Silica diagenesis promotes early primary hydrocarbon migration

Abstract We present evidence that hydrocarbon source rocks can be preconditioned for primary hydrocarbon migration at an early stage of catagenesis by pore-scale processes linked to silica diagenesis. The evidence comes from a detailed petrographic and geochemical study of the Jordan Oil Shale (JOS), an immature to early mature, Upper Cretaceous to Paleogene source rock developed on the platform regions of central and southern Jordan. Diagenesis of biogenic silica led to silicification of the source rock interval and the growth of chert nodules. Localization of bitumen veins in reaction rims around these nodules is interpreted to indicate that silica diagenesis promotes the early mobilization of hydrocarbons from the geochemically identical, disseminated bitumen within the host mudstones. We propose a model in which early-formed bitumen migrated into neoforming mode I fractures that formed as a result of the crystallization pressure imposed from the growing chert nodule. Hydraulic fracturing occurred under elevated bitumen fluid pressures that approached lithostatic stress values under burial depths of the order of 1000 m. The recognition that silica diagenesis can promote the early migration of neoforming bitumen raises the possibility that primary hydrocarbon migration may occur earlier and at shallower depths than predicted by kinetic modeling approaches wherever silica diagenetic reactions are coeval with catagenesis.

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Integrated 3D basin and petroleum systems modelling of the Great Australian Bight

The APPEA Journal ◽

10.1071/aj16133 ◽

2017 ◽

Vol 57 (2) ◽

pp. 733

Author(s):

E. Frery ◽

M. Ducros ◽

L. Langhi ◽

J. Strand ◽

A. Ross

Keyword(s):

Heat Flow ◽

Source Rock ◽

Source Rocks ◽

Integrated Modelling ◽

Hydrocarbon Migration ◽

Petroleum Systems ◽

Basin Modelling ◽

Well Data ◽

Great Australian Bight ◽

Migration Pathways

3D stratigraphic, structural, thermal and migration modelling has become an essential part of petroleum systems analysis for passive margins, especially if complex 3D facies patterns and extensive volcanic activity are observed. A better understanding of such underexplored offshore areas requires a refined 3D basin modelling approach, with the implementation of realistically sized volcanic intrusions, source rocks and reservoir intervals. In this study, an integrated modelling workflow based on a Great Australian Bight case study has been applied. The 244800-km2 3D model integrates well data, marine surveys, 3D stratigraphic forward modelling and 3D basin modelling to better predict the effects of 3D facies variations and heat flow anomalies on the determination of the source rock-enriched intervals, the source rock maturity history and the hydrocarbon migration pathways. Plausible sedimentary sequences have been estimated using a stratigraphic forward model constrained by the limited available well data, seismic interpretation and published tectonic basin history. We also took into account other datasets to produce a thermal history model, such as the location of known volcanic intrusion, volcanic seamounts, bottom hole temperature and surface heat flow measurements. Such basin modelling integrates multiple datatypes acquired in the same basin and provides an ideal platform for testing hypotheses on source rock richness or kinetics, as well as on hydrocarbon migration timing and pathways evolution. The model is flexible, can be easily refined around specific zones of interest and can be updated as new datasets, such as new seismic interpretations and data from new sampling campaigns and wells, are acquired.

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Depositional Setting and Enrichment Mechanism of Organic Matter of Lower Cretaceous Shale in Ri-Qing-Wei Basin in the Central Sulu Orogenic Belt

Frontiers in Earth Science ◽

10.3389/feart.2021.808916 ◽

2022 ◽

Vol 9 ◽

Author(s):

Tengfei Zhou ◽

Yaoqi Zhou ◽

Hanjie Zhao ◽

Manjie Li ◽

Hongyu Mu

Keyword(s):

