昭通示范区黄金坝气田五峰—龙马溪组页岩气储层地质特征

昭通国家级页岩气示范区黄金坝气田是继礁石坝和长宁—威远之后中国又一个在页岩气勘探、开发领域实现重大突破的地区,为了系统地展示黄金坝气田页岩气资源富集的储层条件,为未来的勘探工作提供参考,以五峰—龙马溪组页岩气储层为研究对象,从区域地质条件、储层岩石学、物性和地球化学4个方面对该页岩气储层进行了综合研究。结果表明稳定的区域构造和良好的顶底板条件是黄金坝地区页岩气资源富集的关键,良好的保存条件使储层维持了较高的压力(压力系数1);较高的孔隙度(平均4%)和TOC含量(目的层2%)提供了良好的储集空间,使储层具有较高的含气量(1.35~3.48 cm3/g,平均2.50 cm3/g);天然气地球化学数据表明,区内天然气主要成分为CH4(97%),其次还含有少量的C2H6、C3H8和CO2;天然气同位素数据表明烃类C同位素组成发生了倒转,表明储层具有良好的封闭性。但储层孔隙系统较为复杂,且非均质性极强,从而导致渗透率较低,在储层改造施工过程中应予以充分考虑。总体上,黄金坝气田具有较好的开发前景,生产测试表明,区内直井压裂产量为0.5×104~3.5×104m3/d/井,水平井压裂产量可达12×104~40×104m3/d/井。     

页岩气开采的相关实验、模型和环境效应

页岩气是一种重要的非常规天然气资源,正在改变世界能源、经济和政治格局。渗透率是评价页岩气藏商业开采可行性的重要参数之一,由于页岩的致密性,页岩气的流动机理不同于常规气藏,因此,页岩储层渗透率测试和页岩气流动模型已成为当前国际研究的热点课题之一。在对页岩气开采技术简单介绍的基础上,综述了页岩储层渗透率测试的试验和理论研究现状,分析了气体吸附对页岩渗透率的影响。阐述了页岩气流动模型的最新进展,分析了双重孔隙模型描述气体迁移的准确性,提出了描述均匀储层中页岩气解吸-扩散-渗流多级运移模型。评述了页岩气开采的温室效应和对地下水的影响,并简单介绍了适合页岩气开采的新技术即无水压裂开采技术,即采用CO2对页岩气藏分段压裂,同时将CO2埋存于废弃井中。最后,对页岩储层渗透率测试和页岩气流动模型研究的新发展以及无水压裂技术进行了展望。     

Geochemical and isotopic variations in shallow groundwater in areas of the Fayetteville Shale development,north-central Arkansas

