scholarly journals Modifikasi SLS dengan epoksida dari asam oleat dan hidrogen peroksida untuk meningkatkan kualitas surfaktan pada EOR

2018 ◽  
Vol 10 (3) ◽  
pp. 141
Author(s):  
Chitra Ria Ariska ◽  
Suryo Purwono ◽  
Bardi Murachman
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Chemical Compounds ◽  
Peroxyacetic Acid ◽  
Temperature Ratio ◽  
Aqueous Hydrogen Peroxide ◽  
The Stability ◽  
Ultralow Ift ◽  
Excellent Stability

SLS modification using epoxyde from oleat acid and hydrogen peroxyde to improve the quality of surfactant in EORSurfactant is one of the compounds used in Enhanced Oil Recovery (EOR) which function is to enhance the oil production. One of the surfactants widely used is Sodium Ligno Sulfonat (SLS) due to its high degradability. However the modification with another compound is still needed in orderto decrease its Inter Facial Tension (IFT) until reach the ultralow IFT(±10-3 mN/m). One of the chemical compounds used to modify the surfactant is epoxidebecause it has reactive oxirane ring. The addition of oleic epoxide will increase solubility of surfactant in oil so it brings more stable microemulsion. Epoxidation of oleic acid was carried out with peroxyacetic acid that was generated insitu from aqueous hydrogen peroxide and glacial acetic acid. The modification of SLS was then done by adding the epoxide in various conversion resulted from epoxidation. The experiment was investigated at temperature, ratio of epoxide to SLS and reaction time of 70oC, 1:2 and 1 hour, respectively. The modified product were then measured their IFTat temperature of 30-60oC and tested the stability of microemulsion based on time of formation of microemulsion up back in its original state. The present study revealed that epoxides has capability to decrease IFT. The results of experiment shows that the lowest IFT is modification of epoxide with the conversion of 10% as 3,7 x10-3 mN/m and has most excellent stability with time 113 minutes.Keywords: epoxide, Sodium Ligno Sulfonat (SLS), microemulsion, surfactant, EOR AbstrakSurfaktan adalah salah satu bahan kimia yang digunakan dalam Enhanced Oil Recovery (EOR) untuk meningkatkan produksi minyak. Salah satu jenis surfaktan yang banyak digunakan adalah Sodium Ligno Sulfonat (SLS) karena mudah didegradasi limbahnya. Namun modifikasi dengan senyawa lain masih perlu dilakukan untuk menurunkan tegangan antarmuka atau Inter Facial Tension (IFT) hingga mencapai ultralow IFT (±10-3 mN/m). Salah satu bahan kimia yang dapat digunakan untuk modifikasi surfaktan adalah epoksida karena memiliki cincin oksiren yang reaktif. Penambahan epoksi oleat ini akan meningkatkan kelarutan surfaktan dalam minyak sehingga didapatkan mikroemulsi yang lebih stabil. Modifikasi SLS dibuat dengan menambahkan epoksida dengan variasi konversi yang dihasilkan dari proses epoksidasi. Percobaan dilakukan pada temperatur 70oC, rasio perbandingan epoksida:SLS adalah 1:2 dengan waktu reaksi 1 jam. IFT produk modifikasi diukur pada temperatur 30-60oC dan diuji kestabilan mikroemulsinya berdasarkan waktu pembentukan mikroemulsi sampai kembali pada keadaan semula. Dari penelitian didapatkan bahwa epoksida dapat menurunkan IFT. IFT paling rendah dihasilkan dari modifikasi epoksida dengan konversi 10%, yaitu 3,7 x10-3 mN/m dan memiliki kestabilan paling baik dengan waktu emulsi 113 menit.Kata kunci: epoksida, Sodium Ligno Sulfonat (SLS), mikroemulsi, surfaktan, EOR

scholarly journals The Demulsification Properties of Cationic Hyperbranched Polyamidoamines for Polymer Flooding Emulsions and Microemulsions

Processes ◽  
2020 ◽  
Vol 8 (2) ◽  
pp. 176 ◽  
Author(s):  
Yangang Bi ◽  
Zhi Tan ◽  
Liang Wang ◽  
Wusong Li ◽  
Congcong Liu ◽  
...  
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Polymer Flooding ◽  
Oil Removal ◽  
Tertiary Oil Recovery ◽  
Oil Concentration ◽  
Ft Ir ◽  
The Stability ◽  
Excellent Stability ◽  
Demulsification Efficiency

