Log in

Relevant bibliographies by topics / Reservoir souring

Contents

Journal articles
Dissertations / Theses
Books
Book chapters
Conference papers

Academic literature on the topic 'Reservoir souring'

Author: Grafiati

Published: 4 June 2021

Last updated: 16 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'Reservoir souring.'

Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.

You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.

Journal articles on the topic "Reservoir souring"

1

Sugai, Yuichi, Yukihiro Owaki, and Kyuro Sasaki. "Simulation Study on Reservoir Souring Induced by Injection of Reservoir Brine Containing Sulfate-Reducing Bacteria." Sustainability 12, no. 11 (June 4, 2020): 4603. http://dx.doi.org/10.3390/su12114603.

Full text

Abstract:

This paper examined the reservoir souring induced by the sulfate-reducing bacteria (SRB) inhabiting the reservoir brine of an oilfield in Japan. Although the concentration of sulfate of the reservoir brine was lower than that of seawater, which often was injected into oil reservoir and induced the reservoir souring, the SRB inhabiting the reservoir brine generated hydrogen sulfide (H2S) by using sulfate and an electron donor in the reservoir brine. This paper therefore developed a numerical simulator predicting the reservoir souring in the reservoir into which the reservoir brine was injected. The results of the simulation suggested that severe reservoir souring was not induced by the brine injection; however, the SRB grew and generated H2S around the injection well where temperature was decreased by injected brine whose temperature was lower than that of formation water. In particular, H2S was actively generated in the mixing zone between the injection water and formation water, which contained a high level of the electron donor. Furthermore, the results of numerical simulation suggested that the reservoir souring could be prevented more surely by sterilizing the SRB in the injection brine, heating up the injection brine to 50 °C, or reducing sulfate in the injection brine.

APA, Harvard, Vancouver, ISO, and other styles

2

Jahanbani Veshareh, Moein, and Shahab Ayatollahi. "Microorganisms’ effect on the wettability of carbonate oil-wet surfaces: implications for MEOR, smart water injection and reservoir souring mitigation strategies." Journal of Petroleum Exploration and Production Technology 10, no. 4 (September 12, 2019): 1539–50. http://dx.doi.org/10.1007/s13202-019-00775-6.

Full text

Abstract:

Abstract In upstream oil industry, microorganisms arise some opportunities and challenges. They can increase oil recovery through microbial enhanced oil recovery (MEOR) mechanisms, or they can increase production costs and risks through reservoir souring process due to H2S gas production. MEOR is mostly known by bioproducts such as biosurfactant or processes such as bioclogging or biodegradation. On the other hand, when it comes to treatment of reservoir souring, the only objective is to inhibit reservoir souring. These perceptions are mainly because decision makers are not aware of the effect microorganisms’ cell can individually have on the wettability. In this work, we study the individual effect of different microorganisms’ cells on the wettability of oil-wet calcite and dolomite surfaces. Moreover, we study the effect of two different biosurfactants (surfactin and rhamnolipid) in two different salinities. We show that hydrophobe microorganisms can change the wettability of calcite and dolomite oil-wet surfaces toward water-wet and neutral-wet states, respectively. In the case of biosurfactant, we illustrate that the ability of a biosurfactant to change the wettability depends on salinity and its hydrophilic–hydrophobic balance (HLB). In distilled water, surfactin (high HLB) can change the wettability to a strongly water-wet state, while rhamnolipid only changes the wettability to a neutral-wet state (low HLB). In the seawater, surfactin is not able to change the wettability, while rhamnolipid changes the wettability to a strongly water-wet state. These results help reservoir managers who deal with fractured carbonate reservoirs to design a more effective MEOR plan and/or reservoir souring treatment strategy.

APA, Harvard, Vancouver, ISO, and other styles

3

Mahdi, Najwa H., and Mohammed S. Al-Jawad. "Estimation of H2S Produced from Reservoir Souring." Journal of Petroleum Research and Studies 9, no. 4 (December 1, 2019): 74–88. http://dx.doi.org/10.52716/jprs.v9i4.323.

