of 29.260 mD, and it is distributed among various permeability intervals (Figure 4F). Lithofacies D is characterized by low porosity and ultra-low permeability. The porosity of Lithofacies D ranges from 2.02% to 12.23%, with an average of 5.26%. They are distributed in all porosity intervals but mainly concentrated in the interval less than 8.00% (accounting for 88.46%) (Figure 4E). The permeability of Lithofacies D ranges from .0009 mD to 1.0200 mD, with an average value of .1700 mD, mainly concentrated in .0010 mD–1.0000 mD (accounting for 90.91%) (Figure 4F).
4.2 Pore-throat structure of different lithofacies
The pore-throat structure of a reservoir refers to the geometry, size, distribution, and connectivity of the pore body and throat. The pore-throat structure is the main controlling factor of the flow capability in a reservoir (Li et al., 2019b; Gu et al., 2020; Fan et al., 2022; Tang et al., 2022). In addition to the results discussed previously, we also carried out the pore-throat structure study using NMR, 3D-CT, and MICP data (Figure 5).
FIGURE 5. Pore-throat structure characteristics of different lithofacies in Feixianguan Formation tight oolitic reservoir.
4.2.1 Lithofacies A
Lithofacies A is dominated by micropores, which are residual intergranular pores after cementation (Figure 5). The NMR T2 spectrum reflects a bimodal pore-throat range of these samples. NMR signals with the relaxation time between 0.1 ms and 1 ms represent smaller pore-throat size, and the corresponding porosity component is generally less than .015%. NMR signals with the relaxation time between 10 ms and 100 ms represent slightly larger pore-throat size, and the corresponding porosity component is generally less than .06%, indicating that the heterogeneity of pore-throat in Lithofacies A is strong and the contribution of slightly larger pore-throat to porosity is obviously greater than that of small pore-throat. Curves for Lithofacies A samples (n = 3) show high displacement pressures and low mercury saturation at any given pressure, indicating pore-throats are smaller and pores are less well connected.
4.2.2 Lithofacies B
Lithofacies B is dominated by mold pores ranging from 200 μm to 600 μm (Figure 5). The NMR T2 spectrum reflects a bimodal pore-throat range of these samples. NMR signals with the relaxation time between 0.1 ms and 1 ms represent smaller mold pores, and the corresponding porosity component is generally less than .010%. NMR signals with the relaxation time between 10 ms and 500 ms represent larger mold pore, and the corresponding porosity component is generally greater than .05%, indicating that the heterogeneity of Lithofacies B is relatively weak and the contribution of larger mold pores to porosity is obviously greater than that of small mold pores. Curves for Lithofacies B samples (n = 3) show high displacement pressure and low mercury saturation at any given pressure, indicating mold pores are smaller and pores are less well connected.
4.2.3 Lithofacies C
Lithofacies C is dominated by macropores and small vugs, which are identified as intergranular dissolution pores and enlarged vugs by further dissolution (Figure 5). The NMR T2 spectrum reflects a unimodal pore-throat range, indicating that the difference between the pore diameter and throat diameter is very small. NMR signals with the relaxation time greater than 100 ms represent larger pore-throat size, and the porosity component corresponding to these pore-throats is generally greater than .06%, indicating that the heterogeneity of pore-throats is weak. Also, the range of pore-throat radius also shows that the heterogeneity is weak. The large, well-connected pores and throats of Lithofacies C samples (n = 3) are indicated by low displacement pressures and the high mercury saturation at low injection pressures (.05 MPa–0.1 MPa). The broad, relatively flat plateaus between 0% and 70% mercury saturation suggest that about 70% of the pore volume is accessed by throats with an effective radius between 6 µm and 165 µm. The contribution of permeability mainly comes from the pore-throat with the radius greater than 15 µm.
4.2.4 Lithofacies D
Lithofacies D is dominated by micropores, which are intercrystalline pores formed by intense dolomitization (Figure 5). The NMR T2 spectrum reflects a unimodal pore-throat range, indicating that the difference between the pore diameter and throat diameter is very small (Wang et al., 2019). NMR signals with the relaxation time between 100 ms and 1,000 ms represent a large pore-throat range, and the corresponding porosity component is generally greater than .10%, indicating that the heterogeneity of Lithofacies D is weak. Also, the range of pore-throat radius shows that the heterogeneity is weak. The large, well-connected pores and throats of Lithofacies D samples (n = 3) are indicated by low displacement pressure and high mercury saturation at relatively low injection pressures (.1M Pa–.5 MPa). The broad, relatively flat plateaus between 0% and 70% mercury saturation suggest that about 70% of the pore volume is accessed by throats with an effective radius between 1 µm and 147 µm. The contribution of permeability mainly comes from the pore-throat with the radius between 3 µm and 40 μm.
