Application of Hybrid Biosystems for Stimulation of Oil Production

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.

Self-gasified biosystems for enhanced oil recovery

2021 ◽  
pp. 2150274
Author(s):  
B. A. Suleimanov ◽  
S. J. Rzayeva ◽  
U. T. Akhmedova
Keyword(s):  
Carbon Dioxide ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Experimental Studies ◽  
Microbial Enhanced Oil Recovery ◽  
Heterogeneous Porous Medium ◽  
Oil Displacement ◽  
Subcritical Region ◽  
Reservoir Conditions

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-displacing agents along with a significant amount of gases, mainly carbon dioxide. Earlier, 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 nongasified systems. In a heterogeneous porous medium, the filtration profile of gasified liquids in the SR should be more uniform than for a degassed liquid. 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.

scholarly journals Role of Ionic Headgroups on the Thermal, Rheological, and Foaming Properties of Novel Betaine-Based Polyoxyethylene Zwitterionic Surfactants for Enhanced Oil Recovery

Processes ◽  
2019 ◽  
Vol 7 (12) ◽  
pp. 908 ◽  
Author(s):  
Muhammad Shahzad Kamal ◽  
Syed Muhammad Shakil Hussain ◽  
Lionel Talley Fogang
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Oil Recovery ◽  
Structural Changes ◽  
Foam Stability ◽  
Foaming Properties ◽  
Zwitterionic Surfactants ◽  
Reservoir Conditions ◽  
Thermal Stability Of

Long-term thermal stability of surfactants under harsh reservoir conditions is one of the main challenges for surfactant injection. Most of the commercially available surfactants thermally degrade or precipitate when exposed to high-temperature and high-salinity conditions. In this work, we designed and synthesized three novel betaine-based polyoxyethylene zwitterionic surfactants containing different head groups (carboxybetaine, sulfobetaine, and hydroxysulfobetaine) and bearing an unsaturated tail. The impact of the surfactant head group on the long-term thermal stability, foam stability, and surfactant–polymer interactions were examined. The thermal stability of the surfactants was assessed by monitoring the structural changes when exposed at high temperature (90 °C) for three months using 1H-NMR, 13C-NMR, and FTIR analysis. All surfactants were found thermally stable regardless of the headgroup and no structural changes were evidenced. The surfactant–polymer interactions were dominant in deionized water. However, in seawater, the surfactant addition had no effect on the rheological properties. Similarly, changing the headgroup of polyoxyethylene zwitterionic surfactants had no major effect on the foamability and foam stability. The findings of the present study reveal that the betaine-based polyoxyethylene zwitterionic surfactant can be a good choice for enhanced oil recovery application and the nature of the headgroup has no major impact on the thermal, rheological, and foaming properties of the surfactant in typical harsh reservoir conditions (high salinity, high temperature).

Extractive Capacity of CO2 in Oil Saturated Porous Media

2012 ◽  
Vol 524-527 ◽  
pp. 1807-1810
Author(s):  
Hao Chen ◽  
Sheng Lai Yang ◽  
Fang Fang Li ◽  
San Bo Lv ◽  
Zhi Lin Wang
Keyword(s):  
Porous Media ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Supercritical Condition ◽  
Experimental Results ◽  
Water Flooding ◽  
Saturated Porous Media ◽  
Reservoir Conditions

CO2 flooding process has been a proven valuable tertiary enhanced oil recovery (EOR) technique. In this paper, experiment on extractive capacity of CO2 in oil saturated porous media was conducted under reservoir conditions. The main objectives of the study are to evaluate extractive capacity of CO2 in oil saturated natural cores and improve understanding of the CO2 flooding mechanisms, especially in porous media conditions. Experimental results indicated that oil production decreases while GOR increases with extractive time increases. the changes of the color and state of the production oil shows that oil component changes from light to heavy as extractive time increases. In addition, no oil was produced by water flooding after extractive experiment. Based on the experimental results and phenomena, the main conclusion drawn from this study is that under supercritical condition, CO2 has very powerful extractive capacity. And the application of CO2 flooding is recommended for enhancing oil recovery.

