Assessment of Residual Oil Saturation in a Large Carbonate Reservoir

Pham, Tony Reuben; Al-Shahri, Ali M.

doi:10.2118/68069-ms

Cited by 11 publications

(1 citation statement)

References 2 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…ROS = 34 to 41 percent, determined from well logs in Arab D reservoir, Saudi Arabia. The final S orw values determined from core waterflood and centrifuge tests were not reported (Pham and Al-Shahri, 2001).…”

Section: Carbonate Reservoirsmentioning

confidence: 99%

Material balance approach for determining oil saturation at the start of carbon dioxide enhanced oil recovery

Verma¹

2018

Open-File Report

View full text Add to dashboard Cite

For an overview of USGS information products, including maps, imagery, and publications, visit https://store.usgs.gov. Any use of trade, firm, or product names is for descriptive purposes only and does not imply endorsement by the U.S. Government. Although this information product, for the most part, is in the public domain, it also may contain copyrighted materials as noted in the text. Permission to reproduce copyrighted items must be secured from the copyright owner.

show abstract

Section: Carbonate Reservoirsmentioning

confidence: 99%

Material balance approach for determining oil saturation at the start of carbon dioxide enhanced oil recovery

Verma¹

2018

Open-File Report

View full text Add to dashboard Cite

show abstract

Residual Oil Saturation Determination – Case Studies in Sandstone and Carbonate Reservoirs

Teklu

Brown

Kazemi

et al. 2013

EAGE Annual Conference &Amp; Exhibition Incorporating SPE Europec

View full text Add to dashboard Cite

In petroleum reservoirs only a small fraction of the original oil-in-place is economically recovered by primary, secondary, and tertiary recovery mechanisms. A considerable amount of hydrocarbon ends up unrecovered or trapped due to microscopic phase trapping in porous media which results in an oil recovery factor typically less than 50%. Waterflooding is by far the most widely used method to increase oil recovery. The oil that remains in the porous media after waterflooding is called remaining oil saturation (ROS) which is larger than the relative permeability residual oil saturation (Sorw or simply Sor). This residual oil saturation varies depending on lithology, pore size distribution, permeability, wettability, fluid characteristics, recovery method, and production scheme. The Sor represents a statistical average over a wide range of pore scale residual saturations with in a representative elementary volume (REV). Determination of the residual oil saturation of a reservoir is a key parameter for reserve assessment and recovery estimates. Further, reliable Sor data is important for investigation of potential incremental recovery under Enhanced Oil Recovery (EOR) methods. Various residual oil saturation measurement techniques are available both at laboratory and field scale. None of the techniques can be regarded as a single best method of determining Sor. Depending on the complexity of the reservoir under study, combinations of methods are always advisable for appropriate Sor determination. This paper catalogues a number of field case studies which use different techniques of determining Sor and ROS in sandstone and carbonate reservoirs.

show abstract

Laboratory Study on Polymers for Chemical Flooding in Carbonate Reservoirs

et al. 2014

View full text Add to dashboard Cite

As part of the screening process for chemical EOR, several polymers have been screened as co-injectants in a surfactant-aided water flood scheme. Due to their higher viscosity, polymers improve sweep efficiency and reduce the permeability of rock matrix, therefore help to improve oil recovery. Aimed at a representative carbonate reservoir in the Middle East, a polymer screening study has been conducted with respect to polymer solubility and viscosity retention in high salinity brines, equivalent to our reservoir parameters. The polymers have to pass through a stringent screening process to meet the harsh conditions encountered in the reservoir: high temperature, high salinities and carbonate nature. Salinity effect was studied in a range of brines that included shallow formation water, produced water, and connate water. Among the polymers studied, six were found compatible and have been short-listed. Based on rheological measurements and flow curves, the concentrations of polymers have been determined to achieve the target viscosity under reservoir conditions. Long-term stability and adsorption tests were conducted to ensure the efficiency of the polymer exposed to reservoir conditions. Oil displacement tests with a selected polymer showed an increased oil recovery factor of 11% by polymer flooding and 18% by surfactant-polymer flooding. This study demonstrates the potential application of polymers under extremely harsh reservoir conditions and their promise to be good additives for chemical flooding.

show abstract

Assessment of Residual Oil Saturation in a Large Carbonate Reservoir

Cited by 11 publications

References 2 publications

Material balance approach for determining oil saturation at the start of carbon dioxide enhanced oil recovery

Material balance approach for determining oil saturation at the start of carbon dioxide enhanced oil recovery

Residual Oil Saturation Determination – Case Studies in Sandstone and Carbonate Reservoirs

Laboratory Study on Polymers for Chemical Flooding in Carbonate Reservoirs

Contact Info

Product

Resources

About