Direct Electric Current Oil Recovery (EEOR)—A New Approach to Enhancing Oil Production

Abstract Background Recent trends in bioprocessing have underlined the significance of lignocellulosic biomass conversions for biofuel production. These conversions demand at least 90% energy upgradation of cellulosic sugars to generate renewable drop-in biofuel precursors (Heff/C ~ 2). Chemical methods fail to achieve this without substantial loss of carbon; whereas, oleaginous biological systems propose a greener upgradation route by producing oil from sugars with 30% theoretical yields. However, these oleaginous systems cannot compete with the commercial volumes of vegetable oils in terms of overall oil yields and productivities. One of the significant challenges in the commercial exploitation of these microbial oils lies in the inefficient recovery of the produced oil. This issue has been addressed using highly selective oil capturing agents (OCA), which allow a concomitant microbial oil production and in situ oil recovery process. Results Adsorbent-based oil capturing agents were employed for simultaneous in situ oil recovery in the fermentative production broths. Yarrowia lipolytica, a model oleaginous yeast, was milked incessantly for oil production over 380 h in a media comprising of glucose as a sole carbon and nutrient source. This was achieved by continuous online capture of extracellular oil from the aqueous media and also the cell surface, by fluidizing the fermentation broth over an adsorbent bed of oil capturing agents (OCA). A consistent oil yield of 0.33 g per g of glucose consumed, corresponding to theoretical oil yield over glucose, was achieved using this approach. While the incorporation of the OCA increased the oil content up to 89% with complete substrate consumptions, it also caused an overall process integration. Conclusion The nondisruptive oil capture mediated by an OCA helped in accomplishing a trade-off between microbial oil production and its recovery. This strategy helped in realizing theoretically efficient sugar-to-oil bioconversions in a continuous production process. The process, therefore, endorses a sustainable production of molecular drop-in equivalents through oleaginous yeasts, representing as an absolute microbial oil factory.

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The Isotope Effect of a Direct Electric Current through Liquid and Solid Metals

Zeitschrift für Naturforschung A ◽

10.1515/zna-1956-0112 ◽

1956 ◽

Vol 11 (1) ◽

pp. 71-75

Author(s):

E. Haeffner ◽

Th. Sjöborg ◽

S. Lindhe

Keyword(s):

Liquid Metal ◽

Electric Current ◽

Isotope Effect ◽

Direct Current ◽

Capillary Tube ◽

Isotope Separation ◽

Direct Electric Current ◽

Separation Effect ◽

A Current

The isotope separation effect of a direct electric current in a liquid metal is demonstrated by passing a current through mercury, which is enclosed in a capillary tube. The second part of the paper deals with an attempt of establishing an isotope effect when a direct current is passed through an uranium wire.

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Waterflooding in Carbonate Reservoirs: Does the Salinity Matter?

SPE Reservoir Evaluation & Engineering ◽

10.2118/170254-pa ◽

2014 ◽

Vol 17 (03) ◽

pp. 304-313 ◽

Cited By ~ 50

Author(s):

A.M.. M. Shehata ◽

M.B.. B. Alotaibi ◽

H.A.. A. Nasr-El-Din

Keyword(s):

Oil Recovery ◽

Sudden Change ◽

Oil Production ◽

Deionized Water ◽

Production Performance ◽

Shallow Aquifer ◽

Secondary Recovery ◽

Tertiary Recovery ◽

The Impact ◽

Indiana Limestone

Summary Waterflooding has been used for decades as a secondary oil-recovery mode to support oil-reservoir pressure and to drive oil into producing wells. Recently, the tuning of the salinity of the injected water in sandstone reservoirs was used to enhance oil recovery at different injection modes. Several possible low-salinity-waterflooding mechanisms in sandstone formations were studied. Also, modified seawater was tested in chalk reservoirs as a tertiary recovery mode and consequently reduced the residual oil saturation (ROS). In carbonate formations, the effect of the ionic strength of the injected brine on oil recovery has remained questionable. In this paper, coreflood studies were conducted on Indiana limestone rock samples at 195°F. The main objective of this study was to investigate the impact of the salinity of the injected brine on the oil recovery during secondary and tertiary recovery modes. Various brines were tested including deionized water, shallow-aquifer water, seawater, and as diluted seawater. Also, ions (Na+, Ca2+, Mg2+, and SO42−) were particularly excluded from seawater to determine their individual impact on fluid/rock interactions and hence on oil recovery. Oil recovery, pressure drop across the core, and core-effluent samples were analyzed for each coreflood experiment. The oil recovery using seawater, as in the secondary recovery mode, was, on the average, 50% of original oil in place (OOIP). A sudden change in the salinity of the injected brine from seawater in the secondary recovery mode to deionized water in the tertiary mode or vice versa had a significant effect on the oil-production performance. A solution of 20% diluted seawater did not reduce the ROS in the tertiary recovery mode after the injection of seawater as a secondary recovery mode for the Indiana limestone reservoir. On the other hand, 50% diluted seawater showed a slight change in the oil production after the injection of seawater and deionized water slugs. The Ca2+, Mg2+, and SO42− ions play a key role in oil mobilization in limestone rocks. Changing the ion composition of the injected brine between the different slugs of secondary and tertiary recovery modes showed a measurable increase in the oil production.