Exploration of unconventional natural gas reservoirs such as impermeable shale basins through the use of horizontal drilling and hydraulic fracturing has changed the energy landscape in the USA providing a vast new energy source. The accelerated production of natural gas has triggered a debate concerning the safety and possible environmental impacts of these operations. This study investigates one of the critical aspects of the environmental effects; the possible degradation of water quality in shallow aquifers overlying producing shale formations. The geochemistry of domestic groundwater wells was investigated in aquifers overlying the Fayetteville Shale in north-central Arkansas, where approximately 4000 wells have been drilled since 2004 to extract unconventional natural gas. Monitoring was performed on 127 drinking water wells and the geochemistry of major ions, trace metals, CH₄ gas content and its C isotopes (δ¹³C_CH4), and select isotope tracers (δ¹¹B, ⁸⁷Sr/⁸⁶Sr, δ²H, δ¹⁸O, δ¹³C_DIC) compared to the composition of flowback-water samples directly from Fayetteville Shale gas wells. Dissolved CH₄ was detected in 63% of the drinking-water wells (32 of 51 samples), but only six wells exceeded concentrations of 0.5 mg CH₄/L. The δ¹³C_CH4 of dissolved CH₄ ranged from −42.3‰ to −74.7‰, with the most negative values characteristic of a biogenic source also associated with the highest observed CH₄ concentrations, with a possible minor contribution of trace amounts of thermogenic CH₄. The majority of these values are distinct from the reported thermogenic composition of the Fayetteville Shale gas (δ¹³C_CH4 = −35.4‰ to −41.9‰). Based on major element chemistry, four shallow groundwater types were identified: (1) low (<100 mg/L) total dissolved solids (TDS), (2) TDS > 100 mg/L and Ca–HCO₃ dominated, (3) TDS > 100 mg/L and Na–HCO₃ dominated, and (4) slightly saline groundwater with TDS > 100 mg/L and Cl > 20 mg/L with elevated Br/Cl ratios (>0.001). The Sr (⁸⁷Sr/⁸⁶Sr = 0.7097–0.7166), C (δ¹³C_DIC = −21.3‰ to −4.7‰), and B (δ¹¹B = 3.9–32.9‰) isotopes clearly reflect water–rock interactions within the aquifer rocks, while the stable O and H isotopic composition mimics the local meteoric water composition. Overall, there was a geochemical gradient from low-mineralized recharge water to more evolved Ca–HCO₃, and higher-mineralized Na–HCO₃ composition generated by a combination of carbonate dissolution, silicate weathering, and reverse base-exchange reactions. The chemical and isotopic compositions of the bulk shallow groundwater samples were distinct from the Na–Cl type Fayetteville flowback/produced waters (TDS ∼10,000–20,000 mg/L). Yet, the high Br/Cl variations in a small subset of saline shallow groundwater suggest that they were derived from dilution of saline water similar to the brine in the Fayetteville Shale. Nonetheless, no spatial relationship was found between CH₄ and salinity occurrences in shallow drinking water wells with proximity to shale-gas drilling sites. The integration of multiple geochemical and isotopic proxies shows no direct evidence of contamination in shallow drinking-water aquifers associated with natural gas extraction from the Fayetteville Shale.     

Characteristics of Shale Reservoir and Sweet Spot Identification of the Lower Cambrian Niutitang Formation in Northwestern Hunan Province,China

The accumulation and productivity of shale gas are mainly controlled by the characteristics of shale reservoirs;study of these characteristics forms the basis for the shale gas exploitation of the Lower Cambrian Niutitang Formation(Fm),Southern China.In this study,core observation and lithology study were conducted along with X-ray diffraction(XRD)and electronic scanning microscopy(SEM)examinations and liquid nitrogen(N_2)adsorption/desorption and CH_4 isothermal adsorption experiments for several exploration wells in northwestern Hunan Province,China.The results show that one or two intervals with high-quality source rocks(TOC2 wt%)were deposited in the deep-shelf facies.The source rocks,which were mainly composed of carbonaceous shales and siliceous shales,had high quartz contents(40 wt%)and low clay mineral(30 wt%,mainly illites)and carbonate mineral(20 wt%)contents.The SEM observations and liquid nitrogen(N_2)adsorption/desorption experiments showed that the shale is tight,and nanoscale pores and microscale fractures are well developed.BJH volume(V_(BJH))of shale ranged from 2.144×10~(-3) to 20.07×10~(-3) cm~3/g,with an average of11.752×10~(-3) cm~3/g.Pores mainly consisted of opened and interconnected mesopores(2–50 nm in diameter)or macropores(50 nm in diameter).The shale reservoir has strong adsorption capacity for CH_4.The Langmuir volume(V_L)varied from1.63 to 7.39 cm~3/g,with an average of 3.95 cm~3/g.The characteristics of shale reservoir are controlled by several factors:(1)A deep muddy continental shelf is the most favorable environment for the development of shale reservoirs,which is controlled by the development of basic materials.(2)The storage capacity of the shale reservoir is positively related to the TOC contents and plastic minerals and negatively related to cement minerals.(3)High maturity or overmaturity leads to the growth of organic pores and microfractures,thereby improving the reservoir storage capacity.It can be deduced that the high percentage of residual gas in Niutitang Fm results from the strong reservoir storage capacity of adsorbed gas.Two layers of sweet spots with strong storage capacity of free gas,and they are characterized by the relatively high TOCcontents ranging from 4 wt%to 8 wt%.     

