Abstract
Among 64 bacterial strains isolated in this study, the best two of biosurfactant-producing bacteria were selected and identified based on the phenotypic properties and molecular approach based on 16S rRNA having 100% similarity to the gram-negative Enterobacter aerogenes B19 strain bacteria and rode gram-positive strain Bacillus cereus ISU-02 in the Nucleotide database of the National Center for Biotechnology Information. The study showed that two selected isolates gave the highest positive results that were used to investigate the biosurfactant production including: interfacial reduction, foaming activity, hemolytic activity, CTAB agar plate, drop collapse assay, oil displacement test and emulsification index E24%. Both Bacillus cereus ISU-02 strain and Enterobacter aerogenes B19 strain have reduced the interfacial tension to 27.61 and 28.93, respectively. Biosurfactants produced from both isolates were tested for oil recovery using spontaneous imbibition process. Bacillus cereus ISU-02 strain gave the highest oil recovery of 66.9% for rock permeability of 843 mD, followed by Enterobacter aerogenes B19 strain with oil recovery of 34% for rock permeability 197 mD, while the lowest rate of oil recovery was 12.1% for FW with permeability of 770 mD. An additional oil rate reached to 7.9% has been recovered from the residual oil when the core plug that was treated with formation water alone was retreated with the cell free biosurfactant supernatant. Use of the new biosurfactants has improved oil recovery better than use of formation water alone or formation water with the commercial surfactant SDS.
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Introduction
In most of oil fields, only a small portion of crude oil can be recovered by traditional recovery methods. After the primary and secondary recovery, up to 66% of oil stays caught in the reservoir rocks (Nnaemeka et al. 2018). Water flooding is the most important technique in the secondary recovery stage. This technique includes injecting water in hydrocarbon-bearing zones through a series of injection wells to sweep the trapped oil toward producing wells (Nikzad Amoli 2011). Enhanced oil recovery (EOR) techniques are used to recover the residual oil from reservoir rocks after the primary or secondary stages. One of EOR methods is injection of surfactants with water to improve the sweep efficiency of water flooding technique (Sheng 2010). Many commercial cationic surfactants were able to recover 50–90% of oil (Standnes and Austad 2003 and Strand et al. 2003). Surfactants play an active role in enhanced spontaneous imbibition in oil reservoirs. The surfactant decreases the oil–water interfacial tension and oil–rock surface tension, as well as it may alter the rock wettability to be water-wet through its interaction with rock surface compounds (Austad et al. 2018; Xiao et al. 2016; Pal et al. 2018). But these surfactants are usually harmful to the environment and costly (Abouseoud et al. 2008). Under certain circumstances, bacteria are able to grow under aerobic and anaerobic conditions and saline within oil reservoirs and can be induced to produce biosurfactants which adsorbed on the rock surface and change the reservoir to nearly water-wet (Golabi et al. 2009). The biosurfactants that produced by microorganisms diminish the capillary forces that impede the movement of oil through the pores of rock by reducing oil-rock surface tension. Besides aid in the breakdown of the oil film in the rock by emulsification by dissolving oil with water by emulsification (Al-Bahry et al. 2013). The process by which the use of microorganisms in oil reservoirs to enhanced recovery of the residual oil called microbial enhanced oil recovery (MEOR) (Rashdi et al. 2012). The prime objective of the present study was to isolate indigenous bacteria from produced water. The isolated bacteria were tested to produce biosurfactants which have been used to enhance oil recovery by a spontaneous imbibition process.
Materials and method
Sample collection
Bacterial strains used in this study were isolated from produced water of Al-Rafidiya oil field (Zubair 2 oil field), Basra, in south of Iraq 30.16°N 47.42°E as. All formation-water samples were collected from the stock tank after the separator. Data of physical and chemical properties of the water samples were collected from the daily production reports. All samples were transported from the field to our laboratory in an ice bag under temperature of 4 °C.
