The petroleum resource potential of the Bering Sea region

The Bering Sea sedimentary basin comprises the Bering Sea and the adjacent intermontane depressions on the continents. It includes the following subordinate sedimentary basins: the Norton; Bethel; Saint Lawrence; Anadyr; Navarin; Khatyrka; Saint George; Bristol; Cook Inlet; and Aleutian consisting of the autonomous Aleutian, Bowers, and Komandor basins. All of them exhibit significant geological similarity. The Middle and Upper Miocene terrigenous sequences, which are petroliferous through the entire periphery of the Pacific Ocean, are characterized by their high petroleum resource potential in the Bering Sea continental margin as well, which is confirmed by the oil and gas pools discovered in neighboring onshore lowlands. The younger (Pliocene) and older (up to Upper Cretaceous) sedimentary formations are also promising with respect to hydrocarbons. The integral potential oil and gas resources of the Bering Sea sedimentary basin, including the continental slopes, are estimated by the US Geological Survey to be 1120 × 10⁶ t and 965 × 10⁹ m³, respectively.     

Greenhouse gases generated from the anaerobic biodegradation of natural offshore asphalt seepages in southern California

Significant offshore asphaltic deposits with active seepage occur in the Santa Barbara Channel offshore southern California. The composition and isotopic signatures of gases sampled from the oil and gas seeps reveal that the coexisting oil in the shallow subsurface is anaerobically biodegraded, generating CO₂ with secondary CH₄ production. Biomineralization can result in the consumption of as much as 60% by weight of the original oil, with ¹³C enrichment of CO₂. Analyses of gas emitted from asphaltic accumulations or seeps on the seafloor indicate up to 11% CO₂ with ¹³C enrichment reaching +24.8‰. Methane concentrations range from less than 30% up to 98% with isotopic compositions of –34.9 to –66.1‰. Higher molecular weight hydrocarbon gases are present in strongly varying concentrations reflecting both oil-associated gas and biodegradation; propane is preferentially biodegraded, resulting in an enriched ¹³C isotopic composition as enriched as –19.5‰. Assuming the 132 million barrels of asphaltic residues on the seafloor represent ~40% of the original oil volume and mass, the estimated gas generated is 5.0×10¹⁰ kg (~76×10⁹ m³) CH₄ and/or 1.4×10¹¹ kg CO₂ over the lifetime of seepage needed to produce the volume of these deposits. Geologic relationships and oil weathering inferences suggest the deposits are of early Holocene age or even younger. Assuming an age of ~1,000 years, annual fluxes are on the order of 5.0×10⁷ kg (~76×10⁶ m³) and/or 1.4×10⁸ kg for CH₄ and CO₂, respectively. The daily volumetric emission rate (2.1×10⁵ m³) is comparable to current CH₄ emission from Coal Oil Point seeps (1.5×10⁵ m³/day), and may be a significant source of both CH₄ and CO₂ to the atmosphere provided that the gas can be transported through the water column.     

澳大利亚西北陆架盆地天然气水合物成矿地质条件及资源潜力

澳大利亚西北陆架盆地已被证实具有丰富的油气资源,而天然气水合物的相关研究尚未开展。本文利用天然气水合物地震识别技术,同时结合对澳大利亚西北陆架盆地天然气水合物成矿地质条件的分析,认为澳大利亚西北陆架盆地天然气水合物储量巨大,初步估计天然气水合物分布区蕴含甲烷量达18万亿m3。澳大利亚西北陆架盆地的构造演化是天然气水合物成藏所具备物化条件的基础,因此是天然气水合物成矿的重要影响因素之一。     

Observations of the Karimata Strait througflow from December 2007 to November 2008

