Topic
Petroleum reservoir
About: Petroleum reservoir is a research topic. Over the lifetime, 5403 publications have been published within this topic receiving 83535 citations. The topic is also known as: petroleum deposit.
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TL;DR: Based on the properties of the reservoir and fluids in a high-temperature oil reservoir, a comprehensive model, including formation water evaporation, dissolution, diffusion of CO2 in water, CO2-water-rock geochemical reactions, and relation of porosity and permeability, is established to simulate the CO2 EOR process and subsequent geological storage as discussed by the authors.
31 citations
01 Jan 1982
TL;DR: The Barnett Shale as discussed by the authors is a hard bituminous formation that is easily distinguished in drill cuttings or on electrical and porosity logs, and it is a source of hydrocarbons.
Abstract: The Barnett Shale originated as a normal marine shelf deposit on the southwestern flank of the subsiding Southern Oklahoma aulacogen, probably due to the Middle or Late Mississippian collision of the North American plate with South America and/or North Africa. It is a hard, bituminous formation that is easily distinguished in drill cuttings or on electrical and porosity logs. Subsurface correlations allow the Barnett to be informally subdivided into four or five members which can be traced through most of Jack, Wise, and Montague counties. It unconformably overlies rocks of Early to Middle Ordovician age, and it is in turn — with a few local exceptions — conformably overlain by the shales and limestones of the Marble Falls Formation. The growth of Mississippian pinnacle reefs was initiated with the inundation of North-Central Texas by the warm, shallow Barnett seas. The reef complexes are subdivisible into three constituent facies: the reef core, the reef flanks, and the interreef area. The reef cores are porous enough to serve as stratigraphic traps for oil and gas, and they have yielded excellent production in the northern part of the Fort Worth basin for several decades. The Barnett Shale, though itself unproductive, is believed to be the hydrocarbon source for the reef production.
31 citations
TL;DR: In this paper, hydraulic heads from a calibrated, three-dimensional, constant density, ground-water-flow model were used to compute Hubbert oil potentials and infer secondary petroleum migration directions within the Llanos Basin, Colombia.
Abstract: Hydraulic heads from a calibrated, three-dimensional, constant-density, ground-water-flow model were used to compute Hubbert oil potentials and infer secondary petroleum migration directions within the Llanos Basin, Colombia. The oil potentials for the C7 reservoir show evidence of the development of two hydrodynamic stagnation zones. Hydrodynamic effects on secondary oil migration are greatest in the eastern Llanos Basin, where structural slopes are lowest and local hydraulic-head gradients drive ground-water flow westward down structural dip. The Rubiales field, a large oil reservoir within the eastern Llanos Basin with no structural closure, is located at the edge of one of these stagnation zones. This oil field hosts heavy oils (12 API) consistent with water washing and biodegradation. The best agreement between model results and field conditions occurred in an oil density of 12 API, suggesting that the Rubiales field position is in dynamic equilibrium with modern hydraulic and oil density conditions. Cross sectional ground-water-flow models indicate that the most likely explanation of observed underpressures are caused by hydrodynamic effects associated with a topography-driven flow system. Late Miocene to present-day ground-water flow likely was an important factor in flushing marine connate porewaters from Tertiary reservoirs. Ground-water recharge along the western margin of the basin could help explain the observed low-temperature gradients (20C/km). However, upward flow rates were not high enough to account for elevated temperature gradients of 50C/km to the east.
31 citations
TL;DR: In this paper, the porosities, effective diffusivities and permeabilities of disturbed and intact rock were determined by using two novel methods: the 14 C -polymethylmethacrylate method and the He-gas method.
31 citations
TL;DR: In 1989, a deep test in Cottle County, Texas, discovered an anomalously thick, gas-charged Pennsylvanian (lower Bend Group) clastic section along the Matador arch as discussed by the authors.
Abstract: In 1989, a deep test in Cottle County, Texas, discovered an anomalously thick, gas-charged Pennsylvanian (lower Bend Group) clastic section along the Matador arch. Subsequent exploration and development provided data that support the concept that the natural gas fields in Cottle and King counties, north-central Texas, mark the extent of a hydrocarbon system related to the Broken Bone graben, an elongate 180 km2 pull-apart basin in southeastern Cottle County. The graben results from left-step overstepping of left-lateral fault zones and is a component of the Red River-Matador structural trend of the greater Ancestral Rocky Mountains. Arkosic detritus originating from the Amarillo-Wichita uplift was transported southward, over the region containing the graben, toward the Knox-Baylor trough. Episodic graben subsidence accommodated a part of this sediment load as syntectonic, cyclically stacked Bend Group (Atokan, lower Pennsylvanian) fluvial-deltaic to marine deposits. Organic facies within the graben fill are predominantly terrestrially derived (gas prone) and present in sufficient quantity for significant hydrocarbon generation. Lopatin method basin modeling, vitrinite reflectance (Ro) measurements, and Ro-calibrated pyrolysis-derived maturity measures demonstrate that the Bend Group organic facies in the graben have approached peak gas-generating maturation levels. Generated gas migrated within and outside of the basin following nonsealing faults and channelized fluvial pathways into several reservoir rock types in combination structural and stratigraphic traps. (Begin page 2)
31 citations