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NARROW
GeoRef Subject
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all geography including DSDP/ODP Sites and Legs
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Africa
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Chordata
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Vertebrata
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Osteichthyes
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Mammalia
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Reptilia
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coprolites (1)
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Invertebrata
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Cephalopoda
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Ammonites (3)
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Gastropoda (2)
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Protista
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Foraminifera
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Fusulinina
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Fusulinidae (1)
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Radiolaria (3)
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microfossils
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Fusulinina
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palynomorphs
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Dinoflagellata (4)
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miospores (2)
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Plantae
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algae
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Coccolithophoraceae (3)
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nannofossils (4)
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Spermatophyta
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thallophytes (4)
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geologic age
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Cenozoic
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Paleogene
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Eocene
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Green River Formation (1)
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middle Eocene
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Carrizo Sand (1)
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Claiborne Group (3)
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Queen City Formation (1)
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Sparta Sand (2)
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Yegua Formation (2)
-
-
upper Eocene
-
Jackson Group (1)
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-
-
lower Paleogene (1)
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Oligocene
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Frio Formation (5)
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Hackberry Formation (1)
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middle Oligocene (2)
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Vicksburg Group (4)
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Paleocene
-
Clayton Formation (4)
-
lower Paleocene
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Danian (2)
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K-T boundary (3)
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Midway Group (1)
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Sespe Formation (1)
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Wilcox Group (10)
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Mesozoic
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Cretaceous
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Comanchean
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Buda Limestone (10)
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Edwards Formation (2)
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Fredericksburg Group (1)
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Georgetown Formation (1)
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Glen Rose Formation (2)
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Paluxy Formation (1)
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Pearsall Formation (2)
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Rodessa Formation (1)
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Travis Peak Formation (2)
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Washita Group (3)
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Dakota Formation (1)
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Lower Cretaceous
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Edwards Formation (2)
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Fredericksburg Group (1)
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Georgetown Formation (1)
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Glen Rose Formation (2)
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Mowry Shale (1)
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Paluxy Formation (1)
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Pearsall Formation (2)
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Rodessa Formation (1)
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Sligo Formation (3)
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Travis Peak Formation (2)
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Upper Cretaceous
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Buda Limestone (10)
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Campanian
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Cerro del Pueblo Formation (1)
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lower Campanian (2)
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upper Campanian (1)