4.3 Origin of different lithofacies
4.3.1 Controlling factor of sedimentation
Whether the facies are deposited with platform-margin oolitic shoal or the open platform oolitic shoal, the porous sediments formed in the relatively high-energy environment are the most original material basis for reservoir rock (Tan et al., 2012; Mahmud et al., 2020). Early Triassic transgression led to a rapid sea-level rise in the study area during the early stage of T1f1 deposition. Because the landform is high in southwest and low in northeast (Xing et al., 2017; Ngene et al., 2022; Xia et al., 2022), at this time, the open platform landform highland is in the advantageous position of sedimentary oolitic shoals. Since the top of the oolitic shoals are close to the sea level, the oolitic shoals are susceptible to meteoric freshwater (Figure 6A). With the gradual decline in sea level and the increase in terrigenous debris input, the sedimentary process of oolitic shoals in the open platform stopped (Figure 6B). At this time, the platform-margin is near the wave base level, forming thick oolitic shoals due to high energy. After the formation of oolitic shoals on the platform margin, it is beneficial to forming a barrier environment behind the shoals (Figure 6C). As the sediments continuously filled the trough during T1f1–T1f2 deposition, the platform margin gradually moves to the trough. The barrier environment behind the shoals can be formed multiple times during this period. The whole study area evolved into an open platform, and the difference in sedimentary geomorphology disappeared, which is not conducive to inducing constructive diagenesis (Figure 6D).
FIGURE 6. Sedimentary-diagenetic evolution model of different lithofacies in Feixianguan Formation tight oolitic reservoir.
4.3.2 Controlling factor of diagenesis
4.3.2.1 Fabric-selective dissolution
The exploration experience of oolitic reservoirs around the world indicates that fabric-selective dissolution is involved in the reservoir-forming process, such as Kangan Formation (Tavakoli et al., 2011; Enayati-Bidgoli et al., 2014; Rahimpour-Bonab et al., 2014) in South Pars gas field of the Persian Gulf Basin, Iran, Dalan Formation (Esrafili-Dizaji and Rahimpour-Bonab, 2013) in Zagros area, Messinian stage of the Neogene Miocene in Southeast Spain (Goldstein et al., 2013), and Arab Formation of the Jurassic in Balal Oilfield, Iran (Ebrahim et al., 2018). Lithofacies B is developed in the southwest of the study area, which is characterized by mold pores and multi-stage calcite cement. This phenomenon is strong evidence for the fabric-selective dissolution of the aragonite grains (Moore, 2001; Qie et al., 2021). The southwest part of the study area is close to the paleo-land. Under this background, the depth of seawater in the southwest of the study area is less than that of other parts of the study area. The sedimentary environment of this area is relatively open, and the microscopic characteristics show that it is not affected by dolomitization. The ooids are formed continuously in the turbulent seawater of the submarine paleogeomorphic highland and then deposited, and the ooids are cemented by two-stage sparry calcite. When this area is located in the highstand system tract, the relative decline in the sea level and the vertical accretion of oolitic shoal in the open platform lead to be exposed beyond the sea level. Because of the unstable chemical properties and large specific surface area of aragonite ooids, fabric-selective dissolution is triggered by meteoric freshwater leaching during the syngenetic stage, while calcite cement is preserved because of its stable chemical properties and small specific surface area (Figure 6).
4.3.2.2 Dolomitization
The mechanism interpreted for dolomitization of Feixianguan oolitic dolostone mainly focuses on Eastern Kaijiang–Liangping Trough, including marine-meteoric mixing-zone (Yang et al., 2006), reflux (Jiang et al., 2013; Gu et al., 2020), thermal convection (Huang et al., 2011), or buried (Zheng et al., 2008) model. However, the marine-meteoric mixing-zone model has been questioned for its validity by academia (Hardie, 1987; Machel and Burton, 1994; Luczaj, 2006; Li et al., 2020), and the thermal-convection model seems relatively idealized. In terms of significant difference in the sedimentary environment between Eastern and Western Kaijiang–Liangping Trough, few studies suggest that hydrothermal brine and seepage-reflux brine are responsible for dolomitization in the platform margin of Western Kaijiang–Liangping Trough (Wang et al., 2018; Li et al., 2021a; Li et al., 2021b; Gu et al., 2021). For a long time, the contribution of dolomitization to carbonate reservoir formation has been controversial, and three main viewpoints have been proposed. First, dolomitization has limited contribution to the reservoir space; second, dolomitization only forms the dolomite framework to preserve primary pores; third, saddle dolomite directly precipitated from dolomitization fluid blocks the reservoir space formed by other diagenesis processes (Shen et al., 2016; Zhao et al., 2018; Zhou et al., 2021). There is no saddle dolomite and other minerals precipitated by dolomitization fluid in the oolitic reservoir. According to the proportion of dolomite in the oolitic reservoir, it can be considered that dolomitization is the key to the formation or preservation of the reservoir space in the study area from either the first or the second point of view. Therefore, it is necessary to re-evaluate the dolomitization model in the study area.