Stimulation of indigenous microorganism
To stimulate indigenous microorganisms, 5 ml of produced water was added to Erlenmeyer flask size 250 ml containing 95 ml of mineral estimated media (MSM) composed of 2% of crude oil as a carbon source, 1 g/L KH2PO4, 6 g/L NaNO3, 1 g/L K2HPO4, 0.02 g/L FeSO4, 0.5 g/L MgSO4 and 0.02 g/L Na2MoO4 at a pH of 7.0–7.2 at a pH of 7.0–7.2 (Zhao et al. 2017). Then the mixture was shaken at 180 r.p.m and 35 °C for 48 h using shaker incubator. Volume of 1 ml of the suspension was diluted serially and plated in triplicate on nutrient agar and MacCkonkey agar. The plates were incubated at 35 °C, and streaks were isolated again on nutrient agar to obtain pure isolates. These isolates were kept on nutrient agar slants.
Identification of bacterial isolates
Morphological characterization
Pure isolated colonies that have grown on the nutrient agar plates were examined and recorded as colony morphological characteristics. Bacterial shape and gram stain recorded for all isolates.
Molecular identification
Genomic DNA was extracted from culture by using a commercial kit protocol (Promega Genomic DNA Purification Kit, USA). 16S rRNA genes were amplified using polymerase chain reaction (PCR) was carried out the universal specific primer (27FAGAGTTTGATCMTGGCT-CAG) and (1492RTACGGYTACCTTGTTACGACTT) PCR mixture contained 5 μl of DNA, 2 μl of each primers solution, master mix 25 μl and 16 μl nuclease-free water. Amplification was carried out with thermal cycle machine after initial denaturation for 3 min at 95 °C, and 30 cycles were performed, with each cycle consisting of 20 s at 95 °C, 20 s at 55 °C and 30 min at 72 °C. Cycling was completed by a final elongation step at 72 °C for 5 min (Gittel et al. 2009). Approximately 1500-bp 16S rDNA of each isolates was purified and sequenced at Yang ling tianrun aoke biotechnology company laboratories/China. The bacterial 16S rDNA obtained sequencing was then aligned with known 16S rDNA sequences Gen bank using the Basic Local Alignment Search Tool (BLAST) at the National Center for Biotechnology Information (NCBI).
Screening of biosurfactant-producing bacteria
The selected strains were inoculated for 48 h in mineral salt media (MNS) for screening of biosurfactant production (Tabatabaee et al. 2005). The medium has following composition: glucose; 20 g as a carbon source, K2 HPO4; 5 g, KH2 PO4; 20 g, NaCl; 0.1 g, MnSO4·7H2 O; 0.22 g, (NH4)2 SO4; 30 g, FeSO4·7H2O;0.01 g, CaCl2·2H2O;0.02 g, MgSO4·7H2O; 0.2 g, and distilled water up to 1000 ml adding 1 mL of trace element stock solution which composed of (g/L): FeCl3.6H2O ZnSO4.7H2 O 0.75, CoCl2.6H2O 0.08, CuSO4.5H2O 0.075, MnSO4.H2O 0.75, H3 BO3 0.15, Na2 MoO4.2H2 O 0.05. The pH of medium was maintained at 7–7.2. Erlenmeyer flask was inoculated with 2% inoculum and incubated at 37 °C in shaker at180 rpm for 72 h. The culture was centrifuged at 12,000 rpm for 30 min, and the cell-free supernatant (CFS) was used for detection of biosurfactant production.
Investigation of biosurfactant production
Surface tension
Surface tension was determined using Tensiometer (sigma 700/Sweden) by ring method on 125 ml of each bacterial supernatant at room temperature. The results were compared to sterile medium as negative control (Rosli Wan Sulaiman and Soo Lee 2012).
Foaming activity
Foaming activity is detected as length of froth stability and foam form by shaking vigorously the supernatant 10 ml for 2 min, the foaming formation was calculated according to the following equation (El-Sheshtawy 2012).
Hemolytic activity
All of the isolated strains were tested for hemolytic activity using human blood agar plate incubated for 24 h at 37 °C to as-say hemolytic activity. The plates were then observed for the presence of clear zone around the colonies indicating biosurfactant production (Carrillo et al. 1996; Bicca et al. 1999).