Full text

Abstract:

The increase of the produce H2S due to water injection is known as reservoir souring. The sulfate reduced bacteria (SRB) which may be exist in the injected water reduces the sulfate which already existing in the reservoir. This study includes prediction of H2S for Mauddud reservoir in the Ahdeb oilfield by using specialized reservoir numerical simulator. Reservoir souring modeling utilized to enable operations to make better decisions for remedial actions to either prevent souring or to mitigate its impact. The aim of this study is to estimate the probability and timing of the start of H2S production in produced fluids. The results showed that the maximum concentration of H2S in the prediction production well was reached to 2.9 Ibm/day which occurs after 180 days this carry out when the SRB concentration was about 2000 ppm .The SRB concentration is increasing in areas where the sulfate is in high concentration and also there is a direct relationship between the SRB concentration and the H2S concentration

APA, Harvard, Vancouver, ISO, and other styles

4

Haghshenas, Mehdi, Kamy Sepehrnoori, Steven L. Bryant, and Mohammad Ali Farhadinia. "Modeling and Simulation of Nitrate Injection for Reservoir Souring Remediation." SPE Journal 17, no. 03 (August 29, 2012): 817–27. http://dx.doi.org/10.2118/141590-pa.

Full text

Abstract:

Summary Reservoir souring refers to the onset of hydrogen sulfide (H2S) production during waterflooding. Besides health and safety issues, H2S content reduces the value of the produced hydrocarbon. Nitrate injection is an effective method to prevent the formation of H2S. Designing this process requires the modeling of a complicated set of biogeochemical reactions involved in the production of H2S and its inhibition. This paper describes the modeling and simulation of biological reactions associated with the injection of nitrate to inhibit reservoir souring. The model is implemented in a general-purpose adaptive reservoir simulator (GPAS). To the best of our knowledge, GPAS is the first field-scale reservoir simulator that models reservoir souring treatment. The basic mechanism in the biologically mediated generation of H2S is the reaction between sulfate in the injection water and fatty acids in the formation water in the presence of sulfate-reducing bacteria (SRB). There are proposed mechanisms that describe the effect of nitrate injection on souring remediation. Depending on the circumstances, more than one mechanism may occur at the same time. These mechanisms include the inhibitory effect of nitrite on sulfate reduction, the competition between SRB and nitrate-reducing bacteria (NRB), and the stimulation of nitrate-reducing sulfide-oxidizing bacteria (NR-SOB). For each mechanism, we specify the biological species and chemical components involved and determine the role of each component in the biological reaction. For every biological reaction, a set of ordinary differential equations along with differential equations for the transport of chemical and biological species are solved. The results of reported experiments in the literature are used to find the input parameters for field-scale simulations. This reservoir simulator can then predict the onset of reservoir souring and the effectiveness of nitrate injection and helps in the design of the process. The comprehensive modeling accounts for variation in biological system characteristics and reservoir conditions that affect the production and remediation of H2S.

APA, Harvard, Vancouver, ISO, and other styles

5

Basafa, Mahsan, and Kelly Hawboldt. "Reservoir souring: sulfur chemistry in offshore oil and gas reservoir fluids." Journal of Petroleum Exploration and Production Technology 9, no. 2 (August 4, 2018): 1105–18. http://dx.doi.org/10.1007/s13202-018-0528-2.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Schofield, Mick, and Jim Stott. "Assessing the Magnitude and Consequences of Reservoir Souring." Journal of Petroleum Technology 64, no. 05 (May 1, 2012): 76–79. http://dx.doi.org/10.2118/0512-0076-jpt.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Johnson, Richard J., Benjamin D. Folwell, Alexander Wirekoh, Max Frenzel, and Torben Lund Skovhus. "Reservoir Souring – Latest developments for application and mitigation." Journal of Biotechnology 256 (August 2017): 57–67. http://dx.doi.org/10.1016/j.jbiotec.2017.04.003.

