This study utilises seismic data to improve understanding of the subsurface fluid flow behaviour in the Taranaki and Great South Basins offshore New Zealand. The aim of this study is to characterise fluid flow features and to investigate their genesis, fluid origins and implications for subsurface fluid plumbing system by integrating seismic interpretation and 3D petroleum systems modelling techniques. After an early phase studying Pliocene pockmarks in the Taranaki Basin, this study has been focused on the subsurface fluid plumbing system and on the fluid expulsion history in the Great South Basin. The Taranaki Basin lies on the west coast and offshore of the North Island, New Zealand. The seismic interpretation revealed that paleo-pockmark formation in the study area relates to fluid escape due to a rapid sediment loading environment in a distal fan setting. Seismic analysis rules out any links between the paleo-pockmarks and faulting. The relationship between paleo-pockmark occurrence and fan depositional thickness variations suggests that pore-water expulsion during overburden progradation is the most likely cause of the paleo-pockmarks. The rapid sediment loading generated overpressure which was greatest on the proximal fan due to a lateral gradient in overburden pressure. Fluids were consequently forced towards the fan distal parts where, eventually, the pore pressure exceeded the fracture gradient of the seal. The Great South Basin lies off the southern coast of the South Island of New Zealand and is located beneath the modern shelf area. Evidence for past and present subsurface fluid flow in this basin is manifested by the presence of numerous paleo-pockmarks, seabed pockmarks, polygonal fault systems, bright spots and bottom simulating reflections (BSR), all of which help constrain aspects of the overburden plumbing system and may provide clues to deeper hydrocarbon prospectivity in this frontier region. The various types of fluid flow features observed in this study are interpreted to be caused by different fluid origins and mechanisms based on evidences from seismic interpretation in the study area. The possible fluid origins which contribute to fluid flow features in the Great South Basin are compactional pore water as well as biogenic and thermogenic hydrocarbons. Using 3D seismic attribute analysis it was possible to highlight the occurrence of these features, particularly polygonal faults and pockmarks, which tend to be hosted within fine-grained sequences. Paleo- and present-day fluid flow features were investigated using 3D basin and petroleum systems modelling with varying heat flow scenarios. The models predict that thermogenic gas is currently being generated in mid-Cretaceous sedimentary sequences and possibly migrates along tectonic faults and polygonal faults feeding present-day pockmarks at the seabed. The models suggest that biogenic gas was the main fluid source for the Middle Eocene paleo-pockmarks and compactional pore fluid may be the main fluid contributor to the Late Eocene paleo-pockmarks. Different heat flow scenarios show that only mid-Cretaceous source rocks have reached thermal maturity in the basin, whilst Late Cretaceous and Paleocene source rocks would be largely immature. The observations and interpretations provided here contribute to the ongoing discussion on basin de-watering and de-gassing and the fluid contributors involved in pockmark formation and the use of pockmarks as a potential indicator of hydrocarbon expulsion. It is clear from this study that seismically-defined fluid flow features should be integrated into petroleum systems modelling of frontier and mature exploration areas in order to improve our understanding on fluid phases, their migration routes, timings and eventual expulsion history.

