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The AAPG/Datapages Combined Publications Database
Houston Geological Society Bulletin
Abstract
Abstract: Developing a Marginal Field Using New Techniques:
South Monagas Unit, Venezuela
By
1Benton Oil and Gas, Carpenteria CA
2Benton Vinccler C.A., Maturin, Venezuela
In 1992, the Venezuelan national oil company, PDVSA, awarded operating service agreements to foreign oil companies for reactivation of marginal oil fields. The South Monagas Unit contains three oil and gas fields, Uracoa, Bombal, and Tucupita, that were not producing prior to the award of the contract. As of November 1996, production from Uracoa exceeded 40 Mbbls/day of heavy oil from 20 vertical, 17 deviated, and 37 horizontal wells.
Initial uncertainties about heavy oil treatment
capability, water and gas production,
oil flow rates, and ultimate recoverable reserves
led to a phased development plan that
has incrementally reduced the risk of financial
exposure over time. The first phase of
development utilized
conventional
geologic
techniques and vertical wells to test
treatment
facilities, mud and gravel-pack technologies,
and flow rates. Positive results led
to the next phase of development which focused
on reservoir performance and well
optimization. A horizontal drilling program
was implemented in December 1993. A
milestone in this program was the first
gravel-pack horizontal well in Venezuela,
completed in February 1995. A pilot 2-D
seismic program in late 1994 confirmed that
high-quality seismic could be acquired to
significantly enhance the development of
Uracoa. A 175 sq. km. 3-D survey was shot
and processed in mid-1995. Concurrently,
borehole imaging logs were acquired in
vertical wells to determine internal reservoir
heterogeneity and sand depositional
models. The sequence stratigraphic model
that evolved, based on outcrop field analogs,
3-D seismic stratigraphy, and regional
well control, is being used to optimize field
development. In addition, new exploration
concepts are being tested without risk using
strategically located water injection
wells as test wells.
Since this talk was given to the AAPG conference last May, an additional 196 sq. km. of 3-D seismic has been acquired over the Bombal and Tucupita fields. A pilot horizontal well drilled at the Tucupita field resulted in an initial high-volume pump rate of 23,482 BOPD with no water.
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