The analyses of hydrocarbon reservoirs in the high-frequency reef and shoal facies of the Lower Ordovician carbonate successions in the Penglaiba Formation (O1P) and Yingshan Formation (O1–2Y) in the Tazhong (Katake) Uplift in central Tarim basin showed three types of hydrocarbon reservoirs: type 1 associated with synsedimentary facies, type 2 developed by hot active basinal dissolution fluids [mesogenetic fluids, geothermal/hydrothermal fluids and thermochemical sulfate reduction-related fluids] and tectonic activity, and type 3 are hypogenic–epigenetic karst reservoirs formed by meteoric and mesogenetic dissolution fluids. Porosity and permeability development in the reef and shoal facies in the highstand system tracts (HST) of the third-order sequence cycles (SQ1–SQ3) correlates well with regression peaks in O1P and O1–2Y, mostly related to multiphase tectonic activity, long-term exposure, denudation and dissolution in near-surface to shallow burial settings. The carbonate successions in the O1P and O1–2Y are composed of seventeen microfacies (MF-1 to MF-17) deposited on a shallow marine platform. Six main groups of microfacies associations (MFA-1 to MFA-6) were recognized, with each microfacies association corresponding to the transgressive system tracts and HST of SQ1–SQ4 in O1P and O1–2Y. The microfacies represent specific sedimentary environment including platform interior and platform margin deposited under particular hydrodynamic conditions. Tectonics and frequent relative sea-level fluctuation associated with rapid transgression and slow regression favored the deposition of the large-scale vertical stacking, high-frequency reef and shoal facies across the carbonate platforms in this uplift. The hydrocarbon reservoirs in this study have relatively moderate porosity and low permeability, and are somewhat potential reservoirs for hydrocarbon exploration in the Tazhong Uplift.
The Tarim basin in Northwest China is the largest oil-bearing basin in China (Fig. 1), where a number of oil and gas fields were recently discovered, with ongoing production in the Ordovician carbonate successions (Li et al. 1996,2012; Zhang et al. 2007). The Lower Paleozoic carbonate strata in the Tarim basin have experienced multiphase diagenetic history from early shallow marine to deep burial (Guo et al. 2016; Jiang et al. 2016), and because they are deeply buried (generally > 8000 m), their primary porosities are almost totally obliterated. This basin is characterized by a long history of deposition, thick carbonate succession in the Cambrian and Ordovician Formations, complex tectonic history and abundant hydrocarbon resources (Fan et al. 2007; Li et al. 2012; Gao and Fan 2014b). Studies have been done on the Lower Ordovician carbonate reservoirs in the Tazhong area of the Tarim basin (Yang et al. 2011; Wu et al. 2012; Zhao et al. 2012). Shallow marine carbonate reservoirs have also been the focus of petroleum exploration and development in this basin (Yang et al. 2011; Lan et al. 2013; Fu et al. 2017). The primary porosity and permeability are commonly reduced by intensive compaction and cementation, and secondary porosity is thought to play a major role as productive reservoir spaces in the shallow–deeply buried carbonate rocks in the Tarim basin (Zhang et al. 2009). The secondary porosity in these carbonate rocks are often related to early, near-surface diagenetic processes and tied to subaerial exposure and freshwater dissolution, and under shallow–deep burial conditions through dissolution by mesogenetic fluids, thermochemical sulfate reduction and hydrothermal fluid activity (Cai et al. 2001, 2008, 2009a, b, 2015a, b, 2016; Yang et al. 2012; Li et al. 2014; 2016; Zhu et al. 2015; Jiang et al. 2015, 2016; Liu et al. 2017). Recently, researchers have been increasing interest in structurally controlled hydrothermal dolomitized rocks for their potential as favorable reservoirs (Dong et al. 2016; Hendry et al. 2015; Zhu et al. 2015; Jiang et al. 2015; Li et al. 2016). Recent exploration has confirmed that huge hydrocarbon resources can be found in these Lower Paleozoic ancient dolomite reservoirs (Cai et al. 2002, 2009a, b, 2015a; Wang et al. 2014). The deeply buried Cambrian dolomites in the Tarim basin are reported to contain significant hydrocarbon resources as a result of localized to widespread source rocks in the Lower Cambrian strata (Cai et al. 2009a, b, 2015b, Zhao et al. 2013), as well as thick, regional anhydrite seal deposits in the Middle Cambrian strata (Wang et al. 2014; Cai et al. 2015a), which is an indication of high prospects for future hydrocarbon discoveries.
Research on carbonate platforms in Tarim basin have been focused on sedimentary environment (Feng et al. 2007; Hu et al. 2009), sequence stratigraphy (Zhang and Liu 1995), and reef and shoal distribution (Gao and Fan 2015; Yang et al. 2011) in the Ordovician carbonate succession. High-energy environments such as platform margin reef and shoals, and intraplatform shoals in the Tarim basin are considered as the most important areas for petroleum exploration. Recently, research has been done on the development of layered deposits and the distribution of reservoirs on platform margin reef and shoals and intraplatform shoal facies (Gu 2001; Gao and Fan 2015). The depositional cycle architecture of the Lower Ordovician depends on the environmental factors that change periodically causing rapid and progressive facies changes with time. Goldhammer et al. (1993), Gonzales (1996) and Chen et al. (1999) have done research on the effects of high-frequency relative sea-level changes in carbonates successions and revealed that depositional cycles are excellent indicators of sea-level fluctuations since their development depend on many variable factors.
Microfacies analysis in carbonate rocks and the interpretation of sedimentary environments have been a fundamental research area for researchers (Wilson 1975; Flügel 2004; Gao et al. 2014). Understanding the patterns of microfacies successions and the influence of sequences stratigraphy on carbonate platforms is vital in predicting favorable hydrocarbon reservoirs (Al-Awwad and Collins 2013; Li et al. 2013a, b). However, little attention has been paid to the variation in microfacies and microfacies associations in the Lower Ordovician carbonate successions in the O1P and O1–2Y and the development of hydrocarbon reservoirs in high-energy reef and shoal facies.
This paper aims to: (1) study the development of favorable hydrocarbon reservoirs in the high-energy reef and shoal complexes, (2) elucidate microfacies characteristics and their sedimentary environments, and (3) attempt an interpretation of the coarsening-upward depositional sequence cycles in the Lower Ordovician Formations in the Tazhong Uplift in central Tarim basin. This interval of the Ordovician period is chosen because it represents a depositional sequence that reveals lithofacies alternations with successive and repeated coarsening-upward trends.
