Determination of Formation Time of Calcareous Cements in Marine Sandstone and Their Influence on Hydrocarbon Accumulation: A Case Study of the Carboniferous Donghe Sandstone in the Hadexun Oilfield, Tarim Basin

Based on core observations, the microheterogeneity, diagenetic features, diagenetic mineral compositions, and stable isotopes of cements in the calcareous interlayers in the Donghe sandstone were studied by polarizing microscopy, cathodoluminescence microscopy, X-ray di ﬀ ractometry, isotope ratio mass spectrometry, and other techniques. By determining the proportions of cements of two phases by a statistical method and their clumped isotope values by an end-member method, the multiphase calcareous cementation was shown to be the major contributor to densi ﬁ cation. Cluster isotopes revealed that the average formation temperatures of calcareous cements in phases II and III of cementation were 45 – 50 ° C and 80 – 90 ° C, indicating that they were products of the A and B phases during early diagenesis, respectively. According to the homogenization temperatures of coeval salt-water inclusions associated with hydrocarbon inclusions, which range from 100 ° C to 130 ° C, basin modeling revealed that the basin underwent mainly one stage of hydrocarbon charging during 8 – 5 Ma in the Miocene period. The cements of the two phases in the oil-free calcareous interlayers in the Donghe sandstone, which are the main controlling factor of the oil-water distribution in the reservoir at present, formed much earlier than the oil ﬁ lling in the oil-bearing sandstone.


Introduction
In the past 30 years, several large oil and gas fields (such as the Donghetang Oilfield, Tazhong 4 Oilfield, and Hadexun Oilfield) have been discovered successively in the Carboniferous Donghe sandstone, which has become an important high-yielding formation in the Tarim Basin [1,2]. The Hadexun Oilfield is the first marine sandstone oilfield with reserves of more than 700 million barrels of oil in place (MBOIP) discovered in the Tarim Basin. Its main production layers include the Carboniferous marine Donghe sandstone and thin sandstone layers in the middle mudstone sections, which are hydrodynamic reservoirs rather than gravity reservoirs [3]. Several previous studies have been carried out on the Donghe sandstone, including studies of its sedimentation and provenance, reservoir characteristics, oil and gas source, and accumulation process, and important understandings were achieved [4][5][6][7][8][9][10][11]. As the oil field entered the middlelate development stage of high water cut (more than 80%), its production entered a declining stage. Therefore, the formation and spatial distribution of interlayers in the sandstone are of great significance to the design and adjustment of the development plan of the oil field [12].
Some important progress in the study of the interlayers in the Donghe sandstone has been made. There are three types of septums in the Donghe sandstone, namely, the calcareous septum, the argillaceous carbonate septum, and the argillaceous septum, which are sedimentary and diagenetic [1,[13][14][15]. These septums have small thickness, ranging narrowly from 0.02 m to 0.6 m, with an average of about 0.2 m, and occur mainly in masses, spots, beddings, and quasilamellae or lamellae. The calcareous cementation in calcareous sandstone was formed by two to four phases, which separated the upper and lower fluids and controlled the change of sea level [8,12,16,17]. As the diagenetic evolution of a sandstone reservoir is a very complex physicochemical process controlled by numerous factors, including sedimentation, structural evolution, mineral composition, burial, heat flow properties, fluid migration, and sequence development, it is difficult to determine the formation temperature and timing of cements accurately [18,19].
