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Author: Friedemann Baur
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Languages : en
Pages : 0
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Author: Friedemann Baur
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Languages : en
Pages : 0
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Author: Kenneth E. Peters
Publisher: AAPG
ISBN: 0891819037
Category : Science
Languages : en
Pages : 354
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"This special volume contains a selection of articles presented at the AAPG Hedberg Research Conference on Basin and Petroleum System Modeling (BPSM) held in Napa, California, on May 3-8, 2009."--P. 1.
Author: Yao Tong
Publisher:
ISBN:
Category :
Languages : en
Pages :
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The Piceance Basin is located in northwest Colorado and was formed during the Late Cretaceous Laramide - Paleogene tectonism, which partitioned the stable Cretaceous Interior Seaway foreland basin into a series of smaller basins. The basin is defined by reverse faults and associated anticlinal fold structures on the margins. From the Late Cretaceous to Cenozoic, the Piceance basin transited from marine to terrestrial depositional setting as a result of the Laramide deformation and the recent vertical regional uplift. Depositional environments varied from shallow marine, fluvial, paludal, lacustrine and terrestrial settings and formed the prolific Mesaverde petroleum system. The earliest commercial production came from a Cretaceous tight sand reservoir situated in Williams Fork Formation of the Mesaverde Group. The underlying coastal plain coals became thermally mature later in the Cenozoic and charged the adjacent Mesaverde Williams Fork Formation with natural gas. Diverse depositional environments not only led to the development of petroleum system but also produced many heterogeneities and "unknowns", which makes the study of the basin evolution history very challenging. Basin and petroleum system modeling utilizes an integrated approach to link these multiple complex geologic processes into a model framework, to explore the uncertainties and to test hypothesis, and scenarios. The Piceance Basin is an ideal settings for investigating a sedimentary basin with diverse depositional settings and exploring uncertainties associated with changing basin history. This thesis is divided into three chapters addressing the following research objectives: (1) to integrate geological, geochemistry and engineering data into a basin model frame work and enhance understanding of Piceance Basin history. (2) To investigate possible geological constraints that reduce the uncertainty in terrestrial basin modeling efforts (3) To tackle complex uncertainties in basin and petroleum system modeling and disentangle the input model parameter's impact on the model response with the aid of efficient uncertainty quantification tools. Chapter 1 presents a comprehensive basin study for the Piceance Basin. This work utilizes integrated data and reconstructs a numerical basin model to summarize the basin evolution history from the Late Cretaceous to present day. During this exercise, a conceptual model was first designed to capture the basin's transformation from marine to terrestrial, with simplification of the basin tectonic history into two major deformation and inversion events. The Cretaceous Cameo Coal source rock maturation history were investigated via the constructed basin model framework. Given limited published calibration data, basin models were calibrated mainly with vitrinite reflectance data. The basin model predictions agree well with the measured thermal maturation data. This work contributed a regional scale 3-dimensional basin model for the study area. The model may serve as a research vehicle for further studies, such as geological scenario tests, unconventional resources characterization and other Laramide basin research. Chapter 2 presents a novel approach that utilizes paleoclimate data to constrain the basin thermal history, especially for terrestrial basins with substantial uplift history. Basin thermal history is a critical part of sedimentary basin studies, especially for understanding the hydrocarbon generation in a petroliferous basin. Two boundary conditions are required to quantify basin thermal conditions: the basal heat flow as the lower boundary condition and the sediment surface temperature as the upper thermal boundary condition. For marine basins, the sediment surface temperature is often estimated from water surface temperature, corrected by water depth from paleobathymetry information. However, as our study area was elevated and exposed subaerially, the sediment surface temperatures can no longer be estimated by water-sediment interface temperature; rather, the surface temperatures are impacted by complicated factors and are subject to larger variations. In our work, we developed a Cenozoic temperature proxy in the study area by utilizing paleoclimate studies focused on macro floral assemblages. The resulting interpreted surface temperature largely reduced the uncertainty in paleo-thermal condition estimation. This work also demonstrates the importance of capturing the surface temperature variation for elevated terrestrial setting basins. Chapter 3 presents the effort of tackling complex input uncertainties and disentangling their correlations with basin model spatial and temporal responses. Uncertainty quantification and sensitivity analysis workflows are implemented, subtle correlation between the input parameter and the basin model responses were identified; source rock geochemical properties may impact the present-day porosity and pore pressure in the underburden rock. Knowing the sensitivity propagation on both spatial and temporal model domain enhances our understanding of highly nonlinear basin models, and brings insights for future model improvement.