The Tazhong Uplift is located in the Central Uplift Belt of the Tarim basin (Fig. 1). The deeply buried Lower Ordovician carbonates in the Tazhong Uplift have suffered multiphase episodes of intense tectonic activity during the Caledonian and early–late Hercynian orogeny (Wu et al. 2012). The Tazhong Uplift is a paleo-uplift that developed as a result of the effect of compressive stress on the Late Cambrian–Early Ordovician carbonate strata (Gao and Fan 2014a; Ngia et al. 2019; Hu et al. 2019). This paleo-uplift stretches for more than 300 km from east–west, 80–100 km wide, and it is bounded by the Tazhong fault-1 in the north and Tazhong fault-2 in the south (Lin et al. 2012). The fault structures in this paleo-uplift mainly developed in the Lower and Middle Paleozoic, and consist of fold–fault structural belt. A series of NW–SE-, NWW–SEE- and NE–SW-trending reverse faults, and NE–SW-trending strike–slip faults (Gao and Fan 2014a, b; Li et al. 2013a, b) developed in the Tazhong Uplift and led to the Tazhong block compartmentalization (Gao and Fan 2014a, b). A series of half-grabens and normal faults developed during Early–Middle Cambrian, indicating that the Tarim craton was a divergent rifted continental margin characterized by fault-related depressions (Gao and Fan 2014a, b). In plain view, the faults controlling half-graben deposition exhibit four patterns such as relay, en-echelon, parallel stripe and quasi-arch types (Li et al. 2013a, b). Relay-patterned faults are associated with a range of parallel, discontinuous and overlapping structural units and are common in the Tazhong area (Li et al. 2013a, b; Gao and Fan 2014a, b). En-echelon faults form near-vertical strike–slip structures and exhibit flower structures in vertical profile in central Tarim basin (Li et al. 2013a, b). The latter two types only occur locally in the Tazhong area. The multiphase episodes of intense tectonic activity in the Tazhong Uplift during the Caledonian and early–late Hercynian orogeny (Wu et al. 2012) could have exerted substantial influence on the deeply buried Cambrian carbonate rocks as they were penetrated by the intrusive diabases and volcanic eruptive edifice through geothermal/hydrothermal fluid inputs (Chen et al. 1997; Jiang et al. 2015; Guo et al. 2016; Ngia et al. 2019). As a result, conjugate fault systems and related fracture networks were created in the Cambrian to Lower Ordovician sedimentary packages particularly in the Tazhong area. The Tazhong Uplift lies between the Tangguzibasi Depression and Manjiaer Depression (Fig. 1). A series of tectonic activities during the Lower and Middle Ordovician in the Tazhong Uplift (Gao and Fan 2014a, b; Li et al. 2013a, b; Hu et al. 2019) resulted in three unconformities (RUS1, RUS2 and RUS3) as the lower, middle and upper boundaries of the Lower Ordovician Formations (Lin et al. 2012). Relative sea-level fluctuation during the Lower Ordovician period in the Tazhong Uplift resulted in the development of vertical stacking sedimentation on the carbonate platform (Liu et al. 2006).
On the basis of petrographic characteristics and biofacies, the Lower Ordovician sedimentary environments and lithofacies could be summarized as follows: Restricted platform depositional facies during the Lower Ordovician include intertidal–supratidal and shallow subtidal–tidal flat or lagoon shoal facies over a wide area in the Tazhong Uplift (Fig. 2). The open platform developed partly during the Lower Ordovician and fully during the Middle Ordovician in both the northern and southern parts of the Central Uplift Belt, and is composed of intraplatform shallow subtidal–intertidal sand shoal facies (Gao and Fan 2015). A short regression phase at the end of the Lower Ordovician resulted in local erosion during the Late Yingshan Formation (Liu et al. 2006; Lin et al. 2012). Platform margin deposits were formed throughout the Lower Ordovician period in the Tazhong Uplift forming a wide facies belt around the Central Uplift Belt. The platform margin extended laterally on both sides of the Central Uplift due to high carbonate production rate and continual deepening of the platform during marine transgression (Zhao et al. 2007). Biostratigraphically, the stratigraphic subdivision of the Lower Ordovician strata in the Tazhong Uplift is based on the study of conodont species (Zhao et al. 2006; Jing 2009) commonly found preserved in platform carbonate rocks (Fig. 3a).
Data and methods
In total, 290 rock samples and cores were obtained from eight wells and the detailed petrographic examination of 210 thin sections, with some stained with Alizarin Red S to differentiate calcite from dolomite, was carried out by petrographic microscope in the Key Laboratory of Exploration Technologies for Oil and Gas Resources, Yangtze University.
The reservoir property data (permeability and porosity) of over 170 samples were measured with permeability and porosity analyzers (MFA-170 and SMP-200). Carbonate microfacies were described following the classification of Dunham (1962) with the modifications of Embry and Klovan (1971), Wilson (1975) and Flügel (2004). A combined detailed analysis of well log (gamma log and resistivity log readings), core data and petrographic studies were carried out in order to analyze the microfacies in the thick coarsening–fining-upward sequences of the Lower Ordovician carbonate succession in the Tazhong Uplift. We established a sedimentary model for the Lower Ordovician carbonate successions to identify the intervals of depositional facies on the carbonate platforms.
Characteristics and depositional sequence cycles of the Lower Ordovician carbonate successions
The Lower Ordovician carbonate successions in the Tazhong Uplift are characterized by vertical stacking pattern, cyclic sequences that are successively and somewhat progressively coarsening-upward, with various facies in the cycles having variable thickness, erosional and flooding surfaces. Six third-order sequences are recognized in these carbonate successions in the Tazhong Uplift. They are determined on the basis of well drilling data, cores and evidence from subaerial exposure events in the facies stacking patterns. The third-order sequences (SQ1–SQ4) contain both transgressive system tracts (TST) and highstand system tracts (HST) (Fig. 3a, b).
Characteristics and depositional sequence cycles of the Penglaiba Formation
The O1P can be divided into two third-order depositional sequences (SQ1 and SQ2), which contains both the TST and HST (Fig. 3a, b). Based on facies changes across sequence boundaries within cyclic strata in the O1P, asymmetrical and minor symmetrical meter-scale depositional cycles were identified (Fig. 3c). The asymmetrical cycles are dominant and are characterized in some places by lapse in facies deposition across the cyclic boundaries (Fig. 3c; points B and D). The symmetrical cycles are less common and show gradual microfacies transition across the boundaries within the cyclic strata (Fig. 3c; points A and C) (Chen et al. 1999,2018).