Clumped isotope analysis of carbonates, as an innovative paleothermometer, can directly provide formation temperature information of a mineral, with no assumptions about the isotopic values of paleofluids [20,21]. At present, its application has been expanded successfully to include analyses of reservoir diagenetic evolution, paleoclimate, paleoelevation reconstruction, structural evolution analysis, genetic analysis of natural gas, and paleothermal history reconstruction, and a series of new understandings has been achieved [22][23][24][25][26][27]. Because the original clumped isotopes within the lattice of a carbonate mineral are retained well during the process of acid digestion, mass-47 CO 2 ( 13 C 18 O 16 O (Δ47)) can be used as an approximation of isotopologue 13 C 18 O 16 O 2− in carbonate rocks, and the abundance of mass-47 CO 2 can represent the abundance of 13 C- 18 O bonds in a carbonate mineral [28]. The carbonate cluster isotope thermometer is based on the exchange reaction between 13 C and 18 O, which depends mainly on temperature [20,21]. In recent years, many scholars have found that the carbonate clumped isotope information would change with increasing formation temperature under certain conditions; however, it can be predicted quantitatively by corresponding models [29,30].
This study is aimed at examining the diagenetic characteristics, mineral composition, and cementation phase of calcareous interlayers in the Donghe sandstone in the Hadexun Oilfield based on microscopic analysis of casting thin sections, cathodoluminescence, and X-ray diffraction (XRD) to clarify the distribution of calcareous cements at the scale of the core and also to accurately define the formation time of calcareous cements in interlayers in the Donghe sandstone using clumped isotope analyses and basin modeling to evaluate their influence on hydrocarbon accumulation based on the burial history and thermal history of the basin.

Geological Setting
The Hadexun Oilfield is geographically located in the floodplain on the south bank of the Tarim River in Shaya County, Xinjiang Uygur Autonomous Region, and structurally located in the Hudexun structural belt in the northern Manjar sag. The Hadexun structural belt is connected with the Lunnan low bulge on the Tabei Uplift to the north, which is part of the nose structural belt as a southward extension of the Lunnan low bulge and is considered to be a typical uplift within a depression ( Figure 1). It is a Carboniferous low-amplitude anticline, developed from the late Early Paleozoic-early Late Paleozoic uplift, extending from NE to SW. The Carboniferous Donghe sandstone in the Hadexun Oilfield is in an unconformity relation with the overlying dark-red breccia and the underlying Silurian tight sandstone, and the reservoir is considered a large-scale stratigraphicstructural reservoir [2,3].
The Donghe sandstone, widely distributed within the basin, is a set of sandstones or sandy conglomerates at the bottom of a transgressive system deposited on a landform that was low in the west and high in the east during the Late Devonian to Early Carboniferous. Generally, it consists of a set of thick sandstones characterized by distinct lithologicelectrical properties, good spatial continuity, relatively low macroheterogeneity, and high microheterogeneity, indicating that it is a typical set of barrier-free, wave-controlled, nearshore sandy deposits. The absence of an Upper Paleozoic structural layer resulted in the Devonian strata overlapping the Silurian strata directly. Influenced by tectonic inversion starting in the Late Himalayan period, the strata were higher and thicker in the south than in the north. The Mesozoic-Cenozoic structural layer is thinner and higher in the south than in the north [2].
Reservoirs in the oil field include Carboniferous marine Donghe sandstone reservoirs and thin sandstone reservoirs in the middle mudstone. The main production layer is the Donghe sandstone at the bottom of the Carboniferous. The Donghe sandstone reservoir is a stratigraphic-structural composite reservoir with a unified temperature-pressure system and tilted oil-water interface. It has a characteristic ultradeep burial depth (more than 5,000 m), a low structural amplitude (less than 34 m), a thin and variable reservoir thickness (0-29 m), a large oil-bearing area (superimposed area is about 200 km 2 ), a tilted oil-water interface (height difference is greater than 90 m), significantly zonal oil properties, and low reserve abundance (less than 30 × 10 4 t/km 2 in most oil-bearing areas). One hypothesis is that the crude oil originated from paleoreservoirs in the north and that the unconformity between the Carboniferous and Silurian acted as the migration passage [10]. Another is that the oil was probably sourced from the Lower Ordovician through vertical migration along faults [7].