A Decline Curve Analysis Model Based on Fluid Flow Mechanisms

2005 ◽  
Vol 8 (03) ◽  
pp. 197-204 ◽  
Author(s):  
Kewen Li ◽  
Roland N. Horne
Keyword(s):  
Fluid Flow ◽  
Linear Relationship ◽  
Relative Permeability ◽  
Oil Recovery ◽  
Single Phase ◽  
Oil Production ◽  
Curve Analysis ◽  
Production Data ◽  
Decline Curve Analysis ◽  
Decline Curve

Summary Decline-curve-analysis models are used frequently but still have many limitations. Approaches of decline-curve analysis used for naturally fractured reservoirs developed by waterflooding have been few. To this end, a decline-analysis model derived on the basis of fluid-flow mechanisms was proposed and used to analyze the oil-production data from naturally fractured reservoirs developed by waterflooding. Relative permeability and capillary pressure were included in this model. The model reveals a linear relationship between the oil-production rate and the reciprocal of the oil recovery or the accumulated oil production. We applied the model to the oil-production data from different types of reservoirs and found a linear relationship between the production rate and the reciprocal of the oil recovery as foreseen by the model, especially at the late period of production. The values of maximum oil recovery for the example reservoirs were evaluated with the parameters determined from the linear relationship. An analytical oil-recovery model was also proposed. The results showed that the analytical model could match the oil-production data satisfactorily. We also demonstrated that the frequently used nonlinear type curves could be transformed to linear relationships in a log-log plot. This may facilitate the production-decline analysis. Finally, the analytical model was compared with conventional models. Introduction Estimating reserves and predicting production in reservoirs has been a challenge for many years. Many methods have been developed in the last several decades. One frequently used technique is the decline-curve-analysis approach. There have been a great number of papers on this subject. Most of the existing decline-curve-analysis techniques are based on the empirical Arps equations: exponential, hyperbolic, and harmonic. It is difficult to foresee which equation the reservoir will follow. On the other hand, each approach has some disadvantages. For example, the exponential decline curve tends to underestimate reserves and production rates; the harmonic decline curve has a tendency to overpredict the reservoir performance. In some cases, production-decline data do not follow any model but cross over the entire set of curves. Fetkovich combined the transient rate and the pseudosteady-state decline curves in a single graph. He also related the empirical equations of Arps to the single-phase-flow solutions and attempted to provide a theoretical basis for the Arps equations. This was realized by developing the connection between the material balance and the flow-rate equations on the basis of his previous papers. Many derivations were based on the assumption of single-phase oil flow in closed-boundary systems. These solutions were suitable only for undersaturated(single-phase) oil flow. However, many oil fields are developed by waterflooding. Therefore, two-phase fluid flow (rather than single-phase flow)occurs. In this case, Lefkovits and Matthews derived the exponential decline form for gravity-drainage reservoirs with a free surface by neglecting capillary pressure. Fetkovich et al. included gas/oil relative permeability effects on oil production for solution-gas drive through the pressure-ratio term. This assumes that the oil relative permeability is a function of pressure. It is known that gas/oil relative permeability is a function of fluid saturation, which depends on fluid/rock properties.

Experimental Studies on Artificial Vibration Oil Production

2003 ◽  
Author(s):  
Ren-yuan Sun
Keyword(s):  
Oil Recovery ◽  
Experimental Studies ◽  
Oil Production ◽  
Vibration Simulation ◽  
New System

A new system for artificial vibration simulation was designed and the effect of artificial vibration on core permeabilities, oil recovery factors under different stage of waterflooding was studied. Experiments show that action of artificial vibration can improve the permeability of cores and oil recovery factors. The oil recovery increment was related to the vibrating parameters including vibrating frequency, amplitude and time. Some oilfield applications and new trends of Artificial Vibration Oil Production (AVOP) were also introduced.

scholarly journals Well Killing Technology before Workover Operation in Complicated Conditions

Energies ◽  
2021 ◽  
Vol 14 (3) ◽  
pp. 654
Author(s):  
Dmitry V. Mardashov ◽  
Mikhail K. Rogachev ◽  
Yury V. Zeigman ◽  
Vyacheslav V. Mukhametshin
Keyword(s):  
Oil Recovery ◽  
Experimental Studies ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Fluid Loss ◽  
Oil Emulsion ◽  
Field Development ◽  
Oil Field Development ◽  
Reservoir Conditions ◽  
Complicated Conditions

