Heavy Oil Reservoir Management

Thakur, Ganesh A.

doi:10.2523/39233-ms

Cited by 6 publications

(1 citation statement)

References 2 publications

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“…Recent results from oil companies operating in offshore areas rank viscous oil with viscosity between 10 and 50 cP @20 °C; extra-viscous oil between 50 and 400 cP; dead viscous oil ranging from 400 to 5000 cP @20 °C; and dead extra-viscous oil varying from 5000 and 50,000 cP @ 20°C. Some other classifications of heavy oil can be found in Speight 1 , Ehlig-Economides et al 2 and Thakur 3 Recently, significant offshore heavy oil discoveries were made in ultra-deep-water of Brazil and West Africa. Among the new technologies required for commercial production of these heavy oil reservoirs in deep water, new artificial lift devices and long horizontal wells length can be detached, completed with efficient sand control mechanisms (Pinto el al 4 ).…”

Section: Introductionmentioning

confidence: 99%

Forecasting the Development of Heavy-Oil Reserves in Ultra-Deep Waters Using Technological Risk Models

Suslick

Schiozer

Francisco

et al. 2003

Proceedings of SPE Hydrocarbon Economics and Evaluation Symposium

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TX 75083-3836 U.S.A., fax 01-972-952-9435. AbstractThe largest remaining reserves of heavy oil can be considered an important energy source for future supply. Recent discoveries of heavy-oil in ultra-deep environments have stimulated several companies in investing in these new assets for future revenues despite the uncertainties about technology development for future field exploitation.This paper presents a forecast model for assessing future technology achievements -necessary for the development of heavy oil fields in ultra-deep water -through logistic utility models. Using simulation results of three hypothetical fields with similar characteristics to some recent discoveries in Campos Basin in Brazil, a scenario for the next ten years was developed based on the decision to go ahead with the projects. A time-trend curve was employed to estimate the necessary period to achieve suitable technologies for field development (costs reduction) using a technological risk-aversion coefficient. The forecast model executes an economic sensitivity analysis on key input variables such as oil prices, oil characteristics (viscosity, API gravity), production profile, capital expenditures and operational costs. These uncertain parameters are important because production technologies for heavy oil in ultra-deep waters are not completely dominated by the industry.Simulations from three selected models indicated that under the worst CAPEX and OPEX scenario for heavy oil, a value reduction of 50% would be necessary for both parameters and the logistic model estimates that the technology would only be available after 10 years.

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Section: Introductionmentioning

confidence: 99%

Forecasting the Development of Heavy-Oil Reserves in Ultra-Deep Waters Using Technological Risk Models

Suslick

Schiozer

Francisco

et al. 2003

Proceedings of SPE Hydrocarbon Economics and Evaluation Symposium

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Experimental study on thermochemical composite system huff-n-puff process in ultra-heavy oil production

Zhang

Liu

Zou

et al. 2023

Fuel

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Reservoir Types and Characterization

Aminian

2016

Exploration and Production of Petroleum and Natural Gas

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A reservoir is a subsurface rock structure, with sufficient size and closure that contains a three-dimensional network of interconnected void (pore) space and is overlain by a fine-grained water-saturated rock. Porosity and permeability are the key features of pore structure and are important factors in the production of hydrocarbons from the reservoir. Porosity represents the capacity of the reservoir rock to contain petroleum. Permeability represents the ability of the reservoir rock to transmit fluids. Together, they influence the fluid storage and movement. The reservoirs are classified according to the initial state of the fluids in the reservoir in three broad categories, including oil, gas-condensate, and gas reservoirs. The classification of the reservoir according to the drive mechanism is another useful approach. Additionally, the reservoirs can be classified as conventional or unconventional based on the technological requirements for development and production. The term unconventional reservoirs include a wide variety of reservoir types. They commonly include tight-gas sandstones, coalbed methane (CBM), shale gas and oil, heavy oil and tar sands, and gas hydrates. To estimate the productive potential of the reservoir and to maximize the economic payback, the reservoir characteristics—including porosity, permeability, fluid saturations, net formation thickness, pressure, fluid properties, and the structure of the reservoir—must be determined. Reservoir characteristics can be evaluated by the analysis of the information obtained from the direct and indirect measurements. Direct measurements in a reservoir are possible on fluid samples and on the reservoir rock samples (cores). The indirect measurements can be obtained by lowering a string of sensors at the end of a wireline into the well to obtain a continuous record of the subsurface rock properties (logs). Another indirect measurement involves a pressure transient test that can be interpreted to diagnose the condition of production and injection wells.

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Heavy Oil Reservoir Management

Cited by 6 publications

References 2 publications

Forecasting the Development of Heavy-Oil Reserves in Ultra-Deep Waters Using Technological Risk Models

Forecasting the Development of Heavy-Oil Reserves in Ultra-Deep Waters Using Technological Risk Models

Experimental study on thermochemical composite system huff-n-puff process in ultra-heavy oil production

Reservoir Types and Characterization

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