Fingerprinting Marcellus Shale waste products from Pb isotope and trace metal perspectives

Drill cuttings generated during unconventional natural gas extraction from the Marcellus Shale, Appalachian Basin, U.S.A., generally contain a very large component of organic-rich black shale because of extensive lateral drilling into this target unit. In this study, element concentrations and Pb isotope ratios obtained from leached drill cuttings spanning 600 m of stratigraphic section were used to assess the potential for short and long term environmental impacts from Marcellus Shale waste materials, in comparison with material from surrounding formations. Leachates of the units above, below and within the Marcellus Shale yielded Cl/Br ratios of 100–150, similar to produced water values. Leachates from oxidized and unoxidized drill cuttings from the Marcellus Shale contain distinct suites of elevated trace metal concentrations, including Cd, Cu, Mo, Ni, Sb, U, V and Zn. The most elevated Mo, Ni, Sb, U, and V concentrations are found in leachates from the lower portion of the Marcellus Shale, the section typically exploited for natural gas production. In addition, lower ²⁰⁷Pb/²⁰⁶Pb ratios within the lower Marcellus Shale (0.661–0.733) provide a distinctive fingerprint from formations above (0.822–0.846) and below (0.796–0.810), reflecting ²⁰⁶Pb produced as a result of in situ ²³⁸U decay within this organic rich black shale. Trace metal concentrations from the Marcellus Shale leachates are similar to total metal concentrations from other black shales. These metal concentrations can exceed screening levels recommended by the EPA, and thus have the potential to impact soil and water quality depending on cuttings disposal methods.     

沁水盆地阳泉区块上古生界煤系页岩气储层特征

页岩储层特征是进行页岩气储集能力评价的基础内容。为探究高演化阶段煤系页岩气储层性质和优选有利储层,运用岩石热解、X射线衍射、扫描电子显微镜、高压压汞、低温N₂和CO₂气体吸附多种实验方法,对沁水盆地阳泉区块上古生界煤系页岩岩心样品进行储层特征研究。结果表明：沁水盆地阳泉区块上古生界煤系页岩,有机碳含量较高(TOC平均为4.9%),处于过成熟阶段(R_ran平均为2.32%),黏土矿物质量分数较高(平均为50.0%),具有低孔低渗的特征(孔隙率平均为6.61%,渗透率平均为0.006 3×10^–3μm²),孔隙类型以粒间孔、粒内孔和微裂缝为主,微米–纳米级孔隙为页岩气的赋存提供了储集空间;孔隙总孔容为0.025 5~0.051 7 mL/g,平均0.038 9 mL/g,总比表面积为12.64~40.98 m²/g,平均28.43 m²/g,微孔(<2 nm)、介孔(2~50 nm)的孔容与比表面积呈良好的正相关性,宏孔(>50 nm)孔容与比表面积则相关性不明显,表明微孔和介孔是阳泉区块煤系页岩气储集的主要载体。总体来说,阳泉区块上古生界煤系页岩具有较好的页岩气储集性能,但页岩储层可压裂性较差,影响页岩气的开发。     

南华北盆地太康隆起煤系页岩气地质特征及勘探潜力

基于南华北盆地上古生界煤系页岩气勘探实践及认识,通过研究该区页岩气烃源岩地球化学特征、储集层特征、含气性特征,总结页岩气地质特征,分析勘探潜力。页岩气主要发育于太原组、山西组,烃源岩有机质类型以Ⅲ型为主,镜质体反射率为2.1%~3.4%,处于过成熟阶段;太原组、山西组泥页岩有机碳含量均值分别为2.34%、1.66%;页岩气储集层矿物成分以石英、黏土矿物为主,主要储集空间类型为矿物质孔和微裂缝;太原组、山西组页岩含气量均值分别为1.73 m³/t、1.55 m³/t,相对于海相页岩含气特征属于中等—偏高的范围;采用容积法计算页岩气地质资源量为7112×10⁸m³,资源丰度为2.54×10⁸m³。经综合对比评价认为庄头斜坡、杞县凹陷是南华北盆地太康隆起页岩气较为有利的勘探目标区。     

