Hydrocarbon generation and potential in continental organic-rich shales at the highly-mature stage, as determined by hydrous pyrolysis under supercritical conditions

2018 ◽  
Vol 187 ◽  
pp. 83-93 ◽  
Author(s):  
Yuandong Wu ◽  
Zhongning Zhang ◽  
Lina Sun ◽  
Yuanju Li ◽  
Cong He ◽  
...  
Keyword(s):  
Mature Stage ◽  
Hydrocarbon Generation ◽  
Supercritical Conditions ◽  
Hydrous Pyrolysis

THE STRUCTURAL DEVELOPMENT AND HYDROCARBON POTENTIAL OF PALAEOZOIC SOURCE ROCKS IN THE ADAVALE BASIN REGION

1984 ◽  
Vol 24 (1) ◽  
pp. 393 ◽  
Author(s):  
V. L. Passmore ◽  
M. J. Sexton
Keyword(s):  
Middle Devonian ◽  
Oil And Gas ◽  
Structural Features ◽  
Source Rocks ◽  
Geochemical Data ◽  
Mature Stage ◽  
Hydrocarbon Generation ◽  
Structural Development ◽  
Seismic Reflection Data ◽  
Basin Region

The Adavale Basin of southwestern Queensland consists of a main depression and several isolated synclinal extensions, traditionally referred to as troughs. The depressions and troughs are erosional remnants of a once more extensive Devonian depositional basin, and are now completely buried by sediments of the overlying Cooper, Galilee and Eromanga Basins. Geophysical and drilling investigations undertaken since 1959 are the only source of information on the Adavale Basin. A single sub-economic discovery of dry gas at Gilmore and a few shows of oil and gas are the only hydrocarbons located in the basin to date.In 1980, the Bureau of Mineral Resources in cooperation with the Geological Survey of Queensland commenced a major, multidisciplinary investigation of the basins in southwestern Queensland. Four long (> 200 km) seismic lines from this study over the Adavale Basin region and geochemical data from 20 wells were used to interpret the Adavale Basin's development and its present hydrocarbon potential.The new seismic reflection data allow the well-explored main depression to be correlated with the detached troughs, some of which have little or no well information. The BMR seismic data show that these troughs were previously part of one large depositional basin in the Devonian, the depocentre of which lay east of a north-trending hingeline. Structural features and Devonian depositional limits and patterns have been modified from earlier interpretations as a result of the new seismic coverage. The maximum sediment thickness is re-interpreted to be 8500 m, considerably thicker than previous interpretation.recognised. The first one, a diachronous Middle Devonian unconformity, is the most extensive, and reflects the mobility of the basement during the basin's early history. The second unconformity within the Late Devonian Buckabie Formation reveals that there were two phases of deformation of the basin sediments.The geochemical results reported in this study show that most of the Adavale Basin sediments have very low concentrations of organic carbon and hydrocarbon fractions. Maturity profiles indicate that the best source rocks of the basin are now in the mature stage for hydrocarbon generation. However, at Gilmore and in the Cooladdi Trough, they have reached the dry gas stage. The maturity data provide additional evidence for the marked break in deposition and significant erosion during the Middle Devonian recognised on the seismic records, and extend the limits of this sedimentary break into the northern part of the main depression.Hydrocarbon potential of the Adavale Basin is fair to poor. In the eastern part of the basin, where most of the data are available, the prospects are better for gas than oil. Oil prospectivity may be improved in any exinite-rich areas that exist farther west, where palaeo-temperatures were lower.

