Homogenization Temperatures Of Inclusions Research Articles

Origin and characteristics of grain dolomite of Ordovician Ma55 Member in the northwest of Ordos Basin, NW China

The origin of grain dolomite in M55 Member of Ordovician Majiagou Formation in northwestern Ordos Basin was studied by geochemical and petrological tests on core samples. Observation of cores, thin sections and casting thin sections, analysis of cathodoluminescence, X-ray diffraction, microscopic sampling of trace elements, laser sampling δ18O and δ13C, and fluid inclusion homogenization temperature were conducted. The results show that the dolomite is the product of recrystallization of micritic to crystal powder dolomite rather than the product of dolomitization of grain limestone. In the spherical grains are residual gypsum and halite pseudo crystals identical with those in the host micritic dolomite. The spherical particles of dolomite has similar trace elements and δ18O and δ13C characteristics to micritic dolomite. Furthermore, Mn/Sr ratio of the fine—medium dolomite between the dolomite grains is about 5-8, while Mn/Sr ratios of calcite in limestone, micritic dolostone in micritic dolomite, and micritic and powdery dolomite are about 0-2, indicating that the dolomite experienced strong diagenesis. Homogenization temperature of inclusions of fine—medium dolomite is about 148. 19 °C, higher than that of inclusions in micritic to crystal powder dolomite (about 122.60 °C), which also supports the conclusion that the grain dolomite experienced burial diagenesis and negative shift of δ18O and δ13C. The δ18O, δ13C values of micritic to crystal powder dolomite match with the negative migration, but those of calcite in limestone don't. It is of great significance to elucidate the genesis of “dolomite recrystallization” for the prediction of such dolomite reservoirs.

Petrogenesis, Ore Mineralogy, and Fluid Inclusion Studies of the Tagu Sn–W Deposit, Myeik, Southern Myanmar

Most of the granite-related Sn–W deposits in Myanmar are located in the Western Granitoid Province (WGP) of Southeast Asia. The Tagu deposit in the southern part of the WGP is a granite related Sn–W deposit. The biotite granite is composed of quartz, feldspars (plagioclase, orthoclase, and microcline), and micas (muscovite and biotite) and belongs to S-type peraluminous granite. Abundances of large-ion lithophile elements (LILEs), such as Rb, K, and Pb, coupled with the deficiency of high-field-strength elements (HFSEs), such as Nb, P, and Ti, indicate that the parental magma for the Tagu granite was derived from the lower continental crust at syn-collisional setting. Mineralized veins consist of early-formed oxide ore minerals, such as cassiterite and wolframite, which were followed by the formation of sulfide minerals. Three main types of fluid inclusions were distinguished from the mineralized quartz veins hosted by granite and metasedimentary rocks: Type-A—two phases, liquid (L) + vapor (V) aqueous inclusions; Type-B—two phases, vapor (V) + liquid (L) vapor-rich inclusions; And type-C—three phases, liquid + CO2-liquid + CO2-vapor inclusions. Quartz in the veins hosted in granite corresponding with earlier deposition contains type-A, type-B, and type-C fluid inclusions, whereas that in the veins hosted in metasedimentary rocks corresponding with later deposition contains only type-A fluid inclusions. The homogenization temperatures of type-A inclusions range from 140 °C to 330 °C (mode at 230 °C), with corresponding salinities from 1.1 wt.% to 8.9 wt.% NaCl equivalent for quartz veins hosted in metasedimentary rocks, and from 230 °C to 370 °C (mode at 280 °C), with corresponding salinities from 2.9 wt.% to 10.6 wt.% NaCl equivalents for quartz veins hosted in granite. The homogenization temperatures of type-B vapor-rich inclusions in quartz veins in granite range from 310 °C to 390 °C (mode at 350 °C), with corresponding salinities from 6.7 wt.% to 12.2 wt.% NaCl equivalent. The homogenization temperatures of type-C H2O–CO2–NaCl inclusions vary from 270 °C to 405 °C (mode at 330 °C), with corresponding salinities from 1.8 wt.% to 5.6 wt.% NaCl equivalent. The original ascending ore fluid was probably CO2-bearing fluid which evolved into two phase fluid by immiscibility due to pressure drop in the mineralization channels. Furthermore, the temperature and salinities of two-phase aqueous fluids were later most likely decreased by the mixing with meteoric water. The salinities of the type-B vapor-rich inclusions are higher than those of the type-C CO2-rich inclusions, which may have resulted from CO2 separation from the fluids. The escape of gases can lead to an increase in the salinity of the residual fluids. Therefore, the main ore-forming mechanisms of the Tagu Sn–W deposit are characterized by fluid immiscibility during an early stage, and fluid mixing with meteoric water in the late stage at a lower temperature.