CTAB agar plate method
Detection of crude biosurfactant
CTAB agar plate strategy is a semiquantitative assay for the identification of anionic surfactants (Thavasi et al. 2011). Blue agar plates contain cetyltrimethylammonium bromide (CTAB 0.2 mg/ml), methylene blue (MB 0.5 mg/100 ml, basic dye) and glucose (2% v/v). Pits were made in CTAB agar medium using a sterile cork borer and filled with 50 μL of the culture supernatant. Anionic biosurfactants were observed by the formation of dark blue halos around the pit (Cooper and Goldenberg 1987).
Detection of isolate colony
Cetyltrimethylammonium bromide (CTAB)–methylene blue agar was prepared by adding 0.2 g CTAB, 0.005 g methylene blue and 15 g agar to 1 L mineral salts medium. Agar plates contained 20 ml medium inoculate with single colony incubated at 30 °C for 24 h. Biosurfactants production was observed by the formation of dark blue halos around the colony (Siegmund and Wagner 1991).
Drop collapse assay
Biosurfactant decreases the surface tension between water and hydrophobic surfaces such as parafilm, the ability to collapse a droplet of water was tested by pipetted 25 μl of extracted biosurfactant as a droplet onto parafilm, and over seconds or minutes the flattening and the spreading of the droplet on the parafilm surface were followed. No influence on the shape of the droplets dye (methylene blue) was added to the water spot for photographic purposes. The droplet was allowed to dry, and the diameter of the dried droplet was recorded by ruler (Kuiper et al. 2004; Tugrul and Cansunar 2005).
Oil displacement methods
Oil spreading test was performed and described by Morikawa et al. (2000). In this method, 20 ml of distilled water was added to a Petri dish (15 cm of diameter) followed by addition of 20 μl of crude oil dropped on the water surface to form a film covering the entire water surface area. Ten microliters of cell free broth culture was then added to the oil surface. The oil will be displaced with an oil-free clearing zone, and diameter of this clearing zone indicates the presence of biosurfactant in the cell-free culture broth. The net area diameters and the oil displacement areas involved were measured to compare the efficacy of the biosurfactant.
Emulsification index test E24
The emulsification index (E24) was measured using the method described by Płaza et al. (2006). A mixture of 2 ml of each cell-free supernatant of all selected strains was taken in separate test tubes with 2 ml of (crude oil, olive oil, engine oil, fraying oil). The mixtures were vortexed for 2 min and left at room temperature for 24 h. The percentage of E24 index was calculated by the given equation: (Barakat et al. 2017; Bento et al. 2005).
Extraction of biosurfactant
Bacterial cells were removed from surfactant-containing medium by centrifugation at 9000 rpm, 20 min, 4 ◦C. The supernatant was subjected to acid precipitation by adding 6 N HCl to achieve a final pH of 2.0 and allowing a precipitate to form at 4 °C. The cell free supernatant was treated with equal amount of ethyl acetate (1: 1) with good stirring and left to separate the organic phase and then filtered with the aid of a rotary evaporator under vacuum. The dark yellow viscous product was collected and evaporated at 40 °C (George and Jayachandran 2008).
Imbibition experiment of enhanced oil recovery
The two produced biosurfactants of this study have been tested for enhanced oil recovery usage. Core imbibition experiments were conducted on core plugs from Zubair oil field, south of Iraq.
Properties of core plugs
Eight core plugs of sandstone rock have been used in this test. The core plugs were supplied by Basra Oil Company (BOC) from Zubair oil field. The plugs have been cleaned, and then porosity and permeability have been measured at laboratories of BOC. General petrophysical properties of the core plugs are indicated in Table 1.
Properties of crude oil and formation water
Tables 2 and 3 show properties of crude oil and produced water of Al-Rafidiya oil field, respectively.