Author: Willy Fjeldskaar
Publisher: MDPI
ISBN: 3036502769
Category : Science
Languages : en
Pages : 366
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This volume describes the nature, causes, and consequences of the diverse fluid movements that produce energy and mineral resources in sedimentary basins. The contained papers point to new capabilities in basin analysis methods and models. The processes that operate in the resource-producing thermo-chemical-structural reactors we call sedimentary basins are reviewed. Efficient ways to infer the tectonic history of basins are described. Impacts on hydrocarbon maturation and migration of glacial tilting, magmatic intrusion, salt migration, and fracturing are illustrated. The conditions under which subsurface flow will channel with distance traveled are identified. Seismic methods that can image and map subsurface permeability channels are described. The surface maturation, surface charge, and chemical reaction foundations of creep subsidence are set forth. Dynamic aspects of the hydrogen resource in basins are analyzed. There is much that is new that is presented in these papers with the intent of stimulating thinking and enthusiasm for the advances that will be made in future decades.
Author: Thomas Hantschel
Publisher: Springer Science & Business Media
ISBN: 3540723188
Category : Science
Languages : en
Pages : 486
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The first comprehensive presentation of methods and algorithms used in basin modeling, this text provides geoscientists and geophysicists with an in-depth view of the underlying theory and includes advanced topics such as probabilistic risk assessment methods.
Author: Chang Samuel Hsu
Publisher: Springer
ISBN: 3319493477
Category : Science
Languages : en
Pages : 1243
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This handbook provides a comprehensive but concise reference resource for the vast field of petroleum technology. Built on the successful book "Practical Advances in Petroleum Processing" published in 2006, it has been extensively revised and expanded to include upstream technologies. The book is divided into four parts: The first part on petroleum characterization offers an in-depth review of the chemical composition and physical properties of petroleum, which determine the possible uses and the quality of the products. The second part provides a brief overview of petroleum geology and upstream practices. The third part exhaustively discusses established and emerging refining technologies from a practical perspective, while the final part describes the production of various refining products, including fuels and lubricants, as well as petrochemicals, such as olefins and polymers. It also covers process automation and real-time refinery-wide process optimization. Two key chapters provide an integrated view of petroleum technology, including environmental and safety issues.Written by international experts from academia, industry and research institutions, including integrated oil companies, catalyst suppliers, licensors, and consultants, it is an invaluable resource for researchers and graduate students as well as practitioners and professionals.
Author: Laura Dafov
Publisher:
ISBN:
Category :
Languages : en
Pages :
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(I) Topics are broadly defined then followed by chapter highlights: Gas hydrate is a solid, ice-like, form of natural gas that is found in the low temperature, high pressure conditions of shallow sediment in deep marine environments and in permafrost regions. This solid form of natural gas is extensively found offshore every continent on Earth and potentially has a greater amount of energy than all other forms of oil, gas, and coal combined. Therefore, it is of interest for industry, academia, and government sectors, particularly for nations that have limited domestic natural gas resources. Gas hydrates tie in with CO2 sequestration or storage, energy resources, the global carbon cycle, and geohazards. Basin and petroleum system modeling is a quantitative algorithmic approach that utilizes diverse datasets including, but not limited to, well logs, paleontology, stratigraphy, petrophysics, and seismic data to make deterministic, iterative, forward-modeling predictions. It integrates geology, geophysics, geochemistry, engineering, geostatistics, and rock physics to model the sedimentary and tectonic evolution of basins, as well as to model and predict the generation, migration, and accumulation of hydrocarbons in up to three dimensions through geologic time. Though widely used for the modeling of conventional oil and gas systems, basin and petroleum system modeling only recently has been used to study gas hydrate systems, with the first non-proprietary gas hydrate basin and petroleum system model published in 2015. Sensitivity analysis is the study of how variation of uncertain input parameters impacts the response of interest and has great potential application to basin and petroleum system modeling of gas hydrates. A couple of strengths of sensitivity analysis are that it helps determine which data are most important to acquire for reducing uncertainty and it can help simplify a complex problem by identifying less important input parameters. Local sensitivity analysis is a one-at-a-time sensitivity analysis technique that analyzes the effect of one parameter on a function at a time, keeping the other parameters fixed. It explores only a small fraction of the design space, especially when there are many parameters, and is a simple screening method