南华北地区二叠系烃源岩分布及地化特征

南华北地区二叠系烃源岩主要发育于太原组、山西组、下石盒子组和上石盒子组,以煤系烃源岩为主.通过对各类烃源岩丰度、类型和成熟度的分析认为,煤系泥岩为主要的有效烃源岩,太原组、山西组和下石盒子组有机质丰度较高;母质类型以Ⅲ型(腐殖型)为主,也有少量Ⅱ2型(腐泥腐殖型);二叠系下统有机质处于过成熟-成熟阶段,中上统处于低成熟...     

南海万安盆地地热演化史的初步研究

热演化史研究是盆地模拟中的重要环节，通过其研究可以为烃源岩成熟度史、生烃史、排烃史模拟提供必要的参数，准确地评价盆地的油气资源。     

莺歌海盆地古新近系烃源条件与有利油气勘探方向

根据莺歌海盆地区域地质背景与古新近系构造沉积演化特征,结合钻井资料和前人烃源岩研究及生烃模拟实验结果,深入研究了不同层位烃源岩尤其是古近系烃源岩地球化学特征,重点剖析了烃源条件及高温高压环境中有机质热演化成烃特点。研究表明,中新统海相陆源烃源岩分布较广泛,其有机质干酪根类型属Ⅱ2—Ⅲ型,处在成熟-高熟大量生气阶段,为盆地浅层及中深层天然气气藏主要烃源岩;始新统及渐新统湖相及煤系亦是盆地重要烃源岩,主要分布在盆地西北部及与琼东南盆地毗邻的东南部,其生源母质类型属偏腐殖型,且处于成熟-高熟/裂解气阶段,具有较大生烃潜力。基于盆地构造沉积演化特点与烃源条件分析,结合近年来天然气勘探成果与有利油气富集区带综合评价,预测盆地临高反转构造带及临高海口-昌化区是勘探古近系烃源供给之油气有利富集区;莺东斜坡以及靠近琼东南盆地1号断裂带附近区域亦是勘探古近系烃源供给之油气的重要勘探领域。同时中深层深部高温超压九大构造圈闭系列则是勘探发现大中型天然气田群建成特大气区的主战场。     

东海陆架盆地丽水凹陷热演化模拟及现今地温场特征

东海陆架盆地丽水凹陷烃源岩埋深大、钻井少、油气发现少,至今对其生油气能力具有较大的争议。为明确烃源岩热演化史,从少量具备实测地层温度和镜质体反射率(Ro)资料的钻井出发,利用正演模拟方法,通过地温与地层深度相关性分析,将钻井地温研究结果外推到无井区。在恢复丽水凹陷探井岩石圈结构及其演化史的基础上,首次系统建立了丽水凹陷的区域地温场并分析其对烃源岩演化的作用。研究表明,古新统下段月桂峰组底界(T100)烃源岩大部分都已成熟,次洼中心局部过成熟;月桂峰组顶界(T90)烃源岩大部分处于低熟—成熟阶段,次洼中心局部高—过成熟;灵峰组顶界(T85)烃源岩处于未熟—低熟状态,西次洼中心有成熟烃源岩。烃源岩特征及演化分析表明,古新统下段月桂峰组烃源岩是丽水凹陷的主力生油气烃源岩。     

构造生烃

生烃是岩石中所含的有机质产生流体有机化合物的化学反应。岩石有机质化学反应存在两种系统：封闭系统和开放系统，随着埋深加大，烃源岩越来越致密，岩石的化学反应逐渐由开放系统转变为封闭系统。目前的生烃理论仅仅是开放系统下烃源岩成熟与生烃理论，烃源岩成熟与生烃是不匹配的。封闭系统下烃源岩成熟与生烃是不匹配的，烃源岩成熟但不生烃，而是形成另外一种成熟的固体有机质。大多数情况是烃源岩为半封闭系统，烃源岩处于欠生烃状态。构造运动形成的断层和裂隙将烃源岩与疏导层沟通，烃源岩迅速由封闭、半封闭系统转变为开放系统。这种生烃系统的转变形成短时间内过量生烃，笔者将这种生烃作用命名为构造生烃，意味着构造运动期即为主生烃期，伴随着多次构造运动可以形成多个幕式生烃高峰。构造生烃理论开拓两个极其重要的勘探领域：第一，新构造勘探。以往认为已经过了生、排烃期的构造得以解放，如渤海湾郯庐断裂带第四纪圈闭不是过了主生烃期，而是正处于构造生烃的过生烃高峰期。以PL19-3为代表的油气运聚强度只有构造生烃能够解释；第二，超深勘探，特别是天然气勘探。深层勘探的下限将大大延伸，生烃门限，特别是生气门限将大大加深，仅生烃而言万米都不是天然气勘探的极限。     

