EOR Polymer Screening for an Oil Field With High Salinity Brines

Leveratto,; Lauri, J.; Sanz, Catherine; Sigal, J.; Ali, S.M. Farouq

doi:10.2118/26989-pa

Cited by 13 publications

(6 citation statements)

References 4 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…However, formation brine salinity is a major challenge for application of the process at a field scale. The higher salinity of formation brine significantly decreases polymer's in situ viscosity and hence presents economic challenges for such projects [68][69][70]. These economic constraints motivate companies to perform low-salinity pre-flush to optimize the process.…”

Section: Pilot Projects Of Polymer Floodingmentioning

confidence: 99%

An Elongational and Shear Evaluation of Polymer Viscoelasticity during Flow in Porous Media

2020

View full text Add to dashboard Cite

This paper uses a combination of approaches to evaluate the viscoelastic phenomenon in high-molecular-weight polymers (24–28 M Daltons) used for enhanced oil recovery (EOR) applications. Rheological data were cross-analyzed with single- and two-phase polymer flooding experiments in outcrop cores and micromodels, respectively. First, the impact of semi-harsh conditions (salinity, hardness, and temperature) was evaluated. Second, the impact of polymer degradation (sand face flow), focusing on the viscoelastic properties, was investigated. Finally, polymer viscoelastic properties were characterized, proposing a threefold rheological approach of rotational, oscillatory, and elongational behavior. Data from the rheological approaches were cross-analyzed with core flooding experiments and performed at a room temperature of 22 °C and at a higher temperature of 55 °C. The change in polymer viscoelastic properties were analyzed by investigating the effluents from core flooding experiments. Oil recovery experiments in micromodel helped our understanding of whether salinity or hardness has a dominating impact on in situ viscoelastic polymer response. These approaches were used to study the impact of mechanical degradation on polymer viscoelasticity. The brines showed notable loss in polymer viscoelastic properties, specifically with the hard brine and at higher temperature. However, the same polymer solution diluted in deionized water exhibited stronger viscoelastic properties. Multiple flow-behaviors, such as Newtonian, shear thinning, and thickening dominated flow, were confirmed through pressure drop analysis against interstitial velocity as already reported by other peer researchers. Turbulence-dominated excessive pressure drop in porous media was calculated by comparing core flood pressure drop data against pressure data in extensional viscometer–rheometer on a chip (eVROC®). In addition, a significant reduction in elastic-dominated flow was confirmed through the mechanical degradation that happened during core flood experiments, using various approaches. Finally, reservoir harsh conditions (high temperature, hardness, and salinity) resulted in a significant reduction in polymer viscoelastic behavior for all approaches.

show abstract

Section: Pilot Projects Of Polymer Floodingmentioning

confidence: 99%

An Elongational and Shear Evaluation of Polymer Viscoelasticity during Flow in Porous Media

2020

View full text Add to dashboard Cite

show abstract

“…In this regard, foam injection is a technical-proven method that can be used to improve formation conformance and water shutoff. − These findings have inspired researchers to perform a study on foam optimization in the last few decades. According to Hiraski, foam is defined as a dispersive system, in which liquid is the continuous phase with gas phase trapped in the thin liquid films called lamellae .…”

Section: Introductionmentioning

confidence: 99%

Design and Fabrication of Anionic/Cationic Surfactant Foams Stabilized by Lignin–Cellulose Nanofibrils for Enhanced Oil Recovery

et al. 2020

View full text Add to dashboard Cite

It has been decades since foams were adapted in further developing water-flooded oilfields. Foam stability is regarded as the governing factor that directly determines the enhanced oil recovery (EOR) efficiency of a foam injection. In this paper, we focus on a series of anionic surfactant-based foaming agent [sodium dodecyl sulfate (SDS)] and non-ionic surfactant-based foaming agent [alkyl polyglycoside (APG)] stabilized by lignin−cellulose nanofibrils (LCNFs), in the absence or presence of a cationic surfactant [hexadecyltrimethylammonium bromide (CTAB)]. Particular attention was placed on the proportion of LCNFs/SDS/ CTAB and LCNFs/APG/CTAB as well as their synergism assessment, including foamability, drainage half-time, foam decay, surface tension, and micromorphology. Our results demonstrate that the synergism between cationic/anionic surfactants and LCNFs retarded film drainage and, thus, produced robust foams. The synergism mechanism, contributed to the electrostatic reaction and hydrogen bond between LCNFs and the surfactants, has been discussed and proposed.

show abstract

“…The residual resistance factor (RRF) is defined as a ratio of the mobility of water after foam flooding (waf) to the water mobility before foam flooding (wbf) [30] . The RRF is calculated as:…”

Section: Foam Flooding Experimentsmentioning

confidence: 99%

Experimental Validation of the Temperature-Resistant and Salt-Tolerant Xanthan Enhanced Foam for Enhancing Oil Recovery

Sun

Wei

et al. 2015

Journal of Dispersion Science and Technology

View full text Add to dashboard Cite

Xanthan enhanced foam (XGF) is a newly developed chemical agent for enhanced oil recovery in high-temperature and high-salinity reservoirs. In this paper, laboratory experiments were performed to characterize the morphology and foam properties of XGF, to study its performance under different temperature and different salinity conditions, respectively. Based on simulate reservoir formation conditions of Xidaliya field, a series of research on XGF were conducted. The experimental results showed that the SEM of XGF reflected a more viscoelastic and stable nature of the foam system. High temperature had a great adverse impact upon the stability of XGF, and the increase of salinity in the solution helped to improve the stability of foam. The foam stability increased remarkably when XG4 is added, and an increase in ambient pressure made enhancement of foam stability became more noticeable. In the presence of crude oil, xanthan could enhance the stability Downloaded by [Columbia University] at 00:21 05 February 2015 2 of emulsions and was more favorable to stabilize foam. XG4 enhanced foam had dramatic properties for mobility controlling and oil displacement in the porous media.

show abstract

EOR Polymer Screening for an Oil Field With High Salinity Brines

Cited by 13 publications

References 4 publications

An Elongational and Shear Evaluation of Polymer Viscoelasticity during Flow in Porous Media

An Elongational and Shear Evaluation of Polymer Viscoelasticity during Flow in Porous Media

Design and Fabrication of Anionic/Cationic Surfactant Foams Stabilized by Lignin–Cellulose Nanofibrils for Enhanced Oil Recovery

Experimental Validation of the Temperature-Resistant and Salt-Tolerant Xanthan Enhanced Foam for Enhancing Oil Recovery

Contact Info

Product

Resources

About