In order to quantitatively estimate the volume and property transports between the South China Sea and Indonesian Seas via the Karimata Strait, two trawl-resistant bottom mounts, with ADCPs embedded, were deployed in the strait to measure the velocity profile as part of the South China Sea-Indonesian Seas transport/exchange (SITE) program. A pair of surface and bottom acoustic modems was employed to transfer the measured velocity without recovering the mooring. The advantage and problems of the instruments in this field work are reported and discussed. The field observations confirm the existence of the South China Sea branch of Indonesian throughflow via the Karimata Strait with a stronger southward flow in boreal winter and weaker southward bottom flow in boreal summer, beneath the upper layer northward (reversal) flow. The estimate of the averaged volume, heat and freshwater transports from December 2007 to March 2008 (winter) is (-2.7 ± 1.1) × 10 6 m3/s, (-0.30 ± 0.11) PW, (-0.18 ± 0.07) × 106m3/s and from May to September 2008 (summer) is (1.2 ± 0.6) × 106m3/s, (0.14 ± 0.03) PW, (0.12 ± 0.04) × 106m3/s and for the entire record from December 2007 to October 2008 is (-0.5 ± 1.9) × 10 6 m3/s, (-0.05 ± 0.22) PW, (-0.01 ± 0.15) × 106m3/s (negative/positive represents southward/northward transport), respectively. The existence of southward bottom flow in boreal summer implies that the downward sea surface slope from north to south as found by Fang et al. (2010) for winter is a year-round phenomenon.     

南太平洋地区盆地形成演化和油气资源潜力分析

本文从南太平洋地区区域构造演化出发,开展盆地类型划分和石油地质条件分析,了解不同类型盆地的油气成藏特征,并分析油气分布规律和资源潜力,以期对未来油气勘探开发国际合作选区提供借鉴。研究表明:（1）南太平洋地区经历了亨特-鲍恩造山运动、澳大利亚板块与南极洲板块分离、塔斯曼海扩张及珊瑚海扩张、巴布亚新几内亚地区的洋壳俯冲和弧-陆碰撞作用,最终形成了澳大利亚东部南缘和海域及新西兰地区以裂谷盆地为主、澳大利亚东部内陆以克拉通盆地为主的包括晚二叠世-三叠纪前陆盆地、古近纪-新近纪前陆盆地、古近纪-现今弧前盆地和弧后盆地6种盆地类型;（2）澳大利亚内陆南缘和东部海域以及新西兰地区裂谷盆地分布广泛,裂谷盆地油气最为富集,但内陆和海域有所差异,内陆南缘裂谷盆地油气资源丰富且石油与天然气的比值约为2:1,而东部海域裂谷盆地因油气成藏条件差,尚无油气发现;（3）根据盆地的剩余可采储量和远景资源量对南太平洋地区的资源潜力进行分析,认为白垩纪-古近纪裂谷盆地和古近纪-新近纪前陆盆地油气资源潜力最大,并优选出吉普斯兰（Gippsland）、塔拉纳基（Taranaki）和巴布亚（Papua）3个有利盆地。     

南海表层沉积物中铂族元素的地球化学分布特征及其影响因素

报道了南海表层沉积物中铂族元素的丰度及其分布特征。52个表层沉积物中铂族元素(PGE)含量变化范围:钌为0.40×10-9~3.20×10-9,平均值为1.20×10-9;钯为0.01×10-9~13.30×10-9,平均值为4.31×10-9;铱为0.59×10-9~4.49×10-9,平均值为1.21×10-9;铂为1.27×10-9~16.21×10-9,平均值为5.26×10-9;铑为0.05×10-9~0.2×10-9,平均值为0.12×10-9;金为0.43×10-9~27.38×10-9,平均值为6.92×10-9。尽管PGE含量与沉积物平均粒径的关系不是很明显,但是整体上随平均粒径的增大,PGE含量出现逐渐减少的趋势,表现出一定的粒度控制规律。南海全海域表层沉积物铂、钯、钌、铑、铱和金的估算背景值分别为1.168×10-9±0.190×10-9,3.228×10-9±0.403×10-9,1.085×10-9±0.189×10-9,4.432×10-9±0.258×10-9,0.123×10-9±0.023×10-9和4.720×10-9±0.413×10-9,远高于我国大陆东部地壳的,而与深海沉积物的基本处于同一水平,表现出了海洋沉积物富集PGE的固有特征。尽管PGE在大陆架区有所富集,但明显富集区主要分布在吕宋岛以西至中央海盆区域,指示海底火山喷发作用释放的PGE对南海中西部深海盆区沉积物中的PGE可能有重要贡献。     

Integrated gravity and magnetic study on patterns of petroleum basin occurrence in the China seas and adjacent areas