Organic Matter ◽

Source Rock ◽

Early Stage ◽

Salt Water ◽

Sedimentary Environment ◽

Source Rocks ◽

Hydrocarbon Generation ◽

Element Geochemistry ◽

High Positive Correlation ◽

Evolution Stage

A suite of source rock consists of mudstone and shale, with great thickness and continuous deposition was found in the well LK-1 in Lingshan island in Ri-Qing-Wei basin. In order to evaluate the hydrocarbon generation prospects of these source rock and find the mechanism of organic matter enrichment, shale samples were selected from the core for TOC (total organic carbon) and element geochemistry analysis. The results show that organic matter abundance of the source rocks are generally high with average TOC content of 1.26 wt%, suggesting they are good source rocks. The geochemical features show that the sedimentary environment is mostly anoxic brackish water to salt water environment with arid to semiarid climate condition. The enrichment mechanism of organic matter varied with the evolution of the basin, which was divided into three stages according to the sedimentary characteristics. In the initial-middle period of rifting evolution (stage 1 and early stage 2), paleoproductivity is the major factor of OM-enrichment reflecting by high positive correlation between the TOC contents and paleoproductivity proxies. While with the evolution of the rift basin, redox condition and terrigenous clastic input became more and more important until they became the major factor of OM enrichment in the middle stage of rift evolution (stage 2). In the later stage of rift evolution (latest stage 2 and stage 3), besides terrigenous clastic input, the effect of paleoclimate on OM-enrichment increased gradually from a minor factor to a major factor.

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Geochemical study of the early cretaceous Fahliyan oil reservoir in the northwest Persian Gulf

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-021-01178-2 ◽

2021 ◽

Vol 11 (6) ◽

pp. 2435-2447

Author(s):

Abbas Khaksar Manshad ◽

Reza Sedighi Pashaki ◽

Jagar A. Ali ◽

Stefan Iglauer ◽

M. Memariani ◽

...

Keyword(s):

Source Rock ◽

Early Cretaceous ◽

Persian Gulf ◽

Source Rocks ◽

Low Viscosity ◽

Hydrocarbon Analysis ◽

Geochemical Study ◽

Carbonate Source Rock ◽

Production Strategy ◽

Carbonate Source

AbstractThree crude oil samples from the Fahliyan Formation in ‘KG’ and ‘F’ fields in the northwest Persian Gulf, namely KG-031, F9A-3H and F15-3H for the geochemical study. In this study, the physicochemical properties, gas chromatography (GC, GC Mass) and (Detailed Hydrocarbon Analysis) DHA analyses for the collected Fahliyan oils were carried out. The API, Trace Element (Ni, V) and S% parameters indicated that the Fahliyan oil was generated from a source rock which deposited in reducing environment condition with a carbonate-shale compound lithology. Moreover, low pour point, higher S% and low viscosity parameters of “KG” sample confirmed the existence of medium oil characteristics in this field. In addition, the geochemical outcomes of GC, GC–MS and DHA analyses indicated that the ‘KG’ oils are more aromatic compared with ‘F’ oil; while biomarkers revealed that Fahliyan reservoir oil is highly mature and was formed from a carbonate source rock containing types II, III kerogen. Thus, sterane/hopane biomarkers (C24/C23 and C22/C21 ratios) revealed that Fahliyan oil originated from carbonate source rocks deposited in an anoxic to dysoxic environment, which is consistent with the above analyses. It was identified that the source rock age is early Cretaceous to late Jurassic. It can be reported that the Fahliyan oils from both fields were generated in the same source rock and have almost the same physical properties, and will have the same production strategy.

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Evaluation of Neoproterozoic Source Rock Potential in SE Pakistan and Adjacent Bikaner- Nagaur Basin India Based on Integrated Geochemical, Geological, and Geophysical Data

10.21203/rs.3.rs-1099958/v1 ◽

2021 ◽

Author(s):

Qamar Yasin ◽

Syrine Baklouti ◽

Ghulam Mohyuddin Sohail ◽

Muhammad Asif ◽

Gong Xufei

Keyword(s):