The Evaluation of Potential of Shale Oil Resources in K1qn1 Formation of Southern Songliao Basin

2014 ◽  
Vol 1006-1007 ◽  
pp. 107-111
Author(s):  
Yan Wang ◽  
Wen Biao Huang ◽  
Min Wang
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Thermal Evolution ◽  
Songliao Basin ◽  
Mature Stage ◽  
Type I ◽  
Hydrocarbon Generation ◽  
Shale Oil ◽  
Oil Resources ◽  
Geochemical Method

Based on the analysis of source rock geochemical index, with K1qn1 Formation of southern Songliao basin as the research objective layer, it’s concluded that the mean TOC value of shale in K1qn1 Formation is higher, generally more than 1%, which belongs to the best source rock. Most of shale organic matter types are type I and type II1. The thermal evolution degree of organic matter is generally in the mature stage: a stage of large hydrocarbon generation. With logging geochemical method applied, the calculated total resources of shale oil in K1qn1 formation are 15.603 billion tons. The II level of resources are 8.765 billion tons, which is more than 50% of the total resources. The I level of resources are 4.808 billion tons while the III level of resources 2.03 billion tons. Overall, the southern Songliao Basin still has a certain degree of prospecting and mining value.

Maturity Evolution of the Cambrian Source Rocks in the Tarim Basin

2012 ◽  
Vol 622-623 ◽  
pp. 1642-1645
Author(s):  
Zong Lin Xiao ◽  
Qing Qing Hao ◽  
Zhong Min Shen
Keyword(s):  
Source Rock ◽  
Tarim Basin ◽  
Source Rocks ◽  
Petroleum Exploration ◽  
Mature Stage ◽  
Hydrocarbon Generation ◽  
Foreland Basins ◽  
Structural History ◽  
Depositional Age ◽  
Petroleum Basin

The Tarim basin is an important petroleum basin in China, and the Cambrian strata are the major source rock successions in the basin. Integrated the source rock depositional and structural history with its geochemical and thermal parameters, this paper simulates the evolution of the Cambrian source rocks with the software Basinview. The simulation result shows that the main hydrocarbon-generation centers of the Manjiaer sag in the Tabei depression and the Tangguzibasi sag in the Southwest depression are characterized by their early hydrocarbon generation, and in the late Ordovician depositional age, they reached dry gas stage. The Kuqa and Southwest depressions developed in the Cenozoic foreland basins made the Cambrian source rocks mature rapidly in the Cenozoic period. The source rock maturity in the Tarim basin now is characterized by high in the east and west and low in the middle, and most of the area is in the over-mature stage in the present. This study can provide available maturity data for the next petroleum exploration work.

Pore characteristics and dominant controlling factors of overmature shales: A case study of the Wangyinpu and Guanyintang Formations in the Jiangxi Xiuwu Basin

2018 ◽  
Vol 6 (2) ◽  
pp. T393-T412 ◽  
Author(s):  
Fenglin Gao ◽  
Yan Song ◽  
Zhuo Li ◽  
Zhenxue Jiang ◽  
Zhiye Gao ◽  
...  
Keyword(s):  
Image Processing ◽  
Gas Adsorption ◽  
Controlling Factors ◽  
Mature Stage ◽  
Jiangxi Province ◽  
Type I ◽  
Hydrocarbon Generation ◽  
Pore Characteristics ◽  
Total Contribution ◽  
Main Controlling Factors

Because of the great potential for hydrocarbon generation, the Lower Cambrian Wangyinpu and Guanyintang Formations of the Jiangxi Xiuwu Basin have become the most important targets for shale-gas exploration in the Jiangxi province. We investigate the pore characteristics and main controlling factors of overmature shale using field emission-scanning electron microscopy, image-processing software (i.e., the Particles [Pores] and Crack Analysis System), X-ray diffraction, and gas-adsorption experiments. The results show that the shales have a high abundance of organic matter (OM), over maturity, and highly siliceous mineral content. The kerogen type is identified as type I. OM pores are the most developed, followed by interparticle (interP) pores and intraparticle (intraP) pores. We combine complementary image processing and gas-adsorption methods to reveal that micropores are mainly from OM pores; mesopores are from OM pores and interP pores; and macropores are from OM pores, interP pores, and intraP pores. Although the number of micropores is at a maximum, the total contribution of mesopores and macropores to the pore volume (PV) is larger than that of micropores. However, the specific surface area (SSA) is mainly from the micropores. OM content and maturity are the main controlling factors for the development of pore structures. Because of overmaturity, OM loses its potential for hydrocarbon generation and new pores cannot be produced. Gas loss leads to reservoir pressure drop, and the pores generated during the mature stage collapse and even disappear because they lack support. Therefore, PV, SSA, and porosity decrease when the OM content is more than 10%. When the OM content is less than 10%, most of the OM pores are preserved because they are protected by the skeleton particles.

