A Comparison of 31 Minnelusa Polymer Floods With 24 Minnelusa Waterfloods

Hochanadel, S.M.; Lunceford, M.L.; Farmer, C.W.

doi:10.2523/20234-ms

Cited by 14 publications

(7 citation statements)

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“…The Minnelusa experiments produced total recovery between 46 and 68% OOIP. The range of recovery values is not unreasonable given the heterogeneity of this reservoir rock (Hochanadel et al 1990). These values are similar to the range observed in field recovery values (discussed below).…”

Section: Laboratory Experiments -Two-phase Experiments -Tertiary Modesupporting

confidence: 81%

“…When there were multiple samples from a single well, preference was given to production over DST samples and the earliest (pre-waterflood) production sample over later production samples. Recovery factors were calculated for fields in which oil and water production, total pore volume and OOIP were reported (Towler and Griffith 1990, Hochanadel et al 1990, Mack and Duvall 1990.…”

Section: Description Of Equipment and Processesmentioning

confidence: 99%

“…Thirty-one of the 51 fields had polymer injection for relatively short periods of application (up to 1 year). These fields usually had lower API gravity oil and polymer treatments were designed to produce a more favorable mobility ratio (Surkalo and Pitts 1986, Hochanadel et al 1990, Brady et al 1998). Fig.…”

Section: Analysis Of Field Datamentioning

confidence: 99%

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Evaluation of the Effect of Low Salinity Waterflooding for 26 Fields in Wyoming

Thyne

Gamage

2011

SPE Annual Technical Conference and Exhibition

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This report evaluates the effectiveness of low-salinity waterflooding in the Minnelusa Formation in the Powder River Basin of Wyoming. The Minnelusa sandstone play constitutes a resource of over one-hundred fields with cumulative production of more than 600,000,000 barrels of oil. We conducted initial laboratory screening using Minnelusa oil and rock with synthetic brine, supplemented with geochemical models of low-salinity injection, to evaluate the potential for low-salinity waterflooding in this formation. The laboratory experiments showed little or no incremental recovery from low-salinity injection. Calculation and comparison of recovery factors for 51 Minnelusa reservoirs were used to further evaluate the effectiveness of low-salinity waterfloods at the field scale. There was no increase in recovery for fields that used low salinity injection (26) compared to fields with mixed or formation water injection (25). Since some Minnelusa fields have relatively fresh formation water, the amount of dilution was quantified using the salinity ratio (SR), defined as the ratio of salinity of injected water to salinity of formation water. This analysis showed that while some fields actually had little or any salinity reduction (13), the remaining fields with significant dilution (38) still showed no correlation between dilution and recovery factor. Since some postulated mechanisms involve change in wettability, injection of low-salinity water may produce later water breakthrough. Analysis of water breakthrough timing and watercut evolution for 23 fields found no significant difference between fields with low-salinity injection and mixed-water or saline injection.

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Section: Laboratory Experiments -Two-phase Experiments -Tertiary Modesupporting

confidence: 81%

Section: Description Of Equipment and Processesmentioning

confidence: 99%

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Evaluation of the Effect of Low Salinity Waterflooding for 26 Fields in Wyoming

Thyne

Gamage

2011

SPE Annual Technical Conference and Exhibition

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“…However, in the present survey, we classified them as polymer floods because of (1) the large size of the anionic polymer banks compared with the other chemical banks, and (2) the approach taken during the design and reporting of these projects. 15,16 Gel Treatments in Injection Wells. The results of our survey of injection-well gel projects are summarized in Table 1.…”

Section: Literature Review Of Field Applicationsmentioning

confidence: 99%

A Survey of Field Applications of Gel Treatments for Water Shutoff

Seright¹,

Liang²

1994

Proceedings of SPE Latin America/Caribbean Petroleum Engineering Conference

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“…The current study attempts to determine if similar results have been seen in the field by examining the projected recovery from 20 Minnelusa water-floods in the Powder River Basin. Hochanadel et al 15 have previously compared Minnelusa floods to determine the efffectiveness of polymer injection to increase the recovery. They found that polymer injection on average increased the oil recovery by 7.5% of OOIP.…”

Section: Introductionmentioning

confidence: 99%

Comparison of 20 Minnelusa Waterfloods in the Powder River Basin

Towler¹,

Griffith²

1999

Proceedings of SPE Rocky Mountain Regional Meeting

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis study compares the oil produced at a projected pore volume (PV) produced predicted from a suitable curve fit. The study compares fresh waterfloods with brine floods. The data plots and curve fitting techniques are such that PV Oil produced could be chosen for the Y axis for easier economic analysis. This technique was developed and described in Griffith 13 . The study was originated from interest generated by work performed by Morrow's research group at the University of Wyoming, (see Tang 26 , and Tang and Morrow 27 ), indicating that fresh water flooding could result in a greater oil recovery then saline floods. Table 1 and Figure 1 shows the comparison of our 20 chosen waterfloods. The Widge field, which extends above the top of the chart, has not produced sufficient water to define the waterflood. The lowest plotted field, the Spirit Field, appears to have watered out very quickly after initialization of the waterflood. Figures 2 and 3 are the 20 flood separated into non-enhanced and enhanced floods. The West Semlek waterflood is placed in the non-enhanced although an attempt had been made to use polymer in the field. We have assigned fresh water flood status to those fields initially flooded with Fox Hills water even though the later makeup water was combined with produced brines. The West Semlek, the one brine flood, is the flood in Figure 1 which has the x marker and intercepts the 2.0 pore volumes fluid (water plus oil) produced at 42% of OOIP produced. In general the fresh water floods had generally higher recoveries than the one brine flood, which is consistent with Morrow's laboratory results.

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A Comparison of 31 Minnelusa Polymer Floods With 24 Minnelusa Waterfloods

Cited by 14 publications

References 0 publications

Evaluation of the Effect of Low Salinity Waterflooding for 26 Fields in Wyoming

Evaluation of the Effect of Low Salinity Waterflooding for 26 Fields in Wyoming

A Survey of Field Applications of Gel Treatments for Water Shutoff

Comparison of 20 Minnelusa Waterfloods in the Powder River Basin

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