Sampling and Analytical Analysis
The Donghe sandstone in the Midwestern part of the basin was deposited in the Late Devonian period, but the sandstone in the eastern and northern parts of the basin were deposited in the Early Carboniferous period. The Donghe sandstone is distributed widely in the Hadexun Oilfield with a thickness ranging from 6 m to 29 m. Samples collected for studying the heterogeneity and clumped isotopes of calcareous interlayers in the Donghe sandstone in Well HD17 in the north and Well HD4 in the south of the Hadexun Oilfield are shown in Figure 2.
The Leica DM 4500P polarizing microscope (Leica, Co., Germany) was used for traditional thin section observation to analyze the composition, texture, and structure of rock and identify rock types, and the CL8200 MK5-1 cathodoluminescence system (CITL Co., United Kingdom), with a working voltage of 15 kV and beam current of 320 μA, was 2 Geofluids used for cathodoluminescence analysis. BasinMod 1D (Platte River Associates, USA) was used for basin modeling, where lithology, stratification, terrestrial heat flow, burial depth, and other geological parameters were based on well logging and regional data of the oil field. Whole-rock analysis and clay mineral composition identification were conducted using a TTR diffractometer (Rigaku Electric Corporation, Japan), and the testing conditions were referred from industrial standard No. SY/T 5163-2010. In the whole-rock mineral analysis, 300-mesh-powdered samples were tested after tableting, referring to the K value of the international standard sample, and mass percentages of minerals were calculated by analysis software. The steps required to determine the clay mineral compositions were as follows: (1) extract clay minerals by the suspension method; (2) air-dry oriented thin sections at room temperature and directly test the natural thin section; (3) retest after saturating with glycol at 60°C for 8 h; (4) test after heating at 550°C for 2.5 h; and (5) calculate the percent content of clay minerals by analysis software. Clumped isotope analyses were performed using the Thermo 253 IRMS gas source isotope ratio mass spectrometer (Thermo Fisher Scientific, USA) in the California Institute of Technology by the following steps. (1) Sample preparation: the crushed calcareous sandstone sample was immersed in 3% hydrogen peroxide for 2 h to ensure removal of organic matter and then dried in an oven at 40°C after Oil field

Manjar Depression
Research area L u n n a n L o w S a li e n c e  3 Geofluids washing 3-4 times with distilled water. (2) Preparation and purification of CO 2 : the 15-20 mg powdered sample was digested in 103% phosphoric acid at 90°C under vacuum for 20 min in an acid bottle after being conveyed by the automatic sampler when started normally. The generated CO 2 was purified on a vacuum line by passing it through dry ice/ethyl alcohol, liquid nitrogen, and a gas chromatography column (GC) to remove water and other pollutants automatically. (3) Measurement of Δ47: the purified CO 2 gas was passed through the Thermo 253 IRMS gas source isotope ratio mass spectrometer, through which signals of 44-49 CO 2 were measured simultaneously. In each measurement, the sample gas and the working gas were tested 7 times alternately, and δ 13 C, δ 18 O, and Δ47 were measured simultaneously. (4) Correction of Δ47 values: an absolute reference frame (ARF), which standardizes interlaboratory data of clumped isotopes based on theoretical predictions of the abundances of clumped isotopes in gaseous CO 2 at thermodynamic equilibrium, was established [31]. Measurements of clumped isotopes of standard gaseous CO 2 (break seal) at a reaction temperature of 25-1000°C were used for determining slope and intercept by using Package R [32], and empirical transfer functions were constructed to convert the raw data measured by the mass spectrometer to the absolute reference frame. In addition, the reaction temperature of a sample of carbonate rock should be 25°C; however, 90°C is usually used to increase the reaction rate and thus shorten the reaction time. A high acid solution temperature would result in an isotope fractionation effect; thus, the value of Δ47 at 25°C was necessarily modified by adding 0.092‰ [29]. (5) Clumped isotope thermometer: empirical functions applicable to all carbonates at 25-350°C were used to transfer the corrected value of Δ47 to the clumped isotope temperatures using the following equation: Δ47, ARF = 0:0428 × 10 6 /T 2 + 0:1174 [33].