The origin, age and duration of hydrothermal alteration associated with iron skarn mineralization determined from clay/phyllosilicate minerals, Bizmişen-Erzincan, East-Central Turkey

The Bizmişen skarn-type iron deposit is one of the major operating mines in east-central Turkey. Middle Eocene (46.3–42.0 Ma) plutonic rocks (quartz diorite) were intruded into Triassic-Cretaceous limestones and Upper Cretaceous ophiolites forming skarns (garnet, diopside, epidote, scapolite and tremolite), iron mineralization and clay-bearing alteration zones (argillic alteration). Clay-rich rocks of the argillic zone, contain mainly quartz, calcite, dolomite, feldspar and clay/phyllosilicate minerals comprising dioctahedral smectite, kaolinite, mixed-layered illite-smectite (I-S) and illite, and trioctahedral vermiculite, serpentine/chrysotile, talc, chlorite and mixed-layered chlorite-smectite (C-S). Na-Ca smectite, I-S, illite and kaolinite are developed at both the quartz diorite-limestone contact and within the quartz diorite body. However, phlogopite, vermiculite, serpentine/chrysotile, talc and chlorite occur at the quartz diorite-ophiolite contacts, indicating the distributions of clay/phyllosilicate minerals are influenced primarily by the host-rock composition. Chlorite geothermometry data suggest ~300 °C for the retrograde stage of skarn formation and ~120 °C for the late argillic alteration overprint, and the formation of low-temperature clays (smectite, vermiculite, C-S) in areas of skarn formation. Kaolinite 1 M (one-layer monoclinic) and I-S (I75-S25, R1 ordering) are indicative of low-temperature (<200 °C) argillic alteration conditions. Optical and electron microscopy studies of kaolinite, smectite and I-S indicate a completely hydrothermal (neo-formation) origin, with the absence of any detrital input. The major and trace/REE whole-rock analyses of clays show they have a composition between the analyses of quartz diorite and ophiolite rocks (i.e., serpentinite and serpentinized peridotite). However, the analyses are closest to those of the quartz diorite. The calculated δ18O and δD values of fluids in equilibrium with the clays (using the average values of the fluid inclusion homogenization temperatures) indicate a pre-dominantly magmatic water source. Assuming the clay-forming fluids originated from magmatic water, the δ18OV-SMOW and δDV-SMOW compositions indicate <200 °C for smectite during the supergene or low-temperature argillic stage, but in excess of 200 °C for I-S and kaolinite during the hypogene or high-temperature argillic stage. 40Ar/39Ar age data of illite and I-S (37.5–25.5 Ma) indicate alteration started during the late Eocene, ~4 Ma after intrusion of the pluton at 42 Ma, and continued to the late Oligocene, with a duration of ~12 Ma. The age data imply a long period of cooling at depth, without exhumation, during epithermal alteration after the retrograde skarn stage. The data show that hydrothermal clays formed from magmatic fluids in a hydrothermal system that persisted well after the intrusion of the igneous body and are indicative of how long hydrothermal systems can persist in areas of mineralization.

Hot fluids, burial metamorphism and thermal histories in the underthrust sediments at IODP 370 site C0023, Nankai Accretionary Complex

Abstract Drilling during International Ocean Discovery Program (IODP) Expedition 370 at Site C0023 encountered instances of hydrothermal mineralization from 775 to 1121 m below seafloor. Fluid inclusion homogenization temperatures measured on barite veins within this interval indicate precipitation from fluids with temperatures up to 220 °C, and salinities ten times higher than interstitial water (16–25 c.f. 2.8–3.6 wt % NaCl). Patches of stratabound mineralization (rhodochrosite, calcite, barite and anhydride) are largely confined to the vicinity of veins and have vertical thicknesses and extents that can be explained by precipitation within the thermal aureoles of veins. Thermal maturities measured on petroleum biomarkers in underthrust sediments record a rise from pre-oil window to early oil window thermal maturities. Basin models show that increases in thermal maturity can be explained by burial metamorphism, and kinetic-based calculations suggest that hot fluids would only have had a minimal effect on hydrocarbon generation. However, the movement of hot fluids still has geochemical implications and creates a complex thermal history where both short-duration, localized heating within fracture zones at hot temperatures (~200 °C for less than 1 yr) and heating during burial over long durations (80–110 °C for 0.5–2 Myrs) need to be considered.

Geochemical constraints on the origins of calcite cements and their impacts on reservoir heterogeneities: A case study on tight oil sandstones of the Upper Triassic Yanchang Formation, southwestern Ordos Basin, China

Calcite cementation has been identified as an active process in the Upper Triassic Yanchang Formation throughout its burial history and as a major diagenetic factor causing strong reservoir heterogeneities. The origins of calcite cements and their relevance to reservoir heterogeneities were investigated using a suite of petrographic and geochemical methods, including optical microscopy with fluorescence and cathodoluminescence, scanning and backscattered electron microscopy with energy-dispersive spectrometry, x-ray diffraction, x-ray fluorescence, electron probe microanalysis, quantitative evaluation of minerals by scanning electron microscopy, fluid inclusion analysis, and carbon and oxygen stable isotope analyses. The sandstones are compositionally immature with relatively high amounts of volcanic rock fragments. The two generations of calcite cements are Ca-I and Ca-II. The Ca-I calcites are distributed along the interface of sandstone and mudstone units and were formed during the Late Triassic to Early Jurassic at formation temperatures of approximately 90°C. The Ca-II calcite mainly developed in the lower part of the fining-upward sandstone units and was formed in the Late Jurassic at higher temperatures of approximately 110°C. The origins of calcite cements were constrained by geochemical and isotope measurements, fluid inclusion homogenization temperature, and in situ element analysis. The Ca-I calcite cement originated from dissolution of the lacustrine depositional carbonates in the interbedded mudstones and reprecipitation in the adjacent sandstones. The Ca-II calcite was mainly related to organic matter decarboxylation, with Ca2+ having been provided internally by volcanic fragment alteration and plagioclase dissolution. Calcite cementation had caused strong reservoir heterogeneities in the Yanchang Formation tight sandstones. The Ca-I calcite cementation destroyed reservoir properties along the interface of sandstones and mudstones. The lower parts of the fining-upward sandstone units were tightly cemented by Ca-II calcite, although they originally had high porosity and permeability. The middle–upper parts of the fining-upward sandstone units contain less calcite cements and thus have better preserved reservoir pores because of oil emplacement inhibiting the calcite cementation processes.

