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Petroleum resource assessment obtained from laboratory tests on old core samples shelved in the open environment tend to underestimate in situ resources. Therefore, hydrocarbon loss and its restoration need to be investigated. The hydrocarbon loss was studied via the difference of programmed pyrolysis parameter (Rock–Eval derived S1) between preserved/fresh cores and their replicas that had been long-term exposed to ambient conditions. However, the in situ hydrocarbon potential is still seemed to be underestimated, because the effect of sample crushing and crucible waiting on pristine S1 detection did not receive enough attention. To solve this issue, 50 preserved shale core samples with R o from 1.00% to 1.51% were collected from the K1qn1 Formation of northern Songliao Basin, Eastern China. All the samples were subjected to four parallel experiments: Dean–Stark extraction and nuclear magnetic resonance (NMR) T1–T2 mapping, using large rock pieces 3–5 cm in size, and thermal desorption gas chromatography (TD–GC) and Rock–Eval analysis, using 60-mesh powdered samples. In addition, a time series of TD–GC and Rock–Eval analyses were conducted on a preserved shale sample to investigate hydrocarbon loss during sample crushing, Rock–Eval crucible waiting process, and elapse-time exposure to the open environment. Rock–Eval pyrolysis was also conducted on one month-exposed shale cores and solvent-extracted samples. The results show that the total hydrocarbon content of large rock pieces is significantly greater than that of powdered samples. Sample crushing or grinding leads C 8− light hydrocarbons to evaporate, and results in a loss of approximately 35% of S1. Rock–Eval crucible waiting process causes C 14− hydrocarbons to evaporate, and results in an additional 25% loss of S1. To compensate for the sample crush induced S1 loss, an exponential distribution model was proposed based on the C 8+ hydrocarbons in the TD–GC S1 fingerprints. Sample maturity, pristine light hydrocarbon (C 14−) proportions, organic matter richness, and oil-bearing pore size primarily control the hydrocarbon loss of old shale samples. The higher the proportion of C 14− and the lower the abundance of organic matter, the higher the amount of hydrocarbon loss. Finally, S1 restoration coefficient charts for large rock pieces and powdered samples with R o ranging from 1.00% to 1.42% are provided. It highlights that previous studies have severely underestimated the in situ S1 when using the Rock–Eval method. This research has great implication for estimating in situ hydrocarbon potential using conventional coring samples. • In situ oil content can be determined by Dean-Stark and NMR T1-T2 mapping using large preserved shale rock pieces. • The C 8- hydrocarbons was restored based on the TD–GC S1 fingerprints using an exponential model. • Factors influencing hydrocarbon loss of old shale samples were discussed. • S1 restoration coefficients charts of large rock pieces and powdered samples were plotted. [ABSTRACT FROM AUTHOR]

This paper discusses the effect of the source rock–reservoir assemblage and the assemblage–induced variability in hydrocarbon expulsion and the subsequent molecular composition as well as molecular thermal maturity within a hybrid shale system. The characterization work was conducted on lithofacies and microlamina scales using core samples from the Chang 7 3 sub-member of the Triassic Yanchang Formation in the Ordos Basin, China. Samples were collected from a narrow interval with a depth range of less than 15 m, and the main characterization work was performed by Rock-Eval pyrolysis and GC–MS analysis. The results show that chemical fractionation of preferential expulsion and migration of the saturated fraction exists in the source rock–reservoir assemblages at both the lithofacies and lamina scales. However, the molecular composition behaves differently at the lithofacies and lamina scale's source rock–reservoir assemblages, in which ∑C 21 − /∑C 22+ is higher in lamina scale reservoir but lower in lithofacies scale reservoir. It is assumed that the low-molecular weight n -alkanes also follow molecular fractionation. The lithofacies reservoir has a lower ∑C 21 − /∑C 22+ because of the strong storage capacity of the laminated micro-reservoir within shale, which prevents the newly generated lighter oil from being charged into the lithofacies reservoir. The variation trends of thermal maturity indices Ts/hopane, the relative pregnane content, and TA(I)/TA(I + II) ratios, which have the same chemical basis with ∑C 21 − /∑C 22+ , carry the same maturity signature as ∑C 21 − /∑C 22+. The above profile of the molecular composition and molecular-derived thermal maturity parameters indicate that within the short interval of a shale system where no differences in thermal maturity are expected, chain scission reactions and their derived thermal maturity indicators are very sensitive to source rock and reservoir. In addition, within a shale system, oil is more easily to expel out from the organic-rich lithofacies that are interbedded with organic-lean lithofacies. Oil expulsion may promote both chain cracking of oil and subsequently kerogen decomposition. This may provide geological evidence to explain why the frequent-stacking assemblage of source rock and reservoir lithofacies in a hybrid shale system is an ideal target for shale oil exploration. [ABSTRACT FROM AUTHOR]

