Laboratory Investigation of Injectivity Losses During WAG in West Texas Dolomrites

Abstract

This paper wss prepemd for Presentatlm at the 1996 SPE Permian Badn Oil and GasRecoveryCofderenceheldh Mkflend,Tertes,2S27 Mati 1998. mi5 peper wss selectedfor praswtatlon~an SW PrOgrsm~lffee folloting reviewof infomtim retained In M abstracteubmlftedby the author(e).Contentsof the peper, ae pre-ted, have notk reviewedby the Sootetyof PetroleumEngineersmd em subJedto c0m3ctiM Ly the author(s).~material, as vaanted, does nol~sserily * eny poaifffflof M SOoiefyof PetmieumEngineers., its Mmre, w~re. Paprs preeentsdd SPE meeflngaare auw to Wblbtlw Wew by Editorial-ieea of the %iety of PetroleumEngineere.Eleotr~lo qodudion, diatributi~, or dora~of any pertof thispsper for ccinmerdelpu~s wfthoulthe wTIttanoc.naenf of the Societyof PetroleumEngineersis ptilbifed. Permiaslw to mpfcduw In pffntIs restrictedto an abstrectof not mom thanw rdq illustrations msy not be copied. The ebstrad must retain msplwws aclmdedgment of Mere and by~cin tie peper was presented,Write Ubmrian,SPE, P.O. BOX SSSS2S, Richerdeon, TX 7~2S2S, U.S.A., b 01-972-952-94S5. AbstractThis study reports infectivity data for the different flow zones present during a Water-Alternating-Gas (WAG) flood. The experiments were carried out on four rock types sampled horn the Grayburg dolomite formation in West Texas. We used liquid C02-water, toluene-liquid C02-water and crude oil-liquid C02-water systems to isolate mechanisms and to address nettability concerns.We found that the infectivity of the chase water zone was comparable to the initial waterflood infectivity, and increased as the trapped C02 dissolved. The infectivity of the C02-rich zone was significantly higher than the initial waterflood infectivity. Ambient condition toluene tests and reservoir condition crude tests gave similar results for the water and C02 zones. However the crude oil, even prior to any C02 inje~ion, exhibited a strong tendency to plug the core samples. We were unable to restore permeability in the plugged up core samples by continuous flushing of different solvents.

Reservoir quality and petrophysical properties of Cambrian sandstones and their changes during the experimental modelling of CO2storage in the Baltic Basin

“…They explored CO 2 dissolution into formation brine at various pH values as the primary sink for CO 2 and precipitation of CO 2 as carbonate minerals. Nevertheless, this process is very site-and condition-dependent and, in several cases, no important rock-fluid interaction impact on the petrophysical properties of the reservoir host rocks has been reported (Prieditis et al 1991;Kamath et al 1998).…”

Experimental modeling of CO2‐fluid‐rock interaction: The evolution of the composition and properties of host rocks in the Baltic Region

“…They explored CO 2 dissolution into formation brine at various pH values as the primary sink for CO 2 and precipitation of CO 2 as carbonate minerals. Nevertheless, this process is very site and condition dependent, and, in several cases, no important rockfluid interaction impact on the petrophysical properties of reservoir host rocks has been reported [Prieditis et al, 1991;Kamath et al, 1998].…”

Experimental and numerical studies on CO2 injectivity in low permeability oil reservoirs

“…As there are complex fluid distribution patterns, more researches focused on the abnormality of CO 2 injectivity during the wateralternating-gas/CO 2 (WAG) process. Experimentally, the effect of some primary features, such as relative permeability, water saturation, WAG ratio and CO 2 slug size, on CO 2 and bring injectivity during WAG flooding were studied and analyzed (Prieditis et al, 1991;Kamath et al, 1998;Shen et al, 2010;Yang et al, 2015). As the laboratory experiments are complicated and time-consuming, analytical or numerical methods are always used to evaluate the WAG injectivity.…”