Recent Developments and Updated Screening Criteria of Enhanced Oil Recovery Techniques

Ahmad, Ahmad Nur Aizat; Bai, Baojun

doi:10.2523/130726-ms

Cited by 7 publications

(11 citation statements)

References 29 publications

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“…From all the floodings carried out with secondary FMB injection, continuous oil production was observed until residual oil saturation was attained when no further oil production occurs. This process is synonymous to water flooding that is usually implemented in oil reservoir after primary recovery process (Al-Adasani and Bai, 2010). During the low temperature flooding, oil production of 65.94% OIIP was achieved, which is comparable with results of previous studies such as Nasralla et al (2011) andAlQuraishi, et al (2015).…”

Section: B Discussion Of Resultssupporting

confidence: 87%

“…Crude oil production sequence from reservoirs located in subsurface under high pressure and temperature is generally classified as primary, secondary and tertiary recovery processes (Al-Adasani and Bai, 2010). The aftermath effect of poor displacement efficiency of primary oil recovery by pressure depletion and secondary oil recovery by water flooding is oil trapping.…”

Section: Introductionmentioning

confidence: 99%

“…The macroscopic factors such as permeability heterogeneity, viscous fingering and negative capillary force at oil-water interface result in remaining oil saturation in the unswept region. Oil production enhancement processes will therefore require alteration of these forces acting on the system through the use of appropriate enhanced oil recovery (EOR) techniques (Al-Adasani and Bai, 2010).…”

Section: Introductionmentioning

confidence: 99%

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Experimental Investigation of Temperature Effects on Low Salinity Enzyme Enhanced Oil Recovery Process

Udoh¹

2020

Nig. J. Technol. Dev.

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In this paper, the effect of temperature on low salinity brine and combined low salinity enzyme oil recovery processes in sandstone rock sample was experimentally investigated. The core flooding displacement tests were conducted with the injection of the enzyme in post-tertiary mode after secondary high salinity brine and tertiary low salinity brine injection processes. Effluents analyses of each of the flooding were carried out and used to evaluate the effect of temperature on rock-fluid interactions and enhanced oil recovery processes. The results showed that tertiary low salinity brine injection and post-tertiary enzyme injection increased recovery by 2.4-8.72% over the secondary high salinity brine flooding at 25 oC. Also, increase in oil recovery (0.57-13.18%) was observed with increase in the system temperature from 25 oC to 70 oC. Furthermore, the effluent of the 70 oC flooding was associated with the earliest low salinity brine ionic breakthrough front at 10 injected pore volume, while the 25 oC flooding breakthrough front occurred at 22 pore volume. However, no obvious effect of temperature on pH of the effluents was observed with all the floodings, but temperature effects were observed with the conductivity and ionic concentrations of all the effluents as evident by varied breakthrough times. Hence, the observed increased recovery in this study is attributable to combined effects of electric double-layer expansion, oil viscosity reduction and interfacial tension reduction. This novel study of the combined low salinity enzyme injection process is significant for the design of enzyme enhanced oil recovery processes. Keywords: Enhanced oil recovery, enzyme, sandstone, low salinity, core flooding, temperature.

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Section: B Discussion Of Resultssupporting

confidence: 87%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Experimental Investigation of Temperature Effects on Low Salinity Enzyme Enhanced Oil Recovery Process

Udoh¹

2020

Nig. J. Technol. Dev.

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“…EOR is a process done after the primary and secondary recovery phase which involves the injection of various type of fluids into a reservoir, then interacts with the system's physical and chemical properties in order to give subsidiary energy for a more favorable oil recovery (Green and Willhite, 1998). There are various types of EOR, such as miscible or immiscible gas injection, chemical injection, thermal recovery, microbial injection, and combination of EOR (Aladasani, 2010). The challenges of EOR development in Indonesia are varied from complicated bureaucracy and regulations by the government, many technical uncertainties, and most importantly the high-priced cost of an EOR study and project which make EOR is classified as a long-term solution.…”

Section: Introductionmentioning

confidence: 99%

Risk Mitigation and Mapping on Tubular System During Microbial Huff and Puff Injection Coupled with Lean Six Sigma Approach at Field X

