scholarly journals Application Potential Analysis of Enhanced Oil Recovery by Biopolymer-Producing Bacteria and Biosurfactant-Producing Bacteria Compound Flooding

2019 ◽  
Vol 9 (23) ◽  
pp. 5119
Author(s):  
Yongqiang Bi ◽  
Jianlong Xiu ◽  
Ting Ma
Keyword(s):  
Oil Recovery ◽  
Laboratory Experiments ◽  
Fermentation Broth ◽  
Enterobacter Cloacae ◽  
Core Flooding ◽  
Heterogeneous Reservoirs ◽  
The Core ◽  
Profile Control ◽  
Application Potential ◽  
Degradation Medium

To study the feasibility of polymer-producing bacteria Enterobacter cloacae (E. cloacae) FY-07 and surfactant-producing bacteria Pseudomonas aeruginosa WJ-1 combined profile control and flooding, the compatibility of FY-07 and WJ-1 was evaluated using laboratory experiments. The results showed that the growth and metabolism of WJ-1 was not significantly affected by the FY-07 in the degradation medium, and the surface tension of fermentation broth was reduced from 70 mN/m to 30 mN/m. FY-07 enhanced the degradation of WJ-1, increasing the ratio of C14- to C15+ from 0.37 to 0.67. The core-flooding experiments indicated the oil recovery of 17.4% when both FY-07 and WJ-1 were injected into the system, as against to 10.4% and 7.9% for FY-07 and WJ-1, respectively, when injected alone. The results demonstrate a good compatibility between the FY-07 and WJ-1 strains and highlight the application potential of stain FY-07 and strain WJ-1 compound flooding for enhancing the oil recovery in heterogeneous reservoirs.

scholarly journals Modification of Xanthan Gum for a High-Temperature and High-Salinity Reservoir

Polymers ◽  
2021 ◽  
Vol 13 (23) ◽  
pp. 4212
Author(s):  
Mohamed Said ◽  
Bashirul Haq ◽  
Dhafer Al Shehri ◽  
Mohammad Mizanur Rahman ◽  
Nasiru Salahu Muhammed ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
Xanthan Gum ◽  
Elevated Temperatures ◽  
High Salinity ◽  
Residual Oil ◽  
Core Flooding ◽  
Nacl Solution ◽  
The Core ◽  
Tertiary Oil Recovery

Tertiary oil recovery, commonly known as enhanced oil recovery (EOR), is performed when secondary recovery is no longer economically viable. Polymer flooding is one of the EOR methods that improves the viscosity of injected water and boosts oil recovery. Xanthan gum is a relatively cheap biopolymer and is suitable for oil recovery at limited temperatures and salinities. This work aims to modify xanthan gum to improve its viscosity for high-temperature and high-salinity reservoirs. The xanthan gum was reacted with acrylic acid in the presence of a catalyst in order to form xanthan acrylate. The chemical structure of the xanthan acrylate was verified by FT-IR and NMR analysis. The discovery hybrid rheometer (DHR) confirmed that the viscosity of the modified xanthan gum was improved at elevated temperatures, which was reflected in the core flood experiment. Two core flooding experiments were conducted using six-inch sandstone core plugs and Arabian light crude oil. The first formulation—the xanthan gum with 3% NaCl solution—recovered 14% of the residual oil from the core. In contrast, the modified xanthan gum with 3% NaCl solution recovered about 19% of the residual oil, which was 5% higher than the original xanthan gum. The xanthan gum acrylate is therefore more effective at boosting tertiary oil recovery in the sandstone core.

scholarly journals Enhanced oil recovery ability of branched preformed particle gel in heterogeneous reservoirs

2018 ◽  
Vol 73 ◽  
pp. 65 ◽  
Author(s):  
Long Yu ◽  
Qian Sang ◽  
Mingzhe Dong
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Water Flooding ◽  
Low Permeability ◽  
High Permeability ◽  
Sweep Efficiency ◽  
Reservoir Heterogeneity ◽  
Heterogeneous Reservoirs ◽  
Preformed Particle Gel ◽  
Profile Control