Based on petrological characteristics, no compaction deformation of ooid is observed in Lithofacies C and D in the study area. A shadowy outline of ooids and dolomite crystalline are observed to be relatively loose, and stylolite is not observed. In Lithofacies C, dolomitization is fabric-selective, and usually ooids and first-stage cements are preferentially dolomitized (Figure 3). Under CL (Figure 7), Lithofacies C and D are non-luminescent. The δ18O values of Lithofacies C and D samples are lower than those of normal Triassic seawater (Allan and Wiggins, 1993; Yoshida and Santosh, 2020), which indicates that the aging effect causes negative oxygen isotope migration in all samples (Figure 8). The unique geochemical characteristics of REE make it record the information of diagenetic fluids and diagenetic environment. It is an important method to understand diagenetic fluids and their origin. The ΣREE in all samples is lower than 12 × 10−6, which generally shows the characteristics of low REE content in marine carbonate rocks (Hu et al., 2010). All Lithofacies D samples are similar to marine limestone including Lithofacies A, showing high LREE content, low HREE content, large positive Ce anomaly, and large positive Y anomaly. The first half of the segments show similar features of marine fluids; the second half of the segments for Lithofacies C samples show large fluctuation and are similar to saddle dolomite curves with remarkable positive Eu anomalies, which are related to hydrothermal activities (Hu et al., 2010; Jiang et al., 2016; Gu et al., 2019).
FIGURE 7. CL characteristics of Lithofacies C and D in Feixianguan Formation tight oolitic reservoir.
FIGURE 8. δ13C vs.δ18O of different lithofacies in Feixianguan Formation tight oolitic reservoir.
The petrological characteristics indicate that dolomitization occurred before large-scale compaction (Figure 3). Fabric-selective dolomitization and CL characteristics indicate that dolomitization of Lithofacies C and D occurs mostly before mineral stabilization, and the corresponding diagenetic environment is a submarine-shallow burial environment which is low in Fe or rich in Mn. Compared with Lithofacies A which has not undergone obvious dolomitization, the δ18O of Lithofacies C and D shows a positive migration. It shows that the enrichment of 18O in reflux brine is caused by slight evaporation (Figure 8). Due to the barrier effect of platform-margin oolitic shoal during the deposition of T1f1–T1f2, penesaline seawater is formed by slight evaporation behind platform-margin oolitic shoals (Figures 6B, C). In the water–rock reaction process between hydrothermal fluids and oolitic limestone, Ca2+ in limestone is replaced by Eu2+ due to their equal valence and similar ionic radius; this leads to a positive Eu anomaly of Lithofacies C (Figure 9). The NW-trending basement faults of the Late Permian–Early Triassic provide migration channels for the upward migration of hydrothermal fluids (Wang et al., 2018). This study demonstrates that hydrothermal fluids also participate in the dolomitization of Lithofacies C (Figures 6A, B). Although the dolomitization mechanism of Lithofacies D is the same as that of C, the shadowy ooid outlines almost completely disappear and the crystal rim exhibits bright red (Figures 6C, D), indicating that the strong recrystallization of dolomite occurs during the dolomitization process, which further improves the pore-throat structure of Lithofacies D.
FIGURE 9. Seawater-normalized REE patterns and binary diagram of different lithofacies in Feixianguan Formation tight oolitic reservoir.
4.3.2.3 Other diagenesis effects
Some other diagenesis effects may also have an impact on petrophysical properties of different lithofacies, but they do not play a decisive role in the origin of different lithofacies (Shan et al., 2021; Sun, 2023). The microscopic characteristics of different lithofacies and the development degree of stylolites show that the mechanical compaction has a destructive effect on the petrophysical properties of Lithofacies A and B but has little effect on Lithofacies C and D, indicating that dolomitization has remarkable effect on improving the anti-compaction of reservoir lithofacies (Figure 10). During the syndiagenetic stage, micritization can be observed in many ooids, but the effect on rock fabric is extremely slight, which does not affect the differential evolution of lithofacies. During the middle-late diagenetic stage (Figure 11), accompanied by hydrocarbon charge and subsequent oxidative cracking of hydrocarbons, the organic acid or thermogenic sulfate reduction (TSR)-induced burial dissolution occurs in the oolitic reservoirs of the study area (Cai et al., 2014). The identified diagenetic processes that took place in different diagenetic stages are presented in Figure 12.