O Gráben de Barra de São João, situado na região de águas rasas da Bacia de Campos, é parte integrante do Sistema de Riftes do Cenozóico, localizado na região sudeste do Brasil. Este sistema foi formado em um evento que resultou na reativação das principais zonas de cisalhamento do Pré-Cambriano do sudeste do Brasil no Paleoceno. Neste trabalho proponho um novo arcabouço estrutural para o Gráben de Barra de São João baseado na interpretação de dados gravimétricos. Dados magnéticos aéreos, dados gravimétricos, uma linha sísmica 2D e um perfil de densidades de um poço foram utilizados como vínculos na interpretação. Para a estimativa do topo do embasamento foi necessário separar o efeito das fontes profundas no dado gravimétrico (anomalia residual). Com isso, foi realizada uma modelagem 2D direta baseada na interpretação sísmica para estimar as densidades das entidades geológicas da área em questão. Após esta modelagem, foi realizada uma inversão estrutural 3D do dado gravimétrico residual a fim de recuperar a profundidade do topo do embasamento. Este fluxograma de interpretação permitiu a identificação de um complexo arcabouço estrutural com três sistemas de falhas bem definido: Falhas normais de orientação NE-SW, e um sistema de falhas transcorrentes NW-SE e E-W. Estas orientações dividem o gráben em diversos altos e baixos internos. O dado magnético aéreo corrobora esta interpretação. A existência de rochas ultra-densas e fortemente magnéticas no embasamento foram interpretadas como um ofiolito que foi provavelmente intrudido (por obducção) na época do fechamento de um oceano no Proterozóico. / Barra de São João Graben, shallow water Campos Basin, is part of the Tertiary rift system that runs parallel to the Brazilian continental margin. This system was formed in an event that caused the reactivation of the main Precambrian shear zones of southeastern Brazil in the Paleocene. I propose a new the structural framework of Barra São João Graben based on gravity data interpretation. Magnetic data an available 2D seismic line and a density well-log of a nearby well were used as constraints to our interpretation. To estimate the top of the basement structure we separated the gravity effects of deep-sources from the shallow basement (residual anomaly). Then, we performed a 2D modeling exercise, where we keptfixed the basement topography and the density of the sediments, to estimate the density of the basement rocks. Next, we inverted the residual anomaly to recover the depth to the top of the basement. This interpretation strategy allowed the identification of a complex structural framework with three main fault systems: NE-SW normal faults system, and a NW-SE and E-W transfer fault systems. These trends divide the graben into several internal highs and lows. The magnetic anomalies corroborate our interpretation. The existence of ultra-dense and strongly magnetized elongated bodies in the basementwere interpreted as ophiolite bodies that probably intruded by the time of the shutdown of the Proterozoic ocean.

Magister Scientiae - MSc (Earth Science) / The Orange basin is relatively underexplored with 1 well per every 4000km2 with only the Ububhesi gas field discovery. Block 1 is largely underexplored with only 3 wells drilled in the entire block and only well A?F1 inside the 1500km2 3?D seismic data cube, acquired in 2009. This study is a reservoir characterization of well A?F1, utilising the acquired 3?D seismic data and re?analysing and up scaling the well logs to create a static model to display petrophysical properties essential for reservoir characterization. For horizon 14Ht1, four reservoir zones were identified, petro?physically characterized and modelled using the up scaled logs. The overall reservoir displayed average volume of shale at 24%, good porosity values between 9.8% to 15.3% and permeability between 2.3mD to 9.5mD. However, high water saturation overall which exceeds 50% as per the water saturation model, results in water saturated sandstones with minor hydrocarbon shows and an uneconomical reservoir.

Natural gas hydrates store a substantial portion of the Earth's organic carbon, although their occurrence is restricted by thermobaric boundaries and the availability of methane-rich fluids. The complexity of geological systems and the multiphase flow processes promoting hydrate formation can result in a mismatch between the predicted and the observed hydrate distribution. The purpose of this research is to achieve a better comprehension of the factors that influence the distribution of gas hydrates and the mechanism of fluid movements beneath and across the gas hydrate stability zone (GHSZ). Therefore, this study integrates seismic, petrophysical and geochemical data from different gas hydrate provinces. This work provides evidence that hydrates can occur below bottom-simulating reflectors, in the presence of sourcing thermogenic hydrocarbons. The relationship between fluid-escape pipes and gas hydrates is further explored, and pipe-like features are suggested to host a significant volume of hydrates. The host lithology also represents a critical factor influencing hydrate and free gas distribution and, in evaluating a natural gas hydrate system, needs to be considered in conjunction with the spatial variability in the methane supply. The three-dimensional distribution of gas hydrate deposits in coarse-grained sediments, representing the current target for hydrate exploration, is shown to be correlated with that of the underlying free gas zone, reflecting sourcing mechanisms dominated by a long-range advection. In such systems, the free gas invasion into the GHSZ appears controlled by the competition between overpressure and sealing capacity of the gas hydrate-bearing sediments. Globally, the thickness of the free gas zones is regulated by the methane supply and by different multi-phase flow processes, including fracturing, capillary invasion and possibly diffusion. In conclusion, this research indicates that geological, fluid flow and stability factors interweave at multiple scales in natural gas hydrate systems.