Influence of multistage oil emplacement on carbonate cementation in the Eocene Shahejie Formation, Dongying Sag, Bohai Bay Basin, China

Abstract The influence of multi-stage oil emplacement on carbonate cementation was investigated on the basis of determining the sequence of oil emplacement and carbonate cementation in the clastic reservoirs of the upper part of the fourth member of the Eocene Shahejie Formation (Es4s) in the Yanxie 229 area, Dongying Sag. The sequence of multistage oil emplacement and carbonate cementation was determined by projecting the homogenization temperatures (Ths) of two-phase aqueous inclusions on a burial and thermal history plot. The ratio of the number of quartz grains with yellow-fluorescent oil inclusions therein to the total number of quartz grains (YGOI) and the ratio of the number of quartz grains with blue-fluorescent oil inclusions therein to the total number of quartz grains (BGOI) were calculated to analyze the paleo-oil saturation of each stage of oil emplacement. The YGOI and BGOI values reflect the relative level of the paleo-oil saturation of the first-stage yellow-fluorescent (FSYF) oil and the second-stage blue-fluorescent (SSBF) oil, respectively. A large number of primary pores were preserved in the oil layers, whereas only a small number of dissolution pores and micropores were developed in the oil-bearing water layers and dry layers. Calcite, dolomite, ferrocalcite, and ankerite cementation and two-stage oil emplacement occurred in the Es4s reservoirs. The FSYF oil emplacement occurred earlier than the ankerite cementation and ferrocalcite cementation but later than the calcite cementation and dolomite cementation. The SSBF oil emplacement occurred later than all phases of carbonate cementation. The dolomite cementation was not influenced by the FSYF oil emplacement because it occurred earlier than the FSYF oil emplacement. The ankerite cementation was dominantly inhibited by the FSYF oil emplacement in the oil layers and the degree of inhibition increased with the increase in paleo-oil saturation of the FSYF oil. The SSBF oil emplacement further increased the paleo-oil saturation in the oil layers, which enhanced the inhibition of the ankerite cementation and even stopped it. The ankerite cementation in the dry layers and oil-bearing water layers was slowed down or stopped due to the lack of pores and the low transportation rate of external material, which was caused by the intense ankerite cementation prior to the SSBF oil emplacement.

The origin of CH4-rich fluids in reduced porphyry–skarn Cu–Mo–Au systems

Although most of the methane on Earth is of biogenic origin, significant abiogenic methane has been identified in a variety of geological environments. Moreover, the presence of methane has been reported recently in fluid inclusions from a number of reduced porphyry deposits. The genesis of this methane, however, remains poorly understood. Here, we present results of a study of magma-exsolved CH4-rich aqueous fluid inclusions in the Seleteguole reduced porphyry–skarn Cu–Mo–Au deposit, NW China. Four types of fluid inclusions, namely intermediate-density two-phase aqueous inclusions, low-density vapor inclusions, brine inclusions and aqueous liquid inclusions, have been distinguished on the basis of the phases present at room temperature. The intermediate-density inclusions were trapped as a single phase and contain 3.8–10.4 mol/kg CH4, corresponding to an oxygen fugacity between ΔFMQ − 1 and ΔFMQ − 0.5. This attests to the remarkably reduced nature of the fluid. The δ13C value of the CH4-hosted fluid inclusions ranges from –29.4‰ to –19.1‰ (PDB), which distinguishes this methane from biogenic methane. Indeed, the high homogenization temperature of the CH4-rich inclusions (~400 °C) implies that the CH4 was exsolved directly from the magma. Given the environment in which the magma was likely generated, i.e., at or immediately above a subducting plate, we propose that the methane was produced by reactions involving organic matter-bearing carbonate rocks in the subduction zone. Although Cu, Mo and Au in most porphyry systems are interpreted to have been transported under oxidizing conditions, our results indicate that reduced aqueous liquids and vapors are also capable of transporting appreciable concentrations of these metals.