The geochemical characteristics of natural gases from Lower Paleozoic Jingbian gas field are abnormal and the carbon isotope of most natural gases has reversed, which led to a dispute over the source of natural gas in the Lower Paleozoic. The Upper Paleozoic Yulin gas field is adjacent to the Jingbian gas field, but the geochemical characteristics of the Yulin gas field did not appear abnormal. Besides, the ethane carbon isotope of Upper Paleozoic Yulin gas field is much higher than that of Lower Paleozoic Jingbian gas field. In order to identify the reasons for the carbon isotope reversal of natural gas in Lower Paleozoic Jingbian gas field and its relationship with natural gas source, We conducted the components and stable carbon isotopes of natural gas from Upper Paleozoic Yulin gas field and Lower Paleozoic Jingbian gas field. On the basis of these experiments, we compared the natural gas components and carbon isotope of 100 samples from both Upper Paleozoic Yulin gas field and Lower Paleozoic Jingbian gas field. The results indicate that higher maturity will break the conventional rule, when maturity reaches a certain threshold; δ 13 C ethane value will decrease with maturity. Although δ 13 C methane value will also increase with maturity, the extent will be relatively smaller. This leads to unusual δ 13 C methane  > δ 13 C ethane in the region with higher maturity. In the process of downward migration of coal-derived gas from Carboniferous-Permian coal measures, component fractionation and carbon isotope fractionation might occur, resulting the ethane components and carbon isotope value of Lower Paleozoic less than those of Upper Paleozoic, which will lead to the carbon isotope reversal. The mixing of oil-derived gas and coal-derived gas at different ratios may also lead to the reversal of carbon isotopes. The natural gas types of Jingbian gas field are mainly coal-derived gas generated from Carboniferous-Permian coal measure strata, with a small amount of oil-derived gas generated from Carboniferous-Permian marine-terrigenous limestone. [ABSTRACT FROM AUTHOR]

• Extracted bitumen and solid bitumen were characterized simultaneously. • Characterization was carried out at lamina scale and lithofacies scale. • Biomarkers reveal greater thermal maturity in source rocks than reservoirs. • Raman spectroscopy reveals greater thermal maturity in reservoirs than source rocks. • Organic–inorganic interactions increase the aromaticity of solid bitumen. Organic solvent extracted bitumen (EB) and microscopically observed solid bitumen (SB) carry many geological implications in unconventional source-rock reservoirs. EB is a commonly used term in organic geochemistry, and SB is normally used in organic petrology. Although both EB and SB are secondary organic matter initially formed from kerogen degradation and partially describe the same components, they are defined by different physical and chemical criteria and have specific applications, and thus are rarely comparatively investigated. In this study, by taking the shale of the seventh member of the Upper Triassic Yanchang Formation in the Ordos Basin, China, as a case study, we performed an integrated characterization on the two types of bitumen. The characterization was carried out on source rocks and reservoir assemblages at two scales: lamina-scale (organic-rich lamina and silty lamina) and lithofacies-scale (shale and sandstone). Programmed temperature pyrolysis (Rock-Eval 7 pyrolysis), gas chromatography–mass spectrometry (GC–MS), and Raman spectroscopy were used in this study. The samples are distributed within a 12 m interval and therefore should have experienced the same degree of thermal stress. However, maturity parameters derived from GC–MS for EB and Raman spectroscopy for SB exhibit a different inferred thermal maturity between source rocks and reservoirs at both lithofacies- and lamina-scales. The side-chain scission reactions related (non-)biomarker parameters such as Ts/C 30 H, Σ n C 21− /Σ n C 22+ alkanes, relative C 21 + C 22 sterane content and TA(I)/TA(I + II) suggest higher thermal maturity in source rocks (shale and organic-rich lamina) than the corresponding reservoirs (sandstone and silty lamina), while Raman-derived parameters RBS and G-FWHM indicate higher maturity in reservoirs than the corresponding source rocks. It is speculated that the EB measured by GC–MS comprises saturated and aromatic components corresponding to relatively mobile hydrocarbons. The maturation of the source rock exerts greater control over this component than that of the reservoir. In comparison, the SB measured using Raman spectroscopy mainly consists of solid residue left behind after migration and/or decomposition of a once-liquid oil phase that is less readily able to move. It is more intensely altered by the organic–inorganic interactions (mineral dissolution–precipitation processes) in the reservoir than that in the source rock, resulting in a consolidated SB with higher aromaticity. The storage ability of silty lamina in shale may complicate the data interpretation of geochemical differences in EB- and SB-derived parameters. On a practical note, when assessing thermal maturity, taking into the account the lithology or rock texture, which affects the organic–inorganic interactions, as well as specific components detected by different techniques may provide helpful clues to explain some contradictory results. [ABSTRACT FROM AUTHOR]

