Recovery potential of biopolymer (B-P) formulation from Solanum tuberosum (waste) starch for enhancing recovery from oil reservoirs

Olabode, Oluwasanmi; Ojo, Temiloluwa; Oguntade, Tomiwa; Oduwole, Doyin

doi:10.1016/j.egyr.2020.05.027

Cited by 17 publications

(9 citation statements)

References 4 publications

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“…It is necessary to find the optimum polymer concentration that will yield the most economic oil recovery to reduce the costs of polymer injection. Biodegradable polymers such as described by Olabode et al [15] can also be experimented to compare with other bioand non-biopolymers. The advent of nanofluids and polymer nanoparticles (PNP) has helped to increase polymer effective-ness and reduce its adsorption rates in reservoirs for enhanced oil recovery (Nezhad et al, [35], Cheraghian et al, [1] & [36]).…”

Section: Conclusion and Recommendationmentioning

confidence: 99%

“…Costs incurred during large field scale deployment of polymers, high adsorption rates, and adverse environmental impacts have led to the advent of biopolymers (BP) for enhanced oil recovery processes. Nowadays, biopolymers are extracted from waste food materials such as potatoes peels [15] and banana peels and mango kernel [16] through an esterification and carboxymethylation [17].…”

Section: Introductionmentioning

confidence: 99%

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Comparative Study of Biopolymer Flooding: A Core Flooding and Numerical Reservoir Simulator Validation Analysis

Sowunmi

Efeovbokhan

Orodu

et al. 2022

Modelling and Simulation in Engineering

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Polymers increase the macroscopic efficiency of the flooding process and increase crude oil recovery. The viscosity of 3 polymers xanthan, guar, and Arabic gums is measured in the lab and experimented with as EOR options. Xanthan and guar gum polymers are measured in weight percentages of 0.1, 0.2, 0.2, 0.4, 0.5, and 1, while gum Arabic is measured in 0.4, 0.5, 1, 5, 10, and 15 weight percentages. The viscosity experiments showed that gum Arabic had the lowest viscosity at 15% wt. Xanthan gum and guar gum had significantly higher viscosities than gum Arabic at corresponding weight percentages. At the same weight of 0.5%, xanthan, guar, and Arabic gums recorded a 63%, 53%, and 46% oil recovery, respectively. Due to the limitations surrounding core flooding experiments such as human error, equipment failure, and measurement of oil recoveries, it is necessary to validate the results obtained with other methods such as reservoir simulation. A reservoir model is built (using Eclipse) and incorporated with polymer and viscosity functions measured in the lab to validate results from the core flooding experiments. Peak oil recovery of 9.96%, 9.95%, and 9.90% was recorded for xanthan, guar, and Arabic gum, respectively, at a weight percentage of 0.5% weight. Also, increasing the wt% of injected polymers increases oil recovery. Results also indicate that the trend of oil recoveries during core flooding follows that observed during reservoir simulation and oil production increased as percentage weight increased for all the polymer cases considered.

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Section: Conclusion and Recommendationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Comparative Study of Biopolymer Flooding: A Core Flooding and Numerical Reservoir Simulator Validation Analysis

Sowunmi

Efeovbokhan

Orodu

et al. 2022

Modelling and Simulation in Engineering

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“…Due to high water cuts across the cases, operators will have to consider the cost of water treatment facilities for the period of use. Thus, related EOR schemes such as prescribed by Olabode et al [16] and Olabode et al [17] should be considered. The results obtained in this project are ideal results but did not consider other physical factors.…”

Section: Conclusion and Recommendationmentioning

confidence: 99%

Modelling Low-Salinity Water Flooding as a Tertiary Oil Recovery Technique

Olabode

Alaigba

Oramabo

et al. 2020

Modelling and Simulation in Engineering

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In this project, low-salinity water flooding has been modeled on ECLIPSE black oil simulator in three cases for a total field production life of twenty-five years. In the first case, low-salinity water flooding starts fifteen years after secondary water flooding. For the second case, low-salinity water flooding starts five years after secondary water flooding and runs till the end of the field production life. For the third case, low-salinity water flooding starts five years after secondary water flooding, but low-salinity water flooding is injected in measured pore volumes for a short period of time; then, high-salinity water flooding was resumed till the end of the field production life. This was done to measure the effect of low-salinity water flooding as slug injection. From the three cases presented, oil recovery efficiency, field oil production rate, and field water cut were observed. Increased percentages of 22.66%, 35.12%, and 26.77% were observed in the three cases, respectively.

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“…d Water cut profile in ultra-thin oil rim reservoirs before the implementation of secondary and enhanced oil recovery as described by Olabode et al (2018c). Enhanced oil recovery methods introduced by Olabode et al (2020a) and Olabode et al (2020b) for heavy oil reservoirs can also be considered for heavymedium oil rim reservoirs. These models can be used as a matrix for similar field case studies.…”

Section: Conclusion and Recommendationmentioning

confidence: 99%

Optimizing productivity in oil rims: simulation studies on horizontal well placement under simultaneous oil and gas production

Olabode

Isehunwa

Orodu

et al. 2020

J Petrol Explor Prod Technol

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Thin oil rim reservoirs are predominantly those with pay thickness of less than 100 ft. Oil production challenges arise due to the nature of the gas cap and aquifer in such reservoirs and well placement with respect to the fluid contacts. Case studies of oil rim reservoir and operational properties from the Niger-Delta region are used to build classic synthetic oil rim models with different reservoir parameters using a design of experiment. The black oil simulation model of the ECLIPSE software is activated with additional reservoir properties and subsequently initialized to estimate initial oil and gas in place. To optimize hydrocarbon production, 2 horizontal wells are initiated, each to concurrently produce oil and gas. Well placements of (0.5 ft., 0.25 ft. and 0.75 ft.) are made with respect to the pay thickness and then to the fluid contacts. The results show that for oil rim with bigger aquifers, an oil recovery of 8.3% is expected when horizontal wells are placed at 0.75 ft. of the pay thickness away from the gas oil contact, 8.1% oil recovery in oil rims with larger gas caps with completions at 0.75 ft. of the pay zone from the gas oil contacts, 6% oil recovery with relatively small gas caps and aquifer and 9.3% from oil rims with large gas caps and aquifers, with completions at mid-stream of the pay zone.

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Recovery potential of biopolymer (B-P) formulation from Solanum tuberosum (waste) starch for enhancing recovery from oil reservoirs

Cited by 17 publications

References 4 publications

Comparative Study of Biopolymer Flooding: A Core Flooding and Numerical Reservoir Simulator Validation Analysis

Comparative Study of Biopolymer Flooding: A Core Flooding and Numerical Reservoir Simulator Validation Analysis

Modelling Low-Salinity Water Flooding as a Tertiary Oil Recovery Technique

Optimizing productivity in oil rims: simulation studies on horizontal well placement under simultaneous oil and gas production

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