Organic geochemical characteristics and hydrocarbon generation potential of Upper Triassic black shales in the North Qiangtang Depression
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摘要:研究目的
基于浅地表地质调查认为，上三叠统黑色泥页岩是羌塘盆地最重要的烃源岩。然而，由于缺乏深钻井样品，盆地深部这套烃源岩特征尚不清楚。北羌塘坳陷东部QZ−16井钻遇了迄今为止盆地最深的上三叠统烃源岩，并发现了较显著的气测异常及大量沥青，为盆地深部烃源岩品质研究与生烃潜力分析提供了新的机遇。
研究方法以QZ−16井上三叠统黑色泥页岩为研究对象，通过有机地球化学测试分析研究，揭示羌塘盆地深部该套烃源岩的有机质丰度、类型、成熟度、来源及其与沥青油苗之间的油源关系。
研究结果与已有的地质浅钻及地表露头相比，QZ−16井上三叠统黑色泥页岩TOC含量总体较低（0.12%~1.09%，均值为0.47%），但普遍高于II型干酪根的过成熟烃源岩的TOC下限标准（0.3%）；氯仿沥青A和生烃潜量（S1+S2）参数可能不能真实反映研究区过成熟烃源岩的有机质丰度；干酪根类型指数（8.75~18.5）、Ph/nC18（0.65~1.06）、Pr/nC17（0.34~0.61）值及C27−C28−C29甾烷特征等表明有机质为低等浮游生物与陆生高等植物的混合来源，为II2型干酪根，且多形成于较强的还原环境；干酪根颜色（棕褐色—黑色）、Tmax（536~602 ℃）、镜质体反射率（Ro=2.44%~2.77%）及生物标志化合物参数表明该套黑色泥页岩有机质热演化程度为过成熟；油源对比参数反映QZ−16井上三叠统沥青油苗与黑色泥页岩之间具有较好的亲缘关系，为自生自储型。
结论北羌塘坳陷上三叠统黑色泥页岩为过成熟烃源岩，具有一定的生烃潜力，该成果为羌塘盆地烃源岩评价提供了新的参考依据。
创新点:（1）首次对北羌塘拗陷深部钻井（QZ−16井）样品开展了烃源岩评价与生烃潜力分析；（2）提出了北羌塘拗陷上三叠统黑色泥页岩为过成熟烃源岩并具有一定的生烃潜力。
Abstract:This paper is the result of oil and gas exploration engineering.
ObjectiveGeological investigations of petroleum potential suggest that the Upper Triassic black shales represent the most significant source rock interval in the Qiangtang Basin. However, the organic geochemical characteristics and hydrocarbon generation potential of these source rocks in the deep basin are still under ongoing research due to the lack of deep drilling activities.
MethodsThe well QZ−16, located in the eastern part of the North Qiangtang Depression, has encountered the deepest Upper Triassic strata in the basin to date, revealing significant gas anomalies and a substantial amount of bitumen. This provides a new opportunity to enhance the understanding of deep basin source rocks. Here, organic geochemical analyses of the Upper Triassic black shales were conducted to investigate the organic matter quality, quantity, and levels of thermal maturity as well as the oil−source relationship between the source rock and bituminous oil.
ResultsThe TOC content of the Upper Triassic black shales in the well QZ−16 is generally poor to fair organic matter richness, ranging from 0.12% to 1.09%, with an average of 0.47%. These values are higher than the average TOC limit (0.3%) of over−mature source rocks with type II kerogen. The degree of thermal maturity is suggested to be in the over−mature stage based on significantly high Tmax (536−602 ℃) and vitrinite reflectance values (Ro = 2.44%−2.77%). The chloroform asphalt A and hydrocarbon generation potential (S1+S2) may not reliably reflect the organic matter abundance due to the source rocks being in the over−mature stage. Kerogen type index (8.75−18.5), Ph/nC18 (0.65−1.06), Pr/nC17 (0.34−0.61) and C27−C28−C29 sterane characteristics indicate a mixed organic matter source comprising of lower plankton and higher terrestrial plants of Type II2 kerogen. Most source rock intervals were deposited under strongly reducing conditions, exhibiting a brown−black kerogen color, which align with biomarker parameters, indicating that the thermal evolution of the black shale is over mature. The oil source correlation parameters reveal a strong affinity between the Triassic bituminous oil seedling and black shale in the well QZ−16, which is self−generated and self−stored.
ConclusionsThe Upper Triassic black shales in the North Qiangtang Depression are mature source rocks with certain hydrocarbon generation potential. The results of this study provide a new reference for evaluating source rocks and analyzing hydrocarbon generation potential in the Qiangtang Basin.