Lamina, a common lithologic unit in shale, is the smallest unit for organic–inorganic fluid–rock interactions. The effects of lamina-scale diagenetic processes are superimposed to exert on lithofacies-scale diagenetic sequences, which further impose on the entire diagenetic system of a shale reservoir. Organic acids from kerogen maturation are indispensable components in diagenetic reaction. However, previous studies mainly focused on low molecular weight (LMW) water soluble acids, few studies have paid attention to the role of high molecular weight (HMW) carboxylic acids dissolved in fluid–rock reactions. Herein, by taking the shale of the seventh member of the Upper Triassic Yanchang Formation in the Ordos Basin, China, as a case study, we investigate the mutual impacts between mineral alteration and HMW organic acid degradation. The characterization is carried out at two scales: lamina-scale (organic-rich clay-rich lamina and organic-lean silty lamina) and lithofacies-scale (shale and sandstone). Integrated analytical techniques (microdrill technique, thin section observation, X-ray diffraction, advanced mineral identification and characterization system, Rock-Eval pyrolysis, Fourier transform ion cyclotron resonance mass spectrometry) are performed. Results show that, in reservoirs of both silty lamina and sandstone, consumption of LMW aqueous acids through mineral transformation reactions promotes the forward evolution of HMW carboxylic acids in the bitumen phase toward decarboxylation or dehydration. During diagenesis, short chain fatty acids (SCFAs) are more easily broken down into small acids and, thus, more susceptible to be consumed. The lamina-scale reservoirs (silty lamina) have the privilege to receive abundant aqueous organic acids to maintain the micro-geochemical environment and progressively boost organic–inorganic fluid–rock interactions. The resultant dissolution pores not only accumulate plenty of bitumen but also an appreciable amount of bitumen dissolved acids. Because of the strong storage capacity of silty lamina within lithofacies-scale source rock (shale), fluids are less readily to expel out to lithofacies-scale reservoir (sandstone). As a result, the sandstone may not receive enough fluids from shale to maintain a consistent diagenetic environment, resulting in the observed discontinuous diagenesis of quartz precipitation transition to quartz dissolution. [ABSTRACT FROM AUTHOR]