下扬子陆域下寒武统烃源岩特征及其对南黄海油气勘探的借鉴

早寒武世下扬子陆块与华夏陆块均向北漂移并拼合成南方古陆,发生褶皱隆升,但对下扬子陆块北部(现今下扬子地区)影响不大,总体处于浅海台地相。因为早寒武世早期受上升流等因素的影响,下扬子地区早寒武世有机质来源丰富,在缺氧还原的沉积环境形成了优质烃源岩。下扬子地区下寒武统烃源岩呈NE向展布,受"一台两盆"构造格局影响存在2个沉积中心:一个在安吉—休宁深水陆棚区,厚度100~300m;另一个在泰州—盐城深水陆棚区,厚度50~150 m。海侵主要来自东北方向,烃源岩向东北方向减薄。从陆域烃源岩厚度分布趋势看,南黄海盆地烃源岩厚度应在50~200m之间。中生代南方古陆与华北陆块拼合形成中国大陆时,对下扬子古生代形成的油气藏产生了严重的破坏。台缘相烃源岩厚度大、埋深大、生烃早,生成的油气藏在中生代南北陆拼贴期遭到破坏,是现今古油藏的烃源供给者。我们推测南黄海下寒武统为台地相沉积,埋藏相对较浅,热演化程度相对较低,大部分烃源岩可能在燕山中—晚期发生过二次生烃,有利于常规油气藏的保存。     

南海深水区白云凹陷烃源岩热演化与油气资源潜力预测

基于钻井、测井、地震及地质等资料及盆地数值模拟技术,结合成因法及类比法,对南海深水区白云凹陷现今地温场特征、烃源岩热演化、烃源岩排烃强度、烃源岩排烃量以及已发现油气田石油、天然气聚集系数进行了系统研究,进而综合预测白云凹陷油气资源潜力。研究表明,白云凹陷地温梯度较高,介于34~67℃·km~(–1)之间,均值为40℃·km~(–1),有利于有机质的成熟与烃类生成;各烃源岩现今均处于成熟生油或过成熟生气阶段,烃源岩成熟度从珠海组顶面到文昌组底面增幅较大,文昌组烃源岩底面过成熟面积占凹陷面积的53.7%;各烃源岩排气强度均大于排油强度,且恩平组上段为主力排烃层位;文昌、恩平及珠海组3套烃源岩总排烃量为1143×10~8m~3油当量。且结合石油、天然气聚集系数预测白云凹陷保守资源量为25.2×10~8m~3油当量。     

二次生烃机理在中下扬子高演化烃源岩评价中的应用

在野外地质观察、油气地球化学和样品分析的基础上,通过总结二次生烃特征和生烃机理,将其应用到中下扬子区海相高演化烃源岩生烃潜力的评价。模拟实验结果表明,二次生烃具有明显的迟缓现象,也仍具有相对的生烃高峰,二次生烃量与一次生烃量的总和小于连续热演化的生烃量,这些特征都与一次生烃的演化程度密切相关,初始演化程度成为评价高演化烃源岩二次生烃潜力的关键因素。中下扬子区中—古生界发育的6套烃源岩中,下二叠统、下志留统和下寒武统烃源岩具有较强的生烃能力,是主要的烃源层。下古生界烃源岩进入生烃时间较早,在强烈的构造运动背景下,生成的油气难以保存;上古生界烃源岩热演化程度相对较低,燕山—喜山期的再次沉降地区成为二次生烃的供源区。因此,下古生界台地相区和上古生界烃源岩具有一定的二次生烃潜力。     