Full text

APA, Harvard, Vancouver, ISO, and other styles

8

Basafa, Mahsan, and Kelly Hawboldt. "Sulfur speciation in soured reservoirs: chemical equilibrium and kinetics." Journal of Petroleum Exploration and Production Technology 10, no. 4 (January 2, 2020): 1603–12. http://dx.doi.org/10.1007/s13202-019-00824-0.

Full text

Abstract:

AbstractReservoir souring is a widespread phenomenon in reservoirs undergoing seawater injection. Sulfate in the injected seawater promotes the growth of sulfate-reducing bacteria (SRB) and archaea-generating hydrogen sulfide. However, as the reservoir fluid flows from injection well to topside facilities, reactions involving formation of different sulfur species with intermediate valence states such as elemental sulfur, sulfite, polysulfide ions, and polythionates can occur. A predictive reactive model was developed in this study to investigate the chemical reactivity of sulfur species and their partitioning behavior as a function of temperature, pressure, and pH in a seawater-flooded reservoir. The presence of sulfur species with different oxidation states impacts the amount and partitioning behavior of H2S and, therefore, the extent of reservoir souring. The injected sulfate is reduced to H2S microbially close to the injection well. The generated H2S partitions between phases depending on temperature, pressure, and pH. Without considering chemical reactivity and sulfur speciation, the gas phase under test separator conditions on the surface contains 1080 ppm H2S which is in equilibrium with the oil phase containing 295.7 ppm H2S and water phase with H2S content of 8.8 ppm. These values are higher than those obtained based on reactivity analysis, where sulfur speciation and chemical reactions are included. Under these conditions, the H2S content of the gas, oil, and aqueous phases are 487 ppm, 134 ppm, and 4 ppm, respectively.

APA, Harvard, Vancouver, ISO, and other styles

9

Fan, Fuqiang, Baiyu Zhang, Penny L. Morrill, and Tahir Husain. "Isolation of nitrate-reducing bacteria from an offshore reservoir and the associated biosurfactant production." RSC Advances 8, no. 47 (2018): 26596–609. http://dx.doi.org/10.1039/c8ra03377c.

Full text

APA, Harvard, Vancouver, ISO, and other styles

10

Skjevrak, I., D. C. Standnes, U. S. Thomsen, J. Xu, K. Håland, A. Kjølhamar, and P. K. Munkerud. "Field observations of reservoir souring development and implications for the Extended Growth Zone (EGZ) souring model." Journal of Petroleum Science and Engineering 204 (September 2021): 108721. http://dx.doi.org/10.1016/j.petrol.2021.108721.

Full text

APA, Harvard, Vancouver, ISO, and other styles

More sources

Dissertations / Theses on the topic "Reservoir souring"

1

Walsh, Sally. "The isolation and starvation-survival of thermophilic sulphate-reducing bacteria." Thesis, University of Exeter, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.307293.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Marsland, Simon David. "Non-oxidative dissolution of iron sulphide minerals : of relevance to inorganic chemical souring of oil reservoirs." Thesis, Imperial College London, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.326670.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Haghshenas, Mehdi. "Modeling and remediation of reservoir souring." Thesis, 2011. http://hdl.handle.net/2152/ETD-UT-2011-08-3972.

Full text

Abstract:

Reservoir souring refers to the increase in the concentration of hydrogen sulfide in production fluids during waterflooding. Besides health and safety issues, H₂S content reduces the value of the produced hydrocarbon. Nitrate injection is an effective method to prevent the formation of H₂S. Although the effectiveness of nitrate injection has been proven in laboratory and field applications and biology is well-understood, modeling aspect is still in its early stages. This work describes the modeling and simulation of biological reactions associated with reservoir souring and nitrate injection for souring remediation. The model is implemented in a general purpose adaptive reservoir simulator (GPAS). We also developed a physical dispersion model in GPAS to study the effect of dispersion on reservoir souring. The basic mechanism in the biologically mediated generation of H₂S is the reaction between sulfate and organic compounds in the presence of sulfate-reducing bacteria (SRB). Several mechanisms describe the effect of nitrate injection on reservoir souring. We developed mathematical models for biological reactions to simulate each mechanism. For every biological reaction, we solve a set of ordinary differential equations along with differential equations for the transport of chemical and biological species. Souring reactions occur in the areas of the reservoir where all of the required chemical and biological species are available. Therefore, dispersion affects the extent of reservoir souring as transport of aqueous phase components and the formation of mixing zones depends on dispersive characteristics of porous media. We successfully simulated laboratory experiments in batch reactors and sand-packed column reactors to verify our model development. The results from simulation of laboratory experiments are used to find the input parameters for field-scale simulations. We also examined the effect of dispersion on reservoir souring for different compositions of injection and formation water. Dispersion effects are significant when injection water does not contain sufficient organic compounds and reactions occur in the mixing zone between injection water and formation water. With a comprehensive biological model and robust and accurate flow simulation capabilities, GPAS can predict the onset of reservoir souring and the effectiveness of nitrate injection and facilitate the design of the process.
text

APA, Harvard, Vancouver, ISO, and other styles

Books on the topic "Reservoir souring"

1

executive, Health and safety. Oilfield Reservoir Souring (OTH). Health and Safety Executive (HSE), 1993.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

Book chapters on the topic "Reservoir souring"

1

Streets, Matthew, and Leanne Walker. "Microbial Reservoir Souring." In Microbial Bioinformatics in the Oil and Gas Industry, 207–25. Boca Raton: CRC Press, 2021. http://dx.doi.org/10.1201/9781003023395-10.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Vance, Ian, and David R. Thrasher. "Reservoir Souring: Mechanisms and Prevention." In Petroleum Microbiology, 123–42. Washington, DC, USA: ASM Press, 2014. http://dx.doi.org/10.1128/9781555817589.ch7.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Fischer, David, Monica Canalizo-Hernandez, and Amit Kumar. "Effects of Reservoir Souring on Materials Performance." In Microbiologically Influenced Corrosion in the Upstream Oil and Gas Industry, 111–37. Boca Raton : Taylor & Francis, CRC Press, 2017.: CRC Press, 2017. http://dx.doi.org/10.1201/9781315157818-6.

Full text

APA, Harvard, Vancouver, ISO, and other styles

4

Hubert, C. "Microbial Ecology of Oil Reservoir Souring and its Control by Nitrate Injection." In Handbook of Hydrocarbon and Lipid Microbiology, 2753–66. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-540-77587-4_204.

Full text

APA, Harvard, Vancouver, ISO, and other styles

5

Carlson, Hans K., and Casey R. J. Hubert. "Mechanisms and Monitoring of Oil Reservoir Souring Control by Nitrate or Perchlorate Injection." In Microbial Communities Utilizing Hydrocarbons and Lipids: Members, Metagenomics and Ecophysiology, 225–49. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-14785-3_17.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Carlson, Hans K., and Casey R. J. Hubert. "Mechanisms and Monitoring of Oil Reservoir Souring Control by Nitrate or Perchlorate Injection." In Microbial Communities Utilizing Hydrocarbons and Lipids: Members, Metagenomics and Ecophysiology, 1–25. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-319-60063-5_17-1.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Gittel, Antje. "Problems Caused by Microbes and Treatment Strategies Monitoring and Preventing Reservoir Souring Using Molecular Microbiological Methods (MMM)." In Applied Microbiology and Molecular Biology in Oilfield Systems, 103–7. Dordrecht: Springer Netherlands, 2010. http://dx.doi.org/10.1007/978-90-481-9252-6_12.