Petrological Features and Mineral Composition of
Calcareous Sandstone. The content of carbonate cements in the Donghe sandstone varies greatly. As shown in Figure 3, the content approaches zero in sandstone in which the hydrocarbon emplacement occurred, suggesting an inhibitory effect of the hydrocarbon emplacement to carbonate cementation. The results of the mineral composition analysis, which were precisely consistent with those of the   Geofluids microscopic thin section analysis, indicated that the calcareous cements are dominated by calcite, which has contents as high as 26.9-73.5% and attains a content of 94.8% in the limestone samples, as listed in Table 1. In Well HD4 in the south, the sandstones developed in calcareous interlayers within the Donghe sandstone are predominantly lithic quartz sandstone or feldspathic lithic sandstone, with medium-fine granular or inequigranular and subrounded clastics, the long axes of which are slightly directional. The clastics are mainly quartz, followed by lithic fragments and feldspar, and the reservoir cements have relatively high contents of calcite, which occurs as clots or poikilitic cements. The pores are mainly intergranular pores, and according to the physical properties, the sandstones are classified as having low porosity and low permeability.
In Well HD17, the sandstones are dominantly lithic quartz sandstone, with fine to very fine, subangular to subrounded clastics that are arranged with slight directionality. As shown in Figure 4, the clastics are mainly quartz, followed by lithic fragments and feldspar, and the reservoir cements have a relatively high content of calcite, which occurs as poikilitic cement, and rare ankerite. The pores are mainly intergranular pores, and the sandstones are low-porosity and low-permeability sandstones. The differences of clastic content and grain size between the northern and southern Hadexun area indicate the possibility of different provenances in the two wells.

Cathodoluminescence Characteristics of Calcareous
Sandstone. In this study, three phases of cement were identified by cathodoluminescence and electron microprobe analyses. Phase I carbonate cements consist of nonluminescent Fe-free and Mg-free calcites, fill space between clastic particles, often occur as crystal stocks or lamellar crystals, and are spatially distributed between particles with loose or no contact. This indicates that the cements formed in the exposure or shallow burial stage (early diagenetic phase A), when the compaction of particles was very weak. When exposed to cathodoluminescence for a properly increased period, the cements fluoresce light orange-yellow (Figures 5(a) and 5(b)), which appears only in some samples with low cement content.
The main compositions of carbonate cements of phases II and III are calcites, which fluoresce orange-red or orangeyellow. Phase II carbonate cements surround quartz grains and show orange-red cathodoluminescence. Phase III carbonate cements grew in the middle of pores, which are the principal locale for the cement, and show bright-orange cath-  5 Geofluids location of phase I cements, which formed mainly between particles with spot-line contacts, indicating that they formed in the shallow burial stage (early diagenetic phase B).

Oxygen and Carbon Isotopes and Δ47 in Calcareous
Cement. Carbon and oxygen isotopic analysis of a reservoir is an effective method to study the origin of carbonate cements. This study analyzed the carbon and oxygen isotope data of six samples of carbonate cement in the work area. The isotope ratios were reported relative to the Pee Dee Belemnite (PDB) standard, and the accuracy of the isotope measurement was less than 0.03%. In the Donghe sandstone in Well HD4 in the southern part of the Hadexun area, the average δ 13 C PDB values of carbonate cements from five measurements ranged from −4.4‰ to −3.1‰, and the average δ 18 O PDB values ranged between −10.6‰ and−6.9‰. In the Donghe sandstone in Well HD17 in the northern part of the area, the average δ 13 C PDB values of carbonate cements from five measurements ranged from −7.8‰ to −4.5‰, and the average δ 18 O PDB values ranged between −9.8‰ and 6.9‰ ( Table 2). The measurements showed that the apparent Δ47 values of the calcareous cements range from 0.545 to 0.590 in Well HD17 in the northern part of the Hadexun area and between 0.546 and 0.572 in Well HD4 in the southern part of the Hadexun area.