西湖凹陷平北地区烃源岩特征及生排烃史

为了综合确定平北地区的主力烃源岩，深化其油气成藏动力学过程研究，在烃源岩分布特征及有机质丰度、类型和成熟度分析的基础上，应用舍油气盆地数值模拟技术，定量恢复了研究区主要烃源岩层系的生排烃历史。研究表明，平北地区主要发育始新统平湖组、渐新统花港组两套烃源岩系，其中平湖组暗色泥岩为主力烃源岩，具较高的有机质丰度、成熟度、生排烃强度与排烃效率；以平湖组为源岩的油气系统应是本区油气勘探的主要目标。     

中国近海断―坳转换期煤系烃源岩特征——以西湖凹陷平湖组烃源岩为例

西湖凹陷是东海陆架盆地最重要的含油气凹陷,古近系晚始新统平湖组烃源岩是西湖凹陷主力烃源岩,晚始新世平湖组沉积时期西湖凹陷处于断―坳转换时期,平湖组为一套海陆过渡相煤系地层,形成于半封闭海湾沉积环境。本文对断坳转换平湖组煤系烃源岩的分布、母质来源和生烃特征进行系统分析。结果表明:断—坳转换下的煤系烃源岩广覆式分布,平湖组煤系烃源岩富含反映干燥针叶类裸子植物来源的异海松烷和潮湿蕨类植物来源的β-扁植烷等二萜类化合物,从斜坡带向凹陷中央具有β-扁植烷增加的特征。从显微结构上表现为富含树脂体的煤系烃源岩,其具有"早期利于生油、晚期持续生气"的生烃模式。正是这种分布格局、母质来源和生烃特征决定了西湖凹陷油气藏具有"东气西油"的分布格局。     

Geochemical characteristics and hydrocarbon generation modeling of the Jurassic source rocks in the Shoushan Basin, north Western Desert, Egypt

The Shoushan Basin is an important hydrocarbon province in the Western Desert, Egypt, but the origin of the hydrocarbons is not fully understood. In this study, organic matter content, type and maturity of the Jurassic source rocks exposed in the Shoushan Basin have been evaluated and integrated with the results of basin modeling to improve our understanding of burial history and timing of hydrocarbon generation. The Jurassic source rock succession comprises the Ras Qattara and Khatatba Formations, which are composed mainly of shales and sandstones with coal seams. The TOC contents are high and reached a maximum up to 50%. The TOC values of the Ras Qattara Formation range from 2 to 54 wt.%, while Khatatba Formation has TOC values in the range 1-47 wt.%. The Ras Qattara and Khatatba Formations have HI values ranging from 90 to 261 mgHC/gTOC, suggesting Types II-III and III kerogen. Vitrinite reflectance values range between 0.79 and 1.12 VRr %. Rock−Eval T_max values in the range 438-458 °C indicate a thermal maturity level sufficient for hydrocarbon generation. Thermal and burial history models indicate that the Jurassic source rocks entered the mature to late mature stage for hydrocarbon generation in the Late Cretaceous to Tertiary. Hydrocarbon generation began in the Late Cretaceous and maximum rates of oil with significant gas have been generated during the early Tertiary (Paleogene). The peak gas generation occurred during the late Tertiary (Neogene).     