The China seas and adjacent areas contain numerous petroleum basins. One of the main challenges for future oil and gas exploration is to identify the inherent patterns of petroleum basin distribution. The formation and evolution of petroleum basins along with the migration and accumulation of oil and gas are often closely related to the tectonic environment. The gravity and magnetic fields with high lateral resolution and wide coverage provide important data for regional tectonic research. Based on the gravity data in the Global Satellite Gravity Anomaly Database (V31.1) and magnetic data from the Earth Magnetic Anomaly Grid (2-arc-minute resolution) (V2), this study uses integrated gravity and magnetic field technique to obtain integrated gravity and magnetic field result for the China seas and adjacent areas, and then adopts the normalized vertical derivative of the total horizontal derivative technique to conduct partition. Finally, it identifies the relationship between the partition characteristics and tectonics as well as the patterns of petroleum basin occurrence. The research shows that the partition of gravity and magnetic field integrated result has a good correlation with the Neo-Cathaysian tectonic system and tectonic units. The petroleum basins are characterized according to three blocks arranged from north to south and four zones arranged from east to west. The north?south block structure causes the uneven distribution of oil and gas resources in the mainland area and the differences in the hydrocarbon-bearing strata. Petroleum basins are more abundant in the north than in the south. The ages of the main oil- and gas-bearing strata are “Paleozoic–Mesozoic, Paleozoic–Mesozoic–Cenozoic, and Paleozoic–Mesozoic”, in order from north to south. The difference in the overall type of oil and gas resources in all basins is controlled by the east–west zonation. From east to west, the oil and gas resource type exhibits a wave-like pattern of “oil and gas, gas, oil and gas, gas”. The vertical distribution is characterized by an upper oil (Mesozoic–Cenozoic) and lower gas (Mesozoic–Paleozoic) structure. Within the study area, the Paleozoic marine strata should be the main strata of future natural gas exploration.     

Nutrient fluxes to the Bay of Biscay from Cantabrian rivers (Spain)

Nutrient fluxes to the Bay of Biscay from the Cantabrian basin have been quantified for the first time. Data between 1981 and 1995 of the main 16 Cantabrian rivers from the COCA monitoring programme have been used. Values of water flow and dissolved inorganic nitrogen (DIN), phosphate and silicate concentrations have been taken. Equations are proposed to quantify the fluvial nutrient contributions to the Cantabrian Sea. The annual average of continental outputs to the Bay of Biscay from the Cantabrian basin is 16.1 × 10⁹ m³ of freshwater, 1.0 × 10⁹ mol of N in DIN, 0.062 × 10⁹ mol of phosphate and 1.2 × 10⁹ mol of silicate. In comparison with the French rivers, those of the Cantabrian have small fluxes and their outflow is very disperse, not forming large coastal plumes. From April to September, when the primary production is relatively important, the DIN contribution to the Cantabrian coastal reservoir is 10%. Coastal fertilisation due to continental waters could be considered as negligible and only influences areas very close to river mouths, except for the Nalón River. Its flux represents 33 % of nitrate, 39 % of phosphate and 15 % of silicate of the total continental inputs of nutrients to the Cantabrian Sea.     

Heat flow derived from BSR and its implications for gas hydrate stability zone in Shenhu Area of northern South China Sea

Bottom simulating reflectors (BSRs), known as the base of gas hydrate stability zone, have been recognized and mapped using good quality three-dimensional (3D) pre-stack migration seismic data in Shenhu Area of northern South China Sea. Additionally, seismic attribute technique has been applied to better constrain on the distribution of gas hydrate. The results demonstrate that gas hydrate is characterized by “blank” zone (low amplitude) in instantaneous amplitude attribute. The thickness of gas hydrate stability zone inferred from BSR ranges from 125 to 355 m with an average of 240 m at sea water depth from 950 to 1,600 m in this new gas hydrate province. The volume of gas in-place bound in hydrate is estimated from 1.7 × 10⁹ to 4.8 × 10⁹ m³, with the most likely value of around 3.3 × 10⁹ m³, using Monte Carlo simulation. Furthermore, geothermal gradient and heat flow are derived from the depths of BSRs using a conductive heat transfer model. The geothermal gradient varies from 35 to 95°C km⁻¹ with an average of 54°C km⁻¹. Corresponding heat flow values range from 43 to 105 mW m⁻² with an average of 64 mW m⁻². By comparison with geological characteristics, we suggest that the distribution of gas hydrate and heat flow are largely associated with gas chimneys and faults, which are extensively distributed in Shenhu Area, providing easy pathways for fluids migrating into the gas hydrate stability zone for the formation of gas hydrate. This study can place useful constraints for modeling gas hydrate stability zone from measured heat flow data and understanding the mechanism of gas hydrate formation in Shenhu Area.     