Oil Heterogeneity of Donghe Sandstone and Its Control Factors.
A comparison between the mineral compositions and diagenetic characteristics of oil-bearing and oil-free sandstones suggests that calcareous cementation is the major cause of the porosity reduction in the sandstone and that it also results in the oil-bearing heterogeneity in the generated tight sandstones (Figure 3). In the sandstones in the Hadexun Oilfield without calcareous cement, pores in the reservoir rocks are mainly intergranular dissolution pores. The main reservoirs have medium porosity, ranging between 12.5% and 20%, with an average of 13.8%, and medium-high permeability, ranging from 50 to 1000 × 10 −3 μm 2 , with an average of 222 × 10 −3 μm 2 . The calcareous interlayers in the Donghe sandstone in the Hadexun Oilfield are higher than those in the Donghetang Oilfield, which is located in the northwest with calcite content averaging 10% [8]. The porosity of calcareous sandstone ranges between 5.1% and 7.3%, with an average of 6%.
The carbon isotope values of the calcareous cements analyzed are within the range of those of carbonates of freshwater origin, which range from −5‰ to −1‰. The previous carbon isotope analyses of calcareous cements in the Donghe sandstone also indicated a freshwater origin and a relation to organic carbon dissolution in only a few samples [34,35]. According to the carbon and oxygen isotope chart shown in Figure 6, only two cements of the Donghe sandstone in the Hadexun area lie in the freshwater calcite area, and the rest are within the diagenetic calcite area [14,36]. However, this result is not consistent with previous results showing that the calcareous cements are of epigenetic and syngenetic freshwater origin, which was confirmed by petrologic features and microscopic analysis of mineral cements [12,14,16,17]. The Z value, which can be used to determine the genetic types of calcareous cements, is calculated by the empirical formula Z = 2:048 × ðδ 13 C PDB + 50Þ + 0:498 × ðδ 18 O PDB + 50Þ. When the Z value is greater than 120, it indicates marine cements; when the value is less than 120, it indicates freshwater cements [37]. According to calculations using the carbon and oxygen isotope results of the analyzed cements of the Hedong sandstone in the Hadexun area (Table 3), the Z values of calcareous cements in both Well HD4 and Well HD17 are less than 120, indicating that the cements are freshwater carbonate cements influenced by meteoric freshwater.
A previous study of the Donghe sandstone in adjacent areas reported that carbonate cements were one of the main factors controlling hydrocarbon accumulation and that the reservoir quality often depended on their content and distribution [1]. In recent years, some scholars have suggested that the sequence stratigraphy played a controlling role in the diagenetic process, that carbonate cementation tended to occur in the early development stage of the transgressive system tract and high-stand system tract, and that cementation did not occur easily in the late development stage of the low-stand system tract and the high-stand system tract [12,16,17]. The role of depositional facies and sequence stratigraphy impacts the diagenesis and the heterogeneity of sandstone reservoirs [18,19]. Horizontally, the physical properties of the Donghe sandstone reservoirs are relatively poor near the pinch-out boundary but significantly better far from it, showing a variation trend as a whole that is favorable in the south but slightly poor in the north [38].

Diagenetic Stage and Genesis of Calcareous Sandstone.