Saturating cores with crude oil
First, the core plugs were dried in a hot air oven at 65 °C for 24 h and mass of each dray core was measured using a sensitive balance. Figure 1a shows the dry cores. Second, the cores were saturated with crude oil using vacuum pump desiccator as shown in Fig. 1b. Mass of each saturated core was measured. Figure 1c shows cores saturated with crude oil. Mass of original oil in place and oil saturation percentage were calculated as follows:
a Core plugs after drying. b Saturating core plugs with crude oil. c Cores after saturation
where OOIP = mass of original oil in place, g; SOV = volume of original oil in place, g; TPV = total pore volume, cm3; CV = bulk volume of the core, cm3; OSP = oil saturation percentage.
EOR experiments using imbibition process
The produced free cell supernatant biosurfactant (F.C.S.B.sr.), crude extracted biosurfactant (Cr.B.sr) and free cell supernatant bioemulsifier (F.C.S.B.em.) have been tested for EOR application. Effectiveness of using the new biosurfactants, bioemulsifier, formation water (FW) and the commercial surfactant sodium dodecyl sulfate (SDS) for oil recovery has been compared. Ten of imbibition experiments have been conducted. Table 4 shows recovery liquids and properties of cores used in these experiments. The imbibition experiments included immersing each of the core plugs saturated with oil in a cylinder filled with the recovery liquid for fourteen days at 40° C. Then the recovered oil has been extracted from the recovery liquid using hexane (Qazi et al. 2013). The core samples 224 and 227 have been subjected to two imbibition processes sequentially. The first one included immersing each of both plugs in FW and then immersing in F.C.S.B.em to observe if any extra oil can be recovered by F.C.S.B.em after the primary recovery by FW.
Results and discussion
Isolation and identification of selected strains
The phenotypic characteristics of cells and colonies are shown in Fig. 2 . The results of molecular approach depended on 16S rRNA studies of organisms showed 100% similarities with Enterobacter aerogenes B19 strain and 99% Bacillus cereus ISU-02 strain for, respectively, in Nucleotide database of National Center for Biotechnological Information (NCBI) (Table 5).
(a cells–c colonies) Enterobacter aerogenes strain B19 and (b cells–d colonies) Bacillus cereus strain ISU-02
Zafra et al. (2014) isolated Enterobacter aerogenes with potential for polycyclic aromatic hydrocarbons (PAHs) biodegradation from heavy crude oil-contaminated soil.
Screening of biosrfactant activity
Table 6 shows the susceptibility of selected isolates tested for biosurfactant production and their effectiveness through different screening methods.
The interfacial surface tension
The results showed ability of the two isolates Bacillus cereus strain ISU-02 and Enterobacter aerogenes B19 strain to reduce surface tension to 27.61 and 28.9383, respectively. These results seem similar to results that obtained for surfactin which reduced surface tension of water to 25 mN (Cooper et al. 1981), and rhamnolipids which decreased surface tension of water to 26 mN (Syldatk et al. 1985). The interfacial surface tension plays an important role in oil recovery and bioremediation of heavy crude oil (Volkering et al. 1998).
Foaming activity
Both isolates showed high foaming ability when growing on the nutrient medium stability for more than 2 days (Fig. 3). This is a good test to examine the production of biosurfactant as noted researchers Meenal and Madhura (2016).
Foaming activity of different strains comparing with control
Hemolytic activity
Both selected isolates showed excellent in hemolysis activity as shown in Fig. 4. Biosurfactants have amphiphilic in nature which can partition into the phospholipid membrane RBC (Almansoory et al. 2014).
Hemolytic activity of different strains: a Enterobacter aerogenes strain B19 and b Bacillus cereus strain ISU-02
CTAP methods
This methods use for detection of extracellular glycolipids or other anionic surfactants (Sabnis and Juvale 2016). Enterobacter aerogenes B19 strain showed positive results due to formation of dark blue halos around the pit and colony (Fig. 5), while the Bacillus cereus ISU-02 strain gave a negative result.