A basin modeling and organic geochemistry study in the Vallecitos syncline,San Joaquin Basin,California

The Vallecitos syncline is a westerly structural extension of the San Joaquin Basin. The Vallecitos oil field, comprised of eight separate areas that produce from Cretaceous and Paleogene reservoirs, accounted for 5.4 MMB of oil and 5.6 BCF associated of gas through 2010. However, exploration for oil and gas in the Vallecitos area is challenging due to structural complexity and limited data. The purpose of this study is to evaluate whether source rocks are actively generating petroleum in the Vallecitos syncline and to improve our understanding of burial history and timing of hydrocarbon generation. We conducted biomarker analysis on twenty-two oil samples from the Vallecitos syncline. Source-related biomarkers show two genetic groups of oil, which originated from two different source rocks. These results differ from earlier published interpretations in which the Kreyenhagen Formation is the only source rock in the Vallecitos syncline, and suggest that the Cretaceous Moreno Formation in the syncline also is an active source rock.Stratigraphic evidence and modeling suggest that late Cenozoic episodes of erosion due to folding and uplift removed significant overburden on the flanks of the syncline. To better understand the petroleum systems and clarify the total active source rocks in the area, 2D burial histories were generated through the Vallecitos syncline. A published cross-section through the deepest part of the syncline was selected to conduct thermal history, basin evolution, and migration analyses. The 2D model results indicate that the lower Kreyenhagen Formation has various maturities within the formation at different locations in the present-day syncline. The basal part of the Kreyenhagen Formation is in the dry gas window and maturity decreases away from the central part to the flanks. It remains immature along shallow portions of the present-day flanks. In contrast, the basal part of the Moreno Formation achieved extremely high maturity (past the gas generation zone) but is in the oil generation zone on the flanks of the syncline at shallow depth. All of our geochemical and 2D model results suggest that there are two active source rocks in the Vallecitos syncline. Accordingly, we propose that there are two active petroleum systems in the Vallecitos syncline.     

Effect of sedimentary heterogeneities on hydrocarbon accumulations in the Permian Shanxi Formation,Ordos Basin,China: Insight from an integrated stratigraphic forward and petroleum system modelling

Sedimentary heterogeneities are ubiquitous in nature and occur over a range of scales from core, reservoir to basin scales. They may thus exert significant influences on hydrocarbon generation, migration and accumulation. The sedimentary heterogeneities of the Permian Shanxi Formation in the Ordos Basin, China were modelled using Sedsim, a stratigraphic forward modelling program. The simulation results were then used to construct a 3D petroleum system model using PetroMod. The effects of sedimentary heterogeneities on hydrocarbon accumulations were evaluated by comparing the integrated Sedsim-PetroMod model with the classic 3D basin model. The Sedsim simulation shows that considerable sedimentary heterogeneities are present within the Shanxi Formation, as a result of the interplay of the initial topography, tectonic subsidence, base level change and sediment inputs. A variety of lithologies were developed both laterally and vertically within the Shanxi Formation at kilometre and metre scales, respectively, with mudstones mainly developed in the depositional centre, while sandstones developed in the southern and northern margin areas. A typical source-ward retrogradation is well developed within the Lower Shanxi Formation.A base-case classic 3D basin model was constructed to quantify the Permian petroleum system in the Ordos Basin. The geological and thermal models were calibrated using Vr and borehole temperature data. The source rocks of the Upper Paleozoic became mature (R_o > 0.5%) and high mature (R_o > 1.2%) in the late Triassic and late Jurassic, respectively, in the central and southern areas. During the Early Cretaceous, a tectonically induced geothermal event occurred in the southern Ordos Basin. This caused the source rocks to reach over maturity (R_o > 2.0%) quite rapidly in the early Late Cretaceous in the central and southern areas. All the source rock transformation ratios (TR) at present are greater than 70% in the P₁ coal and P₁ mudstone layers with TR values approaching 100% in the central and southern areas. The transformation ratios of the P₁ limestone are close to 100% over the entire interval.In the base-case model, a large amount of hydrocarbons appear to have been expelled and migrated into the Shanxi Formation, but only a minor amount was accumulated to form reservoirs. In the model, the Shanxi Formation sandstone layer was set to be homogeneous vertically and there was no regional seal rocks present at the top of the Shanxi Formation. Therefore hydrocarbons could not be trapped effectively with only minor accumulations in some local structural highs where hydrocarbons are trapped both at the top and in the up-dip direction by the adjacent mudstone facies. In contrast, the integrated Sedsim-PetroMod model takes into account of the internal lithological and sedimentary facies heterogeneities within the Shanxi Formation, forming complex contiguous sandstone-mudstone stacking patterns. Hydrocarbons were found to have accumulated in multiple intervals of lithological traps within the Shanxi Formation. The results indicate that lithological distinctions, controlled by sedimentary heterogeneities in three dimensions can provide effective sealing in both the top and up-dip directions for hydrocarbon accumulations, with gas being mainly accumulated near the depocentre where lithological traps usually formed due to frequent oscillations of the lake level.     