Source Rock ◽

Early Stage ◽

Seismic Inversion ◽

Source Rocks ◽

Maturity Index ◽

Thermal Maturity ◽

Index Profile ◽

Southeastern Part ◽

Seismic Reflection Data ◽

Rock Eval

Abstract Discoveries of heavy crude oil in the Neoproterozoic rocks (Infracambrian rock sequence) from the Bikaner-Nagaur Basin of India emphasizes the significance to study and explore the Neoproterozoic source rocks potential in the southeastern part of Pakistan. This study evaluates the potential of the source rock in the Infracambrian rock sequence (Salt Range Formation) based on surface geochemical surveys, Rock-Eval pyrolysis, source biomarkers, geophysical characterization, and seismic inversion using machine learning for maturity index estimation. Core samples of Infracambrian rock were extracted for Rock-Eval pyrolysis and biomarker characterization. Also, 81 geo-microbial soil and gas samples were collected from the surface to explore the petroleum system and potential source rocks in the subsurface. We followed the standard laboratory procedures to investigate the origin and concentration of hydrocarbons gases at the surface, thermal maturity, the source facies, and the environment of deposition of organic matter. The results show that the investigated samples are characterized by restricted marine clay devoid of carbonate source facies with thermal maturity in the early-stage of the oil generation window. Surface geochemical samples also confirm higher concentrations of thermogenic C2-C4 hydrocarbons over the vicinity of anticlinal structures proving the existence of an effective migration path along deep-seated faults to the surface. The inverted maturity index profile demonstrates a reasonable correlation of thermal maturity with the surface geochemical survey, source biomarkers, and Rock-Eval pyrolysis. It validates the reliability of multilayer linear calculator and particle swarm optimization algorithms for inverting seismic reflection data into a maturity index profile. The obtained results indicate a higher probability of heavy and light oil along the eastern flank of Pakistan, where Infracambrian rocks are thicker and more thermally mature, and deep-seated pledged structural closures occur, in comparison to the Bikaner-Nagaur Basin, India.

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PETROLEUM GENERATION AND SOURCE ROCK ASSESSMENT IN TERRIGENOUS SEQUENCES: AN UPDATE

The APPEA Journal ◽

10.1071/aj90023 ◽

1991 ◽

Vol 31 (1) ◽

pp. 297 ◽

Cited By ~ 1

Author(s):

T.G. Powell ◽

C.J. Boreham

Keyword(s):

Elemental Composition ◽

Source Rock ◽

Early Stage ◽

Source Rocks ◽

Simple Relationship ◽

Petrographic Composition ◽

Petroleum Potential ◽

Lower Ratio ◽

Coal Measures ◽

Cooper Basin

Analytical pyrolysis and sealed tube pyrolysis at low temperatures have been used to study the timing and petroleum generating capacity of selected Permian through Tertiary coals and carbonaceous shales in relation to their petrographic and elemental composition. The results show that judicious application of flash pyrolysis techniques in conjunction with more conventional procedures are essential for effective source rock assessment in terrigenous source rocks, particularly in those of lower quality.Although the petroleum potential of the samples follows the broad trends in petrographic composition established for Australian coals, that is, relative proportions of vitrinite, inertinite and liptinite, there is much variation which cannot be explained petrographically at the maceral group level. Furthermore, there is no simple relationship between pyrolytic hydrocarbon yield from terrigenous kerogens and overall elemental composition. The yield and composition of pyrolysable normal hydrocarbons varies widely depending on the nature and amount of liptinite macerals, particularly for samples with Hydrogen Indices below 300. Liptinite-poor (Mass balance calculations based on Rock-Eval analyses of samples from the Jurassic Walloon Coal Measures show that the maximum oil formation occurs over a very narrow maturation window from 0.8 to 1.0 per cent Ro, although small amounts of oil may be generated at lower maturation levels. The gas to oil ratio of the generated hydrocarbons is constant up to a reflectance level of 1.0 per cent Ro, where upon the proportion of gas increases rapidly. The low quality Permian source rocks from the Cooper Basin have a lower ratio of labile to refractory kerogen than the Jurassic and Tertiary examples. As a result, the gas to oil ratio of hydrocarbons formed in the oil window is higher and the oil potential appears to be exhausted at an earlier stage of maturation. Efficient migration of hydrocarbons from Permian sediments in the Cooper Basin also appears to occur at a relatively early stage of maturation compared with the Jurassic Walloon Coal Measures.

