Modeling of tectono-thermal evolution of Permo-Carboniferous source rocks in the southern Qinshui Basin, China: Consequences for hydrocarbon generation

2020 ◽  
Vol 193 ◽  
pp. 107343 ◽  
Author(s):  
Kun Yu ◽  
Yiwen Ju ◽  
Baoxin Zhang
Keyword(s):  
Thermal Evolution ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Qinshui Basin ◽  
Southern Qinshui Basin

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

Energies ◽  
2019 ◽  
Vol 12 (4) ◽  
pp. 650 ◽  
Author(s):  
Jinliang Zhang ◽  
Jiaqi Guo ◽  
Jinshui Liu ◽  
Wenlong Shen ◽  
Na Li ◽  
...  
Keyword(s):  
Source Rock ◽  
Thermal Evolution ◽  
Vitrinite Reflectance ◽  
Three Dimensional ◽  
Source Rocks ◽  
Rock Properties ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Accumulation ◽  
Southeastern Part ◽  
Petroleum Generation

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.

scholarly journals Fine evaluation and favorable area prediction of deep source rocks in northern Songliao Basin

2021 ◽  
Vol 329 ◽  
pp. 01056
Author(s):  
Fan Zhang ◽  
Yanjie Li ◽  
Xiaoshan Ji ◽  
Qiuli Huo ◽  
Yuming Wu ◽  
...  
Keyword(s):  
Natural Gas ◽  
Comprehensive Evaluation ◽  
Thermal Evolution ◽  
Songliao Basin ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Gas Generation ◽  
The North ◽  
Geological Conditions ◽  
Exploration Area

Focusing on Xujiaweizi fault depression, the geological conditions and geochemical characteristics of deep natural gas formation in the north of Songliao basin are evaluated, the natural gas resources are estimated, and the favorable areas are optimized. Shahezi Formation shale is a set of coal bearing sediments with high organic matter abundance (TOC is 1%～12%), high over maturity (Ro is 1%～4%) and shore shallow lake facies, which are mainly distributed in Xujiaweizi fault depression, Gulong-Lindian fault depression and Yingshan fault depression. The thickness, TOC, Ro and hydrocarbon generation of four thirdorder sequences with different lithology (mudstone and coal) are carefully evaluated for the Shahezi Formation shale in the deep layer of Songbei. The comprehensive evaluation shows that the mudstone thickness of Es4 member in Anda and Xuzhong areas of Xujiaweizi fault depression is large (150 ~ 525m), TOC is high (1% ~ 4%), thermal evolution degree is high (Ro is 1.2% ~ 3.4%), and gas generation intensity is high (20 ~ 815) × 108m3 / t), moderate buried depth (3000~4500m) and overlapping area of 756km2. It is a favorable exploration area for natural gas and shale gas in Daqing Oilfield.

scholarly journals Effects of igneous intrusions on source rock in the early diagenetic stage: A case study on Beipiao Formation in Jinyang Basin, Northeast China

2020 ◽  
Vol 12 (1) ◽  
pp. 990-1002
Author(s):  
Shouliang Sun ◽  
Tao Zhang ◽  
Yongfei Li ◽  
Shuwang Chen ◽  
Qiushi Sun
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Thermal Evolution ◽  
Vitrinite Reflectance ◽  
Scientific Basis ◽  
Source Rocks ◽  
Temperature History ◽  
Hydrocarbon Generation ◽  
Intrusive Body ◽  
Geochemical Parameters

AbstractMesozoic intrusive bodies play an important role in the temperature history and hydrocarbon maturation of the Jinyang Basin in northeastern China. The Beipiao Formation, which is the main source rock in Jinyang Basin, was intruded by numerous igneous bodies and dykes in many areas. The effects of igneous intrusive bodies on thermal evolution and hydrocarbon generation and migration in the Beipiao Formation were investigated. A series of samples from the outcrop near the intrusive body were analyzed for vitrinite reflectance (R0%) and other organic geochemical parameters to evaluate the lateral extension of the thermal aureole. The R0 values of the samples increase from a background value of ∼0.9% at a distance above 200 m from the intrusive body to more than 2.0% at the vicinity of the contact zone. The width of the altered zone is equal to the thickness of the intrusive body outcropped in the field. Organic geochemical proxies also indicate the intrusive body plays a positive and beneficial role in the formation of regional oil and gas resources. Due to the influence of the anomalous heat from the intrusive body, the hydrocarbon conversion rate of the source rocks of the Beipiao Formation was significantly improved. The accumulation properties and the storage capacity of the shales also greatly improved due to the intrusive body as indicated by the free hydrocarbon migration in the shales. This new understanding not only provides a reliable scientific basis for the accurate assessment of oil and gas genesis and resources in the Jinyang Basin but also provides guidance and reference for oil and gas exploration in the similar type of basin.

