Download or read book Petroleum Systems Modelling Gippsland Basin Victoria written by C. M. Edwards and published by . This book was released on 2020 with total page 147 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Fundamentals of Basin and Petroleum Systems Modeling written by Thomas Hantschel and published by Springer Science & Business Media. This book was released on 2009-04-09 with total page 486 pages. Available in PDF, EPUB and Kindle. Book excerpt: 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.

Download or read book Petroleum Systems Modelling Otway Basin Victoria written by B. G. K. Van Aarssen and published by . This book was released on 2020 with total page 88 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Petroleum System of the Gippsland Basin Australia written by Michele G. Bishop and published by . This book was released on 2000 with total page 42 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Basin Modeling written by Kenneth E. Peters and published by AAPG. This book was released on 2012-04-20 with total page 354 pages. Available in PDF, EPUB and Kindle. Book excerpt: "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.

Download or read book Petroleum System of the Gippsland Basin Australia written by Michele G. Bishop and published by . This book was released on 2015-02-16 with total page 28 pages. Available in PDF, EPUB and Kindle. Book excerpt: This work has been selected by scholars as being culturally important, and is part of the knowledge base of civilization as we know it. This work was reproduced from the original artifact, and remains as true to the original work as possible. Therefore, you will see the original copyright references, library stamps (as most of these works have been housed in our most important libraries around the world), and other notations in the work. This work is in the public domain in the United States of America, and possibly other nations. Within the United States, you may freely copy and distribute this work, as no entity (individual or corporate) has a copyright on the body of the work.As a reproduction of a historical artifact, this work may contain missing or blurred pages, poor pictures, errant marks, etc. Scholars believe, and we concur, that this work is important enough to be preserved, reproduced, and made generally available to the public. We appreciate your support of the preservation process, and thank you for being an important part of keeping this knowledge alive and relevant.

Download or read book Petroleum Geochemistry and Petroleum Systems Modelling of the Canning Basin Western Australia written by K. A. R. Ghori and published by . This book was released on 2013 with total page 33 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Petroleum Systems Play Fairways and Prospectivity of the Gazettal Area V99 2 Offshore Southern Gippsland Basin Victoria written by Mark A. Smith and published by . This book was released on 1999 with total page 33 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Petroleum Geochemistry and Petroleum Systems Modelling of the Perth Basin Western Australia written by and published by . This book was released on 2018 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Evaluating Petroleum Systems Using Advanced Geochemistry and Basin Modeling written by Meng He and published by . This book was released on 2012 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: 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 ...

Download or read book Petroleum and Basin Evolution written by Dietrich H. Welte and published by Springer Science & Business Media. This book was released on 2012-12-06 with total page 555 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book has been prepared by the collaborative effort of two somewhat separate technical groups: the researchers at the Institute for Petroleum and Organic Geochemistry, Forschungszentrum Jii lich (KFA), and the technical staff of Integrated Exploration Systems (IES). One of us, Donald R. Baker, from Rice University, Houston, has spent so much time at KFA as a guest scientist and researcher that it is most appropriate for him to contribute to the book. During its more than 20-year history the KFA group has made numerous and significant contributions to the understanding of petroleum evolution. The KFA researchers have emphasized both the field and laboratory approaches to such important problems as source rock recognition and evaluation, oil and gas generation, maturation of organic matter, expulsion and migration of hydrocarbons, and crude oil composition and alteration. IES Jiilich has been a leader in the development and application of numerical simulation (basin modeling) procedures. The cooperation between the two groups has resulted in a very fruitful synergy effect both in the development of modeling software and in its application. The purpose of the present volume developed out of the 1994 publication by the American Association of Petroleum Geologists of a collection of individually authored papers entitled The Petroleum System - From Source to Trap, edited by L. B. Magoon and W. G. Dow.