O Gráben de Barra de São João, situado na região de águas rasas da Bacia de Campos, é parte integrante do Sistema de Riftes do Cenozóico, localizado na região sudeste do Brasil. Este sistema foi formado em um evento que resultou na reativação das principais zonas de cisalhamento do Pré-Cambriano do sudeste do Brasil no Paleoceno. Neste trabalho proponho um novo arcabouço estrutural para o Gráben de Barra de São João baseado na interpretação de dados gravimétricos. Dados magnéticos aéreos, dados gravimétricos, uma linha sísmica 2D e um perfil de densidades de um poço foram utilizados como vínculos na interpretação. Para a estimativa do topo do embasamento foi necessário separar o efeito das fontes profundas no dado gravimétrico (anomalia residual). Com isso, foi realizada uma modelagem 2D direta baseada na interpretação sísmica para estimar as densidades das entidades geológicas da área em questão. Após esta modelagem, foi realizada uma inversão estrutural 3D do dado gravimétrico residual a fim de recuperar a profundidade do topo do embasamento. Este fluxograma de interpretação permitiu a identificação de um complexo arcabouço estrutural com três sistemas de falhas bem definido: Falhas normais de orientação NE-SW, e um sistema de falhas transcorrentes NW-SE e E-W. Estas orientações dividem o gráben em diversos altos e baixos internos. O dado magnético aéreo corrobora esta interpretação. A existência de rochas ultra-densas e fortemente magnéticas no embasamento foram interpretadas como um ofiolito que foi provavelmente intrudido (por obducção) na época do fechamento de um oceano no Proterozóico. / Barra de São João Graben, shallow water Campos Basin, is part of the Tertiary rift system that runs parallel to the Brazilian continental margin. This system was formed in an event that caused the reactivation of the main Precambrian shear zones of southeastern Brazil in the Paleocene. I propose a new the structural framework of Barra São João Graben based on gravity data interpretation. Magnetic data an available 2D seismic line and a density well-log of a nearby well were used as constraints to our interpretation. To estimate the top of the basement structure we separated the gravity effects of deep-sources from the shallow basement (residual anomaly). Then, we performed a 2D modeling exercise, where we keptfixed the basement topography and the density of the sediments, to estimate the density of the basement rocks. Next, we inverted the residual anomaly to recover the depth to the top of the basement. This interpretation strategy allowed the identification of a complex structural framework with three main fault systems: NE-SW normal faults system, and a NW-SE and E-W transfer fault systems. These trends divide the graben into several internal highs and lows. The magnetic anomalies corroborate our interpretation. The existence of ultra-dense and strongly magnetized elongated bodies in the basementwere interpreted as ophiolite bodies that probably intruded by the time of the shutdown of the Proterozoic ocean.

No description available.