鄂西宜昌地区寒武系常规、非常规天然气显示及勘探意义

鄂西寒武系具有良好的油气成藏条件,但由于地层时代早、经历构造运动次数多,勘探成果不理想。近期在宜昌地区寒武系水井沱组获得页岩气流,并在寒武系天河板组、石龙洞组等多套层系获得了天然气显示,表明鄂西宜昌地区是寒武系页岩气、天然气的有利勘探区。以储集层为核心划分出水井沱组页岩气、天河板组-石龙洞组常规天然气成藏组合。寒武系水井沱组页岩生烃潜力大、含气性高,以页岩中的有机质孔和微裂缝作为储集空间,构成自生自储的页岩气藏;水井沱组页岩气测试获工业气流,气体组分中甲烷含量超过90%。宜地2井天河板组发生井喷,气体成分以甲烷为主,储集空间主要为半充填状裂缝和溶孔,地层水为氯化镁型,保存条件中等。石龙洞组砂屑云岩储层具有累计厚度大、低孔中低渗并局部发育高孔渗段的特点。以水井沱组富有机质页岩为烃源岩,以天河板组灰岩裂缝和石龙洞组白云岩孔洞为储集空间,以覃家庙组含膏云岩和云质膏岩为盖层,组成垂向供烃的生储盖组合。油气成藏演化史分析表明,寒武系烃源岩在早志留世开始生油,早二叠世开始生气,晚三叠世达到生气高峰期,经历了多期次构造运动的改造,现全部转化为气态烃。宜昌地区为页岩气有利区,也是天河板组-石龙洞组常规天然气勘探的有利区。上述认识对鄂西地区寒武系天然气勘探领域的拓展具有重要指导意义。     

Discovery and Analysis of Shale Gas in a Carboniferous Reservoir and its Enrichment Characteristics in the Northern Nanpanjiang Depression,Guizhou Province,China

Shale gas resources are considered to be extremely abundant in southern China, which has dedicated considerable attention to shale gas exploration in recent years. Exploration of shale gas has considerably progressed and several breakthroughs have been made in China. However, shale gas explorations are still scarce. Summary and detailed analysis studies on black shale reservoirs are still to be performed for many areas. This lack of information slows the progress of shale gas explorations and results in low quantities of stored black shale. The Carboniferous Dawuba Formation, which is widely distributed and considerably thick, is one of the black shale formations targeted for shale gas exploration in southern China in the recent years. The acquisition and analysis of total organic carbon, vitrinite reflectance,types of organic matter, mineral composition, porosity, and permeability are basic but important processes. In addition, we analyzed the microscopic pores present in the shale. This study also showesd the good gas content of the Dawuba Formation, as well as the geological factors affecting its gas content and other characteristics. To understand the prospect of exploration, we compared this with other shale reservoirs which have been already successfully explored for gas. Our comparison showesd that those shale reservoirs have similar but not identical geological characteristics.     

中国非常规油气的战略思考

本文基于非常规油气的内涵,分析了致密砂岩油气和泥页岩油气的成藏地质条件,论述了非常规油气资源潜力巨大,指明中国非常规油气资源战略发展方向。研究表明,中国非常规油气藏是富集在近源储集体或烃源岩的低孔、低渗的微米级纳米级的储集空间中连续油气聚集,淡化了圈闭、油气藏边界的概念。依据成藏地质条件和油气资源潜力的差异,非常规油气藏主要指致密砂岩油气和泥页岩油气藏。致密砂岩油气藏多位于斜坡、坳陷区,具有广覆式有效烃源岩;源、储关联密切,多呈互层式;油气运移距离短,以非达西渗流为主;储集体渗透率、孔隙度极低。泥页岩油气藏圈闭概念淡化,典型的储源一体;多形成于盆地坳陷或斜坡区,泥页岩大面积连续分布;有机质丰度大,热演化成熟度高;多发育纹层结构,纳米级孔隙、裂缝储集系统;储集层脆性系数大,地层压力高。烃源岩呈现多时代、多层系、多沉积环境特征,从震旦系到第三系均有富含有机质的烃源岩发育,沉积环境囊括陆相海、陆交互相海相,非常规油气资源潜力巨大。常规与非常规油气在时、空域的紧密伴生和规律聚集,使得常规非常规油气在平面上和纵向上形成“有序聚集”体系。对“有序聚集”的不同类油气藏进行“整一化勘探、整一化部署、整一化开采”,实现常规非常规油气整一化科学有序开发,避免整体油气资源的破坏和遗漏;从而丰富油气地质理论,促进油气勘探由“点带面”向综合有序三维空间迈进。     