Oil and gas bearing in Norwegian Sea basins

The Norwegian passive continental margin is represented by an extensive gentle shelf and continental slope. On the continental slope, there are the isolated Vøring, Møre and Ras basins, the Halten Terrace is situated to the east of them at the shelf, then the Nordland submarine ridge and the Trondelag Platform at the seaboard. There are Paleozoic, Mesozoic and Cenozoic sediments in its sections. Two complex structures are clearly distinguished in the sedimentary section: the lower stage (up to the Upper Cretaceous), reflecting the rifting structure of the basins, broken by a system of dislocations to a series of horsts, grabens, and separated blocks; and the upper stage, poorly dislocated, like a mantle covering the lower stage, with erosion and sharp unconformity. The Halten Terrace is the principal oil and gas production basin. At present, there are more than 50 oil, gas, and condensate fields in it. The following particularities have been discovered: than the field lays in the deepwater, than the age of the hydrocarbon pay is younger. It is also interesting that all gas fields are situated in the Vøring and Møre basins and western part of the Halten Terrace; the oil and gas fields, mainly at the center of the Halten Terrace; but pure oil fields, in the north of the terrace. In conformity with discovering the particularities, it is possible to say that the prospects of oil and gas bearing in the Norwegian Sea are primarilyt related to the Halten Terrace and the Vøring and Møre basins, especially the territories situated at the boundary of the two basins, where it is possible to discover large hydrocarbon accumulations like the Ormen-Lange field, because the Paleocene-Upper Cretaceous productive turbidite thick at the boundary of these basins is on the continental slope, which is considered promising a priori.     

A laboratory study on capillary sealing efficiency of Iranian shale and anhydrite caprocks

Caprock has the most important role in the long term safety of formation gas storage. The caprocks trap fluid accumulated beneath, contribute to lateral migration of this fluid and impede its upward migration. The rapid upward passage of invasive plumes due to buoyancy pressure is prevented by capillary pressure within these seal rocks. In the present study, two main seal rocks, from the Zagros basin in the southwest of Iran, a shale core sample of Asmari formation and an anhydrite core sample of Gachsaran formation, were provided. Absolute permeabilities of shale and anhydrite cores, considering the Klinkenberg effect, were measured as 6.09 × 10⁻¹⁸ and 0.89 × 10⁻¹⁸ m², respectively. Capillary sealing efficiency of the cores was investigated using gas breakthrough experiments. To do so, two distinct techniques including step by step and residual capillary pressure approaches were performed, using carbon dioxide, nitrogen and methane gases at temperatures of 70 and 90 °C, under confining pressures in the range 24.13–37.92 MPa. In the first technique, it was found that capillary breakthrough pressure of the cores varies in the range from 2.76 to 34.34 MPa. Moreover, the measurements indicated that after capillary breakthrough, gas effective permeabilities lie in range 1.85 × 10⁻²¹ – 1.66 × 10⁻¹⁹ m². In the second technique, the minimum capillary displacement pressure of shale varied from 0.66 to 1.45 MPa with the maximum effective permeability around 7.76 × 10⁻²¹ – 6.69 × 10⁻²⁰ m². The results indicate that anhydrite caprock of the Gachsaran formation provides proper capillary sealing efficacy, suitable for long term storage of the injected CO₂ plumes, due to its higher capillary breakthrough pressure and lower gas effective permeability.     

A seasonal comparison of prokaryote numbers,biomass and heterotrophic productivity in waters of the KwaZulu-Natal Bight,South Africa

