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Book Chapter

Geologic Modeling and Uncertainty Analysis of a Gulf of Mexico Reservoir

By
Yuhong Liu
Yuhong Liu
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Peter G. Rigsby
Peter G. Rigsby
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Rohit Sinha
Rohit Sinha
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Steve Peterson
Steve Peterson
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Joy Thomas
Joy Thomas
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Gregory Zimmerman
Gregory Zimmerman
Marathon Oil Corporation, Houston, Texas, U.S.A.
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Published:
January 01, 2011

Abstract

Uncertainty analysis in a deep-water turbidite reservoir in the Gulf of Mexico is discussed in this chapter. Six major factors were addressed in the study to capture uncertainty: reservoir compartmentalization; acoustic impedance (AI) attenuation caused by the salt overhang; AI attenuation caused by fluid effects; petrophysical properties; pressure, volume, and temperature; and aquifer strength uncertainty. We characterized and quantified the uncertainties in the reservoir by integrating information from various disciplines: geophysics, petrophysics, geology, and engineering. This uncertainty workflow enabled us to make sound business decisions in a timely manner.

A base case scenario model was first built integrating well and seismic data. Multiple realizations were then simulated by varying petrophysical parameters such as porosity, permeability, and saturation; turning on and off various potential barriers; and processing the impedance volume for different scenarios. The effect of the drive mechanism on ultimate recovery was also studied by running scenarios with varying amounts of aquifer size and strength. The outputs of various scenarios were compiled to generate a probability distribution curve of the expected reserves and production rates. The outputs were then incorporated into an economic model to evaluate the viability of the project.

The field in this study was discovered in 2001 with the drilling of the exploration well 3 (Figure 1). Two sidetracks were subsequently drilled from the discovery well to delineate the size of the reservoir. After analysis of all available data, it did not appear that the reservoir potential, considering the expected costs of developing this remote field, would provide an economic project, especially with oil prices fluctuating between $20 and $30/ bbl at the time. Analysis of this opportunity continued throughout the next several years, but the project remained uneconomic.

A commercial agreement was reached with a host platform to process the production in 2007. The increase in oil prices further improved project economics. However, an increase in project costs accompanied the increase in oil price, and a great deal of uncertainty associated with reservoir performance still exists, despite having drilled three additional wells in the prospect area. Because of the immense cost associated with this project, coupled with the limited and uncertain resource base, it was paramount from a business perspective that the range of possible outcomes for this project be defined so that the economics could be evaluated from a stochastic perspective. Providing a range of possible outcomes is required in the portfolio management tool as it provides the management with more information than one can glean from a single deterministic economic scenario.

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Contents

AAPG Memoir

Uncertainty Analysis and Reservoir Modeling: Developing and Managing Assets in an Uncertain World

Y. Zee Ma
Y. Zee Ma
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Paul R. La Pointe
Paul R. La Pointe
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American Association of Petroleum Geologists
Volume
96
ISBN electronic:
9781629810102
Publication date:
January 01, 2011

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