Smart Water as Wettability Modifier in Carbonate and Sandstone: A Discussion of Similarities/Differences in the Chemical Mechanisms

Rezaeidoust, Alireza; Puntervold, Tina; Strand, Skule; Austad, Tor

doi:10.1021/ef900185q

Cited by 508 publications

(328 citation statements)

References 24 publications

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“…All brines were prepared using Schlumberger manuals. From the literature, sea water has shown good recovery in carbonate reservoirs (RezaeiDoust et al 2009;Zhang et al 2007). Also the effect of sulphate ions in water has shown some additional oil recovery.…”

Section: Brinesmentioning

confidence: 99%

Selecting a potential smart water for EOR implementation in Asab oil field

Abubacker

Al-Attar

Zekri

et al. 2017

J Petrol Explor Prod Technol

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The IFT and contact angle are believed to have direct impact on wettability alteration of crude oil/water/rock systems. In this work, extensive laboratory work was conducted to investigate the effect of these two key parameters on wettability alteration at elevated temperature (90°C) and ambient conditions. Twenty-six brines representing various scenarios of dilution and sulphate spiking were prepared and tested to identify the smart water most effective in the alteration of wettability. Sea water (SW) was used a base brine. Diluted and sulphate-spiked versions of SW were synthetically prepared following the standard brine preparation procedures. Also standard procedures were followed for the measurement of IFT and contact angle measurements using Teclis tracker. Pendant drop method was implemented to measure the IFT at ambient and 90°C conditions using a special software package that adopts the axisymmetric drop shape analysis and fits the Laplace equation. The same software package was used to take snapshots of oil drops at 90°C, and contact angle was measured manually. The effects of dilution and/or sulphate spiking on the observed IFT and contact angle measurements were investigated using a proposed brine categories-based plotting technique. Natural SW and its sulphate-spiked versions have shown the least oil/brine IFT at ambient and 90°C conditions. The sulphate-spiked SW and its dilutions have resulted in the reduction in oil/brine IFT, whereas the diluted SW showed an increase in oil/brine IFT. Further reduction in IFT was observed at the elevated temperature. SW and SW/50 (50 times diluted sea water) were the only two brines that could yield a contact angle of 113°and 114°, respectively, indicating the change in wettability from oil-wet to the border line of intermediate-wettability conditions. The natural SW that contains 3944 mg/L of sulphate ion has been found to be the most effective in promoting wettability change and thus represents the selected smart water for EOR implementation in Asab oil field. The contact angle measurements were made from the drops formed by the natural drainage process. These measurements are believed to duplicate contact angles in the selected reservoir because of the continuous change in fluids saturation. Keywords

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Section: Brinesmentioning

confidence: 99%

Selecting a potential smart water for EOR implementation in Asab oil field

Abubacker

Al-Attar

Zekri

et al. 2017

J Petrol Explor Prod Technol

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“…In this way the organic material is soluble in water. Inorganic ions like Calcium, Magnesium and Sodium break up the water structure around the organic molecules and therefore the solubility decreased when the concentration of these ions increased [RezaeiDoust et al 2009]. …”

Section: Salting-in Effectmentioning

confidence: 99%

“…The suggested recovery mechanism for carbonates is wettability alteration [Aladasani et al 2012;Yousef et al 2011], due to ion exchange [Al Shalabi et al 2013;Brady et al 2012], electric double layer expansion [Alotaibi et al 2011], Calcite dissolution [Hio 2008;Yousef et al 2011;Zhang and Sarma 2012] and pH increase. Other mechanisms are insitu surfactants generation, emulsion formation [Emadi and Sohrabi 2013;Mahzari and Sohrabi 2014], salting-in effect [RezaeiDoust et al 2009] and fines migration [Zahid et al 2012]. Chapter 1.…”

Section: Introductionmentioning

confidence: 99%

Calcite Dissolution Behaviour During Low Salinity Water Flooding in Carbonate Rock