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Cenomanian (29)
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Eutaw Formation (2)
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Aguja Formation (13)
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Austin Chalk (48)
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Austin Group (26)
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Eagle Ford Formation (123)
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Escondido Formation (2)
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Navarro Group (8)
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Olmos Formation (4)
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Prairie Bluff Chalk (11)
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Taylor Marl (6)
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Woodbine Formation (36)
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Javelina Formation (4)
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K-T boundary (3)
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Maestrichtian (13)
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Mooreville Chalk (2)
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Niobrara Formation (4)
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Ripley Formation (3)
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Santonian (2)
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Saratoga Chalk (1)
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Senonian (22)
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Straight Cliffs Formation (1)
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Turonian (20)
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Tuscaloosa Formation (7)
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Franciscan Complex (1)
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Jurassic
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Posidonia Shale (1)
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Bossier Formation (3)
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Haynesville Formation (12)
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Smackover Formation (2)
-
-
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Nugget Sandstone (1)
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Triassic
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Montney Formation (3)
-
Upper Triassic
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Yanchang Formation (1)
-
-
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Vaca Muerta Formation (2)
-
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Paleozoic
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Carboniferous
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Mississippian
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Barnett Shale (12)
-
-
Pennsylvanian
-
Upper Pennsylvanian
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Canyon Group (3)
-
-
-
-
Devonian
-
Middle Devonian
-
Marcellus Shale (8)
-
-
Upper Devonian
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Huron Member (1)
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Ohio Shale (1)
-
-
-
Ordovician
-
Lower Ordovician
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Ellenburger Group (1)
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-
Middle Ordovician (1)
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Upper Ordovician (1)
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Utica Shale (2)
-
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Permian
-
Lower Permian
-
Wolfcampian (2)
-
-
-
Silurian
-
Lower Silurian (1)
-
-
upper Paleozoic
-
Bakken Formation (5)
-
-
Woodford Shale (2)
-
-
Precambrian
-
upper Precambrian
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Proterozoic
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Neoproterozoic
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Maranon Complex (1)
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igneous rocks
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igneous rocks
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plutonic rocks
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volcanic ash (2)
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silica minerals
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orthosilicates
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nesosilicates
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zircon group
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zircon (2)
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-
-
sheet silicates
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chlorite group
-
chlorite (2)
-
-
clay minerals
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kaolinite (3)
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montmorillonite (2)
-
smectite (5)
-
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illite (3)
-
-
-
sulfates
-
anhydrite (1)
-
gypsum (1)
-
-
sulfides
-
pyrite (3)
-
-
-
Primary terms
-
absolute age (2)
-
Africa
-
East Africa
-
Tanzania (1)
-
-
North Africa
-
Tunisia (1)
-
-
-
Asia
-
Far East
-
China
-
Yangtze Platform (1)
-
-
-
Middle East (1)
-
-
Atlantic Ocean
-
North Atlantic
-
Gulf of Mexico
-
Mississippi Canyon (1)
-
-
North Sea (1)
-
Northwest Atlantic
-
Demerara Rise (1)
-
-
-
-
Australasia
-
Australia (2)
-
-
biogeography (5)
-
bitumens
-
asphalt (1)
-
-
brines (1)
-
Canada (2)
-
carbon
-
C-13/C-12 (11)
-
organic carbon (3)
-
-
Caribbean region
-
West Indies
-
Antilles
-
Greater Antilles
-
Cuba (1)
-
Jamaica (1)
-
Puerto Rico (1)
-
-
-
-
-
Cenozoic
-
Tertiary
-
Catahoula Formation (1)
-
lower Tertiary (4)
-
Neogene
-
Miocene (1)
-
Pliocene (1)
-
-
Paleogene
-
Eocene
-
Green River Formation (1)
-
lower Eocene (7)
-
middle Eocene
-
Carrizo Sand (1)
-
Claiborne Group (3)
-
Queen City Formation (1)
-
Sparta Sand (2)
-
Yegua Formation (2)
-
-
upper Eocene
-
Jackson Group (1)
-
-
-
lower Paleogene (1)
