Doe/netl-2012/1540 Mobility And Conformance Control For Carbon Dioxide Enhanced Oil Recovery (Co2-Eor) Via Thickeners, Foams, And Gels - U.s. Department Of Energy Page 10

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identified in the lab of which only a few (Chaser CD 1045, Alipal CD 128, and Chaser CD 1040)
were used extensively in pilot tests.
Foam generation requires interactions between the porous medium and the injected fluids, thus a
multitude of lab-scale studies directed at understanding the effects of temperature, pressure,
surfactant type, surfactant concentration, flow rate, foam quality, brine salinity, rock type, rock
wettability, matrix permeability, presence of fractures, degree of heterogeneity, presence of vugs,
oil composition, and oil saturation on the performance of these foams were conducted.
Laboratory foam mobility results for various porous media indicated that foams are typically
most readily formed in higher permeability, water-wet to mixed wettability, fracture-free cores.
Carbon dioxide foams have been found to reduce the residual oil saturation beyond that achieved
by CO
floods when the foam flood occurred after the CO
flood in cores initially containing
2
2
high oil and residual water saturation.
Eleven field tests using foams were conducted beginning in the mid-1980s that focused primarily
on blocking thief zones and impeding gravity override. There was a good deal of variability in
the degree of technical and economic success ascribed to these conformance control tests. About
half of these projects were considered to be successful technical efforts, and favorable economic
assessments were associated with most of them. However, about half of the field tests reported
problems that rendered the technical results as either unsuccessful or inconclusive. Problems
noted during these field tests included the dilution of CO
foam by subsequently injected water,
2
the inability of foam to be effective in formations containing fractures or extremely high
permeability open flow paths, the very short propagation of the CO
from the injection well, cold
2
weather ice and hydrate formation, unacceptably large decreases in injectivity associated with
co-injection, and other unspecified “operational problems.” The inability to determine how
much incremental oil was associated with application of the CO
foam was also cited as an
2
impediment to providing an accurate assessment of the process. Specific conformance control
field test results include:
 During the Unocal/Long Beach Oil Dev. Co. Wilmington Immiscible Trial at Long
Beach, California in 1984, a SAG conformance control pilot successfully diverted flow
into the T zone. Gas and water injection profiles indicated that the T zone received as
much as 43.3% of the injected gas, a dramatic increase from the 1.3% value prior to
SAG.
 Chevron initiated a CO
WAG flood at their Rangeley Weber Sand Unit in Colorado. The
2
operators found the results encouraging in that the foam project—which resulted in the
incremental production of roughly 50 BOPD during April and May 1989—paid out in
two months.
 One of the best documented field tests of CO
-in-brine foams occurred during 1992 in the
2
Phillips’ East Vacuum Grayburg/San Andres Unit (EVG/SAU). The operator estimated
that 14,700 bbl. and 4,460 bbl. of incremental oil were produced as a result of the first
and second SAG tests, respectively.
 During Amoco’s Wasson ODC Unit conformance control foam test in 1994, CO
2
breakthrough was delayed from 8 to 22 days and CO
production was reduced from
2
roughly 2000–2500 Mscf/d to 1000–1500 Mscf/d.
vi

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