The microfacies in the lower cycle of the shallowing-upward and coarsening-upward, meter-scale cyclic sequence (SQ1) are composed of crystalline dolomites, bioclastic lime mudstones (marlstones)–wackestones, dolomitic limestone and argillaceous dolomite, constituting the TST (Fig. 3a–c). The microfacies in the upper cycle of the HST of SQ1 include coarse-grained bioclastic ooidal–peloidal packstone–grainstone and bioclastic floatstone. The thickness of the lower cycle microfacies varies in different intervals and ranges from 80 to 140 m, whereas that of the upper cycle microfacies ranges from about 85–290 m. On the other hand, the microfacies in the lower cycle of the TST of SQ2 are composed of lime mudstones (marlstones), ostracod–oyster wackestone–packstone, argillaceous dolomite and dolomitic limestone. The HST represents the coarse-grained upper cycle microfacies (Fig. 3a, b). The thickness of the lower cycle microfacies varies in different intervals and range from 70 to 175 m, and that of the upper cycle range from about 45–195 m. Bioturbation occurs locally within the bioclastic lime mudstone (marlstone)–wackestones facies with clasts of bioclastic ooids and peloids common (Fig. 4e).
The microfacies in the lower and upper cycles in the SQ1 and SQ2 of the O1P Formation are separated at their bottom by conspicuous erosional surfaces (Fig. 4b, c, f). Ooids and peloids with numerous bioclasts oriented parallel to beddings are observed and are considered as deposits from unidirectional tidal and storm surge flow (Fig. 4b, c, f). The topmost part of SQ2 is a surface of unconformity (RUS2) (Fig. 3a–c). Below the surface of the RUS2 unconformity in the O1P are karst breccia (Fig. 4f, g), which may have developed at the base of a talus slope on the platform margin or probably associated with erosion, burial dissolution, faulting activity and collapse filling of karst caves in the weathered karst belt (Fig. 3a–c) (Gong and Liu 2003; Baryakh and Fedoseev 2011).
The microfacies of the SQ1 and SQ2 in the O1P are characterized by relatively low–medium gamma-ray readings throughout (Fig. 3a, b), which reflect medium–high-energy depositional conditions in restricted shallow marine subtidal–intertidal platform and platform margin reef and shoals.
Characteristics and depositional sequence cycles of the Yingshan Formation
On the basis of well logging and core data, the thickness of the O1–2Y ranges from 300 to 700 m (Jianfa et al. 2015). This formation is divided in to four third-order sequences (SQ1–SQ4), which contains both the TST and HST (Fig. 3a–c). This formation is mostly characterized by shallow subtidal–intertidal depositional cycles comprising of deep subtidal fine- to medium-grained microfacies at their base and shallow subtidal to intertidal coarse-grained microfacies toward the top of the sequence, representing incomplete shallowing subtidal–intertidal aggradational facies stacking patterns. In addition, the facies changes across the sequence boundaries within cyclic strata constitute meter-scale asymmetrical and minor phases of symmetrical cycles (Fig. 3c).
The microfacies of the lower cycle of the TST of SQ1 in the O1–2Y are lime mudstone (marlstones)–wackestone. The microfacies in the upper cycle are regarded as the HST of SQ1 and comprise intertidal–supratidal coarse-grained microfacies (Fig. 3a, b). The thicknesses of the fining-upward lower cycle microfacies vary in different places and intervals, and range from about 40–95 m, whereas those of the coarse-grained upper cycle microfacies range from 40 to 70 m.
The lower cycle microfacies in the TST of SQ2 are composed of argillaceous dolomite and dolomitic limestone interbedded with bioclastic lime mudstones–wackestones (Fig. 3a). The bioclastic lime mudstones (marlstones) somewhat contains nodules, with argillaceous–calcareous sediments infills around the nodules, reflecting deposition in a low-energy environment. The coarse-grained upper cycle members correspond to the HST of SQ2 and comprise mixed microfacies (Fig. 3a). The maximum flooding surface of this sequence is characterized by bioclastic lime mudstones (marlstones)–wackestones. The thickness of the deepening-upward and fining-upward lower cycle microfacies varies in places and ranges from about 20–60 m, and that of the coarse-grained, coarsening-upward upper cycle microfacies ranges from about 40–97 m.
The SQ3 constitutes the upper part of the O1–2Y (Fig. 3a, b) and begins with interbedded bioclastic lime mudstone–wackestone as the lower cycle microfacies, constituting the TST of the sequence. The maximum flooding surface of the SQ3 is characterized by the upper part of the bioclastic lime mudstone–wackestone bed. The microfacies in the HST of SQ3 include medium-thick-bedded bioclastic ooidal–peloidal packstones–grainstones and ostracod–oyster–algae floatstone interbedded with bioclastic limestone. The thickness of this sequence ranges from about 20–65 m for the fine-grained lower cycle microfacies and 45–145 m for the coarse-grained upper cycle microfacies (Fig. 3a, b). The increase in mud content at the topmost part of SQ3 reflects the start of the drowning process of the carbonate platform. The microfacies of SQ1–SQ3 are characterized by relatively low–medium gamma-ray readings (Fig. 3a, b) throughout and reflect moderate–high hydrodynamic sedimentary conditions on platform margin and platform interior.
The shallowing-upward subtidal–intertidal cycles in this formation are typically asymmetrical cycles exhibiting both thickening and coarsening-upward trends (Fig. 3c; points F, H and J), and reflect a prolong marine regression and upward increase in hydrodynamic conditions that are usually controlled by relative sea-level fluctuation (Chen et al. 1999; Zhu et al. 2017). The minor symmetrical cycle phases in this formation constitute the lower cycle microfacies of the sequences (SQ1–SQ4) (Fig. 3c, points E, G, I and K). The topmost part of this formation (e.g., TST) belongs partly to the Dapingian Stage of the Middle Ordovician period which is considered as a drowning-upward third-order sequence (SQ4) (Fig. 3a–c) (Yang et al. 2010; Gao and Fan 2015). The SQ4 was deposited on shallow intertidal–supratidal flat under low-amplitude/high-frequency sea-level rise during early marine transgression. A few stromatolite hemispheroid laminae (Fig. 4h) and laminoid fenestrae are sporadically present in the argillaceous bioclastic limestones of the SQ3 and SQ4 in the O1–2Y. The TST of SQ4 is characterized by relatively medium–high gamma-ray readings (Fig. 3a, b) throughout and reflects deposition under low–moderate-energy environment.