Effect of tectonic evolution on hydrocarbon charging time: A case study from Lower Shihezi Formation (Guadalupian), the Hangjinqi area, northern Ordos, China

A giant gas field has been discovered in the Lower Shihezi Formation in the Hangjinqi area, northern Ordos Basin, China. Coal seams and mudstone in the Taiyuan and Shanxi Formation are considered as source rocks and sandstone in the Lower Shihezi Formation is treated as reservoirs for gas. The charging time in the sandstone reservoirs was studied based on the homogenization temperature of aqueous inclusions, thermal and burial history simulation and K-Ar dating of authigenic illite. Two episodes of gas charging in the northern part and one episode in the southern part were delineated in the reservoirs of the Hangjinqi area, evidenced by microscopic observation of the occurrence of fluid inclusions and the analysis of salinity in aqueous inclusions. In the southern part of the study area gas charging occurred between circa 171-162 Ma, whereas in the northern part gas charging was between 158-144 Ma and 120-109 Ma, respectively. The gas charging events appeared to be influenced by the tectonic evolution of northern Ordos Basin. Paleo topography caused reduction in thickness of source rocks northwards, and contributed to differences in hydrocarbon generation potential and thermal evolution between the northern and the southern part of the study area. Therefore, gas charging occurred in the southern part prior to that in the northern part. Furthermore, tilting occurred in Middle Jurassic and provided the driver and pathways for gas, leading to a first charging event in the northern part of the study area.

Study on Hydrocarbon Accumulation Period in Deep Water Areas of the South China Sea: An Example from the Miocene Reservoir of the Ledong-Lingshui Sag in the Qiongdongnan Basin

Qu, X.-Y.; Chen, S.-R.; Yang, X.-B.; You, L., and Zhong, J., 2019. Study on hydrocarbon accumulation period in deep water areas of the South China Sea: An example from the Miocene reservoir of the Ledong-Lingshui Sag in the Qiongdongnan Basin. In: Gong, D.; Zhu, H., and Liu, R. (eds.), Selected Topics in Coastal Research: Engineering, Industry, Economy, and Sustainable Development. Journal of Coastal Research, Special Issue No. 94, pp. 112–116. Coconut Creek (Florida), ISSN 0749-0208.According to the observation of fluid inclusions under microscope and the measurement of homogenization temperature, this paper studies the accumulation period and the characteristics of fluid inclusions of the miocene reservoir of Ledong-lingshui sag in Qiongdongnan basin. The results show that the fluid inclusions are mainly distributed along the quartz fracture zone while some are at the edge of the quartz grains or cut through several clastic grains. The fluid inclusions mainly include brine inclusions, liquid hydrocarbon inclusions, hydrocarbon inclusions and liquid hydrocarbon inclusions, in which hydrocarbon inclusion is at the third stage of development, which are mostly yellow blue and white when exposed to fluorescent light. The maturity of organic matters is relatively high. The homogenization temperature of fluid inclusions is discontinuously distributed, the peak values of which are mainly concentrated in the range of 130 -150°C. According to the characteristics, occurrence and homogenization temperature of the fluid inclusions, Miocene reservoirs are mainly composed of three-phrase hydrocarbon fluid filling and first-stage CO2 fluid filling. Among them, the second and third-stage hydrocarbon fluid filling is the main hydrocarbon generation stage, and the CO2 fluid filling occurs in the late stage of gas charging. Considering the burial history and thermal evolution history, the accumulation period belongs to 1.9Ma-1Ma, which is the late Pliocene of Neogene of Yinggehai- Pleistocene of Quaternary of Ledong.

The Barika gold-bearing Kuroko-type volcanogenic massive sulfide (VMS) deposit, Sanandaj-Sirjan zone, Iran

The Barika deposit is the first documented auriferous Kuroko-type volcanogenic massive sulfide (VMS) deposit in Iran. It is hosted in meta-andesites of the Sanandaj-Sirjan metamorphic Zone (SSZ). The mineralization and host rocks have been metamorphosed to lower greenschist facies. The deposit has Au and Ag grades in the stratiform lens averaging 3.5 and 175 g/t, respectively, and contains 2.3 tonnes of Au and 143 tonnes of Ag. The base metal (Pb + Zn + Cu) content of the deposit is low (<1 wt%). The stratiform part of the Barika deposit is approximately 150 m long and up to 20 m thick, and consists of massive to semi-massive sulfides, some of which are banded, which are overlain by barite and siliceous exhalites. The >200 m long and up to 500 m wide stringer zone immediately stratigraphically underlies the stratiform mineralization. Veins within the stringer zone are composed of quartz, pyrite, galena, sphalerite, tetrahedrite-tennantite, and rare chalcopyrite. Stratiform mineralization is composed of pyrite, sphalerite, galena, stibnite, tetrahedrite-tennantite, several Ag-(As-Sb-Pb) sulfosalt minerals (guettardite, ferdowsiite, barikaite, stephanite, pyrargyrite, trechmannite, miargyrite, As-rich andorite, As-rich geocronite, Sb-rich seligmanite and smithite), realgar, and electrum.Based on mineral assemblages and textures, four mineralization stages are recognized. During stage 1, pyrite, sphalerite, galena, tetrahedrite-tennantite, and stibnite were deposited during synvolcanic hydrothermal activity. During stages 2 and 3, post-mineralization deformation and shearing contemporaneous with regional metamorphism modified most of the primary textures in the stratiform mineralization. Stage 2 mineralization represents Stage 1 mineralization that was remobilized during regional metamorphism, and this mineralization is characterized by gold as submicroscopic inclusions or as “invisible” gold locked in pyrite, as well as electrum in the barite mineralization. Regional metamorphism and deformation (D1) caused recrystallization of primary mineralization (mainly pyrite) and migration of submicroscopic gold via solution-precipitation creep to the grain boundaries to form microscopic electrum. Stage 3 mineralization is attendant with D2 movement along the Barika shear zone that controlled the overall geometry of the deposit and resulted in the development of ductile-brittle deformation textures and the formation of several Ag(As-Sb-Pb)-rich sulfosalt minerals and electrum. Most of the electrum grains occur together with sulfosalt minerals that fill open spaces formed during shearing. Stage 4 mineralization is marked by the formation of white, barren quartz veins and high-angle normal faults that were developed during D3 extension-related uplift.Primary two-phase fluid inclusions in quartz of the stringer zone and barite from the stratiform mineralization homogenize between 132° and 283 °C (average ~ 200 °C). Salinities of the primary fluid inclusions range from 1.4 to 9.6 wt% NaCl eq. The sulfur isotope compositions of sulfide minerals from stratiform and stockwork mineralization in the Barika deposit range from δ34S −0.8 to +5.6‰. This relatively narrow range suggests that the sulfur in the sulfide mineralization was derived from the leaching of igneous sulfur from the underlying andesitic rocks, similar to most Japanese Kuroko VMS deposits. Temperatures of formation for Barika sulfides estimated based on sulfur isotope values for coexisting galena-sphalerite (Δ = 2–4.8‰) and galena-pyrite (Δ = −3.3 to −5.4‰) pairs range from 146 to 293 °C, and these are consistent with fluid inclusion homogenization temperatures. The primary mineralizing fluids have a calculated δ18O value of between +4.3and +6.3‰, based on the δ18O compositions of quartz from the stringer zone and assuming a temperature of 200 °C and that isotopic equilibrium was attained.