Reservoir heterogeneity is the main cause of high water production and low oil recovery in oilfields. Extreme heterogeneity results in a serious fingering phenomenon of the displacing fluid in high permeability channels. To enhance total oil recovery, the selective plugging of high permeability zones and the resulting improvement of sweep efficiency of the displacing fluids in low permeability areas are important. Recently, a Branched Preformed Particle Gel (B-PPG) was developed to improve reservoir heterogeneity and enhance oil recovery. In this work, conformance control performance and Enhanced Oil Recovery (EOR) ability of B-PPG in heterogeneous reservoirs were systematically investigated, using heterogeneous dual sandpack flooding experiments. The results show that B-PPG can effectively plug the high permeability sandpacks and cause displacing fluid to divert to the low permeability sandpacks. The water injection profile could be significantly improved by B-PPG treatment. B-PPG exhibits good performance in profile control when the high/low permeability ratio of the heterogeneous dual sandpacks is less than 7 and the injected B-PPG slug size is between 0.25 and 1.0 PV. The oil recovery increment enhanced by B-PPG after initial water flooding increases with the increase in temperature, sandpack heterogeneity and injected B-PPG slug size, and it decreases slightly with the increase of simulated formation brine salinity. Choosing an appropriate B-PPG concentration is important for B-PPG treatments in oilfield applications. B-PPG is an efficient flow diversion agent, it can significantly increase sweep efficiency of displacing fluid in low permeability areas, which is beneficial to enhanced oil recovery in heterogeneous reservoirs.

A Laboratory Study of Coinjection of Water and CO2 to Improve Oil Recovery and CO2 Storage: Effect of Fraction of CO2 Injected

SPE Journal ◽  
2020 ◽  
pp. 1-9
Author(s):  
Emmanuel Ajoma ◽  
Thanarat Sungkachart ◽  
Saria ◽  
Hang Yin ◽  
Furqan Le-Hussain
Keyword(s):  
Oil Recovery ◽  
Laboratory Experiments ◽  
Water Pressure ◽  
Co2 Storage ◽  
Water Injection ◽  
Molar Fraction ◽  
Co2 Injection ◽  
The Core ◽  
Carbon Dioxide Co2 ◽  
Water Saturated

Summary To determine the effect on oil recovery and carbon dioxide (CO2) storage, laboratory experiments are run with various fractions of CO2 injected (FCI): pure CO2 injection (FCI = 1), water-saturated CO2 (wsCO2) injection (FCI = 0.993), simultaneous water and gas (SWAG) (CO2) injection (FCI = 0.75), carbonated water injection (CWI) (FCI = 0.007), and water injection (FCI = 0). All experiments are performed on Bentheimer sandstone cores at 70°C and 11.7 MPa (1,700 psia). The oil phase is composed of 65% hexane and 35% decane by molar fraction. Before any fluid is injected, the core is filled with oil and irreducible water. Pressure difference across the core and production rate of gas are measured during the experiment. The collected produced fluids are analyzed in a gas chromatograph to determine their composition. Cumulative oil recovery after injection is found to be 78 to 83% for wsCO2, 78% for SWAG, 74% for pure CO2, 53% for CWI, and 35% for water. Net CO2 stored is also found to be the highest for wsCO2 (59 to 65% of the pore volume), followed by that for CO2 injection (56%) and that for SWAG (42%). These results suggest that wsCO2 injection might outperform pure CO2 injection at both oil recovery and net CO2stored.

Evaluation and Application of Endogenous Microorganism Activator in Reservoir after Chemical Flooding

2014 ◽  
Vol 1051 ◽  
pp. 404-409
Author(s):  
Jian Jun Le ◽  
Ji Yuan Zhang ◽  
Lu Lu Bai ◽  
Rui Wang ◽  
Zhao Wei Hou ◽  
...  
Keyword(s):  
Electron Microscopy ◽  
High Pressure ◽  
Oil Recovery ◽  
Physical Simulation ◽  
Chemical Flooding ◽  
Core Flooding ◽  
Simulation Experiments ◽  
The Core ◽  
Enhance Oil Recovery ◽  
Growth And Reproduction

To further enhance oil recovery in reservoir after chemical flooding, an efficient activator formulation for promoting metabolism of endogenous microorganism was researched. Changes in community structure, growth and metabolites of endogenous microorganism were analyzed by methods of aerogenic experiments, physical simulation experiments, electron microscopy scanning (SEM), T-RFLP and Pyrophosphate sequencing. To evaluate whether endogenous microorganism activator screened in laboratory could activate endogenous microorganisms and enhance oil recovery in reservoirs after polymer flooding. The flooding effect and mechanism were studied, and this activator was used in a testing well group in Daqing oilfield. The results of the aerogenic experiments showed that the activator could activate the endogenous microorganisms in the injected water and make them produce a lot of biogas. The pressurized gas reached 2MPa after 60d static culture of activator in a high pressure vessel. The results showed that the activator could activate the endogenous microorganisms in the injected sewage and make them have a lot of growth and reproduction in the core and physical simulation of natural core flooding experiment. In the field test,the incremental oil production was 5957 t while the water content declined by 2.2% after injecting the activator, which provides an effective way to further enhance oil recovery in reservoir after chemical flooding.