Microfacies analysis and interpretation
Microfacies characteristics and interpretation
Deposition in the central Tarim basin especially in the Tazhong Uplift is interpreted to have been on platform interior (restricted subtidal–intertidal platform, intraplatform sand shoals and open platform) and platform margin (reef and sand shoals) during the Lower Ordovician times (Lin et al. 2012; Gao and Fan 2015). On the basis of well logging, cores and thin-section analysis, in addition to depositional characteristics of allochems and early diagenetic features, seventeen microfacies (MF-1 to MF-17) were recognized in the study area. The attributes of these microfacies are shown in Figs. 4, 5, 6 and 7, and the detailed description and interpretation of each type of microfacies are shown in Table 1. The recognized microfacies are somewhat compared with the Standard Microfacies Types (SMF) of Wilson (1975) and Facies Zones (FZ) of Flügel (2004), and their depositional environments are interpreted following Flügel (2004).
Microfacies association and interpretation of sedimentary environment
The carbonate microfacies in this study are described and differentiated using the classification of Dunham (1962) and Embry and Klovan (1971). Six main types of microfacies association (MFA-1 to MFA-6) are recognized and shown in Fig. 8. These microfacies association enabled the recognition of the major environments of deposition, including platform interior and platform margin. Platform reef and shoal facies dominates the shallowing-upward and coarsening-upward cycles in the HST of SQ1–SQ3 in the O1P and O1–2Y (Fig. 3a, b).
MFA-1 (Fig. 8a) of the O1P includes several microfacies (i.e., MF-1 to MF-7). The occurrence of MF-6 and MF-7 at the bottom of the coarsening-upward third-order depositional sequence (SQ1) represented by MFA-1 indicates deposition in a low-energy subtidal environment after a short transgression phase. Succeeding MF-6 and MF-7 microfacies is MF-5 that was deposited in restricted subtidal–intertidal environments under low- to moderate-energy conditions. MF-1 to MF-4 succeed MF-5 and form the top microfacies which are thought to terminate the growth of reefs as a result of a drop in relative sea level, deposited in restricted supratidal–intertidal zones. Therefore, MFA-1 was developed in the platform interior under low- to moderate–high-energy conditions.
MFA-2 corresponds to the SQ2 and represents the topmost part of the O1P, comprising many microfacies (Fig. 8b). MF-4, MF-13 MF-14 MF-15 and MF-16 are the microfacies at the bottom of the coarsening-upward cycle of MFA-2 that was probably deposited in shallow restricted environments. MF-10 is the middle microfacies of the cycle and represents reef and sand shoal deposits. MF-8 and MF-9 are the top end microfacies of the cycle that were deposited on platform margin/marginal slopes (i.e., reef slope sand shoals). Based on the above assertions, MFA-2 may have developed in platform interior and platform margin/marginal slopes under low- to moderate–high-energy conditions. The gamma-ray curves associated with MFA-1 and MFA-2 of the SQ1 and SQ2, respectively, in the O1P are funnel-shaped, having gamma-ray readings ranging from 10 to 75 API units (Fig. 8a, b). The jagged edges of the gamma-ray log in this figure correspond to mud-rich components in the individual microfacies of the associations. MFA-3 (Fig. 8c) is composed of microfacies that are not very different from those of MFA-1 and MFA-2 and it corresponds to the SQ1 in the O1–2Y. The occurrence of MF-5 and MF-12 at the base of MFA-3 represents restricted subtidal–intertidal and shallow shelf margin deposits. They are related to environment characterized by short period of marine transgression. The microfacies in the middle and top (MF-1, MF-10 and MF-11) of MFA-3 correspond to the HST of SQ1 that may have developed under moderate–high-energy conditions due to a drop in relative sea level. MFA-3 may have developed mainly in the platform interior (e.g., restricted subtidal–intertidal platform, open platform and intraplatform sand shoals).
MFA-4 (Fig. 8d) corresponds to the SQ2 in the O1–2Y. It has microfacies such as MF-13, MF-15 and MF-16 in the lower part of the coarsening-upward sequence cycle and represents facies deposited under low–moderate-energy conditions. The occurrence of MF-2, MF-3 and MF-14 in the middle and MF-8, MF-9 and MF-10 at the top of the HST of SQ2 indicates deposition under moderate–high-energy conditions. MFA-4 sequence cycles are common in wells Tz1, Tz2, Tz3, Z2 and Z4 (Figs. 2 and 9), and were developed in platform interior and platform margin under low- to moderate–high-energy conditions. The vertical stacking patterns of the microfacies in MFA-3 and MFA-4 reflect changes in depositional conditions from low–moderate energy at the lower–moderate- and moderate–high-energy conditions at the top of the sequence, respectively.
MFA-5 (Fig. 8e) corresponds to the SQ3 in the middle of the O1–2Y. MFA-5 comprises microfacies such as MF-8, MF-9, MF-10, MF-11 and MF-17. The bottom of this microfacies association corresponds to a short period of marine transgression and is represented by MF-17. The middle cycle microfacies correspond to the HST of SQ3 and have microfacies such as MF-10 and MF-11. The faintly laminated structures in most samples of MF-17 and fenestral structures in MF-11 (Fig. 8d, f) are typical of tidal flat–lagoon and restricted shallow marine low-energy environments. MF-8 and MF-9 are the microfacies at the topmost part of MFA-5 and may have developed under moderate–high-energy conditions. Hence, MFA-5 probably developed in platform interior and platform margin/marginal slopes under low- to moderate–high-energy conditions. The gamma-ray curves of MFA-3, MFA-4 and MFA-5 are funnel-shaped, with wide gamma-ray values ranging from 8 to 90 API units (Fig. 8c–e). The jagged edges of the gamma-ray curves in this figure correspond to argillaceous components in the individual microfacies of the associations. The TST of SQ4 that constitutes the topmost part of the O1–2Y corresponds to MFA-6 (Fig. 8f). It comprises microfacies such as MF-11, MF-12, MF-13, MF-14 and MF-17. MF-17 forms the base of MFA-6 and was deposited in a low-energy deep marine environment. MF-13 and MF-14 are coarse-grained microfacies and form the middle cycle of the SQ4 which may have developed under moderate-energy condition. MF-12 interbedded with MF-11 form the topmost microfacies that were formed in restricted shallow marine environment. MFA-6 belongs to the Dapingian Stage of the Middle Ordovician and represents a drowning-upward third-order sequence (SQ4) of the carbonate platform that corresponds to a long period of marine transgression (TST) (Yang et al. 2010; Gao and Tailiang 2015). They were deposited in subtidal–tidal flats/lagoon under low–moderate hydrodynamic energy as shown by the increase in mud content toward the top of the SQ4 sequence. The gamma-ray curve for MFA-6 is almost box-shaped with wide gamma-ray values ranging from 6 to 115 API units. Its jagged edges correspond to the argillaceous-rich components of the individual microfacies of the association (Fig. 8f).