The KwaZulu-Natal Bight is a shallow indentation of the eastern seaboard of South Africa, characterised by a narrow (45 km wide) extension of the continental shelf, with a shelf break at about 100 m. It has a complex hydrography: the waters of the bight are derived from the fast-flowing, southward-trending Agulhas Current, which is fed mostly by the tropical and subtropical surface waters of the South-West Indian Ocean subgyre, which are generally oligotrophic in nature, notably depleted in reduced nitrogen and phosphate except at river mouths and during periodic upwelling of deeper nutrient-rich water. Despite this, the bight is believed to be relatively productive, and it is suggested that efficient nutrient recycling by prokaryotes may sustain primary productivity efficiently, even in the absence of new nutrient inputs. Here we have measured bacterial numbers, biomass and heterotrophic productivity during summer and winter in conjunction with phytoplankton standing stock and factors that influence it. Bacterial distribution closely matched phytoplankton distribution in surface waters, and was highest close to the coast. Bacterial standing stocks were similar to those of oligotrophic systems elsewhere (0.5–5.0 × 10⁵ cells ml^–1; 1 × 10^–8 to 1.25 × 10^–7 g C ml^–1) and increased in association with the development of phytoplankton blooms offshore and with inputs of allochthonous material by rivers at the coast. Heterotrophic productivity in summer was lowest in the far south and north of the bight (0.5 × 10^–10 g C ml^–1 h^–1) but higher close to the shore, over shallow banks, and in association with increased phytoplankton abundance over the midshelf (1.0–3.5 × 10^–9 g C ml^–1 h^–1). There were marked seasonal differences with lower bacterial standing stocks (5 × 10⁴ to 2 × 10⁵ cells ml^–1; 4–5 × 10^–9 to 1–2 × 10^–8 g C ml^–1) and very low bacterial productivity (4 × 10^–11 to 1 × 10^–10 g C ml^–1 h^–1) in winter, probably resulting from lowered rates of primary productivity and dissolved organic matter release as well as reduced riverine allochthonous inputs during the winter drought.     

Gravity crustal models and heat flow measurements for the Eurasia Basin,Arctic Ocean

The Gakkel Ridge in the Arctic Ocean with its adjacent Nansen and Amundsen Basins is a key region for the study of mantle melting and crustal generation at ultraslow spreading rates. We use free-air gravity anomalies in combination with seismic reflection and wide-angle data to compute 2-D crustal models for the Nansen and Amundsen Basins in the Arctic Ocean. Despite the permanent pack-ice cover two geophysical transects cross both entire basins. This means that the complete basin geometry of the world’s slowest spreading system can be analysed in detail for the first time. Applying standard densities for the sediments and oceanic crystalline crust, the gravity models reveal an unexpected heterogeneous mantle with densities of 3.30 × 10³, 3.20 × 10³ and 3.10 × 10³ kg/m³ near the Gakkel Ridge. We interpret that the upper mantle heterogeneity mainly results from serpentinisation and thermal effects. The thickness of the oceanic crust is highly variable throughout both transects. Crustal thickness of less than 1 km dominates in the oldest parts of both basins, increasing to a maximum value of 6 km near the Gakkel Ridge. Along-axis heat flow is highly variable and heat flow amplitudes resemble those observed at fast or intermediate spreading ridges. Unexpectedly, high heat flow along the Amundsen transect exceeds predicted values from global cooling curves by more than 100%.     

南极罗斯海重力场特征及莫霍面深度反演

本文基于中国南极考察第30航次、第32航次所获得的实测重力资料,结合NGDC资料,开展12个航次重力场数据的平差融合工作,全部386个交点平差后标准差减小为±1.53×10−5 m/s2,与卫星重力差值平均值为1.49×10−5 m/s2,均方差为±3.81×10−5 m/s2,并在此基础上采用频率域界面反演法计算莫霍面深度。研究发现,与沉积盆地对应重力异常低值相悖,在罗斯海北部盆地、维多利亚地盆地、中央海槽、东部盆地4个主要盆地腹地却表现为重力异常高值,跨度达100 km以上。莫霍面深度分布整体呈南深北浅之势,范围为10~28 km。伴随着罗斯海西部盆地的多次拉张及岩浆活动,该区域的地壳厚度和莫霍面深度高值和低值相间分布,并表现出越来越大的差异性。综合剖面结果表明,罗斯海重力异常值的长波长变化与莫霍面的起伏呈正相关关系,但是反演的莫霍面深度与区域重力场特征并非完全对应,所以岩浆底侵和地壳侵入仍不足以导致罗斯海盆地的重力异常或盆地几何形状。     