Download or read book Thermal Modeling of Petroleum Generation written by Colin Barker and published by Elsevier Science & Technology. This book was released on 1996 with total page 538 pages. Available in PDF, EPUB and Kindle. Book excerpt: Petroleum exploration has always been limited by the lack of adequate subsurface control. Exploration problems are usually problems of extrapolation i.e. to greater depth, to laterally equivalent rocks, or back through time.Models are widely used as a way of describing complex geological systems so that they can be treated quantitatively and used as the basis for extrapolations and predictions. Models consider, typically, a simplified geological system that can be described mathematically. It is very important to know what simplifying assumptions have been made, when these assumptions are valid, and under what conditions their use may not be appropriate. This requires an understanding of the concepts involved in building the model and how the model operates.Models are best used as a tool for probing the system and evaluating the sensitivity of the conclusions to possible uncertainties in the values of the input parameters. In a sense, models permit experimental petroleum geochemistry and allow the user to answer the What if? questions e.g. What if the geothermal gradient had been higher in the past? What if the organic matter type had been different?This book provides students, exploration geologists, and others who would like to use the available models, with a general idea of how the models work, what they can do, and what their limitations are.It also provides the information necessary to obtain the input data required by the commercial models.

Download or read book A Regional Review of the Offshore Gippsland Basin written by Tun U. Maung and published by . This book was released on 1990 with total page 84 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Conventional Gas Prospectivity Assessment and Resource Estimation Onshore Gippsland Basin Victoria written by David Whittam and published by . This book was released on 2021 with total page 101 pages. Available in PDF, EPUB and Kindle. Book excerpt: 1. Introduction -- 1.1 Victorian Gas Program -- 1.2 Study area -- 2. Regional geology -- 2.1 Tectonic development -- 2.2 Basin structure -- 3. Prospectivity assessment -- workflow -- 3.1 Resource estimation and reporting framework -- 3.2 Assessment unit definition -- 3.3 Play element mapping -- 4. Previous exploration -- 4.1 Well classification -- 4.2 Exploration activity -- 4.3 Hydrocarbon shows -- 4.4 Post-drill analysis -- 5. Play fairway mapping -- 5.1 Seaspray Group -- 5.2 Cobia Subgroup -- 5.3 Halibut Subgroup -- 5.4 Golden Beach subgroup -- 5.5 Emperor Subgroup -- 5.6 Strzelecki Group -- 5.7 Intra Strzelecki -- 5.8 Prospective Resource Areas -- 6. Resource assessment -- 6.1 Assessment method -- 6.2 Reference case estimate -- 6.3 Stochastic estimate -- 7. Conclusions -- References -- Glossary -- Abbreviations and units -- Appendix A1 Petroleum Resources Management System -- Appendix A2 Onshore Gippsland Basin exploration wells -- Appendix A3 Isochore maps -- Appendix A4 Play fairway exploration statistics -- Appendix A5 Resource estimation workflow -- Introduction -- Data inputs -- Stochastic model -- Outputs (results) -- Appendix A6 Resource estimation data tables -- Attachment A1 ESRI ArcmapTM project -- Attachment A2 Resource estimation ExcelTM workbook.

Download or read book Hydrocarbon play fairways of the onshore Gippsland Basin Victoria written by Chiupka J. W. and published by . This book was released on 1996 with total page 50 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Basin and Petroleum System Modeling and Global Sensitivity Analyses of Natural Gas Hydrates written by Laura Dafov and published by . This book was released on 2021 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: (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.

Download or read book Three dimensional Petroleum Systems Modelling of the Wind River Basin Wyoming written by Jean Emmanuel Yazou and published by . This book was released on 2022 with total page 98 pages. Available in PDF, EPUB and Kindle. Book excerpt: This study’s objectives were to develop a three-dimensional structural framework of the Wind River Basin of Wyoming and if possible to use it as input into a petroleum systems model for the basin. It was hoped that this model would then be used to identify existing, as well as new unconventional reservoir sweet spots within the basin. Different data types were assembled to achieve that objective as well as the use of modeling techniques. While 1D and 2D petroleum system models within the basin already exists in the literature, this study used modeling techniques to attempt the simulation of not only the basin’s history through geologic time but also the thermal maturity of the basin. To perform this study, the following phases were defined: the structural framework development, the geothermal and thermal data input and the 3D modeling input for simulation. Even though no successful simulation was achieved, the reconstructed structural framework of the Wind River Basin from the Precambrian to the topography was of high degree of accuracy, detailing main structural features and populated with geothermal and thermal data. A present heat flow map of the Wind River Basin was another important input in this study with the highest values found around the center of the Wind River Basin.