Depositional model of the Lower Ordovician carbonate platform in the Tazhong Uplift
Figure 9 shows a conceptual model which summaries the distribution of the facies on the carbonate platform in the Tazhong Uplift during the Lower Ordovician period. This conceptual model provides a somewhat reference for the interpretation of facies changes in the study area and is proposed based on the variation of microfacies and their corresponding associations. This depositional model should be seen as a predictive tool for this study and not as a detailed paleogeographic reconstruction of the study area.
The area covered by platform facies expanded during the Lower Ordovician, with widespread platform facies in the west of central Tarim basin which later evolved to open platform and restricted platform across a large area, and have many intraplatform shoals (Figs. 2 and 9). The platform reef and shoals’ deposits formed during the Lower Ordovician period in the central Tarim basin were mostly aggradational depositional cycles on rimmed carbonate platform (Gao and Fan 2015; Zhu et al. 2017).
During the HST of the SQ1 and SQ2 in the O1P (Fig. 3a, b), high-energy reef and shoal facies formed a buffer zone at the platform margin (wells Z11 and GL1) (Figs. 2 and 9) (e.g., Gao and Fan 2015). Open platform facies (well Z4), intraplatform sand shoal facies (wells Z1, Z2 and Tz1) and restricted subtidal–intertidal platform and/or tidal flat–lagoon facies (wells Tz2 and Tz3) constitute the platform interior (Fig. 9). Carbonate sand shoal facies were laterally widespread and prominent in the study area during the Lower Ordovician with vertical stacking pattern cycles that alternately generated thick reefal facies. Sand shoal facies were mainly developed along platform margin/marginal slope breaks, whereas intraplatform sand shoals were developed within the platforms. The platform sand shoal facies were widespread toward the northwestern part of the carbonate platform. Thick reefal and shoal facies are well preserved in cores of wells Z11 and GL1 drilled toward the southeast of the platform. The reef and sand shoals on the platform margin appeared vertically stacked and seem to have developed continuously as an aggradational depositional sequence, while the intraplatform sand shoals within the platforms occurred isolated (Gao and Fan 2015).
Well logging data show that the middle cycle microfacies and topmost cycle microfacies in the HST of SQ1 and SQ2 of the O1P which constitutes MFA-1 and MFA-2, respectively, probably terminated the growth of reef and shoals toward the northwestern part of the platform as a result of a drop in relative sea level. The middle and upper cycle microfacies were deposited on open platform (Z4), reef and shoals on platform margin (Z11 and GL1) and intraplatform sand shoals (Tz1, Z1 and Z2) (Figs. 2 and 9), under moderate- to high-energy conditions. The lower cycle microfacies were deposited in low-energy tidal flats (subtidal–supratidal platform) and lagoons (Tz2 and Tz3), and open platform (Z4) (Fig. 9) after a short shallow marine transgressive phase in the platform interior.
The depositional environment of the SQ1–SQ4 in the O1–2Y changes frequently from TST to HST (Fig. 3a–c). The microfacies associations (MFA-3 to MFA-6; Fig. 8c–f) represent the lower to upper cycle microfacies of the third-order sequences (SQ1–SQ4) in the O1–2Y. The lower cycle microfacies of MFA-3 to MFA-6 were deposition in the platform interior (Tz2 and Tz3) and on platform margin (Z11) (Fig. 9), characterized by a short period of marine transgression and constituted the TST of the SQ1–SQ4. The middle-upper cycle microfacies of MFA-3 to MFA-5 (Fig. 8c–e) constitute the HST of SQ1–SQ3 in the O1–2Y and are common in cores from wells drilled in platform interior and reef shoals on platform margin. MFA-6 represents the TST of SQ4 (Fig. 8f) and its microfacies are common in cores from wells drilled in platform interior and platform margin in the study area. The above interpretation suggests that the microfacies of the SQ1–SQ4 in the O1–2Y were somewhat not uniformly distributed and show significant distinction in their microfacies from the TST to HST sequence cycles (Fig. 3a, b).
Effects of relative sea-level fluctuation on the depositional sequence cycles
Meter-scale depositional cycles dominate the shallow marine subtidal–intertidal carbonate successions in the study area and correspond to high-frequency depositional cycles, which are fundamental sequence stratigraphic units of carbonate platforms and basic elements in the interpretation of transgressive–regressive processes (Flügel 2004). The development of a series of microuplifts linked by intraplatform lows and microslopes in the study area could lead to the differentiation of sedimentary environments and provide the sedimentary framework of alternating reefs, sand shoals and swamps (Eugene et al. 2006; Gao and Fan 2013; Chen et al. 2018). Widespread platform margin reefs and shoals on microuplifts, and fine-grained facies in low areas between shoals developed during the Lower Ordovician period in the Tazhong Uplift (Gao and Fan 2014a; Zhu et al. 2017) (Figs. 2 and 9). The platform reef and sand shoal facies in this uplift are mostly intraclasts, bioclastic carbonate sand- to gravel-sized deposits composed of coarse-grained microfacies such as MF-1, MF-2, MF-3, MF-4, MF-8, MF-9, MF-10, MF-11, MF-13, MF-14 and MF-15, and constitute the coarsening-upward and shallowing-upward cycles of the HST of SQ1–SQ3 in the O1P and O1–2Y. The silt- to fine-grained low area (inter-shoals) mircofacies include MF-5, MF-6, MF-7, MF-12, MF-16 and MF-17 that constitutes the deepening-upward and fining-upward cycles of the TST of SQ1–SQ2 in the O1P and SQ1–SQ4 in the O1–2Y.