Well killing is an important technological stage before conducting workover operation, one of the tasks of which is to preserve and restore the natural filtration characteristics of the bottomhole formation zone (BFZ). Special attention should be paid to the choice of well killing technologies and development of wells in complicated conditions, which include abnormally low reservoir pressure, high oil-gas ratio and carbonate reservoir type. To preserve the filtration characteristics of the productive formation and prevent fluid losses in producing wells during well killing operation, blocking compositions are used. At the same time, an informed choice of the most effective well killing technologies is required. Consequently, there is a need to conduct laboratory physicochemical and coreflood experiments simulating geological, physical, and technological conditions of field development, as similar as possible to actual reservoir conditions. The article presents the results of experimental studies on the development well killing technologies of producing wells during workover operation in various geological, physical, and technological conditions of oil field development. Physicochemical and coreflood laboratory experiments were carried out with the simulation of the processes of well killing and development of wells in reservoir conditions with the use of modern high-technology equipment in the Enhanced Oil Recovery Laboratory of the Department of Development and Operation of Oil and Gas Fields at St. Petersburg Mining University. As a result of the experimental studies, new compositions of well killing and stimulation fluids were developed, which ensure to prevent fluid loss, gas breakthrough, as well as the preservation, restoration and improvement of the filtration characteristics of the BFZ in the conditions of terrigenous and carbonate reservoirs at different stages of oil field development. It is determined that the developed process fluids, which include surfactants (YALAN-E2 and NG-1), have a hydrophobic effect on the porous medium of reservoir rocks, which ultimately contributes to the preservation, restoration and improvement of the filtration characteristics of the BFZ. The value of the presented research results is relevant for practice and confirmed by the fact that, as a result of field tests of the technology for blocking the BFZ with the composition of inverse water–oil emulsion during well killing before workover operation, an improvement in the efficiency of wells operation was obtained in the form of an increase in their oil production rate by an average of 5–10 m3/day, reducing the time required for the well to start operating up to 1–3 days and reducing the water cut of formation fluid by 20–30%.

scholarly journals Quick, Easy and Economic Mineralogical Studies of Flooded Chalk for EOR Experiments Using Raman Spectroscopy

2018 ◽  
Author(s):  
Laura Borromeo ◽  
Nina Egeland ◽  
Mona Wetrhus Minde ◽  
Udo Zimmermann ◽  
Sergio Andò ◽  
...  
Keyword(s):  
Raman Spectroscopy ◽  
Effective Stress ◽  
Oil Recovery ◽  
Secondary Growth ◽  
Mineral Dissolution ◽  
Petroleum Exploration ◽  
Reservoir Conditions ◽  
Electron Microscopes ◽  
Non Destructive

Understanding the chalk-fluid interactions and the associated mineralogical and mechanical alteration at sub-micron scale are major goals in Enhanced Oil Recovery. Mechanical strength, porosity, and permeability of chalk are linked to mineral dissolution that occurs during brine injections, and affect the reservoir potential. This paper presents a novel "single grain" methodology to recognize the varieties of carbonates in rocks and loose sediments: Raman spectroscopy is a non-destructive, quick, and user-friendly technique representing a powerful tool to identify minerals down to 1 µm. An innovative working technique for oil exploration is proposed, as the mineralogy of micron-sized crystals grown in two flooded chalk samples (Liége, Belgium) was successfully investigated by Raman spectroscopy. The drilled chalk cores were flooded with MgCl2 for c. 1.5 (Long Term Test) and 3 years (Ultra Long Term Test) under North Sea reservoir conditions (Long Term Test: 130°C, 1 PV/day, 9.3 MPa effective stress; Ultra Long Term Test: 130°C, varying between 1-3 PV/day, 10.4 MPa effective stress). Raman spectroscopy was able to identify the presence of recrystallized magnesite along the core of the Long Term Test up to 4 cm from the injection surface, down to the crystal size of 1-2 µm. In the Ultra Long Term Test core the growth of MgCO3 affected nearly the entire core (7 cm). In both samples, no dolomite or high-magnesium calcite secondary growth could be detected when analysing 557 and 90 Raman spectra on the Long and Ultra Long Term Test, respectively. This study can offer Raman spectroscopy as a breakthrough tool in petroleum exploration of unconventional reservoirs, due to its quickness, spatial resolution, and non-destructive acquisition of data. These characteristics would encourage its use coupled with electron microscopes and energy dispersive systems or even electron microprobe studies.

scholarly journals Application of Polymer Based Nanocomposites for Water Shutoff—A Review

Fuels ◽  
2021 ◽  
Vol 2 (3) ◽  
pp. 304-322
Author(s):  
Velima Obino ◽  
Upendra Yadav
Keyword(s):  
Thermal Stability ◽  
Oil Recovery ◽  
Experimental Studies ◽  
High Water ◽  
Polymer Gel ◽  
Polymer Hydrogels ◽  
Undesirable Characteristic ◽  
Gel Treatment ◽  
Reservoir Conditions ◽  
Thermal Stability Of