The shale of the Permian Lucaogou Formation in the Jimusar sag, Junggar Basin (abbreviated as the Lucaogou shale) is a typical lacustrine type-II source rock, and is among the most representative target zones for shale oil exploration in China. However, little attention has been paid to the dynamic changes of the shale decomposition; hydrocarbon generation, retention, and expulsion; physico-chemical properties; and producibility of shale oil at different stages of maturation in this shale. Semi-open pyrolysis experiments were performed on the Lucaogou shale; products including expelled gas, oil (expelled oil), bitumen (retained oil), and residual rock were obtained, and their quantities and chemical and physical compositions were comprehensively characterized. The results show that the density and molecular weight of the oil are lower than those of the bitumen, whereas the API gravity of the oil is higher than that of the bitumen, indicating the preferential expulsion of light hydrocarbons and short chains. The saturate, aromatic, resin and asphaltene (SARA) percentages of oils under the current semi-open pyrolysis experiments were similar to those of natural oils recovered from the Lucaogou Formation, suggesting that semi-open pyrolysis can achieve the same purpose as hydrous pyrolysis to simulate natural oil composition. The measured vitrinite reflectance (Ro) of the pyrolyzed shale was lower than the calculated Easy%Ro, which is in accord with findings from the Chang 7 shale (another typical lacustrine type-II shale in China) but distinct from previously reported type-III coals and marine type-II shales. Similar to the Chang 7 shale, the decomposition process of the Lucaogou shale did not follow the sequential reaction model described as kerogen → bitumen → oil or kerogen → NSOs → HCs. The generation of HCs (oil) and NSOs (bitumen) was independent and followed the "alternate pathway" mechanism under semi-open pyrolysis conditions. In the early oil window (Ro ˂ 1.0%), the hydrocarbon expulsion efficiency was relatively low, meaning that the shale simultaneously retained considerable amounts of oil during peak oil generation. The producibility of shale oil reached its maximum at the end of the oil window (1.0–1.2 %Ro), and this interval is considered the most suitable for fracturing technology. • Hydrocarbon generation, retention, and expulsion process of lacustrine type-II shale was systematically explored. • Semi-open pyrolysis system was applied to simulate natural maturation of shale. • Both chemical and physical properties of oil and bitumen were analyzed. [ABSTRACT FROM AUTHOR]

• Pyrolysis experiments conducted on large-capacity, semi-open pyrolysis reactor. • Generation-retention-production under ICP for shales with varied TOC characterized. • Quantitative model for oil/gas generation-retention-production under ICP established. Shales with varying TOC content (0.5–26%) from the seventh member of the Triassic Yanchang Formation (abbreviated as Chang 7 shale) were artificially matured via semi-open pyrolysis to systematically study the characteristics of hydrocarbon generation, retention, and production under in-situ conversion process (ICP) conditions. The results show that with increasing Ro, the quantities of both generated oil and gas present an S-shape increase trend, with their generation rates reaching the maximum at 0.9 %Ro and 1.1 %Ro, respectively. The retention quantity and capability of oil and gas of shales first increase and then decrease as a function of thermal severity. With increasing TOC, larger amounts of oil and gas are retained, but the retention capability of the shale decreases. The shale simultaneously retains the largest amount of oil during the maximum oil generation period. The quantities of produced oil and gas share the same variation trend with the that of generated oil and gas, and the maximum oil and gas production rates are consistent with maximum generation rates. The greater the TOC, the greater the shale production potential. With increasing thermal maturity, the oil production potential of shales decreases slowly and then becomes relatively steady, while the gas production potential first changes slightly and subsequently decline rapidly. Based on the oil and gas generation-retention-expulsion characteristics, quantitative prediction models as a function of TOC and Ro are established, which will contribute to future engineering of the ICP. [ABSTRACT FROM AUTHOR]

There is a substantial amount of oil shale resources in the seventh member of the Triassic Yanchang Formation (abbreviated as Chang 7) in the Ordos Basin, and its geological and geochemical characteristics are highly suitable for in-situ conversion process (ICP). A comprehensive characterization of its hydrocarbon generation, expulsion and retention features will help determine the optimum conditions for future field tests. However, typical thermal simulation experiments based on either open-system or closed-system are not applicable to provide data to construct the models. Therefore, in this study, eight parallel thermal simulation experiments, which were based on the newly designed temperature-based semi-open pyrolysis experiments were performed on the Chang 7 oil shale. The yields (including cumulative yields and net incremental yields) and compositional characteristics of the expelled oil, expelled gas, and retained oil were analyzed. Results show that the hydrocarbon expulsion has a coupling relationship with hydrocarbon generation that can be divided into four stages: (1) Slow hydrocarbon generation stage (300–320 °C, 0.53–0.55 % Ro). Minimal amounts of oil and gas are generated in this stage. The hydrocarbon expulsion efficiency increases rapidly. (2) Quick oil-generation stage (320–380 °C, 0.55–1.09 % Ro). The fast cracking of kerogen and thermal bitumen generates a large amount of oil. The hydrocarbon expulsion efficiency remains relatively stable. (3) The secondary oil cracking and quick gas-generation stage (380–420 °C, 1.09–1.66 % Ro). The oil yield begins to decrease after reaching its maximum and a large amount of hydrocarbon gas is generated. The oil generation capability of kerogen is basically exhausted. The hydrocarbon expulsion efficiency and gas/oil ratio increase rapidly at this stage. (4) The heavy hydrocarbon gas cracking stage (after 420 °C, 1.66 % Ro). The oil yield continues to decline, accompanied by the onset decline in the gas yield (except methane). At this time, the hydrocarbon expulsion efficiency continues to increase but at a rather low speed. Under the experimental conditions in this study, 1.24–1.66% Ro is considered a favorable thermal maturity interval, in which maximum oil production with relatively light components can be obtained and the hydrocarbon gas is abundant. • Newly designed semi-open pyrolysis experiments were used. • Hydrocarbon generation and hydrocarbon expulsion are simultaneously simulated. • Appropriate thermal maturities were found to achieve optimal pyrolysis conditions. [ABSTRACT FROM AUTHOR]