Investigation of Indigenous Microbial Enhanced Oil Recovery in a Middle Salinity Petroleum Reservoir

2011 ◽  
Vol 365 ◽  
pp. 326-331 ◽  
Author(s):  
Yue Hui She ◽  
Fu Chang Shu ◽  
Zheng Liang Wang ◽  
Long Jiang Yu
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Freezing Point ◽  
Most Probable Number ◽  
Petroleum Reservoir ◽  
Microbial Enhanced Oil Recovery ◽  
Core Flooding ◽  
Probable Number ◽  
The Core

Culture-based techniques were applied to analyze the diversity of indigenous microbial communities in the Qinghai middle salinity petroleum reservoir (QH-MSPR). The results of the most probable number (MPN) method indicated there was an abundance of indigenous microbes (105-106MPN/ml). Two isolations (BIOS682) from the QH-MSPR were identified as Brevibacillus agri and Brevibacillus levickii. The study showed that BIOS682 enhanced the degradation rate of Huatugou crude oil. The viscosity and freezing point of crude oil after treatment by BIOS682 were all decreased. The results of TLC and FTIR spectrum analysis of the biosurfactant produced by BIOS682 indicated that it was identical to that of lipopeptide. The core-flooding tests showed that the incremental oil recoveries were 7.05-10.15%. Thus, BIOS682 may provide a viable application of microbial enhanced oil recovery (MEOR).

scholarly journals Experimental Study on Expansion Characteristics of Core-Shell and Polymeric Microspheres

2018 ◽  
Vol 2018 ◽  
pp. 1-9 ◽  
Author(s):  
Pengxiang Diwu ◽  
Baoyi Jiang ◽  
Jirui Hou ◽  
Zhenjiang You ◽  
Jia Wang ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Early Stage ◽  
Average Diameter ◽  
Control Agent ◽  
Field Application ◽  
Experimental Results ◽  
Core Shell ◽  
The Core ◽  
Profile Control ◽  
Polymeric Microsphere

Traditional polymeric microsphere has several technical advantages in enhancing oil recovery. Nevertheless, its performance in some field application is unsatisfactory due to limited blockage strength. Since the last decade, novel core-shell microsphere has been developed as the next-generation profile control agent. To understand the expansion characteristic differences between these two types of microspheres, we conduct size measurement experiments on the polymeric and core-shell microspheres, respectively. The experimental results show two main differences between them. First, the core-shell microsphere exhibits a unimodal distribution, compared to multimodal distribution of the polymeric microsphere. Second, the average diameter of the core-shell microsphere increases faster than that of the polymeric microsphere in the early stage of swelling, that is, 0–3 days. These two main differences both result from the electrostatic attraction between core-shell microspheres with different hydration degrees. Based on the experimental results, the core-shell microsphere is suitable for injection in the early stage to block the near-wellbore zone, and the polymeric microsphere is suitable for subsequent injection to block the formation away from the well. A simple mathematical model is proposed for size evolution of the polymeric and core-shell microspheres.

Feasibility Study on Enhanced Oil Recovery Using Fuzzy-Ball Fluid in Offshore Heterogeneous Sandstone Reservoir

2020 ◽  
Author(s):  
Chao Wang ◽  
Lihui Zheng ◽  
Panfeng Wei ◽  
Mingzheng Yang ◽  
Wang Zhang ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Field Tests ◽  
Economic Feasibility ◽  
Low Permeability ◽  
Core Flooding ◽  
Heterogeneous Reservoirs ◽  
Output Ratio ◽  
Polymer Surfactant ◽  
Low Permeability Reservoirs

Abstract The heterogeneity of reservoirs in offshore oilfields, which causes low utilization of low-permeability reservoirs and poor exploitation of crude oil, is usually serious. Till date, fuzzy-ball fluids have been used to improve oil recovery of terrestrial heterogeneous reservoirs, but it is still uncertain whether it could enhance the recovery of offshore oilfields, because of high cost and special operating environment in offshore oilfields. To this end, laboratory core flooding experiments and field tests were conducted. The results of the feasibility analysis show that: (1) Fuzzy-ball fluid has good injection and plugging performance, which means fuzzy-ball fluid has great potential to be applied in enhancing recovery. (2) Fuzzy-ball fluid can greatly improve oil recovery, especially the recovery of low-permeability cores. Compared with polymer, surfactant and microsphere, fuzzy-ball fluid led to 30% higher recovery of low-permeability cores. (3) The application of fuzzy-ball fluid in enhancing recovery has good economic feasibility. The input-output ratio of fuzzy-ball fluid is 1:4.3. It is concluded that the use of fuzzy-ball fluid in the heterogeneous sandstone reservoirs for enhanced oil recovery is feasible.