Regional tectonic movements and relative sea-level changes (frequent transgression–regression transitions) affect the depositional thickness and scale of reefs and shoals of the Lower Ordovician carbonate platform in the Tazhong area. The development of reef and shoal platform in this area corresponds to high-frequency cycles, and early and late period of a falling hemicycle (e.g., Gao et al. 2005; Gao and Tailiang 2015; Chen et al. 2018). As such, high-frequency sea-level fluctuations on carbonate platform presumably manifested as swift transgression and slow regression with multicyclic and high-frequency oscillations (Tan et al. 2009). In addition, each high-frequency sea-level oscillation and rapid transgression generated a low-energy environment with weak hydrodynamic conditions below the fair-weather wave base that resulted in the deposition of deepening-upward and fining-upward sequence cycles dominated by silt- to fine-grained inter-shoal mircofacies (Fig. 3a–c). Subsequently, during early regression or the early phase of sea-level decline and due to vertical stacking pattern sedimentation, underwater microuplift areas were subjected to strong moderate–high-energy conditions above the fair-weather wave base. This resulted in the progressive development of sand–gravel-sized intraclasts, bioclastic sediments on reef and shoal of platform margin. Consequently, the platform sand shoals’ sediments gradually grew upward until they reached sea level, resulting in coarsening-upward and shallowing-upward sequence cycles as shown in the HST of SQ1–SQ3 in the O1P and O1–2Y (Figs. 3a, b and 8a–e). Under continuous high-frequency relative sea-level fluctuations, multicyclic superimpositions of the vertical stacking patterns or vertical accretion sedimentation are generated on the individual platforms, resulting in multicyclic development of reef and sand shoal microfacies (Fig. 3a–c). On carbonate platforms with paleomicro-uplifts linked by intraplatform lows and microslopes, high-frequency relative sea-level variations associated with rapid transgressive phase and slow regression presumably favored the deposition of large-scale shallowing-upward and coarsening-upward vertical stacking patterns of meter-scale cycles (SQ1–SQ3) of reef and shoal facies. These large-scale facies stacking patterns probably developed in response to abundant growth of biogenic sediments under moderate–high hydrodynamic conditions that repeatedly rework and distributed the bioclastic debris across the platforms. These facies stacking patterns corresponds to high-frequency depositional cycles enhanced by the direction and strength of wave and tidal currents, which, in turn, controls the scale of the multicyclic vertical stacking patterns of the platform reef and shoal during relative sea-level drop (Sfidari et al. 2014; Gao and Tailiang 2015).
In summary, relatively low paleomicro-uplifts on carbonate platforms, tectonics and frequent relative sea-level fluctuation associated with swift transgressive phase and slow regression are the main factors influencing the development of the large-scale high-frequency reef and shoal facies stacking patterns across the carbonate platforms in the Tazhong Uplift.
The evolutionary patterns, characteristics and types of hydrocarbon reservoirs in reef and shoal complexes in the Tazhong area
The evolutionary patterns of hydrocarbon reservoirs in reef and shoal complexes
The multiphase episodes of intense tectonic activity in the Tazhong Uplift during the Caledonian and early–late Hercynian orogeny (Wu et al. 2012) could have exerted substantial influence on the deeply buried Lower Paleozoic carbonate rocks as they were penetrated by the intrusive diabases and volcanic eruptive edifice through geothermal/hydrothermal fluid inputs (Chen et al. 1997; Jiang et al. 2015; Guo et al. 2016; Ngia et al. 2019). As a result, conjugate fault systems and related fracture networks were created in the Cambrian to Lower Ordovician sedimentary packages particularly in the Tazhong area (Wu et al. 2012; Li et al. 2013a, b).
High-temperature oil field gases (CO2, HF and H2S) generated from relatively deep strata from hydrothermal decomposition of hydrocarbon (e.g., Li et al. 2014; Cai et al. 2014, 2015a, 2016; Jiang et al. 2015) diluted with Mg-rich saline formation waters forms the geothermal/hydrothermal fluids (Cai et al. 2008, 2009b; Yang et al. 2012; Jiang et al. 2015; Li and Cai 2017; Ngia et al. 2019). This thermochemical sulfate reduction derived high-temperature basinal dissolution fluids driven by convective–advective flow, migrate upward along structures like faults and related fracture networks, permeable horizons and brecciation that act as conduits for the upward and lateral migration from depth. As such, high-quality carbonate reservoirs are better developed along the faults and related fracture networks and permeable horizons that act as migration pathways for these hot active basinal fluids (TSR and geothermal/hydrothermal). However, the premise for fluid lateral migration is that the rocks with original relatively high primary porosity and permeability (i.e., macroscopic intercrystalline and intracrystalline pores in dolomites, bioclastic ooidal to peloidal packstone grainstones, intraclasts bioclastic oncoid packstone, brecciated bioclastic peloidal packstone, intraclasts bioclastic packstone, ooidal, cortoid grainstone, bioclastic peloidal grainstone, etc.) in high-energy reef shoal facies of the O1P and O1–2Y are the facies where secondary vuggy/moldic porosity would further develop during the shallow to deep burial diagenetic process. This interpretation is supported by the preferential occurrence of large secondary pore spaces, including dissolved vuggy/moldic pores, intercrystalline pores, solution-enlarged fractures, etc., with varying sizes (up to several centimeters in size and 12% porosity) in the carbonate microfacies in the study Lower Ordovician strata, which are somewhat close to the faults and related fractures.
Moreover, mesogenetic dissolution (shallow burial) has been proposed as a viable means of carbonates and sulfates dissolution, and thus significantly improved or rearranged the previous porosity (e.g., Mazzullo and Harris 1992; Li et al. 2014; Cai et al. 2014; Jiang et al. 2015). The mesogenetic fluids (carbonic acid, sulfuric acid, H2S, HF and organic acids) associated with kerogen maturation and early petroleum charge from deeply buried Cambrian source rocks (Jin et al. 2009; Cai et al. 2002, 2009a, b, 2015b, 2016) are formed during hydrocarbon generation. The mesogenetic dissolution fluids, geothermal/hydrothermal basinal fluids and TSR-related fluids (e.g., Mazzullo and Harris 1992; Worden and Smalley 1996; Cai et al. 2001, 2003, 2004, 2008, 2015a, b, 2016; Jin et al. 2009; Yang et al. 2012; Li et al. 2014; Jiang et al. 2015; Jia et al. 2015, 2016; Li and Cai 2017) generated at depth are responsible for the development of volumetrically significant macroscopic intercrystalline, vuggy/moldic and dissolved fracture porosity in most carbonate microfacies in the Lower Ordovician strata in the study area. Although secondary hydrocarbon reservoir spaces generated by mesogenetic dissolution fluids, geothermal/hydrothermal basinal fluids and TSR-related fluids mimic with those created by meteoric dissolution fluids, the secondary pore spaces generated by the former are relatively larger, deeply penetrating and possess relatively good reservoir qualities, thereby contributing significantly to the development of hydrocarbon reservoir spaces in shallow burial carbonates in the study area.
The petrophysical properties, characteristics and types of hydrocarbon reservoir in reef and shoal complexes in the Tazhong area
Carbonate platform reef and shoal complex are the main targets of hydrocarbon exploration in the Lower Paleozoic strata in central Tarim basin (Zhao et al. 2007; Li et al. 2012; Lan et al. 2013; Gao and Fan 2015; Fu et al. 2017). Hydrocarbon reservoirs in reef and shoal facies are widely developed in the Lower Ordovician carbonate platforms in the Tazhong Uplift in central Tarim basin (e.g., Zhao et al. 2007).