In-Situ Hydrocarbon Generation Method from Oil Shale Using Hydrous Pyrolysis

2019 ◽  
Author(s):  
A. Turakhanov ◽  
A. Tsyshkova ◽  
E. Popov ◽  
A. Cheremisin
Keyword(s):  
Oil Shale ◽  
Hydrocarbon Generation ◽  
Hydrous Pyrolysis

Hydrocarbon Source Rock Quality and Analysis of Hydrocarbon Potential in K1sh of Zhaozhou Sag

2014 ◽  
Vol 962-965 ◽  
pp. 121-126
Author(s):  
Lei Shi ◽  
Lai Xing Cai ◽  
Wen Biao Huang ◽  
Min Wang ◽  
Shuang Liu
Keyword(s):  
Source Rock ◽  
Kinetic Method ◽  
Chemical Kinetic ◽  
Mean Value ◽  
Mature Stage ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Source Rock ◽  
Resource Potential ◽  
High Resource ◽  
Generating Capacity

Use of drilling, logging and seismic data, research on K1shgeology and geochemical characteristics of Zhaozhou Sag, combining the geohistory, thermal history and chemical kinetics evaluation of tight gas resource potential of K1sh. The results show that, TOC of K1shin Zhaozhou Sag mean value is 1.12%; The type of organic matter mostly of type III andII1; the average maturity of 2.41%, more than 70% entered the mature stage. Mudstone are developed widely, the average thickness of 140 meters. In the simulation experiments based on hydrocarbon generation thermal, In the study area by using chemical kinetic method for the quantitative evaluation of hydrocarbon source rock in the deep formation. The results show that, K1shin Zhaozhou Sag total generating capacity is 4.68×1012m3, the results can be seen from the generated gas, the K1shin Zhaozhou Sag has high resource potential.

scholarly journals Preliminary investigation of the hydrocarbon generation potential from the post-rift Abbas shale Formation (Pliocene) in the Tihamah Basin, south-eastern Yemeni Red Sea

2020 ◽  
Author(s):  
Mohammed Hail Hakimi ◽  
Abbas F. Gharib ◽  
Nor Syazwani Z. Abidin ◽  
Madyan M. A. Yahya
Keyword(s):  
Preliminary Investigation ◽  
Source Rocks ◽  
Mature Stage ◽  
Preliminary Evaluation ◽  
Hydrocarbon Generation ◽  
Organic Facies ◽  
Petroleum Generation ◽  
Good Potential ◽  
Facies Types ◽  
Rock Eval

AbstractPliocene shales included in the post-rift Abbas Formation were recovered from an exploratory well (Kathib-01) in the Tihamah Basin and geochemically analyzed. A preliminary evaluation of the organic facies of the Abbas shales and their petroleum generation potential was conducted based on basic organic geochemical results. Most Abbas shale samples had total organic carbon (TOC) contents < 1% and a fair source potential, while the remaining samples, with TOC contents > 1%, had a relatively good potential. Overall, the Rock–Eval hydrogen index values of the shales analyzed were between 96 and 234 mg of hydrocarbon per gram of TOC (mg HC/g TOC), indicating two dominant organic facies: types III and II/III kerogen, which indicate the presence of mainly gas- and oil-prone source rocks. We conclude that the Pliocene Abbas shales in the Tihamah Basin are still in a very early-mature stage (with respect to the oil window) and, hence, have not generated petroleum yet.

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