Some scholars have reported that the carbonate cements are  7 Geofluids composed mainly of massive and crystal-stock calcites formed at the early stage of diagenesis, which account for 94% of the carbonate cements. The calcareous interlayers are mainly dependent on the carbonate cementation that occurred at the early stage of diagenesis, and the phase I carbonate cements are similar to calcite cements precipitated from seawater in shallow oxidizing conditions, where the calcium is sourced from the sea [8]. Other scholars have analyzed the proportions of carbonate cements of different phases and concluded that the carbonate cements are precisely dominated by phase I calcites, which account for more than 83% of the total carbonate cements. However, their formation environment was reported as a meteoric freshwater environment in the hypergene condition [16,17]. Nevertheless, phase II and III carbonate cements were found in most of the samples used in this experiment. It was reported that the nonluminous carbonate of phase I would have dissolved in the subsequent diagenetic stage, which provided material for the phase II and III carbonate cements. A comparison of major elements (iron and manganese) of cements of the various phases identified microscopically using the electron microprobe demonstrated significantly higher contents of Mn in the phase II and III cements. The average contents of Mn and Fe are 2142 × 10 −6 and 414 × 10 −6 [8,10]. The sig-nificant difference of Fe and Mn contents in the carbonate cements of the different phases indicates that they formed in different diagenetic stages, which confirms the cement phases identified microscopically in this experiment.
Previous studies also identified phase IV carbonate cements, which are composed mainly of ferruginous calcite and ferruginous dolomite, show nonluminescence or dark orange-red cathodoluminescence, and are typically characterized by replacement of feldspar grains [8,13]. Complete replacement of feldspar grains is observed, indicating that the phase IV carbonate cements formed in the middle burial stage (middle diagenetic phase A) [8,10]. However, no obvious phase IV carbonate cement was observed in this experiment, and minor dolomite was detected only in the samples at 5230.13 m in Well HD17 (Table 1).
The diagenetic process can be described as follows. With an increase of burial depth, the space between grains was reduced under the influence of compaction, resulting in a change of grain contacts from point contacts to line contacts. Thus, a semiclosed or nearly closed diagenetic environment formed. Communication with external fluids was limited, and the reducibility of the diagenetic environment was enhanced subsequently. As a result, the phase II and III carbonate cements have higher contents of iron and manganese     Additionally, how to determine the exact formation time of calcareous cement has become a great problem in diagenetic research. The abundance of isotopologue 13 C 18 O 16 O (Δ47) in carbonates is sensitive to the growth temperature of the minerals and independent of the fluids (waters) from which the carbonates grew. The Δ47 value can be calculated from equation (1) below, where R47 is the abundance ratio of mass 47 relative to mass 44 of CO 2 in the sample and R * 47 is the corresponding ratio of mass 47 relative to mass 44 that would occur in the sample if it had a stochastic distribution [20,21]. It is worth pointing out that the measured apparent Δ47 values of the calcareous cements are essentially average values of cements of multiple phases.
In this experiment, calcareous cements were detected in the calcareous interlayers. Statistical analysis of the calcareous cements of the different phases detected from cathodoluminescence images was performed using Avzaon, and the result showed that the relative contents of carbonate cements of different phases varied significantly among different samples ( Table 2). This is possibly a result of the mixing of meteoric fresh water and seawater in pores in the sandstones of the wave-controlled, delta-shore sedimentary system and subsequent diagenetic differences. According to the proportions of cements of different phases (Table 2), the true Δ47 values of each phase can be calculated by solving equations in the multiple variables. Considering the dominance of the two phases of cements, the Δ47 values of the phase II and III calcareous cements in calcareous interlayers of the Donghe sandstone were represented by Δ47 II and Δ47 III , and their proportions in sample i were defined as a i % and b i %, respectively. To calculate the unknown Δ47 II and Δ47 III , the number of linear equations required has to be greater than or equal (equation (2)) to the number of phases of cements (i ≥ 2 in this case). According to Tables 2 and 3, the calculated values of Δ47 II and Δ47 III are 0.610-0.620 and 0.492-0.520, respectively.