南海海域新生代沉积盆地的油气资源

南海新生代经历过大陆张裂与分离、海底扩张和地块碰撞等构造演化历史,南海北部为被动大陆边缘,南部是碰撞挤压边缘,东部为俯冲聚敛边缘,西部是走滑边缘。在这种构造体制下,形成了许多沉积盆地。北部和西部边缘上发育着张性沉积盆地和走滑拉张盆地;在南部边缘上,其北部发育着张性盆地,南部为挤压环境下形成的盆地,如前陆盆地、前孤盆地;东部边缘上发育着前孤盆地。目前油气勘探实践证明,南海南部的油气资源比北部丰富。究其原因,南海北部为被动大陆边缘,张性沉积盆地的烃源岩体积较小,而南部挤压环境下形成的沉积盆地的烃源岩体积大;北部的地热流较南部小,因此地温梯度也较小,故南部边缘烃源岩的成熟度比北部高;由于南部边缘处于挤压构造环境,在沉积盆地中形成了许多挤压构造,而北部边缘一直处于张性构造环境,形成的构造较少且较小;同时,南部边缘沉积盆地中,烃源岩生烃与构造形成在时间上搭配较好。因此,在南海南部边缘沉积盆地中形成了许多大型油气田,而南海北部边缘沉积盆地中,大型油气田较少,中小型油气田较多。     

Structure and oil and gas perspectives of the Californian borderland

The Californian borderland is the largest oil and gas region of the Pacific coast of the United States. Here, a series of large and minor sedimentary basins with established or inferred oil and gas bearing properties are recognized. The Californian borderland is located on a Nevadan-type active continental margin. The bodies of such margins are composed of giant accretion formations and occupy not only their underwater parts but also vast land areas. The accretion formations are dominated by rocks of a deep-water origin. The Californian borderland represents a system of basins and ranges that compose the underwater margin and the Coastal Ranges of California and the basement within the Great Valley. In the depressions of the accretion orogen, which are small in size but feature high subsidence rates, significant thicknesses of deposits are accumulated (up to 6?8 km). In the depressions of the Californian borderland, they are represented by young Neogene (rarer Eocene-Oligocene) formations of mainly terrigenous or siliceous-terrigenous compositions. The active tectonic regime resulted in a sharp reduction of the age range of the oil and gas bearing deposits, which are represented only by Late Cretaceous and Cenozoic rocks. Full-scale oil and gas production here is performed in the Santa Barbara-Ventura and Santa Maria basins. The principal oil and gas bearing unit is the Monterrey Formation of the Middle Miocene. By January 2006, the production on the Californian borderland comprised about 17.8 million tons of oil and over 1 billion m³ of gas. Up to 1.4 billion tons of oil and 200 billion m³ of gas reserves are regarded to be not recovered on the Pacific coast of the United States in the region of the Californian borderland.     

海平面变化对太湖流域排涝的影响

太湖流域位于长江三角洲地区,其排涝过程受长江口海平面变化及潮位变化的控制。本文采用一维河网非恒定流理论,建立了太湖流域河网水文模型,并对1991年太湖流域洪涝过程进行的模拟。在此基础上,假定当太湖流域发生1991年特大暴雨过程时,海平面上升0.5m和长江口发生了百年一遇高潮位,太湖最高水位可分别达到5.01m和4.99m,整个梅雨期排涝量分别比1991年少排14.9×10⁸m³和13.1×10⁸m³,加剧了该地区洪涝灾害的严峻程度。     

Increase in anthropogenic CO2 in the Atlantic Ocean in the last two decades

Data from the first systematic survey of inorganic carbon parameters on a global scale, the GEOSECS program, are compared with those collected during WOCE/JGOFS to study the changes in carbon and other geochemical properties, and anthropogenic CO₂ increase in the Atlantic Ocean from the 1970s to the early 1990s. This first data-based estimate of CO₂ increase over this period was accomplished by adjusting the GEOSECS data set to be consistent with recent high-quality carbon data. Multiple Linear Regression (MLR) and extended Multiple Linear Regression (eMLR) analyses to these carbon data are applied by regressing DIC with potential temperature, salinity, AOU, silica, and PO₄ in three latitudinal regions for the western and eastern basins in the Atlantic Ocean. The results from MLR (and eMLR provided in parentheses) indicate that the mean anthropogenic CO₂ uptake rate in the western basin is 0.70 (0.53) mol m^?2 yr^?1 for the region north of 15°N; 0.53 (0.36) mol m^?2 yr^?1 for the equatorial region between 15°N and 15°S; and 0.83 (0.35) mol m^?2 yr^?1 in the South Atlantic south of 15°S. For the eastern basin an estimate of 0.57 (0.45) mol m^?2 yr^?1 is obtained for the equatorial region, and 0.28 (0.34) mol m^?2 yr^?1 for the South Atlantic south of 15°S. The results of using eMLR are systematically lower than those from MLR method in the western basin. The anthropogenic CO₂ increase is also estimated in the upper thermocline from salinity normalized DIC after correction for AOU along the isopycnal surfaces. For these depths the results are consistent with the CO₂ uptake rates derived from both MLR and eMLR methods.     