that is widely used across disciplines. Furthermore, the local sensitivity analysis method does not evaluate parameter interactions for non-linear effects. On the other hand, global sensitivity analysis is a powerful tool that has never before been used for gas hydrate basin and petroleum system modeling despite it being effective at evaluating parameter interactions for non-linear effects. Global sensitivity analysis helps understand and simplify the complexity of problems and elucidates what model variables impact data, decisions, and forecasts. (II) Chapter 1 highlights: We built a detailed (more than 25 million cells) quantitative 3D basin and petroleum system model of Terrebonne Basin, Gulf of Mexico, for dynamic gas hydrate studies and to be used to support planning for scientific drilling. Original interpretations of the geology, using seismic imaging and well logs, are presented, including a proposed mechanism for the presence of giant gas mounds. Our model predicts present-day gas and gas hydrate volumes, saturations and distributions of accumulations, marine gas hydrate recycling (by which gas hydrate saturations at the base of the gas hydrate stability zone increase through time due to, for example, sediment burial), and the potential source of gas in the basin (specifically, thermogenic versus biogenic). The source of gas determines whether light or heavy gases likely exist, which have different economic implications, the latter being more valuable. Our model is calibrated to porosity and pressure data and our model-based gas hydrate saturation predictions align with what is observed in well log and seismic data vertically and laterally. We suggest that our 3D model has application to future studies that seek to understand gas hydrates as they relate to faults, fractures, lithologic variations, salt tectonics, erosion, pressures, changing water column conditions, temperature changes, and gas sources, as these Earth system features have all been incorporated into our model. (III) Chapter 2 highlights: By harnessing theoretical 2D basin and petroleum system models and real-world inspired models based on the well-studied salt diapir-associated gas hydrate sites at Green Canyon (Gulf of Mexico) and Blake Ridge (U.S. Atlantic coast), we demonstrate that salt structures provide a heat flow-driven mechanism for marine gas hydrate recycling that results in enhanced saturations. Our work also provides insight into the roles of basal heat flows, salt diapir diameters, and sediment thermal conductivities in controlling optimal gas hydrate accumulations in salt basins. Broadly speaking, we suggest that gas hydrate and associated gas accumulations above salt diapir crests represent attractive targets for hydrocarbon resource exploration and for scientific drilling expeditions aimed at characterizing these systems. It therefore follows that salt basins are compelling localities for studying our newly proposed mechanism of salt diapir heat flow-driven enhanced gas hydrate and gas accumulations. (IV) Chapter 3 highlights: We developed a widely-applicable, novel automated method that results in thousands of unique 2D basin and petroleum system models of gas hydrates and it applies global sensitivity analysis to them. To put this in perspective, only tens of basin and petroleum system models of gas hydrates have been published. Our work is the first time, at least in the public domain, that global sensitivity analysis has been coupled with basin and petroleum system modeling of gas hydrates. This tool improves the efficiency of basin and petroleum system modeling of gas hydrates by ~40 times, as well as eliminating sampling bias by randomly building models using the Monte Carlo approach. We believe our 2D basin and petroleum system model scenarios, as well as their associated organized databases of 10s of thousands of extracted input and output values, can be used as templates and guides for future basin and petroleum system modeling of gas hydrates and of other hydrocarbon systems. Our work provides insight into the relative importance of different geologic properties when assessing gas hydrate stability zone thicknesses, gas hydrate saturations, and gas saturations by utilizing quantitative and objective measures of sensitivity. Furthermore, this powerful tool reveals important geologic input interactions that cannot otherwise be observed using the traditionally used method of local sensitivity analysis. One of our many geologic takeaways or recommendations is that professionals who plan to explore for gas hydrate accumulations should consider shallow to midwater depths more so than deepwater, because our results show that those basin models are more conducive, geologically, for gas hydrate accumulations that have relatively high saturations. Our two distinct sets of models span a wide range of basin scenarios intended to represent: (1) the entire world and (2) the sites where gas hydrates have been found or inferred. We use these results to answer questions about how to improve global map predictions. Our work provides original plots illustrating the relationship between basal heat flow and the gas hydrate stability zone that could be useful in new ventures or other exploration of conventional petroleum systems where a gas hydrate stability zone is observed or inferred. Basal heat flow is among the least known values when gathering information about a basin. Our plots can be used as a guide to determine what the likely range of basal heat flows is acceptable for a basin, which can result in the difference between generation of oil or gas.