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Basin Modeling as a Tool for Research of Regional Oil and Gas Generation Processes and the Possibility of Replacement of Oil and Gas Riches Illustrated through Traygorodsko-Kondakovskoye Oil Field

10.2118/206598-ms ◽

2021 ◽

Author(s):

Vladimir Andreevich Zubkov ◽

Pavel Vladimirovich Molodykh ◽

Ivan Vasilievich Goncharov ◽

Vadim Valerievich Samoilenko ◽

Svetlana Vasilievna Fadeeva

Keyword(s):

Organic Matter ◽

Source Rock ◽

Oil And Gas ◽

Oil Field ◽

Source Rocks ◽

Material Base ◽

Basin Modeling ◽

Hydrocarbon Migration ◽

Bazhenov Formation ◽

Gas Source

Abstract The article presents the results of two-year of research aimed at replenishing the resource and raw material base of the northwestern part of the Tomsk region. The practical application possibilities of basin modeling at the prospecting and exploratory stages of geological study of the subsurface are illustrated. The research was divided into two phases. The first of them has sub-regional coverage and includes an area of 25,000 km2 bounded by the Chkalovsky oil and gas condensate field in the southeast and the administrative boundaries of Tomsk Oblast in the northwest. The section is confined to the Alexandrovsky arch, covers part of the Koltogorsko-Nyurolsky chute and the eastern periclinal of the Nizhnevartovsky arch. At the first stage, a three-dimensional model of oil-and-gas bearing basin formation was created, the tasks of which were to replenish the history of generation and formation of ideas about the ways of hydrocarbon migration. The basin submergence has been reconstructed here and the thermal flow history has been restored. The uneven intensity of heat flow at the bottom of the sedimentary cover over the area is explained by tectonic processes and is complicated by a massive granitoid intrusion. In JSC "Tomsk Petroleum institute", the knowledge base of geochemical features of oil-and-gas source rocks and oils of Western Siberia was formed for years, which allowed to use their own kinetic spectra for the surveyed region. To calibrate the paleotemperatures, both the optical characteristics of vitrinite coals and the indicators of the geochemical properties of organic matter of the Bazhenov formation (4/1 MDBT and Tmax) were used. As a result, the conclusion about the presence of two generation centers of different nature was made, the time and volume of oil generation by organic matter of the Bazhenov formation were predicted. Next, the modeling parameters of hydrocarbon migration and accumulation are described. Modeling shows that the primary migration occurs due to the emergence of abnormally high pore pressure during the generation of hydrocarbons and fluid autofracture of the oil and gas source rock. The results of calculations of secondary migration by two different methods are compared. Despite a number of limitations, the results obtained show a fairly high convergence to real data. At the second stage, on the basis of the regional (parent) model a local daughter model of the formation of the Traygorodsko-Kondakovskoye field within the area of 480 km2 covered by 3D seismic exploration was plotted. The rationale for the necessity and description of the results of additional special geochemical studies of fluids and oil source rock, carried out before starting to build a detailed model of the local stage, is given. The article outlines the basic parameters and gives the differences between the local model and the parent model. Conclusions are made about the possibility of assessing the conductive properties of fault in the formation of deposits. The prediction of trap saturation and resource potential assessment is the result, the achievement of which reduced the risks of geological exploration and formed the recommendations for further geological study of the subsurface.

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Oil to Source Rock Correlation Using Biomarker Data Through Pattern Matching and Fingerprinting Analysis in “Kitkat” Field, Jabung Block, South Sumatra Basin

Proc. Indon. Petrol. Assoc., Digital Technical Conference, 2020 ◽

10.29118/ipa20-sg-251 ◽

2020 ◽

Author(s):

S., R. Muthasyabiha

Keyword(s):