Petrophysical properties of the hydrocarbon reservoirs
Hydrocarbon reservoirs with high porosity and permeability are assembled in the Lower Ordovician high-energy reef and shoal facies in the O1P and O1–2Y. Three hundred and nineteen (350) samples of seventeen reef and shoal microfacies (MF-1 to MF-17) were obtained from eight wells in the carbonate successions of the O1P and O1–2Y in the Tazhong Uplift and analyzed for their petrophysical properties (Table 2).
The results of the average porosity and permeability of the seventeen microfacies (MF-1 to MF-17) reservoirs in the Penglaiba Formation are: MF-1 (4.95%) and (0.428 × 10−3 mD), MF-2 (4.15%) and (0.425 × 10−3 mD), MF-3 (3.44%) and (0.582 × 10−3 mD), MF-4 (2.03%) and (0.119 × 10−3 mD), MF-5 (5.97%) and (1.614 × 10−3 mD), MF-6 (1.12%) and (0.124 × 10−3 mD), MF-7 (5.97%) and (0.697 × 10−3 mD), MF-8 (3.56%) and (0.769 × 10−3 mD), MF-9 (1.69%) and (0.427 × 10−3 mD), MF-10 (5.86%) and (0.689 × 10−3 mD), MF-11 (5.72%) and (0.489 × 10−3 mD), MF-12 (1.28%) and (0.489 × 10−3 mD), MF-13 (1.48%) and (0.175 × 10−3mD), MF-14 (3.46%) and (0.560 × 10−3mD), MF-15 (2.03%) and (0.287 × 10−3 mD), MF-16 (3.74%) and (0.902 × 10−3 mD), and MF-17 (1.51%) and (0.306 × 10−3 mD) (Fig. 10a–h).
On the other hand, the values of the average porosity and permeability of the seventeen microfacies (MF-1 to MF-17) reservoirs in the Yingshan Formation are slightly higher than those of their counterpart in the Penglaiba Formation, and these values are: MF-1 (3.66%) and (0.554 × 10−3 mD), MF-2 (4.24%) and (0.527 × 10−3 mD), MF-3 (4.26%) and (0.478 × 10−3 mD), MF-4 (3.02%) and (0.377 × 10−3 mD), MF-5 (2.84%) and (0.683 × 10−3 mD), MF-6 (1.18%) and (0.277 × 10−3 mD), MF-7 (1.86%) and (0.487 × 10−3 mD), MF-8 (3.28%) and (1.128 × 10−3 mD), MF-9 (3.52%) and (0.466 × 10−3 mD), MF-10 (6.53%) and (1.118 × 10−3 mD), MF-11 (4.53%) and (0.842 × 10−3 mD), MF-12 (1.79%) and (0.692 × 10−3 mD), MF-13 (2.4%) and (0.514 × 10−3 mD), MF-14 (3.33%) and (0.757 × 10−3 mD), MF-15 (2.39%) and (0.742 × 10−3 mD), MF-16 (3.79%) and (0.691 × 10−3 mD), and MF-17 (1.64%) and (0.331 × 10−3 mD) (Fig. 10a–h). There exists a weak positive relationship in the cross-plot of the average porosity and permeability of the seventeen microfacies (MF-1 to MF-17) samples from the Penglaiba and Yingshan Formations. This relationship probably reflects similar evolutionary patterns and/or development conditions for the hydrocarbon reservoirs (Fig. 10i).
Hydrocarbon reservoir pore space types and characteristics
The hydrocarbon reservoir spaces in the high-energy reef and shoal facies of the Lower Ordovician O1P and O1–2Y were identified and analyzed by the use of core logs and apoxy pore-cast thin-section data. The primary porosity of these high-energy reef and shoal carbonate facies was extensively reduced by the effect of compaction and cementation during burial. However, the pores that contained hydrocarbon within them at the early stage of the rock's history were presumably preserved, implying that most of the pore space types in this study are of secondary origin (Figs. 6a–c, h and 7a–i).
The results of the analyzes of the high-energy reef and shoal carbonate reservoir spaces showed seven types of dissolved pore spaces, including pores along fractures, vesicular pores, tabular pores, intragranular solution pores, intergranular pores, vuggy/moldic pores and mottled pores (Figs. 6a–c, h and 7a–i). Intragranular solution pores, intergranular pores, tabular pores and vuggy/moldic pores are the most common reservoir pore spaces with pore sizes ranging from 0.05 to 10 mm (Figs. 6b, h and 7b, e, h, i). Although some pore spaces are commonly filled with calcite spar, most of the effective reservoir spaces are commonly preserved.
Three types of fractures/fissures were observed in the high-energy reef and shoal facies, including solution-enlarged fractures, dissolved fissures/stylolites and low–medium–high-angle irregular horizontal fractures (Figs. 4g, 5a–f and 7c, d). The fracture networks and dissolved fissures/stylolites are the main reservoir spaces observed on most cores and thin sections. They usually have low- to medium–high-angle intersections and constitute good reservoir spaces and permeating channels. Dissolved fissures/stylolites appeared as serrated, curved or zigzag-shaped, mesh or reticular pores on the cores and thin sections, and are somewhat filled with calcite spar cements.
A few karst caves have circular shapes in most sand shoal facies, with others appearing as honeycombs and elongated-shaped strips along laminae and sometimes along fractures. Though calcite spar cements and organic matter partially or completely occludes the karst caves (Figs.4f and 7f), a considerable amount of effective reservoir spaces are present.
Types of hydrocarbon reservoirs
Three main types of hydrocarbon reservoirs were recognized in the high-energy reef and shoal facies of the O1P and O1–2Y and classed as follows:
Type 1 reservoirs
Type 1 reservoirs are associated with synsedimentary high-energy reef and sand shoal facies. These reservoir spaces are mainly composed of microporosity and include acicular intragranular pores (0.05–3 mm) within grains and tiny vesicular intercrystalline pores (0.001–2 mm), and pores between calcite cement crystals. They have been extensively reduced by the effect of compaction and cementation during burial diagenesis. The reservoirs are mainly distributed at the vicinity of the third-order sequence boundaries and bedding planes within the Penglaiba and Yingshan Formations, and their development is closely associated with the primary sedimentary facies and the sequence boundary (Fig. 3a, b).