Chandra

Aziz

Daton

et al. 2021

JPGT

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Increasing demand of oil in Indonesia is in contrast with the decreasing oil production every year. Enhanced oil recovery (EOR) has become one of the most favorable method in maximizing the production of mature fields with various applications and research has been done on each type, especially microbial EOR (MEOR). “X” field is a mature oil field located in South Sumatra that has been actively producing for more than 80 years and currently implementing MEOR using huff and puff injection. However, there are some potential risks regarding MEOR processes that may inhibit the production by damaging the well’s tubular system, particularly microbially induced corrosion (MIC). This study reviews the risk mitigation and mapping to prevent corrosion on tubular system during MEOR huff and puff processes, equipped with the approach of Lean Six Sigma.The mitigation and mapping process follow the framework of define, measure, analyze, improve, and control (DMAIC). It starts with defining the problem using supplier-input-process-output-customer (SIPOC) diagram after all the field data necessary has already been collected, then measuring the corrosion rate model using ECE™ software as well as conducting sensitivity analysis of the fluid rates. The analyze phase involves constructing fishbone diagram to identify the root causes, comparison with industry’s specification and standard, and analysis of chromium effect on corrosion rates. Further simulation is conducted to support the analysis and to ensure the improvements and sustainability of the design selection.Based on the simulation results, the normal corrosion rate ranging from 0.0348 – 0.039 mm/year and the pH is around 4.03 – 5.25, while the ±30% fluid rate sensitivity results shown that the change of water flowrate is more sensitive than oil flowrate with the corrosion rate approximately 0.0275 – 0.048 mm/year. The fishbone diagram identifies that material selection and environmental condition as the main root causes, then corrosion resistant alloy (CRA) is used in the tubing string to prevent corrosion in the future by using super 13Cr martensitic steel (modified 2Ni-5Mo-13Cr) as the most suitable material. Further simulation on chromium content supports the selection that corrosion rate can be reduced by adding the chromium content in the steel. The completion design is then capped with choosing the Aflas® 100S/100H fluoro-elastomer as the optimum material for packer and sealing. Overall, the Lean Six Sigma approach has been successfully applied to help the analysis in this study.

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“…EOR methods are the most common approaches after primary and secondary oil production [33][34][35][36][37]. A growing body of literature recognises the importance of EOR processes and enhancing the effectiveness of these methods [38][39][40][41][42][43][44]. Carbon dioxide (CO2), nitrogen (N2) and methane (CH4) flooding are commonly considered as EOR methods.…”

Section: Introductionmentioning

confidence: 99%

Mechanistic study to investigate the effects of different gas injection scenarios on the rate of asphaltene deposition: An experimental approach

Dashti

Zanganeh

Kord

et al. 2020

Fuel

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Asphaltene deposition during enhanced oil recovery (EOR) processes is one of the most problematic challenges in the petroleum industry, potentially resulting in flow blockage. Our understanding of the deposition mechanism with emphasis on the rate of the asphaltene deposition is still in its infancy and must be developed through a range of experiments and modelling studies. This study aims to investigate the rate of asphaltene deposition through a visual study under different gas injection scenarios. To visualise the asphaltene deposition, a high-pressure setup was designed and constructed, which enables us to record high-quality images of the deposition process over time. Present research compares the effects of nitrogen (N2), carbon dioxide (CO2) and methane (CH4) on the rate of asphaltene deposition at different pressures. The experimental results in the absence of gas injection revealed that the rate of asphaltene deposition increases at higher pressures. The results showed that the rate of asphaltene deposition in the case of CO2 injection is 1.2 times faster than CH4 injection at 100 bar pressure. However, N2 injection has less effect on the deposition rate. Finally, it has been concluded that the injection of CO2 leads to more asphaltene deposition in comparison with CH4 and N2. Moreover, the experimental results confirmed that gas injection affects the mechanism of asphaltene flocculation and leads to the formation of bigger 2 flocculated asphaltene particles. The findings of this study can help for a better understanding of the mechanism of the asphaltene deposition during different gas-EOR processes.

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Recent Developments and Updated Screening Criteria of Enhanced Oil Recovery Techniques

Cited by 7 publications

References 29 publications

Experimental Investigation of Temperature Effects on Low Salinity Enzyme Enhanced Oil Recovery Process

Experimental Investigation of Temperature Effects on Low Salinity Enzyme Enhanced Oil Recovery Process

Risk Mitigation and Mapping on Tubular System During Microbial Huff and Puff Injection Coupled with Lean Six Sigma Approach at Field X

Mechanistic study to investigate the effects of different gas injection scenarios on the rate of asphaltene deposition: An experimental approach

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