Fluid evolution of the Wushan skarn-dominant copper deposit in the Middle-Lower Yangtze River metallogenic belt, Eastern China

The Wushan copper skarn deposit (1.37 Mt at 1.17% Cu) is located in the Middle-Lower Yangtze River polymetallic belt. Skarn orebodies mainly occur in the Carboniferous and Permian carbonates adjacent to Early Cretaceous granodiorite porphyries (148–138 Ma). Ore deposition underwent two episodes of metallogenic events, involving hydrothermal evolution followed by skarn formation and porphyry-related mineralization. The skarn episode formed massive, disseminated, veinlet- and breccia-style mineralization at the contact zone, whereas porphyry mineralization is characterized as disseminated and veinlet-style only. Various types of fluid inclusions (daughter mineral-bearing, CO2-bearing, vapor and aqueous–vapor) are classified based on their fluid composition and phase assemblages.The hydrothermal fluids are mainly derived from a magmatic origin, which exsolves during the melt-fluid differentiation. Primary fluid in endoskarn is interpreted as representing two immiscible phases evolving from a low-salinity initial fluid. The initial supersaturated fluid has a relative low salinity and the wide range of Th values (433–626 °C) implies heterogeneous trapping, corresponding to pressures of 371–646 bars and hydrostatic depth of 3.7–6.5 km. Primary fluid inclusions trapped in syn-ore quartz show the coexistence of S-type inclusions (~30.0 wt% NaCl equiv) with vapor-rich and liquid-rich inclusions, indicating fluid immiscibility and phase separation from heterogeneous trapping. The homogenization temperatures (347–434 °C) of primary vapor-rich inclusions represent the trapping temperatures, corresponding the trapped pressures range from 152 to 374 bars and a hydrostatic depth of 1.5–3.7 km. Copper mineralization in episode porphyry occurs on a very small scale and have a clear trend of decreasing temperatures and salinities during fluid evolution. A similar scenario occurred during the porphyry episode in which fluid immiscibility led to copper mineralization.Significant trends of decreasing temperatures and salinities for both mineralization episodes reflect the change from a magmatic fluid-dominated system to a mixed source fluid that incorporated formation water from the country rocks and/or meteoric water. Controlled by the chemical transition of the fluid, this mixing process produced a relatively cool fluid system with lower salinities, which enhanced the precipitation of Cu–Fe sulfides. H–O–C isotope signatures further indicate that both the fluid and metal are predominantly derived from magmatic sources, and that multiple fluid pulses contributed to form skarn minerals and sulfides in the Wushan deposit.

Petroleum charge history in the Baiyun depression and Panyu lower uplift in the Pearl River Mouth Basin, northern South China Sea: Constraints from integration of organic geochemical and fluid inclusion data

The source, thermal maturity, and charge history of oil and gas condensate in the Baiyun depression and the Panyu lower uplift were determined using organic geochemical and fluid inclusion data. Nearly all the gas condensates and oil in the study area originated from Eocene Enping Formation source rocks, whereas the condensate fluids in the eastern area originated from the Enping and Zhuhai Formations. The condensate fluids have a relatively low thermal maturity with a calculated vitrinite reflectance equivalent that typically ranges from 0.8% to 1.0% based on the C29 sterane isomerization ratios and aromatic hydrocarbon maturity parameters. Four types of oil inclusions with various fluorescence colors (yellow–blue) and API gravities (25°–44°) were recognized in the Oligocene and lower Miocene reservoir units, which suggest multiple oil charging events. The homogenization temperatures of the fluid inclusions recorded the oil charge events accompanying large-scale hot fluid movement, which was most likely caused by the charging of high-temperature natural gas from the deeper Wenchang Formation. The trapping pressures of the oil inclusions and the reconstructed burial histories were used to determine the timing of oil charge. The main oil charge occurred from 16–7 Ma throughout the Baiyun depression and Panyu lower uplift, whereas the Panyu lower uplift experienced an additional oil charge from 5–0 Ma. The natural gas charge occurred during the main oil charging period and may continue to the present day. Multiple physical processes, such as gas injection (without gas exsolution), gas washing (with gas exsolution), and migration fractionation, have played important roles in gas condensate formation and controlling the petroleum distribution in the Baiyun depression and Panyu lower uplift.

