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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01 Jan 1982
TL;DR: The Gjoa G-37 well, located on a mid-Eocene wrench-related anticline, penetrated 1300 m of interbedded Paleocene marine shales and alkalic volcanics overlain by 2700 m of Paleocene to Recent shales.
Abstract: Exploration on the continental shelf and slope in the northern Labrador Sea has been carried out by the petroleum industry since 1968. Data acquired include seismic reflection and refraction surveys, magnetic and gravity surveys, vertical seismic profiling and seafloor sampling. In addition, two wells — the Aquitaine et al, Hekja 0-71 and the Esso HB Gjoa G-37 — were recently drilled by industry. Hekja 0-71 was drilled to 3267 m in 1979 and the well was deepened to 4566 m in 1980. The section penetrated is dominantly nearshore to marine sandstones and shales. The lower 1000 m of drilled section consists of alkalic volcanics interbedded with chalky clays and ranges in age from Danian to Early Cretaceous. The gross pay interval between 3210 and 3286 m contains shallow marine to continental fluvial Paleocene sandstones and shales. Porous sandstones comprise 44 m of this interval and tested gas and condensate. The Gjoa G-37 well, located on a mid-Eocene wrench-related anticline, penetrated 1300 m of interbedded Paleocene marine shales and alkalic volcanics overlain by 2700 m of Paleocene to Recent shales and siltstones. Rifting in the northern Labrador Sea began, at the latest, in Early Cretaceous. A transform fault zone dominates all tectonic aspects of the shelf. During the Paleocene, extensive volcanism occurred and wrench-related structures formed. Most rifting ceased by late Eocene to early Oligocene. The sediments deposited are 6000 m thick over large areas and locally, where Cretaceous grabens are present, exceed 8000 m. Some of the sediments contain good reservoir rocks as well as petroleum source resinite, in addition to marine-derived organic matter. The kinds of traps present include extensional as well as wrench-related features and possibly large stratigraphic traps. Reservoirs include possible mid-Eocene and known Paleocene sandstones. In addition, Lower Cretaceous sandstones below the volcanics and lower Paleozoic carbonates and sandstones resting on Precambrian crystallines are anticipated.
37 citations
TL;DR: In this paper, the effect of temperature and confining pressure on permeability in Navajo Sandstone has been quantified by both laboratory and field measurements, showing that simulated fractures in porous rock have a higher percentage rate of decline with depth than whole rock, experience a greater degree of permanent deformation with depth, and are healed effectively when fracture permeabilty approaches that of the whole rock.
Abstract: Fluid flow through fractured porous subsurface reservoirs is an important but often unquantified property. The necessary quantification of this flow is achieved by both laboratory and field measurements. Laboratory experiments of the effect of temperature and confining pressure on permeability in Navajo Sandstone indicate that simulated fractures in porous rock (1) have a higher percentage rate of permeability decline with depth than whole rock, (2) experience a greater degree of permanent deformation with depth than whole rock, (3) are healed effectively when fracture permeabilty approaches that of the whole rock, and (4) experience a reduction in permeability dependent on the macroscopic ductility and previous maximum depth of burial of the host sandstone.
37 citations
TL;DR: The Shuaiba Formation has good reservoir quality ranging in porosity from 18-25% and with average permeability exceeding 100 md as discussed by the authors, which can be clearly defined from the logs.
Abstract: Bu Hasa field in Abu Dhabi was the first giant oil field in the Arabian Gulf to produce from the Lower Cretaceous Shuaiba Formation (Aptian). The field has a productive area of about 155,673 ac (63,047 ha.) and 12.6 billion bbl of oil reserves. The formation is composed mainly of rudistid and algal sediments, rudistid mounds having overlain and built up the topography of an algal platform. The position and elevation of the platform edge, combined with rising eustatic sea level, created a tendency toward both vertical and lateral growth, and regulated the form and distribution of the rudist accumulation. The Shuaiba Formation has good reservoir quality ranging in porosity from 18-25% and with average permeability exceeding 100 md. Nine reservoir units (A-I), classified by their porosity, permeability, and lithology, can be clearly defined from the logs. Eleven main lithofacies have been defined in the Shuaiba from detailed core descriptions. These lithofacies were deposited in three main phases. The earliest phase consisted of chalky mud-supported sediment with some algal colonies, followed by a middle phase characterized by a thick algal platform. During this stage of deposition, a shallow-water carbonate platform developed over the south and central part of the field, grading into deeper, open-marine sedimentation toward the north. The late phase was characterized by rudistid buildups (mainly caprinids and caprotinids). The growth of the thick algal platform in the south and central areas controlled the initial distribution of the main rudistid buildup; toward the north, small rudistid reefs are sparsely developed and present only n the latest stage on high-energy shoals.
37 citations
TL;DR: In this article, the porosity-permeability modeling, reservoir rock typing and incorporation of hydraulic-flow-units are crucial parts of an integrated reservoir characterization/modeling and dynamic simulation study, which control the quality of a reservoir model with effect on wells production behavior and prediction performance.
37 citations
TL;DR: In this article, secondary migration route mapping, based on the movement of oil by buoyancy in well-defined, isolated pressure compartments, integrated with timing of oil generation, indicates that the Ninian field could be sourced from two areas-Late Cretaceous migration from the southeast in the Viking Graben and Tertiary migration from west and southwest-explaining some of the contrasting reservoir and oil characteristics of the NN fields.
Abstract: The Viking (Graben of the North Sea contains a major deltaic reservoir-the Brent Group. Within the Brent Group, the Etive Formation, a coastal barrier sand, is both areally continuous and has excellent porosity and permeability. It is sandwiched between the fine-grained micaceous sandstones of the Rannoch Formation below and the impermeable mudstones of the Ness Formation above. Consequently, the Etive Formation has acted as the most important regional conduit for secondary migration of Upper Jurassic sourced oils. Oil migration through time has left a heavy residue in the uppermost part of the formation. These residues are aromatic-asphaltic, but otherwise resemble locally reservoired oils. Migration-sensitive biological marker ratios obtained from the residues change wi h distance from source. Secondary migration route mapping, based on the movement of oil by buoyancy in well-defined, isolated pressure compartments, integrated with timing of oil generation, indicates that the Ninian field could be sourced from two areas-Late Cretaceous migration from the southeast in the Viking Graben and Tertiary migration from the west and southwest-explaining some of the contrasting reservoir and oil characteristics of the Ninian and Lyell fields.
37 citations