Author: AbuAli Mahdi A
Publisher:
ISBN: 9780891813941
Category :
Languages : en
Pages :
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Author: Meng He
Publisher:
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Category :
Languages : en
Pages :
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In the past decade, three-dimensional (3-D) basin and petroleum system modeling of the subsurface through geological time has evolved as a major research focus of both the petroleum industry and academia. The major oil companies have independently recognized the need for basin and petroleum system modeling to archive data, facilitate visualization of risk, convert static data into dynamic processed data, and provide an approach to evaluate potential prospects in oil and gas exploration. Basin and petroleum system modeling gives geoscientists the opportunity to examine the dynamics of sedimentary basins and their associated fluids to determine if past conditions were suitable for hydrocarbons to fill potential reservoirs and be preserved there. The success of any exploration campaign requires basin and petroleum system modeling as a methodology to predict the likelihood of success given available data and associated uncertainties. It is not guaranteed that hydrocarbons will be found by drilling a closed subsurface structure. Early petroleum system studies began more than 50 years ago. Geoscientists seek to describe how basins form, fill and deform, focusing mainly on compacting sediments and the resulting rock structures. Since then, tremendous efforts have been concentrated on developing methods to model these geological processes quantitatively. Studies such as applying mathematical algorithms to seismic, stratigraphic, palentologic, petrophysical data, and well logs were employed to reconstruct the evolution of sedimentary basins. In the early 1970s, geochemists developed methods to predict the petroleum generation potentials of source rocks in quantitative terms. After that, they began to use sedimentary basin models as geological frameworks for correlations between hydrocarbons and their potential source rocks. Since then, many concepts have been widely used in the petroleum industry, such as oil system, hydrocarbon system, hydrocarbon machine, and petroleum system. The term "petroleum system" is now commonly used in the industry. A petroleum system comprises a pod of active source rock and the oil and gas derived from it as established by geochemical correlation. The concept embodies all of the geologic elements and processes needed for oil and gas to accumulate. The essential elements include effective source rock, reservoir, seal and overburden rock. The processes include trap formation and the generation, migration and accumulation of petroleum. These elements and processes must occur in a proper order for the organic matter in a source rock to be converted into petroleum and then preserved. Absence of any of those elements can cause a dry prospect. In this dissertation, we use "basin and petroleum system modeling" (BPSM) as a method to track the evolution of a basin through geological time as it fills with sediments that could generate or contain hydrocarbons. We could also use it to evaluate and predict undiscovered conventional and unconventional hydrocarbon resources and to further understand the controls on petroleum generation, migration, accumulation. In deterministic forward modeling, basin and petroleum system processes are modeled from past to present using inferred starting conditions. Basin and petroleum system modeling is analogous to a reservoir simulation, but BPSM represents dynamic simulation through geological time. All of the dynamic processes in the basin and petroleum system modeling can be examined at several levels, and complexity typically increases with spatial dimensionality. The simplest is 1D modeling which examines burial history at a point location in a pseudowell. Two-dimensional modeling can be used to reconstruct oil and gas generation, migration and accumulation along a cross section. Three-dimensional modeling reconstructs petroleum systems at reservoir and basin scales and has the ability to display the output in 1D, 2D or 3D and through time. In general, which modeling approach is chosen depends on the purpose of the study and the types of problems to be resolved. Basin and petroleum system modeling continues to grow in importance as a tool to understand subsurface geology and basin evolution by integrating key aspects from geochemistry, geology, geophysics and stratigraphy. Among the above key aspects, geochemistry is the most important tool to understand the processes affecting petroleum systems. Better understanding of petroleum systems improves exploration efficiency. The first step in identifying petroleum systems is to characterize and map the geographic distribution of oil and gas types. Geochemical tools such as biomarkers, diamondoids and carbon isotope analysis are used to conduct oil-oil and oil-source correlation, which is key to understand and determine the geographic extent of petroleum systems in the basin. Chapter 1 offers a good example of how basin and petroleum system modeling and geochemistry improve understanding of active petroleum systems in the San Joaquin Basin, California. The modeling results indicate that there could be a deep, previously unrecognized source rock in the study area. Chapter 2 is a detailed unconventional geochemical analysis (i.e., diamondoid analysis, compound-specific isotopes of biomarkers and diamondoids) on petroleum systems in Arctic (Barents Sea and northern