Hydrocarbon Generation Process Investigation of Permian and the Low Triassic Source Rocks on Lower Yangzte Region

2011 ◽  
Vol 356-360 ◽  
pp. 2929-2932 ◽  
Author(s):  
Yan Ran Huang ◽  
Zhi Huan Zhang ◽  
Ji Yong Liu
Keyword(s):  
Activation Energy ◽  
Thermal Evolution ◽  
Weighted Average ◽  
Lower Triassic ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Generation Process ◽  
Burial History ◽  
Lower Yangtze Region ◽  
Lower Yangtze

On Lower Yangtze region source rocks of Permian and the Lower Triassic activation energy distribution suggests that source rocks experienced some hydrocarbon generation reaction, generally high activation energy mainly because of high maturity, the weighted average activation energy has good positive correlation with maturity. The time of hydrocarbon generation in Huang Qiao area is short, and it’s speed is fast; the time in Ju Rong area is longer, characteristics is prone to early and multi-period; source rocks in Chao Hu region been uplifted to surface, the thermal evolution is lowest of all, and the time is longest. Source rocks secondary hydrocarbon generation exists in many area in Lower Yangtze region, the degree of hydrocarbon generation is mainly depend on sedimentary burial history.

scholarly journals The Impact of Salt Tectonics on the Thermal Evolution and the Petroleum System of Confined Rift Basins: Insights from Basin Modeling of the Nordkapp Basin, Norwegian Barents Sea

Geosciences ◽  
2019 ◽  
Vol 9 (7) ◽  
pp. 316
Author(s):  
Andrés Cedeño ◽  
Luis Alberto Rojo ◽  
Néstor Cardozo ◽  
Luis Centeno ◽  
Alejandro Escalona
Keyword(s):  
Thermal Effect ◽  
Barents Sea ◽  
Thermal Evolution ◽  
Thermal Anomaly ◽  
Petroleum System ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Rift Basins ◽  
Thermal Anomalies ◽  
The Impact

Although the thermal effect of large salt tongues and allochthonous salt sheets in passive margins is described in the literature, little is known about the thermal effect of salt structures in confined rift basins where sub-vertical, closely spaced salt diapirs may affect the thermal evolution and petroleum system of the basin. In this study, we combine 2D structural restorations with thermal modeling to investigate the dynamic history of salt movement and its thermal effect in the Nordkapp Basin, a confined salt-bearing basin in the Norwegian Barents Sea. Two sections, one across the central sub-basin and another across the eastern sub-basin, are modeled. The central sub-basin shows deeply rooted, narrow and closely spaced diapirs, while the eastern sub-basin contains a shallower rooted, wide, isolated diapir. Variations through time in stratigraphy (source rocks), structures (salt diapirs and minibasins), and thermal boundary conditions (basal heat flow and sediment-water interface temperatures) are considered in the model. Present-day bottom hole temperatures and vitrinite data provide validation of the model. The modeling results in the eastern sub-basin show a strong but laterally limited thermal anomaly associated with the massive diapir, where temperatures in the diapir are 70 °C cooler than in the adjacent minibasins. In the central sub-basin, the thermal anomalies of closely-spaced diapirs mutually interfere and induce a combined anomaly that reduces the temperature in the minibasins by up to 50 °C with respect to the platform areas. Consequently, source rock maturation in the areas thermally affected by the diapirs is retarded, and the hydrocarbon generation window is expanded. Although subject to uncertainties in the model input parameters, these results demonstrate new exploration concepts (e.g., deep hydrocarbon kitchens) that are important for evaluating the prospectivity of the Nordkapp Basin and similar basins around the world.

scholarly journals The magma thermal field and the shallow-level gas accumulation of tight gas reservoirs in the middle-eastern parts of the Qinshui Basin