Paleo-pressure evolution and its origin in the Pinghu slope belt of the Xihu Depression, East China Sea Basin

Abstract The Xihu Depression in the East China Sea Basin is one of the prime gas and light oil-producing regions of eastern China. Overpressure evolution and origin in the sandstone reservoirs of the Pinghu (E2p) Formation in the Pinghu slope belt of the Xihu Depression were investigated through a combination of fluid inclusion analyses and basin numerical modeling, combined with measured pore pressures (drill stem and wireline formation tests), well loggings, gas geochemistry, and casting thin section data. Four oil inclusion types, exhibiting different API gravities and hydrocarbon gas inclusions, were identified, using inclusion petrography, microscopic fluorescence, and Raman spectra. Homogenization and ice melting temperatures of coeval aqueous inclusions, determined using microthermometry, combined with burial-thermal histories determined by basin numerical modeling, suggested multiple episodes of oil and natural gas charge in the E2p reservoirs, from the Miocene to the present day. Pore pressure evolution history, reconstructed with fluid inclusion PVTx analysis, indicated that the Pinghu Formation experienced three phases: overpressure generation, followed by overpressure release, and then further overpressure generation. The first phase of weak overpressure was generated during burial in the middle–late Miocene. Currently, it is hard to definitely determine the origin of the first phase of overpressuring. Nevertheless, it can be speculated that the origin may be related to disequilibrium compaction, oil generation and tectonic compression based on burial, tectonic and hydrocarbon generation histories. Following this, a sudden uplift of formations led to overpressure release in the late Miocene, and then, the second phase of moderate overpressure generation occurred during burial in the late Pliocene and Quaternary. Based on well-log signatures, vitrinite reflectance data of mudstones and gas geochemistry, combining with seismic analysis, the second phase of overpressuring was interpreted to have been mainly caused by fluid expansion, which resulted from local gas generation by kerogen maturation and long-distance vertical and lateral pressure transfer.

Characteristics, diagenetic evolution, and controlling factors of the Es1 deep burial high‐quality sandstone reservoirs in the PG2 oilfield, Nanpu Sag, Bohai Bay Basin, China

Significant achievements have been reported for deep oil and gas exploration in the Bohai Bay Basin. Among them, the Nanpu Sag has achieved good deep (greater than 3.5 km) hydrocarbon exploration results. However, the hydrocarbon formation mechanisms and the diagenetic evolution of these high‐quality sandstone reservoirs remain unclear. Mineralogical, petrographic, and fluid inclusion data were selected to investigate the deeply buried sandstone reservoir physical properties, pore systems, and diagenetic features and the main formation mechanisms of the deep high‐quality reservoirs of the Es1 (the top member of the Paleogene Shahejie Formation) sandstones in the Nanpu Sag, eastern China. The results show that the Es1 sandstone reservoirs are dominated by lithic arkoses and have low porosities (average porosity 13.4%) but medium to high permeability (average permeability 188 mD). The pore systems consist of primary intergranular pores, secondary dissolution pores, and microfractures. Loss of porosity is greater due to compaction (average 20.89%) than due to cementation (average 4.82%), and dissolution contributes an improvement in porosity of approximately 5.85%. Two peaks in the inclusion homogenization temperatures were observed: The first fluid inclusion homogenization temperature term ranges from 130°C to 145°C and exhibits yellow fluorescence; the other peak occurs from 155°C to 165°C, showing green fluorescence. Eodiagenesis is due to mechanical compaction, precipitation of early calcite cements and quartz overgrowths, and dissolution of feldspar and carbonate cements. Mesodiagenesis occurs due to mechanical compaction, framework grain (mainly feldspar) dissolution, and precipitation of quartz and late carbonate cements. The main factors controlling the formation of the deep high‐quality reservoirs are the presence of a high hydrodynamic depositional environment (subaqueous distributary channel), the type of provenance (Archean granites), and the creation of secondary porosity by feldspar dissolution.

Characteristics, formation periods and genetic mechanisms of tectonic fractures in the tight gas sandstones reservoir: A case study of Xujiahe Formation in YB area, Sichuan Basin, China