Highlights:(1) Source rock evaluation and hydrocarbon generation potential analysis were carried out for the first time on samples from deep drilling (well QZ−16) in North Qiangtang Depression; (2) It is suggested that the black shale of Upper Triassic in North Qiangtang is over-mature source rock and has certain hydrocarbon generation potential.
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1. 研究目的（Objective）
近年来，新疆阿尔金西段萤石找矿取得的重大突破。萤石矿主要分布于卡尔恰尔—阔什区域性大断裂（阿中断裂）以南的晚奥陶世碱长花岗岩侵入体内及其外接触带附近的富钙质岩系中，圈定了卡尔恰尔—小白河沟、盖吉克—亚干布阳、布拉克北—皮亚孜达坂、托盖里克东南—阿其克南4条沿北东向断裂分布的萤石矿带，整个远景区CaF2资源量已达3500万t以上。中国地质调查局西安矿产资源调查中心于2021—2023年对阿尔金西段小白河沟—克鲁求干道班一带开展了矿产调查评价，在小白河沟地区新发现热液充填型萤石矿产地1处，估算萤石的潜在资源达大型规模，对于拓展阿尔金地区萤石矿床具有借鉴意义。
2. 研究方法（Methods）
在对小白河沟地区以往地物化遥成果资料综合研究基础上，结合本次遥感蚀变异常提取和构造解译圈定了重点工作区，通过开展1∶10000地质草测、1∶10000岩石地球化学剖面测量、1∶500地质剖面测量、槽探及钻探等工作，在小白河沟共圈定萤石矿体21条，实现了找矿突破。通过典型矿床对比，总结了区内萤石矿成矿规律，初步建立了找矿模式，分析了区域萤石成矿潜力及找矿前景。
3. 研究结果（Results）
研究区出露地层基底主要为古元古界阿尔金岩群a岩组和b岩组，二者呈构造面理接触关系。阿尔金岩群a岩组为萤石主要赋矿地层，该岩组出露的岩石类型主要为黑云斜长片麻岩、黑云二长片麻岩、斜长变粒岩、石英岩、大理岩，局部夹有角闪斜长片麻岩（图1b）。区内断裂较为发育，期次较多，主要呈北北东向、北东向、南东东向，南东东向断裂主要与区内的萤石矿化关系密切。地层中岩脉极为发育，在接触带可见岩石具萤石化、钾长石化、碳酸盐化、绿帘石化、硅化等围岩蚀变。
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图 1 区域构造位置图（a）、矿区地质简图（b）、勘探线剖面图（c）及萤石矿岩心（d）Figure 1. Regional structure location map (a), brief geological diagram of ore district (b), prospecting line profile map (c) and cores specimen of fluorite deposit (d)在小白河沟共圈定萤石矿体21条（图1c），长100~1130 m，厚度0.7~4.68 m，矿体沿走向延续性较好，沿倾向呈透镜体状，断续产出，斜切岩体和变质岩，有“膨大缩小”变化，部分呈“透镜体”、“扁豆体”断续分布，主矿体旁侧发育少数分枝。矿体品位23.2%~82.4%，平均品位32.2%，钻孔深部验证效果良好。矿石主要以块状、纹层状为主，主要矿物为萤石，局部发育方解石、带云母和少量石英。萤石以紫色、紫黑色为主，少量呈白色或绿色，具粗晶结构、自形—半自形及他形粒状结构。矿石工业类型主要是CaF2型、CaF2–CaCO3型。围岩蚀变以碳酸盐化、带云母化、钾化、黄铁矿化、绿帘石化、角闪石化等为主。初步估算CaF2资源量117.42万t，具大型萤石矿床远景。
4. 结论（Conclusions）
（1）小白河沟萤石矿是阿尔金西段萤石找矿新发现，这一发现拓展了区内萤石矿向西延伸的空间，同时本次工作区内多数矿体走向和深部延伸均未封边，仍具有较大找矿潜力。
（2）本工作发现了品位较富的大型萤石矿，拓宽了区域找矿思路，具有重要借鉴意义，同时为阿尔金瓦石峡南—卡尔恰尔萤石锂大型资源基地建设提供了有力支撑。
5. 基金项目（Fund support）
本文为中国地质调查局项目（DD20190143、DD20211551、DD20243309）、陕西省自然科学基础研究计划项目（2023−JC−YB−241）、中国地质调查局自然资源综合调查指挥中心科技创新基金项目（KC20230011）联合资助的成果。
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图 1 （a）羌塘盆地地质构造及上三叠统地层分布特征；（b）北羌塘坳陷东部QZ−16井地区地质简图
Figure 1. (a) Tectonic framework of the Qiangtang Basin and showing the distribution of Upper Triassic strata; (b) Simplified geological map of the well QZ−16 in the east part of the North Qiangtang Depression
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图 2 QZ−16井上三叠统地层序列、沉积特征、取样位置及TOC和S的垂向分布
Figure 2. Upper Triassic stratigraphic successions, sedimentary characteristics, sampling locations, vertical distributions of total organic carbon (TOC) and sulfur (S) in the well QZ−16
