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all geography including DSDP/ODP Sites and Legs
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GeoRef Categories
Era and Period
Epoch and Age
Book Series
Date
Availability
Permeability of upper Wolfcamp lithofacies in the Delaware Basin: The role of stratigraphic heterogeneity in the production of unconventional reservoirs Open Access
Grain assemblages and strong diagenetic overprinting in siliceous mudrocks, Barnett Shale (Mississippian), Fort Worth Basin, Texas Available to Purchase
Spectrum of pore types and networks in mudrocks and a descriptive classification for matrix-related mudrock pores Available to Purchase
Diagenesis and sealing capacity of the middle Tuscaloosa mudstone at the Cranfield carbon dioxide injection site, Mississippi, U.S.A. Available to Purchase
Proterozoic granites of the Llano Uplift, Texas: A collision–related suite containing rapakivi and topaz granites Available to Purchase
Morphology, Genesis, and Distribution of Nanometer-Scale Pores in Siliceous Mudstones of the Mississippian Barnett Shale Available to Purchase
Addressing Conventional Parameters in Unconventional Shale-Gas Systems: Depositional Environment, Petrography, Geochemistry, and Petrophysics of the Haynesville Shale Available to Purchase
Abstract The Upper Kimmeridgian to Lower Tithonian Haynesville Shale of East Texas was deposited in a basin rimmed by carbonate platforms to the west and north during a second-order transgression spanning 154–150 Ma. The Haynesville shale gas play is an important resource target in Louisiana and East Texas. Wells are characterized by high initial production and steep decline rates. Potential estimated ultimate recovery (EUR) per well is in the range of 4–7 Bcf, and playreserves of more than 100 Tcf. However, depositional environmental, mineralogy, lithology, textures, geochemistry, porosity, permeability, and wireline-log characteristics are all poorly documented or understood. This paper addresses previously undocumented parameters related to depositional setting, facies, diagenesis, pore space, petrophysics, and significant geochemical markers of the Haynesville Shale. The Haynesville Shale was deposited in a basinal setting surrounded by carbonate shelf of the Haynesville/Cotton Valley Lime. Cotton Valley pinnacle reefs grew within the shale-rich basin. Deposition was during a rapid second-order transgression that resulted in back-stepping of carbonates and smothering of carbonate production by the Haynesville fine-grained sediments. Carbonates were shed into the basin via gravity flows. The basin periodically exhibited a restricted environment of reducing anoxic conditions, as indicated by Molybdenum (Mo) and Fe/S concentrations. Relatively high TOC values (1–8%) are typical of these mudrocks that ranged from calcareous, laminated and/or biotur-bated mudstones to unlaminated siliceous mudstones. Bioturbation may be indicative for smaller-scale sea-level fluctuations and/or anoxic/oxic cycles. Pores are limited and small in size, occurring as micropores and nannopores in both intraparticle and interparticle forms. Nanopores are common and well-developed in some organic matter. Kerogen is seen to affect responses of all logs used for petrophysical characterization of porosity and lithology. Therefore, corrections must be applied when calculating porosity and clay volume.
Natural fractures in the Barnett Shale and their importance for hydraulic fracture treatments Available to Purchase
Predicting and characterizing fractures in dolostone reservoirs: using the link between diagenesis and fracturing Available to Purchase
Abstract Fracture geometries and fracture-sealing characteristics in dolostones reflect interactions among mechanical and chemical processes integrated over geological timescales. The mechanics of subcritical fracture growth results in fracture sets having power-law size distributions where the attributes of large, open fractures that affect reservoir flow behaviour can be accurately inferred from observations of cement-sealed microfractures and other microscopic diagenetic features, which are widespread in dolostones. Fracture porosity is governed by the competing rates of fracture opening and cement precipitation during fracture growth and by cements that post-date fracture opening. Combined analysis of structural and diagenetic features provides the best approach for understanding how fracture systems influence fluid flow. We review previous work and integrate new data on fractures and diagenetic features in cores from the Lower Ordovician Ellenburger and Permian Clear Fork formations in West Texas, and the Lower Ordovician Knox Group in Mississippi, together with outcrop samples of Lower Cretaceous Cupido Formation dolostones from the Sierra Madre Oriental, Mexico, in order to illustrate our approach.