Study of phase behaviour and ionic effect of green surfactants in MEOR

2018 ◽  
Vol 58 (1) ◽  
pp. 84 ◽  
Author(s):  
Bashirul Haq ◽  
Jishan Liu ◽  
Keyu Liu ◽  
Dhafer Al Shehri
Keyword(s):  
Oil Recovery ◽  
Alkyl Group ◽  
Laboratory Experiments ◽  
Carbon Number ◽  
Vital Role ◽  
Phase Behaviour ◽  
Ionic Surfactant ◽  
Core Flooding ◽  
Surfactant Systems ◽  
Group Carbon

The phase behaviour of surfactant systems is an important characteristic for microbial enhanced oil recovery (MEOR) and is a key method for understanding and predicting the performance of surfactant systems. In addition, ions play a vital role in surfactant chemistry and the ionic effects of green surfactants are not yet well characterised. Green surfactants are biodegradable and environmental friendly and perceived to have great potential for MEOR. This study characterises some green anionic and non-ionic surfactants through phase behaviour study, interfacial tension (IFT) and core flooding experiments. At the same time, the combined effect of the surfactants with alcohols on IFT through laboratory experiments are looked into. Our laboratory experiments have confirmed that the non-ionic surfactant is more active in the reduction of IFT than anionic surfactant. Bio-surfactant is unable to form stable middle phase. Temperature and pressure appear to have little effect on the IFT of non-ionic surfactant. There is no significant reduction in IFT values when the non-ionic surfactant is combined with pentanol in varying concentrations. The role of alkyl group carbon number in non-ionic surfactant was also investigated in this study. It was found that the IFT value decreased by increasing the lower limit alkyl group carbon number.

The Enhancement of Heavy Crude Oil Recovery Using Bacteria Degrading Polycyclic Aromatic Hydrocarbons

2011 ◽  
Vol 365 ◽  
pp. 320-325 ◽  
Author(s):  
Yue Hui She ◽  
Fu Chang Shu ◽  
Fan Zhang ◽  
Zheng Liang Wang ◽  
Shu Qiong Kong ◽  
...  
Keyword(s):  
Polycyclic Aromatic Hydrocarbons ◽  
Crude Oil ◽  
Oil Recovery ◽  
Aromatic Hydrocarbons ◽  
Fermentation Broth ◽  
Composition Analysis ◽  
Heavy Crude Oil ◽  
Core Flooding ◽  
Polycyclic Aromatic ◽  
Heavy Crude

Two strains of bacteria degrading polycyclic aromatic hydrocarbons (PAHs) were isolated using enrichment cultures of various heavy crude oil samples obtained from the Dagang Oilfield. The strains, namely S17 and S28, are able to degrade crude oil using phenanthrene as the sole carbon and energy source. The crude oil composition analysis indicates both strains are able to degrade heavy hydrocarbon components in crude oil. Then, the viscosities of heavy crude oil with S17 and S28 were decreased, and the surface tension between fermentative fluid and air were also decreased. The core flooding tests demonstrated that the fermentation broth, containing the two strains, can improve the residual oil recovery ratio by approximately 12.26% after polymer flooding.

scholarly journals The Reservoir Adaptability and Oil Displacement Mechanism of Polymer Microspheres

Polymers ◽  
2020 ◽  
Vol 12 (4) ◽  
pp. 885 ◽  
Author(s):  
Jianbing Li ◽  
Liwei Niu ◽  
Wenxiang Wu ◽  
Meifeng Sun
Keyword(s):  
Oil Recovery ◽  
Polymer Microspheres ◽  
Polymer Microsphere ◽  
Displacement Effect ◽  
Heterogeneous Reservoirs ◽  
Oil Displacement ◽  
Profile Control ◽  
Reservoir Conditions ◽  
Rational Combination ◽  
Core Permeability

Polymer microsphere profile control is a promising approach for the profile control of heterogeneous reservoirs. Matching between polymer microspheres and the reservoir pore throat is crucial for profile control. In this study, the range of the optimal matching factor Ra between polymer microspheres and core porosity was divided through core permeability limit experiments, and the dynamic migration laws and shut-off patterns of microspheres were studied using 9-m-long cores and microscopic models. The oil displacement effect and mechanism of microspheres were analyzed using three cores in parallel. The “injectability limit” and “in-depth migration limit” curves were divided by Ra into three zones: blockage (Ra < 1.09 ± 0.10), near-well profile control (1.09 ± 0.10 < Ra < 5.70 ± 0.64), and in-depth fluid diversion (Ra > 5.70 ± 0.64). During migration in porous media, the microspheres gradually enlarged in size and thus successively shut off in four forms: multi-microsphere bridging shut-off, few-microsphere bridging shut-off, single-microsphere shut-off, and elastic shut-off. Microspheres with a rational combination of sizes versus those with a single particle size further enhanced reservoir oil recovery under certain reservoir conditions. Through “temporary shut-off–breakthrough–temporary shut-off,” the polymer microspheres were able to change the fluid flow rate and streamlines, mobilize residual oils, and enhance the oil recovery rates.

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