At present, there is a lack of research on the structural changes of lacustrine Type-II kerogen, which is regionally distributed but has significant potential for hydrocarbon resources. In our previous work, a series of non-hydrous, temperature-based semi-open pyrolysis experiments have been performed on the Chang 7 oil shale to simulate the thermal maturation (from 0.53 %Ro to 1.68 %Ro) of lacustrine Type-II kerogen. In that work, the parallel reaction pathway for kerogen decomposition was supported. The aim of this work is to reveal the structural changes of the post-pyrolysis kerogen. Integrated analysis including elemental analysis, programmed pyrolysis (Rock-Eval), Fourier transform infrared (FT-IR) spectroscopy, and solid-state 13C nuclear magnetic resonance (13C NMR) spectroscopy were conducted on the native unheated and post-pyrolysis rocks and kerogens. Based on the compositional features of the hydrocarbon products, structural changes of the post-pyrolysis kerogen were investigated, and insights on the initial chemical structure of the kerogen were also obtained. Before the peak hydrocarbon-generating stage (R o < 0.6%), defunctionalization of oxygen-containing functional groups, which leads to the generation of water, CO 2 and NSOs, occurs simultaneously with the detachment of short aliphatic side chains and small aromatic rings, which leads to the generation of volatile fractions (C 6 –C 14 , C 15+ sat and C 15+ aro). This process suggests that the Chang7 kerogen is highly branched. During the peak hydrocarbon-generating stage (0.6–1.09 % R o), the concurrent breakage of weak cross-link bonds and long aliphatic chains lead to the simultaneous peak generation of liquid hydrocarbons and NSOs. This reflects the highly cross-linked features of the Chang7 kerogen. After the peak hydrocarbon-generating stage (R o > 1.09%), the reactions in the previous two stages produce a highly aromatic kerogen. The increased aromaticity of the highly matured kerogen is most likely to be caused by aromatization or dehydrogenation of hydroaromatics and coking of aromatic bitumen, not by fusing or condensation of aromatic rings. • Chemical structural evolution of Chang7 lacustrine Type-II kerogen was characterized for the first time. • Kerogen reached artificial maturation under non-hydrous, temperature-based semi-open pyrolysis experiments. • Parallel bond breaking mechanism of unusual lacustrine Type-II kerogen was supported from chemical structure changes. [ABSTRACT FROM AUTHOR]