-
Oligocene
-
Frio Formation (5)
-
Hackberry Formation (1)
-
middle Oligocene (2)
-
Vicksburg Group (4)
-
-
Paleocene
-
Clayton Formation (4)
-
lower Paleocene
-
Danian (2)
-
K-T boundary (3)
-
-
Midway Group (1)
-
-
Sespe Formation (1)
-
Wilcox Group (10)
-
-
-
-
Chordata
-
Vertebrata
-
Pisces
-
Chondrichthyes
-
Elasmobranchii (2)
-
-
Osteichthyes
-
Actinopterygii
-
Teleostei (1)
-
-
-
-
Tetrapoda
-
Amphibia
-
Lissamphibia (1)
-
-
Mammalia
-
Multituberculata (1)
-
Theria (2)
-
-
Reptilia
-
Anapsida
-
Testudines
-
Chelonia (2)
-
-
-
Diapsida
-
Archosauria
-
Crocodilia (1)
-
dinosaurs
-
Ornithischia
-
Ceratopsia
-
Ceratopsidae (1)
-
-
Ornithopoda
-
Hadrosauridae (1)
-
-
-
Saurischia (2)
-
-
Pterosauria (1)
-
-
Lepidosauria
-
Squamata
-
Lacertilia
-
Mosasauridae (1)
-
-
-
-
Sauropterygia
-
Plesiosauria (1)
-
-
-
-
-
-
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clay mineralogy (3)
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climate change (1)
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coprolites (1)
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crust (1)
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crystal growth (1)
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data processing (14)
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Deep Sea Drilling Project
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IPOD
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Leg 86
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DSDP Site 577 (1)
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deformation (12)
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diagenesis (11)
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Europe
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Gulfian
Multimineral petrophysics of thermally immature Eagle Ford Group and Cretaceous mudstones, U.S. Geological Survey Gulf Coast 1 research wellbore in central Texas
Specific surface area: A reliable predictor of creep and stress relaxation in gas shales
Near-field strain in distributed acoustic sensing-based microseismic observation
Rock classification in the Eagle Ford Formation through integration of petrophysical, geological, geochemical, and geomechanical characterization
Characteristics of Seismicity in the Eagle Ford Shale Play, Southern Texas, Constrained by Earthquake Relocation and Centroid Moment Tensor Inversion
Prediction of the gas-generating characteristics of the Qiongzhusi and Longmaxi Formations, Yangtze Platform, southern China, using analogues
Depositional environment and source rock quality of the Woodbine and Eagle Ford Groups, southern East Texas (Brazos) Basin: An integrated geochemical, sequence stratigraphic, and petrographic approach
Testing of a permanent orbital surface source and distributed acoustic sensing for monitoring of unconventional reservoirs: Preliminary results from the Eagle Ford Shale
Experimental determination of porosity and methane sorption capacity of organic-rich shales as a function of effective stress: Implications for gas storage capacity
Anisotropic dynamic and static mechanical properties of organic-rich shale: The influence of stress
The Bakken–Three Forks super giant play, Williston Basin
Validating the origin of microseismic events in target reservoir using guided waves recorded by DAS
Abstract The potential of polar compound compositions from electrospray ionization ultra-high resolution mass spectrometry (FT-ICR-MS) to characterize petroleum fluids as well as petroleum system processes is shown in the example of the Eagle Ford Formation in Texas, USA. A set of six black oil and nine source-rock bitumen samples is investigated with respect to its organic nitrogen-, sulphur- and oxygen-compound inventory in order to assess maturity, depositional environment, lithofacies and retention and migration behaviour. Compared to conventional geochemical tools based on molecular parameters from gas chromatographic analyses, FT-ICR-MS enables a maturity assessment from immature to late mature stage, which is barely influenced by source or depositional environment. Due to the increased molecular mass and polarity range of its target compounds, FT-ICR-MS is the most convincing tool to describe the retention and fractionation of polar compounds in a petroleum system.
Abstract Reliable evaluation of shale-play potential requires robust geological models that can simulate the generation and retention of petroleum, porosity and permeability in source rocks from first principles, and that can be implemented in basin modelling software. To be predictive, such basin models need to be calibrated against observations from real shale plays. A key control on the amount of retained petroleum is the porosity in the shale and the abundance of organic matter. Scanning electron microscopy of argon-ion milled shale samples can potentially reveal systematic variations in the amount of porosity, pore types and distributions across a range of thermal maturities. These observed variations in porosity can be used to calibrate basin modelling outputs and refine predictive models. For these reasons BP has conducted scanning electron microscopy studies of shale plays including the Eagle Ford Shale, a carbonate-rich mudstone sequence of Cenomanian to Turonian age. The results clearly show that the mean pore size decreases as thermal maturity increases and that organic matter-hosted pores are absent in low thermal maturity samples (where vitrinite random reflectance R o <0.7) and become increasingly more abundant as thermal maturity increases). In moderately mature samples there are organic matter hosted pores that range in pore size from 5 to 500 nm. In highly mature samples, small (<50 nm) organic matter-hosted pores predominate. Our studies reveal that porosity evolution in this organic-rich, fine-grained, carbonate mudrock shows a strong correlation with increasing thermal maturity.