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Worm-like micelles: A new approach for heavy oil recovery from fractured systems

The Canadian Journal of Chemical Engineering ◽

10.1002/cjce.22166 ◽

2015 ◽

Vol 93 (5) ◽

pp. 951-958 ◽

Cited By ~ 17

Author(s):

Amir Kianinejad ◽

Milad Saidian ◽

Marzieh Mavaddat ◽

Mohammad Hossein Ghazanfari ◽

Riyaz Kharrat ◽

...

Keyword(s):

Oil Recovery ◽

Heavy Oil ◽

Heavy Oil Recovery ◽

New Approach

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Pilot Project Evaluating WAG Efficiency for Carbonate Reservoir in Eastern Siberia

10.2118/206417-ms ◽

2021 ◽

Author(s):

Valentina Zharko ◽

Dmitriy Burdakov

Keyword(s):

Oil Recovery ◽

Gas Injection ◽

Oil Production ◽

Pilot Project ◽

Carbonate Reservoir ◽

Recovery Factor ◽

Eastern Siberia ◽

Water Cut ◽

Wag Injection ◽

Injection Rates

Abstract The paper presents the results of a pilot project implementing WAG injection at the oilfield with carbonate reservoir, characterized by low efficiency of traditional waterflooding. The objective of the pilot project was to evaluate the efficiency of this enhanced oil recovery method for conditions of the specific oil field. For the initial introduction of WAG, an area of the reservoir with minimal potential risks has been identified. During the test injections of water and gas, production parameters were monitored, including the oil production rates of the reacting wells and the water and gas injection rates of injection wells, the change in the density and composition of the produced fluids. With first positive results, the pilot area of the reservoir was expanded. In accordance with the responses of the producing wells to the injection of displacing agents, the injection rates were adjusted, and the production intensified, with the aim of maximizing the effect of WAG. The results obtained in practice were reproduced in the simulation model sector in order to obtain a project curve characterizing an increase in oil recovery due to water-alternating gas injection. Practical results obtained during pilot testing of the technology show that the injection of gas and water alternately can reduce the water cut of the reacting wells and increase overall oil production, providing more efficient displacement compared to traditional waterflooding. The use of WAG after the waterflooding provides an increase in oil recovery and a decrease in residual oil saturation. The water cut of the produced liquid decreased from 98% to 80%, an increase in oil production rate of 100 tons/day was obtained. The increase in the oil recovery factor is estimated at approximately 7.5% at gas injection of 1.5 hydrocarbon pore volumes. Based on the received results, the displacement characteristic was constructed. Methods for monitoring the effectiveness of WAG have been determined, and studies are planned to be carried out when designing a full-scale WAG project at the field. This project is the first pilot project in Russia implementing WAG injection in a field with a carbonate reservoir. During the pilot project, the technical feasibility of implementing this EOR method was confirmed, as well as its efficiency in terms of increasing the oil recovery factor for the conditions of the carbonate reservoir of Eastern Siberia, characterized by high water cut and low values of oil displacement coefficients during waterflooding.

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Antimicrobial Efficacy of Exposure of Medical Metal Implants to Direct Electric Current

Biomedical Engineering ◽

10.1007/s10527-022-10128-z ◽

2022 ◽

Author(s):

E. N. Ovchinnikov ◽

N. V. Godovykh ◽

O. V. Dyuryagina ◽

M. V. Stogov ◽

D. N. Ovchinnikov ◽

...

Keyword(s):

Electric Current ◽

Antimicrobial Efficacy ◽

Direct Electric Current ◽

Metal Implants

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Undersaturated Hydrocarbon Reservoir Waterflooding: A simulation Approach to Performance Assessment

10.2118/207148-ms ◽

2021 ◽

Author(s):

Adekunle Tirimisiyu Adeniyi ◽

Miracle Imwonsa Osatemple ◽

Abdulwahab Giwa

Keyword(s):