In an effort to mitigate carbon dioxide (CO2) emissions in the atmosphere, the Southeast Offshore Storage Resource Assessment (SOSRA) project has for objective to identify geological targets for CO2 storage in two main areas: the eastern part of the Gulf of Mexico and the Atlantic Ocean subsurface. SOSRA's second objective is to estimate the geological targets' capacity to store up to 30 million metric tons of CO2 each year with an error margin of ±30%. As part of this project, the research presented here focuses on the outer continental shelf of North Carolina and its potential for the deployment of large-scale offshore carbon storage in the near future. To identify geological targets, workflow followed typical early oil and gas exploration protocols: collecting existing datasets, selecting the most applicable datasets for reservoir exploration, and interpreting datasets to build a comprehensive regional geological framework of the subsurface of the outer continental shelf. The geomodel obtained can then be used to conduct static volumetric calculations estimating the storage capacity of each identified target. Numerous uncertainties regarding the geomodel were attributed to the variable coverage and quality of the geological and geophysical data. To address these uncertainties and quantify their potential impact on the storage capacity estimations, dynamic volumetric calculations (reservoir simulations) were conducted. Results have shown that, in this area, both Upper and Lower Cretaceous Formations have the potential to store large amounts of CO2 (in the gigatons range). However, sensitivity analysis highlighted the need to collect more data to refine the geomodel and thereby reduce the uncertainties related to the presence, dimensions and characteristics of potential reservoirs and seals. Reducing these uncertainties could lead to more accurate storage capacity estimations. Adequate injection strategies could then be developed based on robust knowledge of this area, thus increasing the probability of success for carbon capture and storage (CCS) offshore projects in North Carolina's outer continental shelf. / Doctor of Philosophy / Since the industrial revolution, a significant increase in the anthropogenic emissions of greenhouse gases has been observed worldwide. The rise in concentration of these gases in the atmosphere, specifically carbon dioxide (CO₂), has been linked to an increase in the average temperature on Earth, what is commonly known as global warming. To mitigate the emission of anthropogenic CO₂ in the atmosphere and consequently limit its impact on Earth’s climate, Carbon Capture and Storage projects (CCS) have been developed on various scales. In this type of project, CO₂ is captured from an emitting source (e.g., power plants), then transported via pipelines and stored in deep geological formations. In the United States, onshore CCS projects have demonstrated the technical feasibility of such projects. However, controversies associated with public acceptance and mineral ownership make expansive onshore CCS project development complicated. For these reasons, the U.S. Department of Energy (DOE) has been investigating offshore locations for the deployment of large-scale CCS projects. Southeast Offshore Storage Resource Assessment (SOSRA) is a project sponsored by the U.S. DOE to assess the storage potential of the eastern part of the Gulf of Mexico and the Atlantic Ocean as a first step towards the development of large-scale offshore storage of CO₂. The state of North Carolina was identified as an adequate candidate for CO₂ offshore storage due to its location on the Atlantic coast and its elevated CO₂ emissions from the power plants on its coastal plains. However, as exploration conducted on the outer continental shelf of North Carolina has been minimal, published information regarding the subsurface of this area remains limited to this date. To ensure the safe, long-term storage of CO₂ in this area, an extensive study was needed to select suitable geological formations and determine the storage capacity of each identified target. The research described here aimed to identify such geological targets and estimate the CO₂ storage capacity of North Carolina’s outer continental shelf

The purpose of this diploma thesis is to apply complex seismic attributes on 3D seismic data from Mistelbach block area and trying to figure out whether they are useful by seismic interpretation process. The geology of Vienna basin and the characteristics of Complex seismic attributes will be discussed. The thesis also includes analysis of the Lednice 11 gas reservoir and a new potential hydrocarbon reservoir identification, both using complex seismic attributes.

3D SEISMIC INTERPRETATION AND MODEL OF THE SCHRATTENBERG FAULT SYSTEM IN THE VALTICE AREA Šárka Hlaváčková Abstract The Schrattenberg normal fault system represents a dominant feature of the western margin of the Vienna Basin. Along with the Steinberg fault, they controlled the sedimentary and tectonic development of the area, and considerably participated in the deposition of the basin fill during a relatively short period of time in the Miocene. A detailed interpretation of the fault system is essential for full understanding of the local basin development and its geological architecture. The oil exploration industry targets mainly the Steinberg and Schrattenberg fault system because of the occurrences of oil and natural gas deposits that are related to the basin tectonics, which forms structural traps sealed by the main fault systems or by minor synthetic or antithetic faults. The thesis presents a geological framework of the Mistelbach block near Valtice at the western margin of the Vienna Basin. Geological interpretation includes also the fault framework modeling with the emphasis on the course of the Schrattenberg fault system. The model was built in the Petrel interpretation software with the use of the principles of the 3D seismic interpretation. In particular, seismic stratigraphy methods, Petrel...

The deep structure of the Bohemian Massif, the largest stable outcrop of the Variscan rocks in central Europe, was studied using the data of the international seismic refraction and wide- angle reflection experiments CELEBRATION 2000, ALP 2002 and SUDETES 2003. The data were interpreted by seismic tomographic inversion and by 2-D trial-and-error forward modelling of the P and S waves. Above, additional constraints on the crustal structure were imposed by reflectivity or gravity modelling, and by receiver function interpretation. Knowledge of the crustal velocity structure in the Bohemian Massif was complemented by its azimuthal variation. Though consolidated, the Bohemian Massif can be subdivided into several tectonic units separated by faults, shear zones, or thrusts reflecting varying influence of the crust forming processes. The resultant velocity models determined different types of the crust-mantle transition reflecting variable crustal thickness and delimiting contacts of these tectonic units at depth.