Thermal maturation, potential source rocks and hydrocarbon generation in Mesozoic rocks, Lougheed Island area, Central Canadian Arctic archipelago

Significant oil and gas accumulations occur in and around Lougheed Island, Arctic Canada, where hydrocarbon prospectivity is controlled by potential source rock distribution and composition. The Middle to Upper Triassic rocks of the Schei Point Group (e.g. Murray Harbour and Hoyle Bay formations) contain a mixture of Types I and II organic matter (Tasmanales marine algae, amorphous fluorescing bituminite). These source rocks are within the oil generation zone and have HI values up to 600 mg HC/g Corg. The younger source rocks of the Lower Jurassic Jameson Bay and the Upper Jurassic Ringnes formations contain mainly gas-prone Type II/III organic matter and are marginally mature. Vitrinite reflectance profiles suggest an effective geothermal gradient essentially similar to the present-day gradient (20 to 30°C/km). Maturation gradients are low, ranging from 0.125 to 0.185 log%Ro/km. Increases in subsidence rate in the Early Cretaceous suggest that the actual heat flow history was variable and has probably diminished from that time. The high deposition rates of the Christopher Formation shales coincide with the main phase of rifting in Aptian-Albian times. Uplift and increased sediment supply in the Maastrichtian resulted in a new sedimentary and tectonic regime, which culminated in the final phase of the Eurekan Orogeny. Burial history models indicate that hydrocarbon generation in the Schei Point Group took place during rifting in Early Cretaceous, long before any Eurekan deformation.     

Thermal evolution of the Kuh-e-Asmari and Sim anticlines in the Zagros fold-and-thrust belt: Implications for hydrocarbon generation

Mixed layer clay minerals, vitrinite reflectance and geochemical data from Rock-Eval pyrolysis were used to constrain the burial evolution of the Mesozoic–Cenozoic successions exposed at the Kuh-e-Asmari (Dezful Embayment) and Sim anticlines (Fars province) in the Zagros fold-and-thrust belt. In both areas, Late Cretaceous to Pliocene rocks, show low levels of thermal maturity in the immature stages of hydrocarbon generation and early diagenetic conditions (R0 I–S and R_o% values < 0.5). At depths of 2–4 km, T_max values (435–450 °C) from organic-rich layers of the Sargelu, Garau and Kazhdumi source rocks in the Kuh-e-Asmari anticline indicate mid to late mature stages of hydrocarbon generation. One dimensional thermal models allowed us to define the onset of oil generation for the Middle Jurassic to Eocene source rocks and pointed out that sedimentary burial is the main factor responsible for measured levels of thermal maturity. Specifically, the Sargelu and Garau Formations entered the oil window prior to Zagros folding in Late Cretaceous times, the Kazhdumi Formation during middle Miocene (syn-folding stage), and the Pabdeh Formation in the Late Miocene–Pliocene after the Zagros folding. In the end, the present-day distribution of oil fields in the Dezful Embayment and gas fields in the Fars region is primarily controlled by lithofacies changes and organic matter preservation at the time of source rock sedimentation. Burial conditions during Zagros folding had minor to negligible influence.     