Reservoir characteristics and methane adsorption capacity of the Upper Triassic continental shale in Western Sichuan Depression,China

The well-developed continental shale sequences in the Western Sichuan Depression are characterised by extremely low porosity and permeability, complex lithologies and strong lateral facies changes. The overall lack of proper characterisation of the shale properties has restricted gas exploration and development in the region. In this study, shales from the fifth member of the Xujiahe Formation of the Upper Triassic (T₃x⁵) are comprehensively characterised in terms of their organic geochemistry, mineral composition, microscopic pore structure and gas content. In addition, the influence of various geological factors on the adsorbed gas content is investigated. We proposed a new model for predicting the adsorption gas content of continental shale. The T₃x⁵ shale sequence is found to be rich in organic matter but with variable mineral compositions, pore types and reservoir physical properties. The porosity and permeability of shales are better than those of siltstones and fine sandstones interbedded with the shale under an overall densification background. Mesopores (2–50 nm) are common in the shale sequence, followed by micropores and then macropores. The gas-adsorption capacity of organic-rich shales increases with increasing TOC and clay-mineral contents, maturity and pressure, but decreases with increasing quartz content, carbonate minerals and temperature. The gas-adsorption capacity can thus be expressed as a function of organic matter, clay-mineral content, temperature and pressure. The calculated results are in good agreement with the experiment results and indicate that adsorption gas in the studied shales accounts for 78.9% of the total gas content.     

Occurrence and influence of residual gas released by crush methods on pore structure in Longmaxi shale in Yangtze Plate,Southern China

The composition of gas released under vacuum by crushing from the gas shale of Longmaxi Formation in Upper Yangtze Plate, Southern China was systematically investigated in this study. The effect of residual gas release on pore structures was checked using low-pressure nitrogen adsorption techniques. The influence of particle size on the determination of pore structure characteristics was considered. Using the Frenkel-Halsey-Hill method from low-pressure nitrogen adsorption data, the fractal dimensions were identified at relative pressures of 0−0.5 and 0.5−1 as D₁ and D₂, respectively, and the evolution of fractal features related to gas release was also discussed. The results showed that a variety component of residual gas was released from all shale samples, containing hydrocarbon gas of CH₄ (29.58% −92.53%), C₂H₆ (0.97% −2.89%), C₃H₈ (0.01% −0.65%), and also some non-hydrocarbon gas such as CO₂ (3.54% − 67.09%) and N₂ (1.88%−8.07%). The total yield of residual gas was in a range from 6.1 μL/g to 17.0 μL/g related to rock weight. The geochemical and mineralogical analysis suggested that the residual gas yield was positively correlated with quartz (R²=0.5480) content. The residual gas released shale sample has a higher surface area of 17.20−25.03 m²/g and the nitrogen adsorption capacity in a range of 27.32−40.86 ml/g that is relatively higher than the original samples (with 9.22−16.30 m²/g and 10.84−17.55 ml/g). Clearer hysteresis loop was observed for the original shale sample in nitrogen adsorption-desorption isotherms than residual gas released sample. Pore structure analysis showed that the proportions of micro-, meso- and macropores were changed as micropores decreased while meso- and macropores increased. The fractal dimensions D₁ were in range from 2.5466 to 2.6117 and D₂ from 2.6998 to 2.7119 for the residual gas released shale, which is smaller than the original shale. This factor may indicate that the pore in residual gas released shale was more homogeneous than the original shale. The results indicated that both residual gas and their pore space have few contributions to shale gas production and effective reservoir evaluation. The larger fragments samples of granular rather than powdery smaller than 60 mesh fraction of shale seem to be better for performing effective pore structure analysis to the Longmaxi shale.     