Polymer flooding emulsions and microemulsions caused by tertiary oil recovery technologies are harmful to the environment due to their excellent stability. Two cationic hyperbranched polyamidoamines (H-PAMAM), named as H-PAMAM-HA and H-PAMAM-ETA, were obtained by changing the terminal denotation agents to H-PAMAM, which was characterized by 1H NMR, FT-IR, and amine possession, thereby confirmed the modification. Samples (300 mg/L) were added to the polymer flooding emulsion (1500 mg/L oil concentration) at 30 °C for 30 min and the H-PAMAM-HA and H-PAMAM-ETA were shown to perform at 88% and 91% deoil efficiency. Additionally, the increased settling time and the raised temperature enhanced performance. For example, an oil removal ratio of 97.7% was observed after dealing with the emulsion for 30 min at 60 °C, while 98.5% deoil efficiency was obtained after 90 min at 45 °C for the 300 mg/L H-PAMAM-ETA. To determine the differences when dealing with the emulsion, the interfacial tension, ζ potential, and turbidity measurements were fully estimated. Moreover, diametrically different demulsification mechanisms were found when the samples were utilized to treat the microemulsion. The modified demulsifiers showed excellent demulsification efficiency via their obvious electroneutralization and bridge functions, while the H-PAMAM appeared to enhance the stability of the microemulsion.

Testing the Stability of Mixed CO2/N2-Foam Using New Fluorosurfactant for Enhanced Oil Recovery

2015 ◽  
Author(s):  
Mohammed Abdul Qadeer Siddiqui ◽  
Rahul N. Gajbhiye ◽  
Abdullah S. Sultan ◽  
Sidqi Abu-Khamsin
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
The Stability

Evaluation of foam performance at different temperature for enhanced oil recovery process

2019 ◽  
Vol 16 (3) ◽  
pp. 412-418 ◽  
Author(s):  
Nurul Suhana Abd Rahim ◽  
Ismail Mohd Saaid ◽  
Abubakar Abubakar Umar
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Foam Stability ◽  
Recovery Process ◽  
Effect Of Temperature ◽  
Content Type ◽  
Different Temperatures ◽  
Foam Film ◽  
The Stability

Purpose Application of foam in enhanced oil recovery requires a production of foam that is strong and stable enough to withstand a long period. There are numerous factors that may affect the performance of foam, among which is temperature. Therefore, this study aims to observe the foam performance at different temperature by evaluating the foamability and the stability of the foam. Design/methodology/approach In this study, bulk foam test using FoamScan was conducted to examine the effect of temperature on foam in the presence of crude oil. Nitrogen gas was sparged through the mixture of crude oil, an in-house developed surfactant, and sodium chloride solution as the brine at different temperatures to produce foam at a certain height. The crude oil was extracted from an oilfield in East Malaysia and the in-house developed surfactant was a mixture of amphoteric and anionic surfactants. A camera continuously recorded the height of foam during the generation and the collapse of the foam. The foamability and foam stability properties of each sample were taken as the indicators for foam performance. Furthermore, the entering, spreading and bridging analysis was run to observe the effect of the presence of crude oil on foam performance. Findings In general, the higher the temperature, the less stable the foam is. As the stability of foam is associated with the rate of liquid drainage, it was observed that as temperature increases, the rate of liquid drainage also increases. On the other hand, the entering, spreading and bridging analysis shows that there is entering of oil droplet happening on the interface of foam film that may promote the rupture of the foam film even more. Originality/value It was found that the temperature has a small impact on foamability, whereas the foam stability was significantly affected by the temperature. Therefore, it can be concluded that foamability is not necessarily interrelated to foam stability, contradicting to the findings of few authors.

scholarly journals Laboratory Analysis of Foam Generating Surfactants and Their Thermal Stability for Enhanced Oil Recovery Application

2020 ◽  
Vol 39 (2) ◽  
Author(s):  
Muhammad Khan Memon ◽  
Ubedullah Ansari ◽  
Habib U Zaman Memon
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Foam Stability ◽  
Sodium Dodecyl ◽  
Life Time ◽  
Alpha Olefin Sulfonate ◽  
Alpha Olefin ◽  
Secondary Oil Recovery ◽  
The Stability ◽  
Brine Salinity

