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.

Optimization of carbon dioxide sequestration and improved oil recovery in oil reservoirs

Abstract: Publisher Summary The vast majority of industrialized countries, irrespective of their position regarding the Kyoto Protocol, have started to take actions toward reducing the emission of carbon dioxide (CO2) and other gases, such as methane (CH4) and nitrous oxide (N20), into the atmosphere. However, application of CO2 storage or enhanced oil recovery (EOR) in carbonate reservoirs is more challenging due to their extreme heterogeneity of both porosity and permeability. Past injection/production practices, aquifer strength, reservoir heterogeneity, and CO2 injection schemes, such as injecting CO2 at the top or bottom of the reservoir or using horizontal wells instead of vertical wells for injection and production purposes are among the main factors affecting both oil recovery and CO2 storage capacity. It discusses the effects of different injection schemes and the timing of injection on optimization of oil recovery/CO2 storage capacity for a partially depleted oil reservoir.

Draugen oil field, Haltenbanken Province, offshore Norway

Abstract: The Draugen oil field lies in Block 6407/9 in the Haltenbanken oil and gas province. The field is located 150 km off the coast of Norway and 200 km south of the Arctic Circle, in water depths of 240-280 m. The field was discovered in 1984 by well 6407/9-1. Five more exploration/appraisal wells and two-dimensional seismic assisted in delineating the reservoir. The field is hosted by a low-relief north-south-trending anticline measuring some 20 x 6 km. The reservoir lies at a depth of 1,600 m subsea, and has an oil column of 40 m. The main reservoir is the Late Jurassic Rogn Formation sandstones, interpreted as a shallow-marine sand bar. The formation pinches out to the west and east, and is capped by Spekk Formation shales. A separate, smaller accumulation has also been proved in Middle Jurassic Gam Formation sandstones in the western part of the field. Sand quality in both reservoirs is good to excellent. Field STOIIP is estimated at 180 million Sm{sup 3} of oil. Expectation of recoverable reserves is 67 million Sm{sup 3}. Government approval for field development was given in December 1988. The field will be developed with a concrete gravity base structure and offshore loading.more » The initial development plan calls for six oil producers and six subsea water injectors. The platform will be installed in the summer of 1993, with first oil shortly thereafter. The planned plateau production rate is 14,300 Sm{sup 3}/day dry oil. Pending a gas offtake solution for the Haltenbanken region, produced associated gas will initially be reinjected into a water-bearing structure in the western part of the field.« less

Estimation of critical gas saturation during pressure depletion in virgin and waterflooded reservoirs

Abstract: An important issue in petroleum engineering is the prediction of gas production during reservoir depletion--either following conventional waterflooding operations or in the early stages of hydrocarbon production. The estimation of critical gas saturation for use in corresponding simulation studies is clearly a primary concern. To this end, a 3D, three-phase numerical pore-scale simulator has been developed that can be used to estimate critical gas saturations over a range of different length scales and for a wide range of fluid and rock properties. The model incorporates a great deal of the known physics observed in associated laboratory micromodel experiments, including embryonic nucleation, supersaturation effects, multiphase diffusion, bubble growth/migration/fragmentation, oil shrinkage, and three-phase spreading coefficients. The precise pore-scale mechanisms governing gas evolution have been found to be far more subtle than earlier models would suggest because of the large variation of gas/oil interfacial tension (IFT) with pressure. This has a profound effect upon the migration of gas structures during depletion. In models pertaining to reservoir rock, the process of gas migration is consequently much slower than predictions from more simplistic models would imply. This is the first time that bubble fragmentation and IFT variations have been included in a model of gas evolution at the pore-scale and the implications for production forecasting are expected to be significant. In addition, novel scaling groups have been derived for a number of different facies under both virgin and waterflooded conditions. One future application of these groups would be to scale S gc values obtained from high rate depressurization experiments to the low rate conditions more characteristic of field operations.

Underground storage of natural gas in Illinois--1973

Abstract: Natural gas is stored in underground reservoirs at 37 locations in Illinois. These reservoirs contain more than 580 billion cu ft of gas, about one-third of which is working gas and two-thirds is cushion gas. Potential usuable capacity of these reservoirs is estimated to be 1.2 trillion cu ft. At 11 of the storage projects, gas is stored in depleted, or partially depleted, gas reservoirs. One depleted oil reservoir is used for storage, and in the remaining projects, gas is stored in aquifers that originally contained no hydrocarbons in commercial quantities. At 4 locations, 2 reservoirs at different depths are in various stages of exploration, testing or development for storage. Two projects have been abandoned. Rocks of all systems from Cambrian to Pennsylvanian are used for storage of gas in Illinois. However, most of the storage volume is in sandstone aquifers of Cambrian and Ordovician age. (50 refs.)