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Goliat Field
Strategic geosteering workflow with uncertainty quantification and deep learning: Initial test on the Goliat Field data
Prestack inversion and multiattribute analysis for porosity, shale volume, and sand probability in the Havert Formation of the Goliat field, southwest Barents Sea
Prestack simultaneous inversion to predict lithology and pore fluid in the Realgrunnen Subgroup of the Goliat Field, southwestern Barents Sea
The deep EM real-time data from the Goliat Field compared with the logs mod...
The extra-deep EM (EDAR) real-time data from the Goliat Field compared with...
(a) Location of the Goliat field (adapted from NPD FactMaps) in the Norwegi...
Location map for the Goliat Field (adapted from NPD factMaps) in the Norweg...
Modeling extra-deep electromagnetic logs using a deep neural network
Comparison of six logs using a commercial EM simulator versus its ML approx...
Chronostratigraphy of the Norwegian Barents Sea ( Glørstad-Clark et al., 20...
Introduction to special section: Facies classification and interpretation — Integrating multiscale and multidiscipline data
Halpern C 7 (A) star correlation diagram and (B) transformation diagram. (...
Seismic-derived geomechanical properties of potential CO 2 storage reservoir and cap rock in Smeaheia area, northern North Sea
Introduction to special section: Seismic inversion — Conventional seismic impedance inversion and advanced seismic inversion techniques: Developments, workflow, and case studies
Abstract A dataset with pore pressures from more than 1000 exploration wells has been used to investigate the dynamics of aquifer systems in the Norwegian Continental Shelf (NCS). Variations in aquifer pressures reflect flow of porewater through permeable rocks over geological time. Strongly overpressured regimes are formed within confined aquifers in subsiding areas, where fluid flow out of the aquifer is controlled by vertical seepage. In transitional pressure regimes, fluid flows within permeable beds towards areas with hydrostatic pressures. In the hydrostatic regime, pressure differences result from density differences due to varying formation water salinity and by hydrocarbon columns. An underpressured regime has been encountered in confined aquifers in the platform areas of the Barents Sea, and is related to net uplift and erosion. In the case studies, pressure differences are interpreted in the context of the relevant pressure regime, and with a dynamic approach where segment boundaries and cap rocks are regarded as low-permeability restrictions rather than barriers. The present distribution of pressure regimes was developed over the last few million years due to rapid Pleistocene sedimentation and erosion processes.
Regional petroleum alteration trends in Barents Sea oils and condensates as a clue to migration regimes and processes
Abstract The exploration activities in the Barents Sea started as far back as 1907 with the first geological expedition to the Spitsbergen archipelago. Exploration for oil and gas started with the Kvadhuken well in 1961, followed by several other wells. Fina Exploration drilled two wells on the Island of Hopen in 1973. The NPD acquired the first seismic data in 1969. The universities collected seismic profiles from 1969 as part of the Continental Shelf Project. The first licences in the Barents Sea were awarded in the 5th concession round in Norway in 1980. The results so far (2016) are two fields in production, Snøhvit and Goliat, and several in the evaluation phase. The main exploration challenges in the Barents Sea are the Tertiary uplift and erosion of Jurassic and Cretaceous rocks, and the maturation of the source rocks due to the uplift. The discoveries Gotha and Alta in 2013–15 proved the Permian carbonate play. The awards in the 23rd concession round opened the Barents SE area bordering Russia. One well was drilled in 2017 with encouraging results and two more will be drilled in 2018.
Geochemically driven exploration models in uplifted areas: Examples from the Norwegian Barents Sea
Abstract The most prolific reservoir package in the SW Barents Sea is currently the Upper Triassic–Middle Jurassic Realgrunnen Subgroup, comprising the main hydrocarbon accumulations in the Goliat, Snøhvit and Johan Castberg fields and the Wisting discovery. The interval continues to be the main target as hydrocarbon exploration ventures further into this region. However, the package varies considerably in thickness and reservoir quality throughout the basin, and it is therefore very important to understand how this package developed and what has affected it in the time since it was deposited. Here we review controls on the tectonostratigraphic evolution and facies distribution within the Realgrunnen Subgroup, and exemplify the variability in reservoir characteristics within the subgroup by comparing some key wells in relation to their depositional environment and provenance. New provenance data that record a turnover from reworked Triassic- to Caledonian-sourced mature sediment support facies observations which suggest temporal changes in the depositional environment from marine to fluvial. Much of the variability within the subgroup is attributed the tectonostratigraphic development of the basin that controlled accommodation, facies transitions and sediment distribution. This variability is reflected in subtle differences in reservoir quality important both for exploration and production in the remaining underexplored basin.