2019 ◽  
Vol 23 (1) ◽  
pp. 27-34
Author(s):  
Ke Sun ◽  
Shuheng Tang ◽  
Songhang Zhang ◽  
Zhaodong Xi ◽  
Jun Li
Keyword(s):  
Tectonic Evolution ◽  
Thermal Field ◽  
Middle Eastern ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs ◽  
Qinshui Basin ◽  
Heating Water

In this study, the metal-non-metal mineral gas-water hydrothermal concept is used to analyze the movement channels of magmatic heating water. Further, the concept of fractures-faults-cracks microfissures hierarchical configuration of the movement channels of magmatic heating water is proposed. In addition, the magma thermal field formed by magmatic heating water movement is studied and analyzed. Based on the basin simulation method, which is combined with the paleo-tectonic evolution analysis and restoration of the ancient burial depth in the middle-eastern parts of the Qinshui Basin, the tectonic evolution history, thermal evolution history, and hydrocarbon generation and exhaustion history of tight gas reservoirs in the Yushe-Wuxiang block in the middle-eastern parts of the Qinshui Basin have been investigated. On the basis of the theories and methods that are proposed in this study, the hierarchical configuration of fractures-faults-cracks microfissures movement channels of magmatic heating water in the Yushe-Wuxiang block in the middle-eastern parts of the Qinshui Basin was studied and analyzed. It is observed that the magmatic heating water rises to the source formation through the movement channels of hierarchical configuration, heats the source rocks, accelerates the evolution of the source rock in the shallow layer, and forms a tight gas reservoir. 

scholarly journals Evaluation of Hydrocarbon Generation Using Structural and Thermal Modeling in the Thrust Belt of Kuqa Foreland Basin, NW China

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-18
Author(s):  
Chengfu Lyu ◽  
Xixin Wang ◽  
Xuesong Lu ◽  
Qianshan Zhou ◽  
Ying Zhang ◽  
...  
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Thermal Evolution ◽  
Foreland Basin ◽  
Source Rocks ◽  
Mature Stage ◽  
Hydrocarbon Generation ◽  
Thrust Belt ◽  
Salt Layer ◽  
Kuqa Foreland Basin

The Kuqa Basin is a typical foreland basin in northwest China, characterized by compressive foreland fold-and-thrust belts and a regionally distributed huge salt layer. A large number of overthrust faults, fault-related folds, and salt-related structures are formed on the thrust belt due to strong compression and structural deformation, causing difficulty in simulation of the basin. In this study, modeling of the thermal history of the complicated compressional structural profiles in the Kuqa foreland basin was successfully conducted based on the advanced “Block” function introduced by the IES PetroMod software and the latest geological interpretation results. In contrast to methods used in previous studies, our method comprehensively evaluates the influence of overthrusting, a large thick salt layer with low thermal conductivity, fast deposition, or denudation on the thermal evolution history. The results demonstrate that the hydrocarbon generation center of the Kuqa foreland basin is in the deep layers of the Kelasu thrust belt and not in the Baicheng Sag center, which is buried the deepest. A surprising result was drawn about the center of hydrocarbon generation in the Kuqa foreland basin, which, although not the deepest in Baicheng Sag, is the deepest part of the Kelasu thrust Belt. In terms of the maturity of the source rock, there are obvious temporal and spatial differences between the different structural belts in the Kuqa foreland basin, such as the early maturation of source rocks and the curbing of uplift and hydrocarbon generation in the piedmont zone. In the Kelasu thrust belt, the source rock made an early development into the low mature-mature stage and subsequently rapidly grew into a high-over mature stage. In contrast, the source rock was immature at an early stage and subsequently grew into a low mature-mature stage in the Baicheng Sag–South slope belt. The time sequence of the thermal evolution of source rocks and structural trap formation and their matching determines the different accumulation processes and oil and gas compositions in the different structural belts of the Kuqa foreland basin. The matching of the multistage tectonic activity and hydrocarbon generation determines the characteristics of the multistage oil and gas accumulation, with the late accumulation being dominant. The effective stacking of the gas generation center, subsalt structural traps, reservoir facies of fine quality, and huge, thick salt caprocks creates uniquely favorable geological conditions for gas enrichment in the Kelasu foreland thrust belt.

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