Full text

APA, Harvard, Vancouver, ISO, and other styles

8

Xue, Yuan, Gerrit Voordouw, and Lisa M. Gieg. "Laboratory Protocols for Investigating Microbial Souring and Potential Treatments in Crude Oil Reservoirs." In Springer Protocols Handbooks, 183–210. Berlin, Heidelberg: Springer Berlin Heidelberg, 2015. http://dx.doi.org/10.1007/8623_2015_115.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Westlake, D. W. S. "Ch. R-16 Microbial Ecology of Corrosion and Reservoir Souring." In microbial enhancement of oil recovery—recent advances, Proceedings of the 1990 international conference on microbial enhancement of oil recovery, 257–63. Elsevier, 1991. http://dx.doi.org/10.1016/s0376-7361(09)70164-5.

Full text

APA, Harvard, Vancouver, ISO, and other styles

Conference papers on the topic "Reservoir souring"

1

Evans, Paul. "Reservoir Souring Modelling, Prediction and Mitigation." In ASME 2008 27th International Conference on Offshore Mechanics and Arctic Engineering. ASMEDC, 2008. http://dx.doi.org/10.1115/omae2008-57085.

Full text

Abstract:

The prediction of reservoir souring due to the activity of sulphate-reducing bacteria (SRB) during water injection is an important consideration in material selection for wells and production facilities. A number of reservoir souring models have been developed in the past 16 years or so, with the objective of predicting the timing and magnitude of H2S production. The results of the reservoir souring models are dependent on a number of reservoir geometry, geochemical, microbiological and reservoir geology parameters. For example, the SRB activity is dependent on the availability of essential nutrients such as sulphate and dissolved hydrocarbons in the injection and formation waters. Environmental parameters such as temperature and pressure control in which parts of the reservoir SRB can be active. Water flow path and extent of water breakthrough has a major impact on H2S production. Very low reservoir permeabilities will restrict the movement of SRB into the rock matrix and certain minerals have the ability to scavenge H2S within the reservoir. All of these parameters must be accounted for in a reservoir souring simulation, and this requires the cooperation of reservoir engineers, geologists, production chemists and facilities engineers. Several techniques have been employed in the oil industry to try to control the generation of H2S within the reservoir. These include the application of biocides to control SRB activity, the injection of nitrate to stimulate other bacterial populations to out compete SRB for available food sources and the use of sulphate removal technologies to minimize sulphide production.

APA, Harvard, Vancouver, ISO, and other styles

2

Delshad, Mojdeh, Steven Lawrence Bryant, Kamy Sepehrnoori, and Mohammad Ali Farhadinia. "Development of a Reservoir Simulator for Souring Predictions." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/118951-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Seto, C. J., and D. A. Beliveau. "Reservoir Souring in the Caroline Field." In SPE/CERI Gas Technology Symposium. Society of Petroleum Engineers, 2000. http://dx.doi.org/10.2118/59778-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

4

Kalpakci, Bayram, N. F. Magri, P. D. Ravenscroft, M. D. K. McTeir, and G. T. Arf. "Mitigation of Reservoir Souring—Decision Process." In SPE International Symposium on Oilfield Chemistry. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/28947-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

5

Salimi, Hamidreza, Maryam Namdar Zanganeh, Sven McCarthy, Lucian Pirlea, Haitham Balushi, Mustafa Lawati, and Mohamed Yarabi. "A Novel Quantitative and Predictive Reservoir-Souring Approach to Assess Reservoir Souring During Planned-Waterflood Development Plan." In Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/197616-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

De Siqueira, Alexandre Guedes, Carlos Henrique Vieira Araujo, Rodrigo Reksidler, and Marcio de Castro Pereira. "Uncertainty Analysis Applied to Biogenic Reservoir Souring Simulation." In EUROPEC/EAGE Conference and Exhibition. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/121175-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Kathrada, Muhammad. "Combining Sparse Data with Reaction Kinetics Using Fuzzy Logic to Predict Reservoir Souring." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21394-ms.