2D basin modeling study of the Binak Trough,northwestern Persian Gulf,Iran

The northwestern part of the Persian Gulf is one of the most prominent hydrocarbon exploration and production areas. Oilfields are located in structural highs formed around the Cenomanian depression known as Binak Trough. To evaluate the highly variable source rock maturity, timing of hydrocarbon generation as well as migration pattern and the remaining hydrocarbon potential of the early Cretaceous source rocks, burial and thermal histories were constructed for four production wells and one pseudo well. In addition two cross sections covering the depression and the structural highs around the trough were investigated by 2D basin modeling to provide a better regional overview on basin evolution.The modeling results indicate that whereas the Cretaceous source rocks are immature or early mature at the location of oilfields, they reached sufficient maturity to generate and expel considerable amounts of hydrocarbons in the Binak depression. The main phase of oil generation and expulsion from the Cretaceous source rocks is relatively recent and thus highly favorable for the conservation of hydrocarbon accumulations. Trap charging occurred through the late Miocene to Pliocene after the Zagros folding. 2D models predict that the Albian source rock still has significant hydrocarbon generation potential whereas the lower Neocomian source rock has reached already a high transformation ratio within the deep kitchen area. Oil migration occurs in both lateral and vertical directions. This migration pattern could explain the distribution of identified oil families in the northwestern part of the Persian Gulf.     

四川盆地雷四3亚段油气勘探方向

近年来,中石油和中石化在四川盆地雷口坡组雷四³亚段的勘探陆续取得重要进展,展示了良好的勘探前景。笔者结合新钻探井和最新研究成果,从地层、沉积相、烃源岩、储层和成藏等多方面采用烃源对比、埋藏史及烃源岩热演化史、包裹体测温等方法对四川盆地雷四³亚段的含油气地质条件进行了进一步分析,总结了其油气成藏特征,提出了有利勘探区带,以期有助于拓展四川盆地雷口坡组的勘探领域。研究结果表明:雷四³亚段天然气以雷口坡组和须家河组烃源岩混合来源气为主;储集空间以粒间溶孔、晶间溶孔为主,属低孔低渗储层;雷四³亚段气藏为2期成藏,烃源岩于中、晚侏罗世进入生烃高峰;雷四³亚段具有构造和构造-岩性地层2种气藏类型,龙门山山前断褶带为构造气藏的有利勘探区,新津-邛崃斜坡带与梓潼-盐亭斜坡带是构造-岩性地层气藏的有利勘探区。     

Petroleum source rock characterisation and hydrocarbon generation modeling of the Cretaceous sediments in the Jiza sub-basin,eastern Yemen

Cretaceous sedimentary rocks of the Mukalla, Harshiyat and Qishn formations from three wells in the Jiza sub-basin were studied to describe source rock characteristics, providing information on organic matter type, paleoenvironment of deposition and hydrocarbon generation potential. This study is based on organic geochemical and petrographic analyses performed on cuttings samples. The results were then incorporated into basin models in order to understand the burial and thermal histories and timing of hydrocarbon generation and expulsion.The bulk geochemical results show that the Cretaceous rocks are highly variable with respect to their genetic petroleum generation potential. The total organic carbon (TOC) contents and petroleum potential yield (S₁ + S₂) of the Cretaceous source rocks range from 0.43 to 6.11% and 0.58–31.14 mg HC/g rock, respectively indicating non-source to very good source rock potential. Hydrogen index values for the Early to Late Cretaceous Harshiyat and Qishn formations vary between 77 and 695 mg HC/g TOC, consistent with Type I/II, II-III and III kerogens, indicating oil and gas generation potential. In contrast, the Late Cretaceous Mukalla Formation is dominated by Type III kerogen (HI < 200 mg HC/g TOC), and is thus considered to be gas-prone. The analysed Cretaceous source rock samples have vitrinite reflectance values in the range of 0.37–0.95 Ro% (immature to peak-maturity for oil generation).A variety of biomarkers including n-alkanes, regular isoprenoids, terpanes and steranes suggest that the Cretaceous source rocks were deposited in marine to deltaic environments. The biomarkers also indicate that the Cretaceous source rocks contain a mixture of aquatic organic matter (planktonic/bacterial) and terrigenous organic matter, with increasing terrigenous influence in the Late Cretaceous (Mukalla Formation).The burial and thermal history models indicate that the Mukalla and Harshiyat formations are immature to early mature. The models also indicate that the onset of oil-generation in the Qishn source rock began during the Late Cretaceous at 83 Ma and peak-oil generation was reached during the Late Cretaceous to Miocene (65–21 Ma). The modeled hydrocarbon expulsion evolution suggests that the timing of oil expulsion from the Qishn source rock began during the Miocene (>21 Ma) and persisted to present-day. Therefore, the Qishn Formation can act as an effective oil-source but only limited quantities of oil can be expected to have been generated and expelled in the Jiza sub-basin.     