CTAB agar plate method of different strains: a crude biosurfactant and b isolate colony
Drop-collapse test
The two selected strains showed a positive as shown in Fig. 6. The supernatant droplets containing the biosurfactant spread or even collapse due to reduced force or tension between the liquid surfaces and the hydrophobic surface (Walter et al. 2010), while the distilled water as a negative control remains stable on the surface because the polar water molecules are repulsed from the hydrophobic surface (Sari et al. 2014).
Drop collapse test a different strains comparing with control, b 49 and 36 isolates, c after drying
Oil displacement
The cell-free supernatant of the two selected isolates caused oil spreading as a clear zone on surface oil layer indicating the presence of biosurfactant. A larger diameter of clear zone represents the higher activity of the testing solution (Rodrigues et al. 2006). Enterobacter aerogenes B19 strain showed a zone of displacement diameter 7.6 cm while displacement had observed by Bacillus cereus ISU-02 strain 8.4 cm as shown in Fig. 7.
Oil displacement test a −36, b −49
Emulsification index test E24
Enterobacter aerogenes B19 strain showed the most emulsification activity in all oils tested more than Bacillus cereus ISU-02 strain (Fig. 8 and Table 7) indicating that fraying and crude oil were the most emulsifying. Aniyanwu et al. (2011) revealed that the capacity of a biosurfactant to emulsify hydrocarbon–water blend has been observed to improve the biodegradation of the hydrocarbons and is possibly helpful in improved oil recovery.
Emulsification activity test with different oils left tube −49, right −36
Effect of biosurfactant and bioemulsifier on oil recovery
Figure 9 shows experiments of oil recovery by imbibition process. Table 8 shows results of oil recovery using the imbibition experiments. It can be observed that F.C.S.B.sr gave the highest oil recovery of 66.9% with core permeability of 843 mD, followed by F.C.S.B.em with oil recovery of 34% for core permeability 197 mD, while the lowest rate of oil recovery was 12.1% for FW with permeability of 770 mD. Rate of oil recovery by FW + SDS was 13.6% for core permeability of 210 mD. Results of the present study are in the range of results obtained by other researchers in previous studies (Bordoloi et al. (2008) and Suthar et al. (2008)).
a and b Imbibition experiments with different liquids. c Oil flow from surface of cores. d Rise of oil above the liquid surface. e Repeated treatment core 224 with F.C.S.B.sr after FW
The most important factors affecting oil recovery in the present experiments are the interfacial tensions and core permeability. Reduction in the interfacial tension and increase in the permeability result in increase in oil recovery. Figure 10a–b show effect of permeability, and Fig. 10 shows effect of the interfacial tension (Fig. 11).
a Oil recovery with different liquids. b Oil recovery by the F.C.S.B.Sr. after treated with producing water
Effect of surface tension on oil recovery
Although permeability of the core that was treated with F.C.S.B.em is less than core treated with the commercial surfactant SDS, F.C.S.B.em was more efficient than SDS for oil recovery. The results also showed that additional oil recovery rates have been obtained from the core plugs that were treated with the FW and retreated with the biosurfactants (Runs 6 and 10 in Table 8) which indicates that the biosurfactants in the second imbibition process have increased oil recovery. Increment in oil recovery was a result of reducing the interfacial tension. Observation matches with conclusions of previous studies (Gudiña et al. 2012; Al-Sulaimani et al. 2012; Zhao et al. 2017).
The experiment was conducted for all liquids in fixed conditions such as temperature, time and quantity regardless of other conditions that could hinder the imbibition process. For example, formation of asphaltene aggregates might be responsible for limiting the liquid flow and leading to impede the flow through the channel as mentioned by Mozaffari et al. (2017).
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Hamzah, A.F., Al-Mossawy, M.I., Al-Tamimi, W.H. et al. Enhancing the spontaneous imbibition process using biosurfactants produced from bacteria isolated from Al-Rafidiya oil field for improved oil recovery. J Petrol Explor Prod Technol 10, 3767–3777 (2020). https://doi.org/10.1007/s13202-020-00874-9
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DOI: https://doi.org/10.1007/s13202-020-00874-9