Influence of temperature field on rock and heavy components variation during in-situ combustion process

Zhao, Renbao; Chun-hui, Zhang; Yang, Fengxiang; Heng, Minghao; Shao, Pengtao; Yan-jie, Wang

doi:10.1016/j.fuel.2018.05.037

Cited by 34 publications

(8 citation statements)

References 34 publications

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“…In other words, migration of particles caused the increase of the pressure drop. 50 The cumulative oil recovery curves in Figure 14 shared good consistency with Table 3. The slope of the oil recovery curve of DN-1-assisted hot water flooding obviously went up at 55 °C after DN-1 injection, which meant more oil was displaced.…”

Section: Industrial and Engineering Chemistry Researchsupporting

confidence: 60%

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Amphiphilic-Polymer-Assisted Hot Water Flooding toward Viscous Oil Mobilization

Liu

Mendiratta

Chen

et al. 2019

Ind. Eng. Chem. Res.

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Heavy oil recovery is the most challenging part for the petroleum industry, and several techniques including steam and water injection are currently used that are either energy intensive, expensive, or less efficient. This study aims to evaluate a novel amphiphilic viscosity reducing polymer (DN-1) used along with hot water flooding for promoting viscous oil mobilization. Its performance for heavy oil mobilization was evaluated using viscosity measurements at different temperatures followed by core flooding experiments. Our results indicate that DN-1 at low concentrations could form 3D networks and stable aggregates. DN-1 featured good interfacial properties including low CMC, low IFT, and small contact angle. Even at low concentration it could form dynamic oil in water emulsions, thereby causing easy emulsification and fast demulsification. The injection pressure of DN-1 was much smaller than that of the conventional polymers or associative polymers used for heavy oil development and is beneficial for oil recovery in real reservoir scenarios where a high-pressure gradient cannot be achieved. Interestingly, unlike polymer flooding, this amphiphilic polymer increased displacing phase viscosity, while it simultaneously reduced the displaced oil viscosity. Finally, DN-1-assisted hot water flooding could impressively achieve an ultimate recovery factor of 75.7% at 115 °C that was similar to that by hot water flooding at 175 °C. Even when DN-1 was injected at 55 °C, which was the reservoir temperature, the oil recovery factor was still 12.8% higher than hot water flooding, proving it as an efficient material in improving heavy oil recovery at low temperatures. As per our knowledge, this is the first report on the use of amphiphilic-polymer-assisted hot water flooding for heavy oil recovery.

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Section: Industrial and Engineering Chemistry Researchsupporting

confidence: 60%

“…Alternatively, this could also be attributed to the weakened cementation between core particles due to the high temperature. In other words, migration of particles caused the increase of the pressure drop …”

Section: Results and Discussionmentioning

confidence: 99%

Amphiphilic-Polymer-Assisted Hot Water Flooding toward Viscous Oil Mobilization

Liu

Mendiratta

Chen

et al. 2019

Ind. Eng. Chem. Res.

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“…The studies about the SCW technique for shale rock require the selection of a method that can provide knowledge about the converted products' structure and composition. One of the informative instrumental methods is considered the FTIR spectroscopy, which allows for the evaluation of transformations not only in various hydrocarbons, but also in functional groups, at natural and technology-related processes [42,43]. The IR spectra of the obtained hydrocarbon groups are presented in Figure 5.…”

Section: Resultsmentioning

confidence: 99%

Heavy Oil Hydrocarbons and Kerogen Destruction of Carbonate–Siliceous Domanic Shale Rock in Sub- and Supercritical Water

et al. 2020

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This paper discusses the results of the influences of subcritical (T = 320 °C; P = 17 MPa) and supercritical water (T = 374 °C; P = 24.6 MPa) on the yield and composition of oil hydrocarbons generated from carbonaceous–siliceous Domanic shale rocks with total organic content (Corg) of 7.07%. It was revealed that the treatment of the given shale rock in sub- and supercritical water environments resulted in the decrease of oil content due to the intensive gas formation. The content of light hydrocarbon fractions (saturated and aromatic hydrocarbons) increased at 320 °C from 33.98 to 39.63%, while at 374 °C to 48.24%. Moreover, the content of resins decreased by almost twice. Insoluble coke-like compounds such as carbene–carboids were formed due to decomposition of kerogen after supercritical water treatment. Analysis of oil hydrocarbons with FTIR method revealed a significant number of oxygen-containing compounds, which are the hydrogenolysis products of structural fragments formed after destruction of kerogen and high-molecular components of oil. The gas chromatography–mass spectroscopy (GC–MS) method was applied to present the changes in the composition of mono- and dibenzothiophenes, which indicate conversion of heavy components into lighter aromatic hydrocarbons. The specific features of transforming trace elements in rock samples, asphaltenes, and carbene–carboids were observed by using the isotopic mass-spectrometry method.

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“…From the morphology of the core samples, it can be inferred that the sweep efficiency can reach 90% in a specific well. 64,157 In addition, the produced oil properties varied by well locations and sample collecting timings. The produced oil was upgraded based on the SARA fraction analysis.…”

Section: Xinjiang Oilfield In Chinamentioning

confidence: 99%

“…When the reservoir was converted to an ISC, the estimated OOIP was around 40%. The pilot ISC process was operated, and the process was monitored by temperature and produced oil properties. ,,− Dynamic strategies were applied to improve the combustion front sweep efficiency. A pattern drive was operated at the first stage, and a line drive was followed as a second stage to obtain better control of combustion front propagation.…”

Section: Field Applicationsmentioning

confidence: 99%

In-Situ Combustion for Heavy Oil and Oil Sands Recovery: Recent Progress, Field Applications, and Future Perspectives

Yang,

Chai,

Yuan

et al. 2024

Energy Fuels

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Heavy oil and bitumen resources are estimated to account for about 70% of the global oil reserves. Recovery of these resources economically and environmentally is crucial to satisfy the crude oil demand in the next few decades. Steam injection-based techniques encounter challenges of large water usage, high operating costs, and huge greenhouse gas (GHG) emissions. In-situ combustion, which utilizes the heat generated by oxidation reactions between crude oil and oxygen, is an alternative and promising thermal technique to recover heavy oil and bitumen resources with the expectation to reduce water usage and lower operating costs. But complexity of oxidation behavior and uncertainty of in-situ combustion (ISC) performance prediction have restricted the field application of the ISC process. This paper provides a comprehensive review of the most recent studies about the ISC process and updated field projects. Various experimental studies are first presented to investigate the oxidation mechanisms of crude oil and the ISC enhanced oil recovery (EOR) mechanism. Based on the experimental advances, recent progress on reaction kinetics models and field scale modeling of ISC is presented. Subsequently, currently active field projects have been updated to provide the best practice of field operation. Finally, future perspectives of ISC for heavy oil or oil sands recovery are identified with a focus on in-situ catalytic upgrading and hydrogen generation.

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Influence of temperature field on rock and heavy components variation during in-situ combustion process

Cited by 34 publications

References 34 publications

Amphiphilic-Polymer-Assisted Hot Water Flooding toward Viscous Oil Mobilization

Amphiphilic-Polymer-Assisted Hot Water Flooding toward Viscous Oil Mobilization

Heavy Oil Hydrocarbons and Kerogen Destruction of Carbonate–Siliceous Domanic Shale Rock in Sub- and Supercritical Water

In-Situ Combustion for Heavy Oil and Oil Sands Recovery: Recent Progress, Field Applications, and Future Perspectives

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