In fact, the determination of the dependence between Δ47 and temperature is influenced by a variety of factors, including the settling rate of carbonates, the pH value of geological fluids, and the ionic strength [42]. Fortunately, in recent years, a large amount of research has focused on the equations between Δ47 and temperature (T), and attempts have been made to reduce the uncertainties related to different dissolution rates of carbonates, the variety of carbonate rocks, and different laboratory measurements through standardization [43]. The apparent formation temperatures corresponding to the apparent Δ47 values of the calcareous interlayers in Well HD4 in the southern area range from 53.7 to 71.6°C, and those in Well HD17 in the northern area range from 64.0 to 71°C. The formation temperatures calculated by the end-member method are 41.0-45.1°C and 89.2-94°C, respectively. These were calculated according to the internationally published calibration equation of Δ47 and temperature (Figure 7). It should be noted that the temperatures calculated from the previous calibration curves of Δ47 and temperature are 45-50°C and 90-100°C, respectively [28,[44][45][46][47][48].

Diagenetic Process of Calcareous Cementation in
Calcareous Sandstone. The calcareous cements were apparently identified as the products of the early diagenetic period in this paper, but they actually should be classified as the products of early diagenetic stage A and early diagenetic stage B, according to formation temperature and diagenetic stage division [49,50]. According to the burial and thermal histories, the formation temperature of the phase II carbonate cements indicates that they developed in the Middle Permian period, and their formation is speculated to be related to the shallow burial and tectonic uplift during the Hercynian period. The phase III carbonate cements are suggested to have developed in the Early Neogene period, which is speculatively related to rapid burial. The specific diagenetic process can be described as follows. With increase of burial depth, the space between particles was reduced by compaction, resulting in a change of grain contacts from point contacts to line contacts. Thus, a semiclosed or nearly closed diagenetic environment was formed. The limited communication with external fluids enhanced the reducibility of the subsequent diagenetic environment. As a result, the phase III carbonate cements, which show a relatively bright color under the cathodoluminescence microscope, were developed [8]. 10 Geofluids The analyses of the formation temperatures calculated from Δ47 of the cements in the two wells in the Hadexun Oilfield indicate slightly higher formation temperature in Well HD17 in the northern region than in Well HD4 in the south, indicating that the time of diagenesis was earlier in Well HD4. The consistency of the highest formation temperature in these two wells reflects the same diagenetic process experienced by the Donghe sandstones in the early burial stage at the southern and northern parts of the Hadexun Oilfield. In fact, unconformities are developed at the top and bottom of the Donghe sandstones in the south and the north, and the overlying and underlying strata also effectively support the conclusion that the northern and southern parts of the Hadexun Oilfield had the same overall diagenetic process.
In recent years, many scholars have found that the information of carbonate clumped isotopes could change with increasing formation temperature under certain conditions; however, it can be predicted quantitatively by corresponding models [29,30]. In fact, from the end of the Silurian to the end of the Paleogene (380 Ma) in the Hadexun Oilfield, the burial depth of the Donghe sandstone was always less than 2700 m and the ground temperature was lower than 85°C. The sedimentation rate was as low as 7.03 m/Myr, and the compaction was weak, suggesting that the Donghe sandstone was in the early diagenetic stage during this period, when carbonate cements and secondary enlargements of quartz, kaolinite, and other clay minerals were predominately developed; dissolution of a small amount of feldspars and lithic particles occurred; and primary pores were preserved. Upon entering a temporary rapid burial stage in the Neogene, the burial depth of the Donghe sandstone in the study area was close to 6000 m, and the diagenesis progressed into the middle diagenetic stage.
The carbonate cements that had formed earlier were dissolved, clay minerals such as illite and chlorite were formed, and iron-bearing carbonates were eventually developed in the late diagenetic period. However, this raises the question of whether the characteristic long-term shallow burial and the late, short-term, rapid deep burial at low temperature had an influence on Δ47 as an indicator of the formation temperature of the cements. Based on the burial and thermal histories of this area, it was found that the Δ47 of the calcareous cements in the Donghe sandstone is independent of the burial process, according to the reconstruction formula of Δ47 established by Henkes et al. [29], and can reflect the formation temperatures of the cements, as shown in Figure 8.   11 Geofluids to 0.870 g/cm 3 , respectively. The Donghe sandstone reservoirs have relatively dense natural gas (1.02-1.23), belonging to typical wet gas, with low methane content of 15.46-34.32% and high nitrogen content of 30-40%. The formation water, which is CaCl 2 type, has an average density of 1.1584 g/cm 3 , an average chloride content of 156,000 mg/L, and an average total salinity of 257,000 mg/L. Oil source correlation shows that the crude oils from the Lungu Oilfield and Tahe Oilfield in the Lunnan low bulge have the same oil source, Cambrian-Ordovician marine source rocks in the Mangar sag [6].