The residual oil after primary or secondary oil recovery can be recovered by the methods of EOR (Enhanced Oil Recovery). The objective of this study is screening the surfactants that generate maximum stable foam in the presence of brine salinity at 92oC. Laboratory experiments have been performed to examine and compare the stability of generated foam by individual and blended surfactants in the synthetic brine water. AOS C14-16 (Alpha Olefin Sulfonate) and SDS (Sodium Dodecyl Sulfonate) were selected as main surfactants. Aqueous stability test of AOS C14-16 and SDS with brine water salinity 62070ppm was performed at 92oC. AAS (Alcohol Alkoxy Sulfate) was blended with SDS and AOS C14-16. The solution was stable in the presence of brine salinity at same conditions. Salt tolerance experimental study revealed that AOS C14-16 did not produce precipitates at 92oC. Further, the foam stability of surfactant blend was performed. Result shows that, the maximum life time of generated foam was observed by using blend of 0.2wt% SDS+0.2wt% AOS+0.2wt% AS-1246 and 0.2wt% AOS+0.2wt% IOSC15-18+0.2wt% AAS surfactants as compared to the foam generated by individual surfactants. The success of generated foam by these surfactant solutions in the presence of brine water is the primary screening of surfactant stability and foamability for EOR applications in reservoirs type of reservoirs.

scholarly journals Water treatment technology performance for chemical enhanced oil recovery: modeling, simulation and optimization

2021 ◽  
Vol 11 (9) ◽  
Author(s):  
Mahdi Chemil ◽  
Zahia Zizi ◽  
Nadjib Drouiche ◽  
Mohamed Khodja ◽  
Moundher Hadji
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Hardness ◽  
Rejection Rate ◽  
Operating Conditions ◽  
Total Hardness ◽  
Treatment Technology ◽  
Adequate Treatment ◽  
Simulation And Optimization

AbstractThe use of ASP (alkali–surfactant–polymer) slug could be affected by the use of high hardness water, especially when injecting an alkaline agent (Na2CO3). The injection water quality of the TFT field is not adequate for cEOR (chemical enhanced oil recovery), because it contains a high hardness rate up to 160°f (report DC R&D 2019). With a TDS rate varying between 4 and 6 g/l, it could cause a formation of insoluble complexes with alkaline agents, and on the other hand, the decrease in the performances of the injected surfactants and polymers. In this work, a simulation study was carried out in order to identify the most adequate treatment process between NF (nanofiltration) and RO (reverse osmoses). The performance of the 4040 type membrane modules has been tested under different operating conditions of temperature and feed pressure (25°–45°) and (3.1–22 bar), respectively. Several membrane configurations (6:0, 4:2) have been tested to determine their effect on the process’ performance. The results showed that the NF90 4040 presents the best performances toward the requirements of the cEOR. Furthermore, the membrane configuration effects the quality of permeate and recovery rate. The results showed a rejection rate of 90% and 95%, respectively, for the total hardness (Ca2+ and Mg2+) and the sulfate.

scholarly journals Investigation of Stability of CO2 Microbubbles—Colloidal Gas Aphrons for Enhanced Oil Recovery Using Definitive Screening Design

2020 ◽  
Vol 4 (2) ◽  
pp. 26
Author(s):  
Nam Nguyen Hai Le ◽  
Yuichi Sugai ◽  
Kyuro Sasaki
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Xanthan Gum ◽  
Polymer Concentration ◽  
Sodium Dodecyl ◽  
Screening Design ◽  
Stirring Rate ◽  
Definitive Screening ◽  
The Stability ◽  
Definitive Screening Design

CO2 microbubbles have recently been used in enhanced oil recovery for blocking the high permeability zone in heterogeneous reservoirs. Microbubbles are colloidal gas aphrons stabilized by thick shells of polymer and surfactant. The stability of CO2 microbubbles plays an important role in improving the performance of enhanced oil recovery. In this study, a new class of design of experiment (DOE)—definitive screening design (DSD) was employed to investigate the effect of five quantitative parameters: xanthan gum polymer concentration, sodium dodecyl sulfate surfactant concentration, salinity, stirring time, and stirring rate. This is a three-level design that required only 11 experimental runs. The results suggest that DSD successfully evaluated how various parameters contribute to CO2 microbubble stability. The definitive screening design revealed a polynomial regression model has ability to estimate the main effect factor, two-factor interactions and pure-quadratic effect of factors with high determination coefficients for its smaller number of experiments compared to traditional design of experiment approach. The experimental results showed that the stability depend primarily on xanthan gum polymer concentration. It was also found that the stability of CO2 microbubbles increases at a higher sodium dodecyl sulfate surfactant concentration and stirring rate, but decreases with increasing salinity. In addition, several interactions are presented to be significant including the polymer–salinity interaction, surfactant–salinity interaction and stirring rate–salinity interaction.

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