The purpose of this study is to re-evaluate the petroleum expulsion characteristics of the shale in the seventh member of the Triassic Yanchang Formation (abbreviated as Chang 7 shale) in the Ordos Basin. Modified pyrolysis experiments, temperature-based semi-open pyrolysis were conducted in a temperature range between 300 and 420 °C, which covers the full range of petroleum generation from early kerogen decomposition to the onset of wet gas cracking. The quantities and compositions of the expelled gas, expelled oil, retained oil and residual rock are comprehensively characterized. The results of experiments and product analysis reveal that the peak oil generation period of the Chang 7 shale is relatively early, whereas the growth of petroleum expulsion efficiency (PEE) within that period is slow. During the oil window, the shale expels substantial amounts of petroleum while also retaining considerable amounts. Base on the compositional variations with increasing thermal maturity, two indexes are proposed: Rock-Eval and extraction-based production index (REPI) and isolation index (ISI). REPI is a function of the compositional characteristics both of the retained oil and the residual generative capacity of the shale. It is capable of differentiating the producible part from hard-to-produce part within oil in place, thus, it is a revision of the traditional production index. ISI reflects the proportion of oil existing in the isolated pores of the residual rocks, therefore indirectly indicating pore connectivity. Both the REPI and ISI curves first increase and then decrease with increasing thermal stress, sharing the same inflection point at the onset of wet gas cracking. Before that point, the production capacity of the shale oil gradually increases, and afterward, the probability for shale gas is increased. • A modified temperature-based semi-open pyrolysis system was adopted. • Hydrocarbon generation and expulsion processes were simultaneously simulated. • Two indexes for evaluating shale productive potential were proposed. • Thermal maturity for discriminating the shale oil and gas potential was proposed. [ABSTRACT FROM AUTHOR]

The purpose of this work is to investigate the generation characteristics of bitumen, NSO compounds, oil, and HC compounds during the artificial maturation of a lacustrine Type-II kerogen (which has not been given enough attention before) in order to determine its decomposition process. The analysis is based on the data itself, on the premise of jumping out of the generally accepted sequential reaction model. By taking the kerogen of the Chang 7 shale as an example, seven parallel experiments, in the temperature range from 300 °C to 420 °C were conducted on newly designed temperature-based semi-open pyrolysis system. The overall products are classified into oil and bitumen according to their phase, the C 15+ fractions are classified into C 15+ sat, C 15+ aro and NSOs based on chemical compositions, and the NSOs are further classified into n-pentane NSOs and DCM NSOs according to Behar et al., (2008) and (2010). Results show that large proportion of oil is not merely a result of thermal cracking of bitumen, but also directly from the decomposition of kerogen itself. Both C 15+ sat and C 15+ aro are generated as soon as kerogen starts to decompose. It is not until the initial productivity of kerogen is basically exhausted that NSOs become the main precursor of hydrocarbons. The comparison with Behar et al. [2008, organic geochemistry 39, 1–22] further reveals that, for Chang 7 kerogen, initial decomposition of kerogen generates much more HCs than DCM NSOs. These results contradict the sequential reaction model described as: kerogen → bitumen → oil or kerogen → NSOs → hydrocarbons. Instead, they confirm the "alternate pathway" mechanism proposed by Burnham et al. [ACS symposium, 1989] in which hydrocarbons can be formed immediately from kerogen in parallel with NSOs and the formation of the two species are controlled by bond-breaking reactions that are independent of each other. This study adds geochemical insights into the decomposition mechanism of lacustrine Type-II kerogen. [ABSTRACT FROM AUTHOR]

The Yingjisu Depression in the Tarim Basin produces gas with high wetness, nitrogen content, and ethane carbon isotope is abnormally depleted. The hydrocarbon generation capability of the Jurassic coal strata in this area has been controversial. Anomalies in the geochemical characteristics and the actual geological conditions have resulted in challenges in identifying the source and genetic type of natural gas in the Yingjisu Depression. In the present study, the composition and carbon isotope of natural gas are investigated. In addition, the controversial Jurassic coal strata are comprehensively evaluated, and the biomarkers are analyzed. The actual geological conditions of the Yingjisu Depression are studied combined with geochemical analysis. The components and carbon isotope suggest that the natural gas in the Yingjisu Depression is oil-associated gas generated from marine source rocks in the late mature stage. The formation temperature of the natural gas was higher than 185 °C, which represents secondary cracking oil at high thermal maturity. The Jurassic coal strata has low T max (lower than 435 °C) and % R o = 0.3–0.7. These strata cannot be the source rocks of natural gas in the Yingjisu Depression with high content of N 2 , typical of marine sediment. However, the biomarkers confirmed that the oil and gas in the Yingjisu Depression were derived from the Cambrian–Ordovician source rocks rather than the Jurassic. Therefore, the natural gas in the Yingjisu Depression is the secondary cracking of oil from the Cambrian–Ordovician paleo-reservoir. According to the actual geological conditions, the cracked gas migrated upward along deep faults to accumulate in the Silurian and Jurassic reservoirs, eventually forming the Yingjisu Depression gas field. • Geochemical and geological characteristics were combined to study the natural gas. • Jurassic coal strata have low thermal maturity and could not produce industrial gas. • Natural gas was generated from the Cambrian–Ordovician paleo-reservoir cracking gas. [ABSTRACT FROM AUTHOR]