Oil Recovery ◽

Net Present Value ◽

Oil Production ◽

Base Case ◽

Present Value ◽

Sweep Efficiency ◽

Recovery Method ◽

Solution Approach ◽

Hydrocarbon Reservoir

Abstract There are a good numbers of brown hydrocarbon reservoirs, with a substantial amount of bypassed oil. These reservoirs are said to be brown, because a huge chunk of its recoverable oil have been produced. Since a significant number of prominent oil fields are matured and the number of new discoveries is declining, it is imperative to assess performances of waterflooding in such reservoirs; taking an undersaturated reservoir as a case study. It should be recalled that Waterflooding is widely accepted and used as a means of secondary oil recovery method, sometimes after depletion of primary energy sources. The effects of permeability distribution on flood performances is of concerns in this study. The presence of high permeability streaks could lead to an early water breakthrough at the producers, thus reducing the sweep efficiency in the field. A solution approach adopted in this study was reserve water injection. A reverse approach because, a producing well is converted to water injector while water injector well is converted to oil producing well. This optimization method was applied to a waterflood process carried out on a reservoir field developed by a two - spot recovery design in the Niger Delta area of Nigeria that is being used as a case study. Simulation runs were carried out with a commercial reservoir oil simulator. The result showed an increase in oil production with a significant reduction in water-cut. The Net Present Value, NPV, of the project was re-evaluated with present oil production. The results of the waterflood optimization revealed that an increase in the net present value of up to 20% and an increase in cumulative production of up to 27% from the base case was achieved. The cost of produced water treatment for re-injection and rated higher water pump had little impact on the overall project economy. Therefore, it can conclude that changes in well status in wells status in an heterogenous hydrocarbon reservoir will increase oil production.

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Enhanced Oil Recovery Application of Nanoparticles in Niger Delta Water-Wet Reservoir Rock

10.2118/207150-ms ◽

2021 ◽

Author(s):

Tinuola Udoh

Keyword(s):

Enhanced Oil Recovery ◽

Oil Recovery ◽

Niger Delta ◽

Oil Production ◽

Reservoir Rock ◽

Core Flooding ◽

Core Samples ◽

Recovery Potential ◽

Secondary Formation ◽

Injection Modes

Abstract In this paper, the enhanced oil recovery potential of the application of nanoparticles in Niger Delta water-wet reservoir rock was investigated. Core flooding experiments were conducted on the sandstone core samples at 25 °C with the applications of nanoparticles in secondary and tertiary injection modes. The oil production during flooding was used to evaluate the enhanced oil recovery potential of the nanoparticles in the reservoir rock. The results of the study showed that the application of nanoparticles in tertiary mode after the secondary formation brine flooding increased oil production by 16.19% OIIP. Also, a comparison between the oil recoveries from secondary formation brine and nanoparticles flooding showed that higher oil recovery of 81% OIIP was made with secondary nanoparticles flooding against 57% OIIP made with formation brine flooding. Finally, better oil recovery of 7.67% OIIP was achieved with secondary application of nanoparticles relative to the tertiary application of formation brine and nanoparticles flooding. The results of this study are significant for the design of the application of nanoparticles in Niger Delta reservoirs.

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Enhancing oil recovery by electric current impulses well treatment: A case of marginal field from Oman

Fuel ◽

10.1016/j.fuel.2021.123115 ◽

2022 ◽

Vol 314 ◽

pp. 123115

Author(s):

Svetlana Rudyk ◽

Usman Taura ◽

Mohammed Al-Jahwary

Keyword(s):

Electric Current ◽

Oil Recovery ◽

Marginal Field

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Application of Hybrid Biosystems for Stimulation of Oil Production

10.2118/207061-ms ◽

2021 ◽

Author(s):

Baghir Alakbar Suleimanov ◽

Sabina Jahangir Rzayeva ◽

Ulviyya Tahir Akhmedova

Keyword(s):

Oil Recovery ◽

Single Phase ◽

Experimental Studies ◽

Oil Production ◽

Pore Channel ◽

Subcritical Region ◽

Slippage Effect ◽

Liquid Systems ◽

Reservoir Conditions

Abstract Microbial enhanced oil recovery is considered to be one of the most promising methods of stimulating formation, contributing to a higher level of oil production from long-term fields. The injection of bioreagents into a reservoir results in the creation of oil-dicing agents along with significant amount of gases, mainly carbon dioxide. In early, the authors failed to study the preparation of self-gasified biosystems and the implementation of the subcritical region (SR) under reservoir conditions. Gasified systems in the subcritical phase have better oil-displacing properties than non-gasified systems. The slippage effect determines the behavior of gas–liquid systems in the SR under reservoir conditions. Slippage occurs more easily when the pore channel has a smaller average radius. Therefore, in a heterogeneous porous medium, the filtration profile of gasified liquids in the SR should be more uniform than for a degassed liquid. The theoretical and practical foundations for the preparation of single-phase self-gasified biosystems and the implementation of the SR under reservoir conditions have been developedSR under reservoir conditions. Based on experimental studies, the superior efficiency of oil displacement by gasified biosystems compared with degassed ones has been demonstrated. The possibility of efficient use of gasified hybrid biopolymer systems has been shown.

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