Influence of the Moho surface distribution on the oil and gas basins in China seas and adjacent areas

Owing to the strategic significance of national oil and gas resources, their exploration and production must be prioritized in China. Oil and gas resources are closely related to deep crustal structures, and Moho characteristics influence oil and gas distribution. Therefore, it is important to study the relationship between the variation of the Moho surface depth undulation and hydrocarbon basins for the future prediction of their locations. The Moho depth in the study area can be inverted using the Moho depth control information, the Moho gravity anomaly, and the variable density distribution calculated by the infinite plate. Based on these results, the influences of Moho characteristics on petroleum basins were studied. We found that the Moho surface depth undulation deviation and crustal thickness undulation deviation in the hydrocarbon-rich basins are large, and the horizontal gradient deviation of the Moho surface shows a positive linear relationship with oil and gas resources in the basin. The oil-bearing mechanism of the Moho basin is further discussed herein. The Moho uplift area and the slope zone correspond to the distribution of oil and gas fields. The tensile stress produced by the Moho uplift can form tensile fractures or cause tensile fractures on the surface, further developing into a fault or depression basin that receives deposits. The organic matter can become oil and natural gas under suitable chemical and structural conditions. Under the action of groundwater or other dynamic forces, oil and natural gas are gradually transported to the uplift or the buried hill in the depression zone, and oil and gas fields are formed under the condition of good caprock. The research results can provide new insights into the relationship between deep structures and oil and gas basins as well as assist in the strategic planning of oil and gas exploration activities.     

Hydrocarbon generation and expulsion characteristics of Eocene source rocks in the Huilu area,northern Pearl River Mouth basin,South China Sea: Implications for tight oil potential

In recent years, new oil reservoirs have been discovered in the Eocene tight sandstone of the Huilu area, northern part of the Pearl River Mouth basin, South China Sea, indicating good prospects for tight oil exploration in the area. Exploration has shown that the Huilu area contains two main sets of source rocks: the Eocene Wenchang (E₂w) and Enping (E₂e) formations. To satisfy the requirements for further exploration in the Huilu area, particularly for tight oil in Eocene sand reservoirs, it is necessary to re-examine and analyze the hydrocarbon generation and expulsion characteristics. Based on mass balance, this study investigated the hydrocarbon generation and expulsion characteristics as well as the tight oil resource potential using geological and geochemical data and a modified conceptual model for generation and expulsion. The results show that the threshold and peak expulsion of the E₂w source rocks are at 0.6% vitrinite reflectance and 0.9% vitrinite reflectance, respectively. There were five hydrocarbon expulsion centers, located in the western, eastern, and northern Huizhou Sag and the southern and northern Lufeng Sag. The hydrocarbon yields attributed to E₂w source rocks are 2.4 × 10¹¹ tons and 1.6 × 10¹¹ tons, respectively, with an expulsion efficiency of 65%. The E₂e source rock threshold and peak expulsion are at 0.65% vitrinite reflectance and 0.93% vitrinite reflectance, respectively, with hydrocarbon expulsion centers located in the centers of the Huizhou and Lufeng sags. The yields attributed to E₂e source rocks are 1.1 × 10¹¹ tons and 0.2 × 10¹¹ tons, respectively, with an expulsion efficiency of 20%. Using an accumulation coefficient of 7%–13%, the Eocene tight reservoirs could contain approximately 1.3 × 10¹⁰ tons to 2.3 × 10¹⁰ tons, with an average of 1.8 × 10¹⁰ tons, of in-place tight oil resources (highest recoverable coefficient can reach 17–18%), indicating that there is significant tight oil potential in the Eocene strata of the Huilu area.