Pattern Matching ◽

Source Rock ◽

Vitrinite Reflectance ◽

Hydrocarbon Exploration ◽

Source Rocks ◽

Maturity Level ◽

Fingerprinting Analysis ◽

Kerogen Type ◽

Oil Characteristics ◽

Biomarker Data

Geochemical analysis is necessary to enable the optimization of hydrocarbon exploration. In this research, it is used to determine the oil characteristics and the type of source rock candidates that produces hydrocarbon in the “KITKAT” Field and also to understand the quality, quantity and maturity of proven source rocks. The evaluation of source rock was obtained from Rock-Eval Pyrolysis (REP) to determine the hydrocarbon type and analysis of the value of Total Organic Carbon (TOC) was performed to know the quantity of its organic content. Analysis of Tmax value and Vitrinite Reflectance (Ro) was also performed to know the maturity level of the source rock samples. Then the oil characteristics such as the depositional environment of source rock candidate and where the oil sample develops were obtained from pattern matching and fingerprinting analysis of Biomarker data GC/GCMS. Moreover, these data are used to know the correlation of oil to source rock. The result of source rock evaluation shows that the Talangakar Formation (TAF) has all these parameters as a source rock. Organic material from Upper Talangakar Formation (UTAF) comes from kerogen type II/III that is capable of producing oil and gas (Espitalie, 1985) and Lower Talangakar Formation (LTAF) comes from kerogen type III that is capable of producing gas. All intervals of TAF have a quantity value from very good–excellent considerable from the amount of TOC > 1% (Peters and Cassa, 1994). Source rock maturity level (Ro > 0.6) in UTAF is mature–late mature and LTAF is late mature–over mature (Peters and Cassa, 1994). Source rock from UTAF has deposited in the transition environment, and source rock from LTAF has deposited in the terrestrial environment. The correlation of oil to source rock shows that oil sample is positively correlated with the UTAF.

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Effective source rock selection and oil–source correlation in the Western Slope of the northern Songliao Basin, China

Petroleum Science ◽

10.1007/s12182-021-00554-1 ◽

2021 ◽

Vol 18 (2) ◽

pp. 398-415

Author(s):

He Bi ◽

Peng Li ◽

Yun Jiang ◽

Jing-Jing Fan ◽

Xiao-Yue Chen

Keyword(s):

Organic Matter ◽

Source Rock ◽

Thermal Evolution ◽

Songliao Basin ◽

Source Rocks ◽

Crude Oils ◽

Western Slope ◽

Geochemical Parameters ◽

Group I ◽

Oil Source

AbstractThis study considers the Upper Cretaceous Qingshankou Formation, Yaojia Formation, and the first member of the Nenjiang Formation in the Western Slope of the northern Songliao Basin. Dark mudstone with high abundances of organic matter of Gulong and Qijia sags are considered to be significant source rocks in the study area. To evaluate their development characteristics, differences and effectiveness, geochemical parameters are analyzed. One-dimensional basin modeling and hydrocarbon evolution are also applied to discuss the effectiveness of source rocks. Through the biomarker characteristics, the source–source, oil–oil, and oil–source correlations are assessed and the sources of crude oils in different rock units are determined. Based on the results, Gulong and Qijia source rocks have different organic matter primarily detrived from mixed sources and plankton, respectively. Gulong source rock has higher thermal evolution degree than Qijia source rock. The biomarker parameters of the source rocks are compared with 31 crude oil samples. The studied crude oils can be divided into two groups. The oil–source correlations show that group I oils from Qing II–III, Yao I, and Yao II–III members were probably derived from Gulong source rock and that only group II oils from Nen I member were derived from Qijia source rock.

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Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO2

Earth and Environmental Science Transactions of the Royal Society of Edinburgh ◽

10.1017/s1755691021000013 ◽

2021 ◽

pp. 1-11

Author(s):

Sara LIFSHITS

Keyword(s):

Supercritical Fluid ◽

Oil And Gas ◽

Gas Permeability ◽

Sedimentary Rocks ◽

Source Rocks ◽

Reservoir Properties ◽

Hydrocarbon Migration ◽

Geological Processes ◽

Before And After ◽

Oil Source

ABSTRACT Hydrocarbon migration mechanism into a reservoir is one of the most controversial in oil and gas geology. The research aimed to study the effect of supercritical carbon dioxide (СО2) on the permeability of sedimentary rocks (carbonates, argillite, oil shale), which was assessed by the yield of chloroform extracts and gas permeability (carbonate, argillite) before and after the treatment of rocks with supercritical СО2. An increase in the permeability of dense potentially oil-source rocks has been noted, which is explained by the dissolution of carbonates to bicarbonates due to the high chemical activity of supercritical СО2 and water dissolved in it. Similarly, in geological processes, the introduction of deep supercritical fluid into sedimentary rocks can increase the permeability and, possibly, the porosity of rocks, which will facilitate the primary migration of hydrocarbons and improve the reservoir properties of the rocks. The considered mechanism of hydrocarbon migration in the flow of deep supercritical fluid makes it possible to revise the time and duration of the formation of gas–oil deposits decreasingly, as well as to explain features in the formation of various sources of hydrocarbons and observed inflow of oil into operating and exhausted wells.

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