The Carnian Pluvial Event (CPE) induced an intense carbon-cycle disturbance and biological crisis at a global scale. The eruption of the Wrangellia Large Igneous Province (W-LIP) is considered a possible triggering mechanism; however, this cannot fully explain the significant differences in environmental perturbations across different regions. In this paper, we present detailed records of petrography, mercury geochemistry, carbon and sulfur isotopes, trace elements, and provenance data for the Triassic lacustrine facies of the Ordos Basin in the North China Plate, which provide insights into the important effects of volcanic activities, other than the W-LIP, on palaeoenvironment during the CPE interval. Massive emissions of SO 2 , CO 2 , and pyroclastic deposits resulting from these volcanic activities triggered four humid episodes, each characterized by lake-level rise, negative δ13C org excursion, a transition from mudstones to organic-rich shales facies, as well as algal bloom within a time span of 180 kyrs. The establishment of an age framework in the Ordos Basin enables comparative analyses of environmental evolution during the Carnian age across the North China Plate, the western Tethys domain, and the South China Plate. During the period of global climate perturbation driven by the W-LIP eruption, we conclude that short-term localized volcanic activities may have further induced high frequentcy environmental perturbations, which influenced biological shifts and increase organic carbon burial. These short-term volcanic activities with different occurrence times and frequencies complicate local-scale palaeoenvironmental evolutions, which may be an important reason contributing to significant differences in environmental perturbations during the CPE interval across different regions of the globe. • Four humid episodes and sedimentary changes occurred within 0.18Ma in the Ordos Basin during Carnian age. • Environmental changes in the Ordos Basin was related to the local volcanisms in its nearby Qinling orogenic belts. • Short-term local volcanisms can complicate the environmental evolutions in different parts of globe during the CPE interval. • Local volcanic processes may cause inconsistent environment perturbation in different parts of globe during the CPE interval. [ABSTRACT FROM AUTHOR]

Samples for inclusion analysis were collected to investigate reasons for carbon isotope rollover in the Yan'an gas field (YAGF). Homogenization temperature of fluid inclusions, constituents and carbon isotope of gases in fluid inclusions were measured. Geochemical parameters of gas in wells and fluid inclusions in the northern gas fields (NGF) and YAGF were compared. The results show that geochemical characteristics of well and fluid inclusions gas in the NGF are almost the same, suggesting that it was originated from one set of source rocks. The direct reason for carbon isotope rollover in the YAGF is the depleted ethane carbon isotopes, while the methane carbon isotopes do not change much compared with the primary gas. There was a period of high temperature fluid filling and accumulation (140–160 °C) in the YAGF. The higher thermal maturity has disparate effects on methane and ethane. Higher thermal maturity is an important inducement of carbon isotope rollover. Mixture of oil-derived gas generated from the marine Ordovician Majiagou Formation will also result in carbon isotope rollover. • Gas in fluid inclusions was analyzed and compared with well gas. • Carbon isotope rollover was studied by geochemical analysis. • Primary gas in fluid inclusions of the Yan'an gas field was first reported. • High thermal maturity is the principal prerequisite for carbon isotope rollover. [ABSTRACT FROM AUTHOR]

The geochemical characteristics, genesis and accumulation mechanism of the pre-salt gases of Ordos Basin have been rarely studied in China. Components and carbon isotope values of pre-salt gases are investigated and compared with those of the Upper Paleozoic and post-salt gases. Homogenization temperatures and carbon isotope values of gases of the pre-salt fluid inclusions were also measured. Based on the geochemical parameters, combined with the geological conditions, the genesis and accumulation mechanism of pre-salt gases are studied. The components, carbon isotope values and the first two homogenization temperature ranges (90–120 °C and 120–160 °C) of the pre-salt gases contain those of the Upper Paleozoic and post-salt gases. The pre-salt inclusions have an extra homogenization temperature range (160–200 °C) and the pre-salt rocks also have some hydrocarbon generation capacity, which means the pre-salt rocks may also generate some gases. The pre-salt gases are mixed gases generated from the Upper Paleozoic coal strata, the post-salt and pre-salt Lower Paleozoic Majiagou Formation, which is confirmed by the geochemical characteristics and the geological settings. • Geochemical characteristics of pre-salt gases were analyzed and compared. • Pre-salt fluid inclusions were investigated. • The genesis of the pre-salt gases of Ordos Basin was studied. • The geochemical parameters are consistent with geological conditions. [ABSTRACT FROM AUTHOR]