Radial Permeability Measurements for Shale Using Variable Pressure Gradients

Shale gas is becoming an important component of the global energy supply, with permeability a critical controlling factor for long-term gas production. Obvious deviation may exist between helium permeability determined using small pressure gradient(SPG) methods and methane permeability obtained under actual field production with variable pressure gradients(VPG). In order to more accurately evaluate the matrix permeability of shale, a VPG method using real gas(rather than He) is established to render permeability measurements that are more representative of reservoir conditions and hence response. Dynamic methane production experiments were performed to measure permeability using the annular space in the shale cores. For each production stage, boundary pressure is maintained at a constant and the gas production with time is measured on the basis of volume change history in the measuring pump. A mathematical model explicitly accommodating gas desorption uses pseudo-pressure and pseudo-time to accommodate the effects of variations in pressuredependent PVT parameters. Analytical and semi-analytical solutions to the model are obtained and discussed. These provide a convenient approach to estimate radial permeability in the core by nonlinear fitting to match the semi-analytical solution with the recorded gas production data. Results indicate that the radial permeability of the shale determined using methane is in the range of 1×10-6– 1×10-5 mD and decreases with a decrease in average pore pressure. This is contrary to the observed change in permeability estimated using helium. Bedding geometry has a significant influence on shale permeability with permeability in parallel bedding orientation larger than that in perpendicular bedding orientation. The superiority of the VPG method is confirmed by comparing permeability test results obtained from both VPG and SPG methods. Although several assumptions are used, the results obtained from the VPG method with reservoir gas are much closer to reality and may be directly used for actual gas production evaluation and prediction, through accommodating realistic pressure dependent impacts.     

页岩气含气量和页岩气地质评价综述

页岩气为源岩区油气聚集,属于源岩滞留气,以游离和吸附状态为主存在。富有机质页岩含气量是页岩气资源评价和有利区优选的关键参数。页岩有机质含量和地层的压力、温度、湿度等因素影响页岩的含气量。含气量的确定方法主要有解吸和测井方法。开展页岩气地质评价,除含气量参数外,还要研究地层和构造特征、岩石和矿物成分、储层厚度和埋深、储集空间类型、储集物性、岩石力学参数、有机地球化学参数、区域现今应力场特征、流体压力、储层温度、流体饱和度、流体性质等其它参数。发展有效的系统集成方法,综合分析、评价页岩气资源潜力和预测有利区,目前也在不断探索之中。     

页岩气含气量和页岩气地质评价综述

页岩气为源岩区油气聚集,属于源岩滞留气,以游离和吸附状态为主存在。富有机质页岩含气量是页岩气资源评价和有利区优选的关键参数。页岩有机质含量和地层的压力、温度、湿度等因素影响页岩的含气量。含气量的确定方法主要有解吸和测井方法。开展页岩气地质评价,除含气量参数外,还要研究地层和构造特征、岩石和矿物成分、储层厚度和埋深、储集空间类型、储集物性、岩石力学参数、有机地球化学参数、区域现今应力场特征、流体压力、储层温度、流体饱和度、流体性质等其它参数。发展有效的系统集成方法,综合分析、评价页岩气资源潜力和预测有利区,目前也在不断探索之中。     

An assessment of paleodepositional environment and maturity of organic matter in sediments of the Setap Shale and Belait formations in West Sabah,East Malaysia by organic geochemical methods