Full text

Abstract:

Abstract Hydrogen Sulphide (H2S) is a colourless, flammable and highly toxic gas with a strong odour of rotten eggs that is found in many reservoir fluids and aquifers in the world. This gas is commonly a result of "reservoir souring" – a process which increases the H2S concentration. Increasing amounts of this gas pose serious health, safety and environmental concerns. This can result in significant costs associated with replacement of downhole and surface equipment and increased processing costs, but more lethally a potential loss of life. Many reservoirs particularly those undergoing waterflooding face increasing levels of hydrogen sulphide (H2S) production with time. H2S is a highly toxic gas that can be fatal even at low concentrations. Being able to predict the risk potential of a particular reservoir to increasing H2S production with time would be highly valuable. The objective is to determine apriori whether a reservoir would likely see dangerously high levels of H2S being produced during the lifetime of the reservoir, and if so, be a catalyst in supporting further investigation and mitigation of H2S early in the reservoir development. There is very little published field data with regards to reservoir souring, hence a purely data driven model would not be possible to create. However, we do have a good understanding of the reaction kinetics that goes into the biological process that generates H2S. To this end the best modelling paradigm that can assimilate sparse data with first principles dynamics is fuzzy logic. A fuzzy logic model has been built around the reaction kinetics and then conditioned to the published field data. The model created matches the published field data fairly well. It is now a ready tool that can be used by engineers to make a quick assessment of their reservoirs before going into full blown expensive sampling and laboratory analysis. The novel aspect of this paper is being able to use fuzzy logic to combine the first principles chemistry together with sparse data to produce a model that can be used practically. Fuzzy Logic has been out of the news of late as machine learning and neural networks are the current hot potatoes, however it is often overlooked that fuzzy logic can still be used in low dimensional cases where only sparse data is available.

APA, Harvard, Vancouver, ISO, and other styles

8

Jack, Thomas R., Aleksandr Grigoryan, A. Lambo, Gerrit Voordouw, and Tom Granli. "Troubleshooting Nitrate Field Injections for Control of Reservoir Souring." In SPE International Symposium on Oilfield Chemistry. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/121573-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Dunsmore, B., P. J. Evans, M. Jones, S. Burton, and H. M. Lappin-Scott. "When Is Reservoir Souring a Problem for Deepwater Projects?" In Offshore Technology Conference. Offshore Technology Conference, 2006. http://dx.doi.org/10.4043/18347-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

10

Shi, Xiang, Julia R. de Rezende, and Kenneth Sorbie. "Microbial Ecology Metrics to Assess the Effect of Biocide on Souring Control and Improve Souring Modelling." In SPE International Oilfield Corrosion Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205037-ms.

Full text

Abstract:

Abstract Reservoir souring is a long-standing issue for the oil and gas industry caused by sulfate-reducing microorganisms (SRM) producing H2S from sulfate ions. In this work, we investigated the connections between the development of souring and the change in three key microbial ecology metrics: the abundance, alpha diversity and community structure of a souring microbiota under the biocide treatment of 100 ppm glutaraldehyde (henceforth referred to as GA). These are studied in sand-packed flow-through bioreactors during and after the biocide treatment using cutting-edge DNA assays. Our study suggests that the rebound of microbial sulfide production after the 100 ppm GA treatment is closely associated with the recovery in microbial abundance and microbial alpha diversity. The study also shows that 100 ppm GA treatment may lead to a measurable shift in the SRM community structure. By comparing the effluent microbial community with the sand microbial community, the study suggests that the change in alpha diversity of the produced water microbial community might be an early warning for the sulfide breakthrough due to souring recurrence in practice. This work explores the relationship between souring and the underlining microbial community behaviours in response to the 100 ppm GA treatment and, to characterise these changes, we propose measurable metrics. A conceptual model is also proposed describing the near-term biological process behind the biocide treatment-recovery cycle in a souring scenario. Finally, this work highlights the potential applications and caveats of harnessing the increasingly available field microbial community data for the improvement of souring modelling and field souring control strategies.

APA, Harvard, Vancouver, ISO, and other styles

We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!