Abstract: This work extensively investigated global tight sandstone gas, and geologically and geochemically analyzed the tight sandstone gas in China's Ordos, Sichuan, and Tarim basins. We compared typical tight sandstone gas in China with that in North America. We proposed six conditions for the formation of China's tight sandstone gas, and illustrated the geological characteristics of tight sandstone gas. In China, gas‐bearing tight sandstones were mainly deposited in continental lake deltas and marine‐terrigenous facies basin environments, associated with coal‐measure strata, and were mostly buried deeper than 2000 m under a formation pressure of 20–30 MPa, with pressure coefficients varying from overpressure to negative pressure. In other countries, tight gas bearing sandstones were dominantly deposited in marine to marine‐terrigenous facies environments, occurred in coal‐measure strata, and were mostly buried shallower than 2000 m in low‐pressure systems. We systematically analyzed tight sandstone gas in the Ordos, Sichuan, and Tarim basins in terms of chemical compositions, geochemical characteristics of carbon isotopes, origins, and sources. Tight sandstone gas in China usually has a hydrocarbon content of >95%, with CH41 content >90%, and a generally higher dry coefficient. In the three above‐mentioned large tight sandstone gas regions, δ13C1 and δ13C2 mainly ranges from –42‰ to –28‰ and from –28‰ to –21‰, respectively. Type III coal‐measure source rocks that closely coexist with tight reservoirs are developed extensively in these gas regions. The organic petrology of source rocks and the carbon isotope compositions of gas indicate that tight sandstone gas in China is dominantly coal‐derived gas generated by coal‐measure strata. Our analysis of carbon isotope series shows that local isotope reversals are mainly caused by the mixing of gases of different maturities and that were generated at different stages. With increasing maturity, the reversal tendency becomes more apparent. Moreover, natural gas with medium‐low maturity (e.g., Xujiahe Formation natural gas in the Sichuan Basin) presents an apparent reversal at a low‐maturity stage, a normal series at a medium ‐maturity stage, and a reversal tendency again at a high‐maturity stage. Finally, we proposed four conditions for preferred tight sandstone gas “sweep spots,” and illustrated the recoverable reserves, proven reserves, production, and exploration prospects of tight sandstone gas. The geological and geochemical characteristics, origins, sources, and exploration potential of tight sandstone gas in China from our research will be instructive for the future evaluation, prediction, and exploration of tight sandstone gas in China and abroad. [ABSTRACT FROM AUTHOR]

To identify the reasons for more depleted ethane carbon isotopic value (MD-δ13C 2) in the Southeastern gas field (SEGF), fluid inclusions samples from northern and the SEGF were collected. Homogenization temperature and salinity of fluid inclusions, components and carbon isotopic values of gases released from the crushed inclusions were tested. Geochemical fingerprints information of producing gas in wells and primary gas in inclusions were contrasted. The comparison suggests that geochemical parameters of primary and producing gas in the NGF are similar, whereas those in the SEGF are completely different. The ethane carbon isotopic values of producing gas became more depleted compared with the primary gas, whereas the methane carbon isotopic values are not much different from the primary gas. This indicates that the secondary effect caused the more depleted ethane carbon isotopic values. There was one more period of high temperature fluid filling (140–160 °C) in the SEGF in comparison with the NGF. Higher thermal maturity is the key inducement of the abnormal MD-δ13C 2. • Geochemical parameters comparison of primary gas with producing gas was conducted. • More depleted ethane carbon isotopic values were studied based on geochemistry. • Fluid inclusions and natural gas parameters were combined to study the mechanism. • Higher thermal maturity is the key inducement of the abnormal carbon isotopic values. [ABSTRACT FROM AUTHOR]