The black shale samples collected from two Neogene formations in the Klias Peninsula area, West Sabah, have been assessed and characterized in details by gas chromatography, gas chromatography-mass spectrometry and a variety of organic geochemical parameters. The aims of this study are to describe the characteristics of organic matter of these sediments in terms of source/type of the organic matter, assess its thermal maturity and paleoenvironment of deposition, based primarily on biomarker distributions. The results of both formations do not reveal significant differences within the rock extracts. The gas chromatograms of the saturated hydrocarbon fractions of the Setap Shale and the Belait formations displayed monomodal n-alkane distributions and nearly identical regular sterane compositions with a predominance of C₂₇ regular steranes. These are consistent with open marine depositional environments dominated by marine biological matter. Another related feature of these rock extracts is the presence of a high relative abundance of gammacerane, indicating anoxic marine hypersaline source depositional environment. The relatively high abundance of common land plant-derived biomarkers, such as bicadinanes and oleananes, is a clear indication of a major terrigenous input to the source of the extractable organic matter. The predominance of oleanane biomarkers in both formations is indicative of angiospermis input and Tertiary source rocks. The high C₂₉/C₃₀ hopane ratios, moderate development of C₃₃–C₃₅ hopanes, high abundance of tricyclic terpanes and a slight predominance of C₂₇ regular sterane over C₂₈ and C₂₉ steranes are characteristic features tending to suggest a significant marine influence on these source rocks, thereby suggesting a mixed source input. The 22S/(22S+22R)C₃₂ hopane ratio has reached equilibrium, and this is supported by the high maturity level as indicated by the 22S/22SC_31–33 extended hopane ratios and 20S/(20S+20R)C₂₉ regular steranes ratios.     

Geochemical characteristics,forming conditions and resource evaluation of oil-cracking gas as exemplified by the platform area of the Tarim Basin

Based on the geochemical characteristics of oil-cracking gas and kerogen-cracking gas revealed by simu-lation experiments and the chemical composition of natural gases in actual gas reservoirs, two kinds of natural gases with different relationships between C2/C3 and C1/C2, C2/C3 and C1/C3, C2/C3 and 100×C1/(C1-C5) were identified in the Tarim Basin, and proposed further by the authors. The relationship charts of C2/C3 and C1/C2, C2/C3 and C1/C3, C2/C3 and 100×C1/(C1-C5) can be used to effectively distinguish oil-cracking gas from kerogen-cracking gas. Petro-leum geological analysis of the oil-cracking gas reservoirs showed that the distribution of oil-cracking gas is mostly related with deep-seated faults or faults with a large fault throw, and the burial depth of paleo-oil reservoir is rela-tively high; crude oil-cracking gas resources have been evaluated by using both forward and inversion methods. The plots of C2/C3 vs. C1/C2, C2/C3 vs. C1/C3, and C2/C3 vs. 100×C1/(C1-C5) were used to distinguish between oil-crack-ing gas and kerogen-cracking gas, and estimate the mixed ratios of the two kinds of natural gases in the main gas reservoirs of the platform area.     

Effects of Deep Fluids on Hydrocarbon Generation and Accumulation in Chinese Petroliferous Basins

Deep fluids in a petroliferous basin generally come from the deep crust or mantle beneath the basin basement, and they transport deep substances(gases and aqueous solutions) as well as heat to sedimentary strata through deep faults. These deep fluids not only lead to large-scale accumulations of CO_2, CH_4, H_2, He and other gases, but also significantly impact hydrocarbon generation and accumulation through organic-inorganic interactions. With the development of deep faults and magmatic-volcanic activities in different periods, most Chinese petroliferous basins have experienced strong impacts associated with deep fluid activity. In the Songliao, Bohai Bay, Northern Jiangsu, Sanshui, Yinggehai and Pearl Mouth Basins in China, a series of CO_2 reservoirs have been discovered. The CO_2 content is up to 99%, with δ~(13)C_(CO2) values ranging from-4.1‰ to-0.37‰ and ~3He/~4He ratios of up to 5.5 Ra. The abiogenic hydrocarbon gas reservoirs with commercial reserves, such as the Changde, Wanjinta, Zhaozhou, and Chaoyanggou reservoirs, are mainly distributed in the Xujiaweizi faulted depression of the Songliao Basin. The δ~(13)CCH4 values of the abiogenic alkane gases are generally -30‰ and exhibit an inverse carbon isotope sequence of δ~(13)C_(CH4)δ~(13)C_(C2H6)δ~(13)C_(C3H8)δ~(13)C_(C4H10). According to laboratory experiments, introducing external H_2 can improve the rate of hydrocarbon generation by up to 147% through the kerogen hydrogenation process. During the migration from deep to shallow depth, CO_2 can significantly alter reservoir rocks. In clastic reservoirs, feldspar is easily altered by CO_2-rich fluids, leading to the formation of dawsonite, a typical mineral in high CO_2 partial pressure environments, as well as the creation of secondary porosity. In carbonate reservoirs, CO_2-rich fluids predominately cause dissolution or precipitation of carbonate minerals. The minerals, e.g., calcite and dolomite, show some typical features, such as higher homogenization temperatures than the burial temperature, relatively high concentrations of Fe and Mn, positive Eu anomalies, depletion of 18 O and enrichment of radiogenic ~(87)Sr. Due to CO_2-rich fluids, the development of high-quality carbonate reservoirs is extended to deep strata. For example, the Well TS1 in the northern Tarim Basin revealed a high-quality Cambrian dolomite reservoir with a porosity of 9.1% at 8408 m, and the Well ZS1 C in the central Tarim Basin revealed a large petroleum reserve in a Cambrian dolomite reservoir at ~6900 m. During the upward migration from deep to shallow basin strata, large volumes of supercritical CO_2 may extract petroleum components from hydrocarbon source rocks or deep reservoirs and facilitate their migration to shallow reservoirs, where the petroleum accumulates with the CO_2. Many reservoirs containing both supercritical CO_2 and petroleum have been discovered in the Songliao, Bohaiwan, Northern Jiangsu, Pearl River Mouth and Yinggehai Basins. The components of the petroleum trapped with CO_2 are dominated by low molecular weight saturated hydrocarbons.     