Thermal maturity history and petroleum generation modelling for the Lower Cretaceous Abu Gabra Formation in the Fula Sub-basin,Muglad Basin,Sudan

Two petroleum source rock intervals of the Lower Cretaceous Abu Gabra Formation at six locations within the Fula Sub-basin, Muglad Basin, Sudan, were selected for comprehensive modelling of burial history, petroleum maturation and expulsion of the generated hydrocarbons throughout the Fula Sub-basin. Locations (of wells) selected include three in the deepest parts of the area (Keyi oilfield); and three at relatively shallow locations (Moga oilfield). The chosen wells were drilled to depths that penetrated a significant part of the geological section of interest, where samples were available for geochemical and source rock analysis. Vitrinite reflectances (Ro %) were measured to aid in calibrating the developed maturation models.The Abu Gabra Formation of the Muglad Basin is stratigraphically subdivided into three units (Abu Gabra-lower, Abu Gabra-middle and Abu Gabra-upper, from the oldest to youngest). The lower and upper Abu Gabra are believed to be the major source rocks in the province and generally contain more than 2.0 wt% TOC; thus indicating a very good to excellent hydrocarbon generative potential. They mainly contain Type I kerogen. Vitrinite reflectance values range from 0.59 to 0.76% Ro, indicating the oil window has just been reached. In general, the thermal maturity of the Abu Gabra source rocks is highest in the Abu Gabra-lower (deep western part) of the Keyi area and decreases to the east toward the Moga oilfied at the Fula Sub-basin.Maturity and hydrocarbon generation modelling indicates that, in the Abu Gabra-Lower, early oil generation began from the Middle- Late Cretaceous to late Paleocene time (82.0–58Ma). Main oil generation started about 58 Ma ago and continues until the present day. In the Abu Gabra-upper, oil generation began from the end of the Cretaceous to early Eocene time (66.0–52Ma). Only in one location (Keyi-N1 well) did the Abu Gabra-upper reach the main oil stage. Oil expulsion has occurred only from the Abu Gabra-lower unit at Keyi-N1 during the early Miocene (>50% transformation ratio TR) continuing to present-day (20.0–0.0 Ma). Neither unit has generated gas. Oil generation and expulsion from the Abu Gabra source rocks occurred after the deposition of seal rocks of the Aradeiba Formation.     

Formation of low permeability reservoirs and gas accumulation process in the Daniudi Gas Field,Northeast Ordos Basin,China

The Daniudi Gas Field is a typical large-scale coal-generated wet gas field located in the northeastern Ordos Basin that contains multiple Upper Paleozoic gas-bearing layers and considerable reserves of gas. Based on integrated analysis of reservoir petrology, carbonate cement C–O isotope, geochemistry of source rocks and HC gas and numerical basin modeling, a comprehensive study focusing on the formation of low permeability reservoirs and gas generation process uncovers a different gas accumulation scene in Daniudi Gas Field. The gas accumulation discovered was controlled by the reservoir permeability reduction and gas generation process, and can be divided into two distinct stages by the low permeability reservoir formation time: before the low permeability reservoir formation, the less matured gas was driven by buoyancy, migrated laterally towards NE and then accumulated in NE favorable traps during Late Triassic to early Early Cretaceous; after the low permeability reservoir formation, highly matured gas was driven by excessive pressure, migrated vertically and accumulated in-situ or near the gas-generating centers during early to late Early Cretaceous. The coupling relationship between reservoir diagenetic evolution and gas generation process controlled on gas accumulation of the Daniudi Gas Field. This study will aid in understanding the gas accumulation process and planning further E&D of the Upper Paleozoic super-imposed gas layers in the whole Ordos Basin and other similar super-imposed low permeability gas layer basins.