One highly undesirable characteristic of mature assets that inhibits oil recovery is high water production. Polymer gel treatment is a popular conformance improvement technique applied in this regard due to its cost effectiveness and proved efficiency. Despite this popularity, optimum performance of polymer hydrogels in water shut off is inhibited by excessive aggregation, difficulty in controlling gelation, and their instability at high temperature and high salinity reservoir conditions. To address these shortcomings, research on the application of nanoparticles (NPs) in polymer hydrogels to manage thermal stability and salinity sensitivity has significantly increased in the recent past. By incorporating metal-based NPs, silica or graphene at nanoscale; the gel strength, storage modulus, salinity tolerance and thermal stability of commonly used polymers have been greatly enhanced. In this paper, the advances in experimental studies on polymer-based nanocomposites are discussed and field experiences from adoption of polymer composites reviewed.

scholarly journals Simulation Analysis of CO2-EOR Process and Feasibility of CO2 Storage during EOR

Energies ◽  
2021 ◽  
Vol 14 (4) ◽  
pp. 1154
Author(s):  
Maja Arnaut ◽  
Domagoj Vulin ◽  
Gabriela José García Lamberg ◽  
Lucija Jukić
Keyword(s):  
Oil Recovery ◽  
Reservoir Simulation ◽  
Net Present Value ◽  
Simulation Analysis ◽  
Co2 Storage ◽  
Oil Production ◽  
Utilization Factor ◽  
Reservoir Conditions ◽  
Multiparameter Analysis ◽  
The Impact

In this study, oil production and retention were observed and compared in 72 reservoir simulation cases, after which an economic analysis for various CO2 and oil prices was performed. Reservoir simulation cases comprise different combinations of water alternating gas (WAG) ratios, permeabilities, and well distances. These models were set at three different depths; thus different pressure and temperature conditions, to see the impact of miscibility on oil production and CO2 sequestration. Those reservoir conditions affect oil production and CO2 retention differently. The retention trend dependence on depth was not monotonic—optimal retention relative to the amount of injected CO2 could be achieved at middle depths and mediocre permeability as well. Results reflecting different reservoir conditions and injection strategies are shown, and analysis including the utilization factor and the net present value was conducted to examine the feasibility of different scenarios. The analysis presented in this paper can serve as a guideline for multiparameter analysis and optimization of CO2-enhanced oil recovery (EOR) with a WAG injection strategy.

Evaluation of ionic effect of green surfactants on interfacial tension reduction under reservoir conditions for enhanced oil recovery

2011 ◽  
Vol 51 (2) ◽  
pp. 727
Author(s):  
Bashirul Haq ◽  
Jishan Liu ◽  
Keyu Liu
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Aquatic Toxicity ◽  
Vital Role ◽  
Bacillus Mojavensis ◽  
Reservoir Condition ◽  
Reservoir Conditions ◽  
Ionic Effects

Ions play a vital role in surfactant chemistry of EOR. The ionic effects of green surfactants are not yet well characterised, but they are biodegradable and environmental friendly, and have great potential for EOR. This study characterises some green anionic and non-ionic surfactants through the determination of the interfacial tension (IFT) of each group and the combined effect of the green surfactants with alcohols on IFT and micro emulsions; and the oil recovery factor through laboratory experiments. Alky Polyglucosides (APG) was selected from the non-ionic group, which can produce ultra low IFT. APG surfactants are produced from coconut/palm oil, corn, potato or wheat residues. Bio-surfactants produced by a microbe called Bacillus mojavensis was taken from the anionic group. This study has found that the APG surfactants are completely and quickly biodegradable and environmentally friendly. APG surfactants show low long-term aquatic toxicity for bacteria, favourable for fish and acceptable effects are on Daphnia and Algae. Our laboratory tests have confirmed that APG PG 8166 can reduce IFT from 12–3.16 dyne/cm at 40 ppm under laboratory ambient condition and from 12–4.32 dyne/cm at a reservoir condition of 50oC and 1000psi. In contrast, the bio-surfactant at 40 ppm decreased IFT from 12–4.14 dyne/cm at the same reservoir condition. Temperature appears to have little effect on the IFT of APG surfactants. There is no significant reduction in the IFT values when APG at 10 ppm combined with the pentanol at concentrations of 15–120 ppm.

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