Shale Gas Formation and Occurrence in China: An Overview of the Current Status and Future Potential

Shale gas is one of the most promising unconventional resources both in China and abroad. It is known as a form of self-contained source-reservoir system with large and continuous dimensions. Through years of considerable exploration efforts, China has identified three large shale gas fields in the Fuling, Changning and Weiyuan areas of the Sichuan Basin, and has announced more than 540 billion m~3 of proven shale gas reserves in marine shale systems. The geological theories for shale gas development have progressed rapidly in China as well. For example, the new depositional patterns have been introduced for deciphering the paleogeography and sedimentary systems of the Wufeng shale and Longmaxi shale in the Sichuan Basin. The shale gas storage mechanism has been widely accepted as differing from conventional natural gas in that it is adsorbed on organic matter or a mineral surface or occurs as free gas trapped in pores and fractures of the shale. Significant advances in the techniques of microstructural characterization have provided new insights on how gas molecules are stored in micro- and nano-scale porous shales. Furthermore, newly-developed concepts and practices in the petroleum industry, such as hydraulic fracturing, microseismic monitoring and multiwell horizontal drilling, have made the production of this unevenly distributed but promising unconventional natural gas a reality. China has 10–36 trillion m~3 of promising shale gas among the world's whole predicted technically recoverable reserves of 206.6 trillion m~3. China is on the way to achieving its goal of an annual yield of 30–50 billion m~3 by launching more trials within shale gas projects.     

页岩油气富集的主控因素及误辩:以美国、阿根廷和中国典型页岩为例

页岩气富集不均匀,无论对于不同页岩油气藏还是同一页岩油气藏不同地方,产量都是有高有低.有必要系统分析和对比全球不同页岩油气的地质、石油系统与油气富集的关系,总结页岩油气富集的主控因素,从而采取合理的勘探和开发技术.以美国、阿根廷和中国典型页岩为例,基于野外和岩心观察、样品属性测试分析、储层表征、石油系统分析及油气测试,探究了页岩油气富集的主控因素及存在的认识误区.结果表明,富含有机质和脆性矿物的页岩主要分布于远离造山带物源的非深水的沉积和构造背景,富含石英和高伽马页岩并非判断优质储层的矿物和岩石物理标准,优质碳酸盐页岩应以富含碳酸盐和低伽马值为标准.页岩油气藏实际是细粒富含有机质的自生自储或与富含有机质烃源岩相邻的贫有机质细粒沉积储层.天然裂缝对页岩油气富集具有有利和不利的双重作用.因此,页岩油气富集同时受到沉积和构造环境、岩相及矿物组成、天然裂缝的耦合影响,且对不同沉积盆地、不同属性页岩的影响差异明显.