Timan Pechora Basin) to investigate deep sources in that area. Cutting-edge geochemical analyses were conducted in this project to identify the oil-oil and oil-source relationships and further understand reservoir filling histories and migration pathways. Since the deep source is at a great depth, thermal cracking always occurred in the source or the deeply buried reservoir, thus generating light hydrocarbons and gas. In addition, we hope to better understand the geochemical characteristics of worldwide Phanerozoic source rocks (Paleozoic source rock in Barents Sea-Timan Pechora area, Mesozoic and Cenozoic source rocks in the Vallecitos syncline in San Joaquin Basin). These results could also provide valuable input data for building basin and petroleum system models in the Arctic area once more data become available. Chapter 1 is a study of using basin modeling and geochemical analysis to evaluate the active source rocks in the Vallecitos syncline, San Joaquin Basin, and improve our understanding of burial history and the timing of hydrocarbon generation. Our earlier 1D modeling indicated that there could be two active source rocks in the syncline: Eocene Kreyenhagen and Cretaceous Moreno formations. The results differ from earlier interpretations that the Kreyenhagen Formation was the only source rock in the Vallecitos syncline, and suggest that the bottom of the Cretaceous Moreno Formation in the syncline reached thermal maturity as early as 42 Ma. The synclinal Eocene Kreyenhagen Formation became thermally mature as early as 19 Ma. Thick (~2 km) overburden rock in the central part of the syncline with additional heating from a thermal anomaly pushed the shallow Eocene Kreyenhagen source rock into the oil window in very recent times. In contrast, the Cretaceous Moreno source rock reached extremely high maturity (past the dry gas window). The 2D model results indicate that the bottom part of the Kreyenhagen Formation is in the mature stage of hydrocarbon generation and that the formation remains immature on the flanks of the present-day syncline. In contrast, the bottom part of the Moreno Formation achieved the gas generation zone and is in the oil generation zone on the flanks of the syncline. Biomarker analysis was conducted on 22 oil samples from the syncline. Source-related biomarkers show two genetic groups, which originated from two different source rocks. The 2D model results are supported by biomarker geochemistry and are also consistent with our earlier 1D burial history model in the Vallecitos syncline. In addition, we identified two potential petroleum systems in the Vallecitos syncline. The basin models for this study were conducted by me and Stephan Graham, Allegra Hosford Scheirer, Carolyn Lampe, Leslie Magoon. The detailed geological data was provided by Stephan Graham. The modeling related references and fundamental data were provided by Allegra Hosford Scheirer, but I conducted the modeling. The geochemical laboratory work and data analysis has been completed by me and supervised by Mike Moldowan and Kenneth Peters. The funding for this project was contributed by Basin and Petroleum System Modeling (BPSM) and molecular organic geochemistry industrial affiliates (MOGIA) programs. This chapter was submitted to Marine and Petroleum Geology with co-authors Stephan Graham, Allegra Hosford Scheirer and Kenneth Peters. All co-authors contributed important ideas, discussion, and guidance. Chapter 2 documents the existing deep source in the Barents Sea and northern Timan-Pechora Basin. Total thirty-four oil samples were analyzed to understand the types and distributions of effective source rocks and evaluate the geographic extent of the petroleum systems in the study area. Taxon-specific, age-related and source--related biomarkers and isotope data provided information on the depositional environment of the source rock, source input, and source age of the oil samples. A relationship between biomarker and diamondoid concentration was used to identify mixed oils having both oil-window and highly cracked components. Compound-specific isotope analyses of diamondoids and n-alkanes were used to deconvolute co-sourced oils and identify deep source rocks in the basin. The results suggest five major source rocks in the Barents Sea and the northern Timan-Pechora Basin: Upper Jurassic shale, Lower-Middle Jurassic shale, Triassic carbonate/shale, Devonian marl and Devonian carbonate. The Upper and Lower-Middle Jurassic source rocks are dominant in the Barents Sea. Triassic source rock consists of carbonate in the ons ...
Author: Geological Survey (U.S.)
Publisher:
ISBN:
Category : Geology
Languages : en
Pages : 160
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Investigations about porosity in petroleum reservoir rocks are discussed by Schmoker and Gautier. Pollastro discusses the uses of clay minerals as exploration tools that help to elucidate basin, source-rock, and reservoir history. The status of fission-track analysis, which is useful for determining the thermal and depositional history of deeply buried sedimentary rocks, is outlined by Naeser. The various ways workers have attempted to determine accurate ancient and present-day subsurface temperatures are summarized with numerous references by Barker. Clayton covers three topics: (1) the role of kinetic modeling in petroleum exploration, (2) biological markers as an indicator of depositional environment of source rocks and composition of crude oils, and (3) geochemistry of sulfur in source rocks and petroleum. Anders and Hite evaluate the current status of evaporite deposits as a source for crude oil.