Type 2 reservoirs
Type 2 reservoirs are developed by burial dissolution and tectonic activity. The dissolved vuggy/moldic pore spaces, solution-enlarged fractures/stylolites and tectonic fractures are the main reservoir spaces (Figs. 4g, 5a–f, 6a, b, c, h and 7a–i). Core observation revealed that some vuggy/moldic pores and fracture reservoirs are filled with geothermal/hydrothermal minerals including lead–zinc mineralization, quartz and saddle dolomite, indicating that type 2 reservoirs were modified by multiphase tectonic activity (Zhong et al. 2010; Wu et al. 2012; Li et al. 2013a, b), and shallow to deep burial dissolution by mesogenetic fluids, geothermal/hydrothermal basinal fluids and TSR-related fluids (e.g., Mazzullo and Harris 1992; Worden and Smalley 1996; Cai et al. 2001, 2015a; Jin et al. 2009; Yang et al. 2012; Ehrenberg et al. 2012; Li et al. 2014; Jia et al. 2015; Zhu et al. 2017). The type 2 reservoirs are of secondary origin and constitute the main hydrocarbon reservoirs in the study area.
Type 3 reservoirs
Type 3 reservoirs are hypogenic–epigenetic karst reservoirs. These types of reservoirs are usually associated with karst breccias on the platform margin/marginal slopes and are mainly developed toward the topmost part of the SQ2 in the O1P and below the RUS2 unconformity surface (Fig. 3a, b). They are formed as a result of the high susceptible of the reef and shoal facies to widespread denudation due to a long-term exposure caused by relative sea-level drop (Lin et al. 2012), tectonic activity and dissolution (meteoric and mesogenetic) (Figs. 4f and 7f) (Gong and Liu 2003; Baryakh and Fedoseev 2011; Yang et al. 2011; Ehrenberg et al. 2012; Zhu et al. 2017). These aforementioned factors favored the development of hypogenic–epigenetic karst reservoirs in near-surface shallow burial settings. The type 3 reservoirs are of secondary origin and are the second major hydrocarbon reservoirs in the study area. Hence, the extensive uplift of Tarim block during the Late Permian (Li et al. 2008; Wu et al. 2012; Li et al. 2013a, b) could have been the main cause of the significant exposure to intense denudation and dissolution/karstification of the platform reef and shoal facies in the Tazhong Uplift. This interpretation is supported by the abundant distribution of hydrocarbon reservoirs in the vicinity of unconformities, third-order sequence boundaries, bedding planes, faults and related fracture networks.
In summary, the porosity and permeability of the coarse-grained microfacies in the HST of the third-order sequences (SQ1–SQ3) correlates well with the regression peaks in the O1P and O1–2Y. Moreover, the generation of characteristic hydrocarbon reservoirs in the shallow to deeply buried reef and shoal carbonate facies in the study area by high-temperature active basinal dissolution fluids (mesogenetic fluids, geothermal/hydrothermal fluids and TSR-related fluids) is aided by faults and related fracture networks, stylolites, sequence boundary and other permeable horizons, which act as lateral and vertical migration pathways for these basinal dissolution fluids. The characteristic hydrocarbon reservoirs generated by these basinal dissolution fluids constitute relatively moderate–high-quality hydrocarbon reservoirs in the Lower Ordovician strata and are somewhat the potential reservoirs for hydrocarbon exploration in the Tazhong Uplift in central Tarim basin.
Based on detailed petrographic analysis of thin sections, cores and well logging data of the Lower Ordovician carbonate successions in the Tazhong Uplift in central Tarim basin, the following conclusions are drawn:
The analyses of hydrocarbon reservoirs in the high-frequency reef and shoal facies of the Lower Ordovician carbonate successions in the O1P and O1–2Y in Tazhong Uplift, central Tarim basin showed seven types of dissolved pore spaces, three types of fractures and karst caves. These hydrocarbon reservoirs are classified into three main types: type 1 associated with synsedimentary facies, type 2 developed by hot active basinal dissolution fluids (mesogenetic fluids, geothermal/hydrothermal fluids and TSR-related fluids) and tectonic activity, and type 3 are hypogenic–epigenetic karst reservoirs generated by dissolution fluids (meteoric and mesogenetic). The characteristic hydrocarbon reservoirs generated by these basinal dissolution fluids constitute relatively moderate–high-quality hydrocarbon reservoirs in the studied Lower Ordovician strata. Porosity and permeability development in the reef and shoal facies of the highstand system tracts (HST) of the third-order sequence cycles (SQ1–SQ3) correlates well with regression peaks in O1P and O1–2Y.
The relatively low paleomicro-uplifts linked by intraplatform lows and microslopes, tectonics, and frequent relative sea-level fluctuation associated with rapid transgression and slow regression presumably favored the sedimentation of the large-scale cyclic vertical stack patterns of shallowing-upward reef and shoal facies across the carbonate platforms.
Six third-order depositional sequences (SQ1–SQ4) were identified in this study. Sequence SQ1 and SQ2 were identified in the Penglaiba Formation, and SQ1–SQ4 were recognized in the Yingshan Formation. These third-order depositional sequences are composed of asymmetrical and minor symmetrical sequence cycles, which form repeated shallowing-upward and coarsening-upward cycles. These sequence cycles reflect a short transgrassive phase and prolong marine regression due to upward increased in hydrodynamic energy from the TST to the HST.
Seventeen microfacies (MF-1 to MF-17) were identified within the Lower Ordovician carbonate successions of the Tazhong Uplift. These microfacies were distinguished based on their textures (grain sizes, shape and sorting), fossil contents and matrix contents. Six microfacies associations (MFA-1 to MFA-6) were identified based on their vertical stacking patterns and position in the depositional sequence. MFA-1 to MFA-6 reflect a series of correlative depositional environments. Each type of microfacies in the association reflects a specific depositional environment under particular hydrodynamic conditions. These microfacies associations appear as shallowing-upward and coarsening-upward third-order sequence cycles that represent sedimentary facies such as subtidal–lagoon and tidal flat facies, silt to sand gravel shoal facies, and reef and sand shoal facies deposited in platform interior (restricted subtidal–intertidal platform, intraplatform shoal and open platform) and platform margin, respectively.
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This study was funded by the National Natural Science Foundation Project of China (Grant Nos. 41372126 and 41772103), and National Science and Technology Major Project of China (Grant No. 2016ZX05007-002). We appreciate the constructive suggestions of Dr Deng Qingjie and Dr Sun Chun Yan during the preparation of this manuscript. The authors greatly appreciate the valuable comments and suggestions made by the Editor and reviewers that has helped to restructured this manuscript.
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Ngia, N.R., Hu, M. & Gao, D. Hydrocarbon reservoir development in reef and shoal complexes of the Lower Ordovician carbonate successions in the Tazhong Uplift in central Tarim basin, NW China: constraints from microfacies characteristics and sequence stratigraphy. J Petrol Explor Prod Technol 10, 2693–2720 (2020). https://doi.org/10.1007/s13202-020-00936-y
- Tazhong Uplift
- Tarim basin
- Lower Ordovician
- Vug-fractured karstic reservoirs