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图 3 QZ−16井上三叠统黑色泥岩干酪根显微组分特征
Figure 3. Characteristics of kerogen maceral compositions of Upper Triassic black mudstones in the well QZ−16
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图 4 QZ−16井上三叠统黑色泥岩饱和烃色谱−质谱特征
Figure 4. GC−MS characteristics of some typical Upper Triassic black mudstone samples in the well QZ−16
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图 5 QZ−16井上三叠统黑色泥岩Ph/nC18与Pr/nC17相关关系图
Figure 5. Binary diagrams of Ph/nC18 versus Pr/nC17 of Upper Triassic black mudstones in the well QZ−16
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图 6 QZ−16井上三叠统黑色泥岩有机质成熟度判别图解
Figure 6. Discrimination diagram of organic maturity of Upper Triassic black mudstones in the well QZ−16
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图 7 QZ−16井上三叠统黑色泥岩C27−C28−C29甾烷三角判别图
Figure 7. Ternary diagram of C27−C28−C29 regular steranes in Upper Triassic black mudstones in the well QZ−16
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图 8 QZ−16井上三叠统沥青油苗与烃源岩生物标志物多因素对比图（Bsy为烃源岩，QZ为沥青油苗）
Figure 8. Multifactor correlation diagram of biomarkers between the bitumen oil seepages and Upper Triassic source rocks in the well QZ−16 (Bsy and QZ represent the source rocks and bitumen, respectively)
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图 9 QZ−16井上三叠统沥青油苗与烃源岩单体烃碳同位素对比图（Bsy为烃源岩，QZ为沥青油苗）
Figure 9. δ13C correlation diagram of n−alkanes between the bitumen oil seepages and Upper Triassic source rocks in the well QZ−16 (Bsy and QZ represent the source rocks and bitumen, respectively).
表 1 QZ−16井上三叠统黑色泥岩基础有机地球化学参数
Table 1 Basic organic geochemical parameters of Upper Triassic black mudstones in the well QZ−16
样品编号 TOC S S1 S2 S3 氯仿沥青A/10−6 HI OI Tmax/℃ Ro 16Bsy−1 0.34 1.10 / / / / / / / / 16Bsy−2 0.28 1.11 / / / / / / / / 16Bsy−3 0.53 2.74 / / / / / / / / 16Bsy−4 0.22 0.71 / / / / / / / / 16Bsy−5 0.18 0.30 / / / / / / / / 16Bsy−6 0.64 1.08 0 0 0.20 13.96 0 21 601 2.44 16Bsy−7 0.54 2.62 / / / / / / / / 16Bsy−8 0.76 2.77 0 0 0.18 15.84 0 15 n.d 2.46 16Bsy−9 0.29 1.28 / / / / / / / / 16Bsy−10 0.15 0.10 / / / / / / / / 16Bsy−11 0.12 0.12 / / / / / / / / 16Bsy−12 0.18 0.61 / / / / / / / / 16Bsy−13 0.22 0.66 / / / / / / / / 16Bsy−14 0.17 0.07 / / / / / / / / 16Bsy−15 0.17 0.10 / / / / / / / / 16Bsy−16 0.21 0.95 / / / / / / / / 16Bsy−17 0.57 5.70 / / / / / / / / 16Bsy−18 0.87 3.43 0 0 0.15 19.61 0 13 582 2.54 16Bsy−19 0.37 5.08 / / / / / / / / 16Bsy−20 0.46 5.45 / / / / / / / / 16Bsy−21 0.67 6.31 0 0 0.18 6.66 0 16 536 2.77 16Bsy−22 0.43 4.41 / / / / / / / / 16Bsy−23 0.45 3.45 / / / / / / / / 16Bsy−24 0.40 2.07 / / / / / / / / 16Bsy−25 0.92 4.18 0 0 0.13 5.65 0 9 n.d 2.65 16Bsy−26 0.33 2.56 / / / / / / / / 16Bsy−27 1.09 4.59 0 0 0.18 17.29 0 12 n.d 2.70 16Bsy−28 0.63 4.12 / / / / / / / / 16Bsy−29 0.98 4.08 0 0 0.13 17.88 0 8 602 2.73 16Bsy−30 0.92 4.37 0 0 0.12 13.48 0 10 n.d 2.68 