Ouden¹,

Nasralla²,

Guo³

et al. 2015

Proceedings

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Master of ScienceCalcite dissolution behaviour during low salinity water flooding in carbonate rockby Liselotte den OudenLow salinity water flooding (LSF) has been proved to be a promising enhanced oil recovery method for sandstone reservoirs. The efficiency of LSF in carbonate reservoirs has not been proven completely yet, because there are still uncertainties about the LSF recovery mechanism in carbonate. From experimental studies, it was shown that wettability alteration, due to salinity reduction, is able to mobilize the remaining oil. Some studies attributed the wettability alteration by LSF to Calcite dissolution. Furthermore, Calcite dissolution can influence the salinity and pH of injected brines, and hence the oil recovery.However, there is a lack of experimental data on the Calcite dissolution effect of LSF in carbonate rock.The objective of this experimental study was to get a better understanding of the Calcite dissolution behaviour and how it might affect the oil recovery. Bulk and coreflood experiments have been performed; the experimental data was history matched with the use of PHREEQC. Calcite dissolution decreased with decreasing P CO2 and increased with decreasing pH and increasing NaCl salinity from 500-2000PPM.Increasing the injection rate reduced the interaction time and therefore Calcite dissolution did not reach equilibrium in coreflood at high rates. Calcite dissolution from chalk matched with the Calcite dissolution from pure Calcite, while Calcium concentration in effluent from limestone was higher. The two-phase coreflood experiment confirmed that Calcite dissolution occurs as well if oil is present in the porous media, but showed lower values than in single-phase coreflood experiment. pH increased from 5-6 to 9.5 due to Calcite dissolution, which might have an effect on the rock and oil surface charges, and hence oil recovery improvement. The effluent of the two-phase coreflood showed that an emulsion was formed, which suggested formation of in-situ surfactants. From CT scans, micro-CT scans and material mass balance calculations an increase in porosity around 1% was observed. The increase in the total dissolved species due to Calcite dissolution was not significant, which will not harm LSF effect.

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“…In addition, there is extensive evidence showing that the salinity and composition of the formation water can alter wetting properties of the reservoir rock (Agbalaka et al 2009, Dumore 1964, Jerauld et al 2008, Loahardjo et al 2010, Piper and Morse 1982, Rezaeidoust et al 2009, Robertson 2009). …”

Section: Figure 1 Schematic Of the Contact Angles As Observed For A Cmentioning

confidence: 99%

Interfacial Tension and Contact Angle Determination in Water-sandstone Systems with Injection of Flue Gas and CO2

Shojaikaveh¹,

Rudolph²,

Rossen³

et al. 2013

Proceedings

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SUMMARYCarbon capture and storage (CCS) has the potential for reducing CO2 emissions to the atmosphere. This option includes storage strategies such as CO2 injection into deep saline aquifers, depleted oil and gas reservoirs, and unmineable coal seams. This process is largely controlled by the interactions between CO2, the reservoir fluid and reservoir rock. In particular, the wettability of the rock matrix has a strong effect on the distribution of the injected CO2 into geological formations.In this study, the wetting behavior of Bentheimer sandstone slabs and CO2 and/or flue gas is investigated by means of contact-angle measurements. In addition, the interfacial tension between CO2 and/or flue gas and connate water was determined. The experiments were conducted in a pendant-drop cell, adapted to allow captive-bubble contact-angle measurements and performed at a constant temperature of 318 K and pressures varying between 0.2 and 15 MPa, typical in-situ conditions.The experimental contact angle measurements show that the Bentheimer sandstone/water system is (and remains) water-wet even at high pressures with CO2 and/or flue gas injection. The determined data of the contact angle of the water-sandstone system demonstrate a strong dependence on the bubble size and surface roughness with CO2 and flue gas injection.

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Smart Water as Wettability Modifier in Carbonate and Sandstone: A Discussion of Similarities/Differences in the Chemical Mechanisms

Cited by 508 publications

References 24 publications

Selecting a potential smart water for EOR implementation in Asab oil field

Selecting a potential smart water for EOR implementation in Asab oil field

Calcite Dissolution Behaviour During Low Salinity Water Flooding in Carbonate Rock

Interfacial Tension and Contact Angle Determination in Water-sandstone Systems with Injection of Flue Gas and CO2

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