The main target for hydrocarbon exploration of terrestrial strata in Sichuan Basin is the tight gas sandstone reservoir of the Upper Triassic Xujiahe Formation. Xujiahe Formation in YB area is a major discovery of hydrocarbon exploration in recent years, which is characterized as tight with ultralow porosity, ultralow permeability, and intensive heterogeneity. The tectonic fractures have important influence on accumulation and productivity of gas in the area. In the paper, analysis data of outcrop, core, imaging logging and other experiments were used to determine the characteristics, formation periods and genetic mechanisms of tectonic fractures. There are mainly high-angle and low-angle shear fractures in the area, which caused by tectonic stress. The length of the fractures is mainly 0–4 m from the outcrop and 10–20 cm from the cores and fracture frequencies (number per meter) is mostly 2-7 m−1, 2-4 m−1 respectively. The fracture fillings are mainly calcite, argillaceous and carbonaceous, about 60% of the fractures is unfilled or incompletely filled. Without considering the diagenetic fractures, there are three periods of the fractures: the middle-late Yanshanian tectonic movement, the early-middle Himalaya tectonic movement and the late Himalaya tectonic movement. The first period of the fractures are mainly filled with fine calcite, homogenization temperature of inclusion is 75–85 °C and the maximum effective principal stress of paleostress is 71.64 Mpa. The second period of the fractures are half-filled (or unfilled) with coarse calcite, homogenization temperature of inclusion is 150–175 °C and the maximum effective principal stress of paleostress is 74.91 Mpa. The third period of the fractures are low filling degree and cuts formed fractures clearly, the maximum effective principal stress of paleostress is 86.52 Mpa. For these tectonic movement, there are four sets of the plane “X” shear fractures in the area: NE strike fractures, NW strike fractures, NEE strike fractures, SN strike fractures. There are one set of the profile shear fractures of NWW strike. Finally, the complex fault system of nearly NS, NW and NE strike are formed in YB area.

Impact of Differential Densification on the Pore Structure of Tight Gas Sandstone: Evidence from the Permian Shihezi and Shanxi Formations, Eastern Sulige Gas Field, Ordos Basin, China

The tight sandstone reservoirs of the Permian Shihezi and Shanxi Formation with strong heterogeneity constitute the main producing zone of the eastern Sulige gas field. The process of differential densification results in various reservoir qualities. Mineral composition, structural characteristic, pore system, and diagenesis were investigated with analyses of well logs, thin sections, porosity, and horizontal permeability of the core plugs; environmental scanning electron microscopy (ESEM); nuclear magnetic resonance (NMR); X-ray computed tomography (X-CT); and fluid inclusion homogenization temperature. The results show that lithic sandstone reservoirs experienced complex and various diagenetic evolutions. Eight types of densification modes can be divided according to the diagenesis paths; these modes represent lithofacies with different densification times and reservoir qualities. Intense mechanical compaction is the main reason for the formation of lithofacies 1, 2, and 5. Lithofacies 4, 6, and 7 formed due to intense cementation, increasing the impermeability of the diagenetic system. The primary pore space in lithofacies 3 is preserved due to the overpressure and chlorite coatings. The dissolution and weak cementation of lithofacies 8 contribute to reservoir development. The middle-lower part of braided channel lags and channel bars, the middle part of meandering riverbed lags, and the middle part of point bars are favourable for reservoir development.

3D-Basin Modeling of the Changling Depression, NE China: Exploring Petroleum Evolution in Deep Tight Sandstone Reservoirs

The Changling Depression is the largest and most resource-abundant reservoir in the South Songliao Basin, NE China. The petroleum evolution rules in the Lower Cretaceous deep tight sandstone reservoir are unclear. In this study, 3D basin modeling is performed to analyze the large-scale petroleum stereoscopic migration and accumulation history. The Changling Depression has a complex fault system and multiple tectonic movements. The model is calibrated by the present formation temperatures and observed maturity (vitrinite reflectance). We consider (1) three main erosion episodes during the burial history, one during the Early Cretaceous and two during the Late Cretaceous; (2) the regional heat flow distribution throughout geological history, which was calibrated by abundant measurement data; and (3) a tight sandstone porosity model, which is calibrated by experimental petrophysical parameters. The maturity levels of the Lower Cretaceous source rocks are reconstructed and showed good gas-generation potential. The highest maturity regions are in the southwestern sag and northern sag. The peak hydrocarbon generation period contributed little to the reservoir because of a lack of seal rocks. Homogenization temperature analysis of inclusions indicated two sets of critical moments of gas accumulation. The hydrocarbon filling in the Haerjin and Shuangtuozi structures occurred between 80 Ma and 66 Ma, while the Dalaoyefu and Fulongquan structures experienced long-term hydrocarbon accumulation from 100 Ma to 67 Ma. The homogenization temperatures of the fluid inclusions may indicate a certain stage of reservoir formation and, in combination with the hydrocarbon-accumulation simulation, can distinguish leakage and recharging events.

3D-Basin Modelling of the Lishui Sag: Research of Hydrocarbon Potential, Petroleum Generation and Migration

The Lishui Sag is located in the southeastern part of the Taibei Depression, in the East China Sea basin, where the sag is the major hydrocarbon accumulation zone. A three dimensional modelling approach was used to estimate the mass of petroleum generation and accumulated during the evolution of the basin. Calibration of the model, based on measured maturity (vitrinite reflectance) and borehole temperatures, took into consideration two main periods of erosion events: a late Cretaceous to early Paleocene event, and an Oligocene erosion event. The maturation histories of the main source rock formations were reconstructed and show that the peak maturities have been reached in the west central part of the basin. Our study included source rock analysis, measurement of fluid inclusion homogenization temperatures, and basin history modelling to define the source rock properties, the thermal evolution and hydrocarbon generation history, and possible hydrocarbon accumulation processes in the Lishui Sag. The study found that the main hydrocarbon source for the Lishui Sag are argillaceous source rocks in the Yueguifeng Formation. The hydrocarbon generation period lasted from 58 Ma to 32 Ma. The first period of hydrocarbon accumulation lasted from 51.8 Ma to 32 Ma, and the second period lasted from 23 Ma to the present. The accumulation zones mainly located in the structural high and lithologic-fault screened reservoir filling with the hydrocarbon migrated from the deep sag in the south west direction.