The homogenization temperatures of saline water inclusions associated with crude oil in the Hadexun area range from 100°C to 130°C, and oil and gas were accumulated in a single stage. Based on the regional tectonic evolution and the burial and thermal evolution histories of the strata, the filling period of the crude oil of the Hadexun Oilfield was 8-5 Ma, within the Miocene period. The major filling period of crude oil in the reservoirs is obviously later than the formation time of the calcareous cements. It is inferred that the formation time of the calcite-cemented layers is the early diagenetic cementation stage and that the uncemented sandstone reservoirs are secondary reservoirs formed in the late diagenetic period, as shown in Figure 10. After conducting analyses of the water power and capillary force to identify the causes of the inclined oil-water interface in the Hadexun Oilfield, some scholars concluded that the reservoirs were in an adjustment period, being unsteady reservoirs [3].
As speculated from the tectonic and burial histories, the oil and gas in the Hadexun area migrated laterally from paleoreservoirs near Well Xiang 3 in the north after the north-dipping slope was finalized in the late Himalayas, where a large number of dry asphalt intervals remain today. The Himalayan movement tilted the formations. As a result, some crude oil migrated to an unconformity before the Lunnan No. 1 fault. The unconformity is high in the south and low in the north and high in the middle and low in the east and west, forming a nose-shaped feature. Oil and gas migrated along the "bridge of the nose" to the Hadexun area, forming the Hadexun Oilfield [3]. It was also reported that the oil and gas may have migrated vertically along the fault [7]. Based on the fact that the calcareous cementation is much earlier than the oil accumulation and charge, this paper proposes that the formation of a large number of early calcite-cemented layers caused the oil, which had migrated and accumulated through carrier beds, to migrate along layers separated by them instead of along well-separated channels, forming the inconsistency of the present oil-water interface with the structural contours (the height difference was reported as 178.33 m by [2]).

Conclusions
Based on core observations, microheterogeneity, diagenetic features, diagenetic mineral compositions, and stable isotope analyses of the oiliness difference of calcareous interlayers in the Donghe sandstone, the following conclusions were drawn: (1) It was concluded that calcareous cementation was the major factor resulting in porosity reduction of the tight sandstone. Thin section observations showed that calcareous cementation was also the major factor leading to the oil heterogeneity in the tight sandstone reservoir, and cathodoluminescence imaging revealed that multiphase calcareous cementation is mainly developed in the tight sandstone. Clumped isotope analysis indicated that the formation temperature of the carbonate cements ranges from 45°C to 90°C, corresponding to the Early Cretaceous period. The cements are considered to be the products of the early diagenetic period and are related to early tectonic movement and late burial (2) According to the homogenization temperatures of the coeval salt-water inclusions associated with hydrocarbon inclusions, ranging from 100°C to 130°C, basin modeling revealed that the basin underwent mainly one stage of hydrocarbon charging during  Ma in the Miocene period. Carbonate cements were developed before the massive accumulation of oil (3) Cements in the oil-free calcareous interlayers in the Donghe sandstone are one of the main controlling factors of the oil-water distribution in the reservoirs at present. This study provides a basis for research into the role of carbonate-cemented sandstone in hydrocarbon accumulation and also provides referential techniques and operational procedures for the study of reservoir diagenesis and timing of accumulation

Data Availability
All data supporting the results of this study can be found included in this manuscript.