Effect of crude oil ageing on low salinity and low salinity surfactant flooding

Alagic, Edin; Spildo, Kristine; Skauge, Arne; Solbakken, Jonas

doi:10.1016/j.petrol.2011.06.021

Cited by 98 publications

(42 citation statements)

References 20 publications

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“…The factors controlling whether or not fines migration and possible formation damage occurs are not fully understood. However, Alagic et al (2011) reported a correlation between wettability and fines migration; no indications of fines migration was observed during low salinity injection in aged cores whereas they were observed when unaged, water-wet cores were used. This is in agreement with the results reported by Mungan (1965) and Clementz (1977).…”

Section: Effect Of Salinity On Clay Stability and Surfactant Retentionmentioning

confidence: 93%

“…The studies have shown a moderate increase in oil recovery during injection of low salinity brine (0.2-0.5 wt% NaCl). Some, but not all, of these experiments have included observations indicating fines migration (see for example Alagic and Skauge, 2010;Gamage and Thyne, 2011;Alagic et al, 2011;Spildo et al, 2012). The factors controlling whether or not fines migration and possible formation damage occurs are not fully understood.…”

Section: Effect Of Salinity On Clay Stability and Surfactant Retentionmentioning

confidence: 99%

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A Strategy for Low Cost, Effective Surfactant Injection

Spildo¹,

Djurhuus²,

Sun³

et al. 2011

Proceedings

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Keywords: surfactant solubility phase behaviour microemulsion interfacial tension retention a b s t r a c t Ideally, in a chemical flooding process, one would like to inject a surfactant solution that has good solubility at the relevant conditions, ultralow interfacial tension (efficient oil mobilisation) and low loss of surfactant (better economics) in the porous medium. The key question is -can you have low loss of surfactant, i.e. low retention, at ultralow interfacial tension?To answer this question, we have undertaken a systematic study of surfactant solubility, phase behaviour, interfacial tension and retention as a function of salinity for a given surfactant formulation. The idea is to explore the interrelationship between these properties and find the best condition(s) for combined low interfacial tension and low retention in a surfactant flooding process.For the investigated surfactant formulation, ultra-low interfacial tensions ( o0.01 mN/m) can be found in the Winsor III region at optimal salinity. The aqueous solution at optimal salinity is, however, turbid, and retention values are high. On the other hand, for light oils, there are regions in the Winsor I area where (i) interfacial tensions are low (0.01 mN/m o IFT o0.1 mN/m), but not ultralow, (ii) aqueous solutions are clear and (iii) retention is 10 times lower than at optimal salinity. The search for an optimum surfactant formulation has to consider solution properties and retention in addition to the low interfacial tension. Based on our result, we therefore propose that Winsor I phase behaviour is the best option for a compromise between the properties in question.

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Section: Effect Of Salinity On Clay Stability and Surfactant Retentionmentioning

confidence: 93%

Section: Effect Of Salinity On Clay Stability and Surfactant Retentionmentioning

confidence: 99%

A Strategy for Low Cost, Effective Surfactant Injection

Spildo¹,

Djurhuus²,

Sun³

et al. 2011

Proceedings

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“…(RCOO) 3 C 3 H 5 + 3 NaOH → 3 (RCOONa) + C 3 H 5 (OH) 3 (1) fat + alkali → soap + glycerol 2 (RCOONa) + Ca(HCO 3 ) 2 → (RCOO) 2 Ca + 2 (NaHCO 3 )…”

Section: Ph Contributionmentioning

confidence: 99%

State-of-the Art Low Salinity Waterflooding for Enhanced Oil Recovery

Dang

Nghiem²,

Chen

et al. 2013

All Days

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Low salinity waterflooding (LSW) is an emerging enhanced oil recovery technique in which the salinity of the injected water is controlled to improve oil recovery vs. conventional, higher salinity waterflooding. Despite significant growing interest in LSW, a consistent mechanistic study has not yet emerged, and the mechanisms behind the LSW process have been debated for the last decade due to the complexity of the crude oil-brine-rock interactions. The intent of this paper is to:• Provide a concise review of the current understanding of LSW mechanism and prediction methods;• Address the current development and challenges of LSW modeling and numerical simulation;• Summarize and highlight the success and failur of LSW implementation in pilot tests;• Discuss the potential of a Hybrid LSW in the current and future projects.

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“…These stabilisers alone could significantly affect effective fluid properties especially viscosity and interfacial tension 24,25 , thus having an EOR effect themselves.…”

Section: Introductionmentioning

confidence: 99%

Nanoparticle-Assisted Water-Flooding in Berea Sandstones

Azmi

Raza

et al. 2016

Energy Fuels

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ABSRACT:The use of nanoparticles (NP) to improve reservoir characterisation or to enhance oil recovery (EOR) has recently received intensive interest; however there are still many un-resolved questions. This work reports a systematic study of the effect of rutile TiO 2 nanoparticle-assisted brine flooding. Rutile ellipsoid TiO 2 nanoparticles were synthesised and stabilised by tri-sodium citrate dehydrate for brine flooding of water-wet Berea sandstone cores. Careful characterisation of the rock samples and nanomaterials before and after the flooding was conducted, and the relative contributions to the modified flooding results from the stabiliser and the nanoparticles of different concentrations were examined. The oil recovery performance was evaluated both at break-through (BT) point and at the end of flooding (~3.2 pore volumes). Nanoparticle migration behavior was also investigated in order to understand the potential mechanisms for oil recovery. The results showed that both nanoparticle transport rate and EOR effect were strongly dependent on the particle concentration. The oil recovery efficiency at the BT point was found to increase at low nanoparticle concentrations but decrease at higher values. A maximum 33% increase of the recovery factor was observed at the BT point for a TiO 2 concentration of 20 ppm, but higher nanoparticle concentrations usually had higher ultimate recovery factors. The presence of oil phase was found to accelerate the particle migration though the core. The discussion of various mechanisms suggested that the improvement in the mobility ratio, possible wettability change and log-jamming effect were responsible for the observed phenomena.

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Effect of crude oil ageing on low salinity and low salinity surfactant flooding

Cited by 98 publications

References 20 publications

A Strategy for Low Cost, Effective Surfactant Injection

A Strategy for Low Cost, Effective Surfactant Injection

State-of-the Art Low Salinity Waterflooding for Enhanced Oil Recovery

Nanoparticle-Assisted Water-Flooding in Berea Sandstones

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