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表 2 QZ−16井上三叠统黑色泥岩干酪根显微组分及类型
Table 2 Maceral compositions and kerogen type of Upper Triassic black mudstones in the well QZ−16
样品 干酪根显微组分/% 干酪根
指数干酪根
类型干酪根
颜色壳质组 镜质组 惰质组 无定型腐殖质 无结构镜质体 结构镜质体 丝质体 16Bsy−6 75 10 12 3 18 Ⅱ2 棕褐色 16Bsy−8 70 16 6 8 10.5 Ⅱ2 棕褐色 16Bsy−18 72 6 18 4 14 Ⅱ2 棕黑色 16Bsy−21 68 15 12 5 8.75 Ⅱ2 棕黑色 16Bsy−25 68 10 18 4 9.0 Ⅱ2 棕黑色 16Bsy−27 70 13 12 5 11.25 Ⅱ2 棕黑色 16Bsy−29 76 8 10 6 18.5 Ⅱ2 棕黑色 16Bsy−30 75 10 10 5 17.5 Ⅱ2 棕黑色
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表 3 QZ−16井上三叠统黑色泥岩正构烷烃单体碳同位素特征
Table 3 Carbon isotope characteristics of n-alkanes in Upper Triassic black mudstones in the well QZ−16
样品
编号δ13CPDB/‰ C17 C18 Ph C19 C20 C21 C22 C23 C24 C25 C26 C27 C28 C29 16Bsy−18 / −25.7 / −28.1 −28.5 −29.8 −31.1 −31.6 −31.6 −32.1 −31.8 −32.1 −31.0 −31.8 16Bsy−25 / −28.7 −28.6 −28.9 −29.3 −30.3 −31.3 −32.2 −32.3 −32.0 −31.7 −31.6 −31.4 −31.1 16Bsy−27 −27.3 −28.3 −26.8 −28.7 −28.9 −29.9 −31.2 −32.9 −32.3 −32.3 −32.7 −32.6 −32.4 −33.0 16Bsy−29 / −26.7 −26.7 −27.6 −29.3 −30.8 −32.2 −33.3 −33.2 −33.4 −33.4 −33.6 −33.1 −33.8 16Bsy−30 / −28.0 −27.9 −28.5 −29.4 −30.2 −31.5 −32.8 −32.4 −32.7 −31.6 −32.9 −32.4 −32.7
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表 4 QZ−16井上三叠统黑色泥岩正构烷烃、类异戊二烯烃、萜烷与甾烷参数特征
Table 4 Characteristics of n-alkane, major isoprenoid, terpanes and steranes parameters of Upper Triassic black mudstones in the well QZ−16
样品编号 16Bsy−6 16Bsy−8 16Bsy−18 16Bsy−21 16Bsy−25 16Bsy−27 16Bsy−29 16Bsy−30 主峰碳 C23 C23 C23 C23 C23 C23 C23 C23 CPI 1.12 1.16 1.3 1.13 1.15 1.15 1.19 1.15 OEP 1.01 1.03 1.03 1.02 1 1.03 1.02 1.04 C21−/C22+ 0.4 0.96 0.78 0.6 0.81 1.13 0.82 0.8 Pr/Ph 0.4 0.47 0.53 0.37 0.51 0.4 0.51 0.47 C24TeT/C26TT 0.66 0.6 0.64 0.71 0.71 0.63 0.67 0.72 ST/H30-35 0.61 0.55 0.43 0.49 0.45 0.43 0.56 0.48 C25TT/C24TeT 1.47 1.66 1.45 1.4 1.43 1.44 1.53 1.38 C21+20TT/C23+24TT 0.96 1.03 1.02 1 1.12 0.91 1.17 1.13 G/C30H 0.17 0.14 0.16 0.13 0.13 0.11 0.12 0.11 Ts/Tm 1.02 0.95 0.85 0.98 0.87 0.82 0.86 0.95 C27/% 28 30 30 29 28 27 29 29 C28/% 24 24 23 23 24 25 23 24 C29/% 48 46 47 47 48 48 47 47 C29ααα20S/（20S+20R） 0.44 0.43 0.45 0.44 0.46 0.47 0.45 0.47 C29αββ/（ααα+αββ） 0.41 0.38 0.39 0.39 0.4 0.4 0.39 0.4
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