FIGURE 10. Histograms showing frequency (A) and amplitude (B) of the stylolites in different lithofacies of Feixianguan Formation tight oolitic reservoir.
FIGURE 11. Paragenetic sequence of the diagenetic processes in Feixianguan Formation tight oolitic reservoir.
FIGURE 12. Diagenetic evolution of different lithofacies in Feixianguan Formation tight oolitic reservoir.
5 Conclusion
1) Four types of lithofacies exist in Feixianguan oolitic reservoirs of NE Sichuan Basin, namely, Lithofacies A, Lithofacies B, Lithofacies C, and Lithofacies D. The pore type of Lithofacies A is intergranular pores connected by the tube-shaped throat. Lithofacies B is characterized by mold pores, with the poorly developed throat. The pore type of Lithofacies C and D is intergranular dissolution pores connected by the necking throat and intercrystalline pore connected by the flaky throat, respectively.
2) Lithofacies A possesses small intergranular pores (100 μm–240 μm) that are connected by few tube-shaped throats with a bimodal pore-throat range. The heterogeneity of pore-throat in Lithofacies A is strong, and the contribution of slightly larger pore-throats to porosity is obviously greater than that of small pore-throats. Lithofacies B dominated by mold pores (200 μm–600 μm) also reflects a bimodal pore-throat range. Although the pore heterogeneity of Lithofacies B is weaker than that of Lithofacies A, there is no effective throat connection between the mold pores in Lithofacies B. Lithofacies C dominated by intergranular dissolution pores and vugs possess fairly larger pores (and vugs) that are well connected by large throats with a fairly narrow pore-throat size range. The heterogeneity of pore-throat in Lithofacies C is weak. The pore-throat structure of Lithofacies D is very similar to that of Lithofacies C, but the heterogeneity is obviously much weaker.
3) On the basis of oolitic shoal deposition, the main factors of diagenesis controlling the origin of different lithofacies are fabric-selective dissolution triggered by meteoric freshwater and dolomitization triggered by dolomitization fluids. The origin of Lithofacies B is dominated by meteoric freshwater leaching. The origin of Lithofacies C is not influenced by meteoric freshwater leaching but formed by the effect of seepage reflux and hydrothermal dolomitization fluids. The origin of Lithofacies D is only controlled by seepage-reflux dolomitization. Some other diagenesis effects may also have an impact on petrophysical properties of different lithofacies, but they do not play a decisive role in the origin of different lithofacies.
Data availability statement
The original contributions presented in the study are included in the article/Supplementary Material; further inquiries can be directed to the corresponding author.
Author contributions
GR: experiments, data analysis, visualization, and writing—original draft. QQ: conceptualization, methodology, and supervision. QZ: project administration and supervision. YG: supervision and revising the manuscript. ZY: data analysis and revising the manuscript.
Funding
This study was financially supported by Comprehensive Exploration Research Project of PetroChina Southwest Oil and Gas Field Company in 2019 (No. XNS05JS2019-19) and the National Natural Science Foundation (No. 41402126).
Conflict of interest
Author QZ was employed by PetroChina Southwest Oil and Gas Field CDB Operating Company. Authors YG and ZY were employed by PetroChina Southwest Oil and Gas Field Company.
The remaining authors declare that the research was conducted in the absence of any commercial or financial relationships that could be construed as a potential conflict of interest.
Publisher’s note
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Keywords: tight oolitic reservoir, dolomitization, formation mechanism, controlling factors, lithofacies, Feixianguan Formation
Citation: Ren G, Qin Q, Zhang Q, Guo Y and Ye Z (2023) Study on reservoir characteristics, pore-throat structure, and origin of tight oolitic reservoirs: A case study of Triassic Feixianguan Formation, NE Sichuan Basin, SW China. Front. Earth Sci. 10:1112190. doi: 10.3389/feart.2022.1112190
Received: 30 November 2022; Accepted: 28 December 2022;
Published: 12 January 2023.
Edited by:
Wenlong Ding, China University of Geosciences, ChinaReviewed by:
Zhu Baiyu, Yangtze University, ChinaGuorong Li, Chengdu University of Technology, China
Binfeng Cao, Key Laboratory of Oil and Gas Resources Research, Institute of Geology and Geophysics (CAS), China
Copyright © 2023 Ren, Qin, Zhang, Guo and Ye. This is an open-access article distributed under the terms of the Creative Commons Attribution License (CC BY). The use, distribution or reproduction in other forums is permitted, provided the original author(s) and the copyright owner(s) are credited and that the original publication in this journal is cited, in accordance with accepted academic practice. No use, distribution or reproduction is permitted which does not comply with these terms.
*Correspondence: Guanxiong Ren, rgxxly1991@163.com