Geochemical characteristics of tight sandstone gas and hydrocarbon charging history of Linxing area in Ordos Basin, China

Abstract Genetic type, source, charging history and reasons for secondary biogenic transformation of tight sandstone gas in the Linxing area in China's Ordos Basin have been studied through a combined analysis of gas compositions, isotopes of alkane and carbon dioxide, fluid inclusions and basin simulation. Tight sandstone gas in this area is predominated by methane, and the dryness coefficient is between 0.864 and 0.997 (average = 0.969). The δ13C1 values of methane and ethane in this area range from −44.5‰ to −33.2‰ (average = −39.4‰) and from −27.5‰ to −24.4‰ (average = −25.9‰), respectively. The non-hydrocarbon gases are nitrogen, followed by carbon dioxide and argon, and δ13C of carbon dioxide ranges from −14.6‰ to 8.6‰. The homogenization temperatures of gas and gas-liquid inclusions in P2s and C3t in Linxing range from 80 °C to 170 °C, which are concentrated at 120–130 °C. The identification of gas origin indicates that tight sandstone gas is coal-type gas, which is mainly due to thermal evolution, followed by the mixing of secondary biogenic gas. Geological conditions and gas geochemical characteristics suggest that tight sandstone gas was produced by coal seam and carbonaceous shale in Upper Paleozoic in the Linxing area. The homogenization temperature of inclusion reflects the continuous accumulation process of tight sandstone gas, and the Cretaceous was the main period for gas charging. The monoclinal structure, maturity of source rocks and activity of underground water in this area are the important factors for secondary biogenic gas formation.

Stratigraphic and Structural Control on Hydrothermal Dolomitization in the Middle Permian Carbonates, Southwestern Sichuan Basin (China)

The Qixia Formation and Maokou Formation of Middle Permian in the southwestern Sichuan Basin were pervasively dolomitized during the diagenetic history. Petrographically, four types of dolomites, namely three replacive dolomites (Rd1, Rd2, and Rd3) and one dolomite cement (Cd), were distinguished. Rd1 dolomite occurs as very fine (&lt;50 µm), planar-s to nonplanar crystals; Rd2 dolomite shows planar-e to planar-s crystal shapes with fine crystal sizes (50–250 µm) and is characterized by center-frog and margin-clear; Rd3 dolomite occurs as medium to coarse (250 µm–2 mm), nonplanar crystals; and Cd dolomite is characterized by saddle crystals filling dissolution pores and/or fractures, translucent white color in the hand samples, and strong sweeping extinction under cross-polarized light. In areas close to reactivated basement faults (Zhangcun outcrop and well Hanshen1), Rd3 (~65% by abundance) was the dominant type of replacement dolomite and minor amounts of Rd1 and Rd2 (~10%) were found in this area. Cd (~25%) was extensively developed in fractures and dissolution pores, whereas, in areas far away from the fault zones (Xinjigu outcrop), Rd1 (~20%) and Rd2 (~55%) were dominant replacement dolomites, and only a small portion of them were recrystallized to form Rd3 (~20%), with minor Cd (~5%) dolomite occurring in some dissolution pores. The δ13CV-PDB (−0.37‰ to 4.32‰) and δ18OV-PDB values (−7.41‰ to −5.19‰), 87Sr/86Sr ratios (0.707085 to 0.707795), and rare earth elements (REE) patterns (flat REE patterns with slight light rare earth element (LREE) enrichment and slight negative Ce anomalies) suggest that Rd1 dolomite was formed penecontemporaneously in an evaporitic tidal flat evaporation environment with salinities higher than seawater. The Rd2 dolomite, characterized by δ13CV-PDB (−0.18‰ to 4.89‰) and δ18OV-PDB values from −6.6‰ to −5.5‰, 87Sr/86Sr ratios from 0.707292 to 0.707951, and LREE enrichment and slight negative Ce anomalies, was interpreted as forming from the recrystallization of Rd1 at shallow burial. The δ18OV-PDB values (−12.01‰ to −8.23‰), the prominent positive anomaly of Eu, high 87Sr/86Sr ratios (0.7081–0.7198) and high fluid inclusion homogenization temperatures (149–255 °C) suggest that Rd3 and Cd dolomite were formed from hot fluids. Based on regional stratigraphic data, the Rd3 and Cd were likely formed at depths less than 1500 m; thus, the ambient burial temperature would be lower than 85 °C. The high fluid temperatures recorded by fluid inclusions, thus, indicate that the dolomitization was of hydrothermal nature. The δ18OV-SMOW values, homogenization temperatures, and salinities of the fluid inclusions of Rd3 and Cd in proximal areas were systematically higher than those in distal areas, suggesting that the hydrothermal fluid ascended along faults in proximal areas and then migrated laterally along the strata to distal areas. The dolomites of the Middle Permian carbonates in the southwestern Sichuan Basin, thus, resulted from different dolomitization phases, and the latter hydrothermal dolomitization was controlled by a combination of strata and structures.