Sensitivity analysis and optimization on effective parameters during chemical enhanced oil recovery (CEOR) using experimental design and numerical simulation

Firozjaii, Ali Mohsenatabar; Akbari, Majid; Zargar, Ghasem

doi:10.1080/15567036.2018.1549164

Cited by 9 publications

(5 citation statements)

References 21 publications

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“…In recent decade, several novel synthetic polymers, such as modified HPAM-based polymers have been extensively studied for cEOR field pilot projects globally and in varying reservoir conditions [ 44 , 78 , 104 , 169 , 176 , 202 , 203 , 204 , 205 , 206 , 207 , 207 ]. Nevertheless, to the best of our knowledge, there have only been a few polymer flooding projects undertaken in carbonate reservoirs [ 175 , 208 , 209 ].…”

Section: Numerical Studies and Field Applicationsmentioning

confidence: 99%

“… Two polymers 340 and 454 PAM were studied to ascertain their applicability in the Owasco Unit oil field in the United State (US). In this case, the reservoir lithology was sandstone with a temperature of 77

C [ 205 ]. The upshots from these projects was that emulsion-based synthetic polymer projects encountered greater issues of injectivity in contrast to the projects where the powder-type synthetic polymers were used.…”

Section: Numerical Studies and Field Applicationsmentioning

confidence: 99%

“…There are a few noteworthy recommendations that will aid operators in the appropriate design and planning of polymer-based EOR projects in carbonate reservoirs under harsh conditions, such as high temperature, high salinity, and low permeability. Several recent screening studies and core-flooding tests have led to these recommendations [ 42 , 62 , 65 , 67 , 70 , 71 , 88 , 119 , 120 , 128 , 129 , 150 , 155 , 162 , 163 , 164 , 169 , 170 , 171 , 172 , 173 , 175 , 176 ], along with the simulation runs and field pilots [ 42 , 44 , 78 , 88 , 104 , 169 , 176 , 202 , 203 , 204 , 205 , 206 , 207 , 212 ] in carbonate rocks. These following recommendations will aid in improved designs for field implementation and are intended to possibly resolve the challenges of high temperature, high salinity/hardness, and injectivity issues in low-permeability carbonate formations.…”

Section: Recommended Practices For Polymer Flooding In Harsh Conditionsmentioning

confidence: 99%

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Updated Perceptions on Polymer-Based Enhanced Oil Recovery toward High-Temperature High-Salinity Tolerance for Successful Field Applications in Carbonate Reservoirs

2022

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The aging of the existing reservoirs makes the hydrocarbon extraction shift toward newer reserves, and harsh conditioned carbonates, which possess high temperature and high salinity (HTHS). Conventional polymer-flooding fails in these HTHS carbonates, due to precipitation, viscosity loss, and polymer adsorption. Therefore, to counteract these challenges, novel polymer-based cEOR alternatives employ optimized polymers, polymer–surfactant, and alkali–surfactant–polymer solutions along with hybrid methods, which have shown a potential to target the residual or remaining oils in carbonates. Consequently, we investigate novel polymers, viz., ATBS, Scleroglucan, NVP-based polymers, and hydrophobic associative polymers, along with bio-polymers. These selected polymers have shown low shear sensitivity, low adsorption, and robust thermal/salinity tolerance. Additionally, adding an alkali-surfactant to polymer solution produces a synergy effect of improved mobility control, wettability alteration, and interfacial-tension reduction. Thus, enhancing the displacement and sweep efficiencies. Moreover, low-salinity water can precondition high-salinity reservoirs before polymer flooding (hybrid method), to decrease polymer adsorption and viscosity loss. Thus, this paper is a reference for novel polymers, and their hybrid techniques, to improve polymer-based cEOR field applications under HTHS conditions in carbonates. Additionally, the recommendations can assist in project designs with reasonable costs and minimal environmental impact. The implication of this work will aid in supplementing the oil and gas energy sector growth, making a positive contribution to the Middle Eastern economy.

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Section: Numerical Studies and Field Applicationsmentioning

confidence: 99%

Section: Numerical Studies and Field Applicationsmentioning

confidence: 99%

Section: Recommended Practices For Polymer Flooding In Harsh Conditionsmentioning

confidence: 99%

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Updated Perceptions on Polymer-Based Enhanced Oil Recovery toward High-Temperature High-Salinity Tolerance for Successful Field Applications in Carbonate Reservoirs

2022

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“…Rajabi et al [21] used a PB experimental design to analyze sixteen parameters affecting the development performance of the PUNQ-S3 oilfield and finally screened out seven main parameters using the objective function of net present value. Firozjaii et al [22] conducted the numerical simulation study on factors affecting chemical flooding for enhanced oil recovery. Taking oil recovery as the objective function, the fractional factorial design was used to obtain the combinations of different factors at different levels, and comparative analysis was carried out.…”

Section: Introductionmentioning

confidence: 99%

Study on Main Factors Controlling Development Performance of Heterogeneous Composite Flooding in Post-Polymer Flooding Reservoir

Zhou,

Zhao,

Zhou

2024

Processes

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Heterogeneous composite flooding has performed well with regard to enhanced oil recovery after polymer flooding in recent years. In order to significantly increase oil recovery, the development parameters should be designed differently for each well. However, it is difficult to rapidly allocate development parameters through the lowering of computational costs. Therefore, the authors of this paper carried out research to clarify the main controlling factors of parameter allocation. Firstly, the numerical simulation domain was separated into several regions, with injection wells and production wells at the center of each region. The statistical parameters of each region were calculated. Then, the water injection rate, liquid production rate, and chemical agent concentration were allocated based on the proportion of statistical parameters in each region. A large number of development schemes were designed by combining different injection and production allocations that were calculated based on each statistical parameter. Finally, the development performance of each scheme was simulated and analyzed. The statistical parameters corresponding to the best performance scheme were regarded as the main controlling factors of heterogeneous composite flooding after polymer flooding. These results showed that the main controlling factors for the allocation of the water injection rate were pore volume and permeability variation coefficient. The main controlling factors for liquid production rate were the remaining oil saturation, formation coefficient, and reservoir pressure. The main controlling factors for chemical agent concentration were pressure and permeability variation coefficient. These findings concerning the main factors controlling development parameter allocation were validated by practical application in several well groups of an actual reservoir model. This study provides references for improving heterogeneous composite flooding performance for post-polymer flooding reservoirs in the future.

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“…Chemical flooding is a popular enhanced oil recovery (EOR) method. Studies have shown that this method can be effectively implemented in sandstone and carbonate reservoirs to mobilize/recover trapped residual oil from the rock pore spaces (Bashir et al, 2021; Mohsenatabar Firozjaii et al, 2019; Saha et al, 2018). Injecting chemicals into the reservoir activates several liquid–liquid and solid–liquid interactions.…”

Section: Introductionmentioning

confidence: 99%

Adsorption behavior of surfactants on sandstone reservoir rocks with carbonate cements and its influence on wettability alteration

Phukan,

Saha,

Mazumdar

2023

J Surfact & Detergents

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This study investigates the adsorption behaviors of surfactants in sandstone reservoir rocks containing various amounts of carbonate cement/minerals and their impact on wettability alteration under low‐salinity conditions. Two types of rock samples from sandstone reservoirs of Assam oilfields in India are selected based on XRD results. These rock types are (i) high carbonate cement (HCC) core sample with higher carbonate cement (calcite 5.6% and dolomite 4.0%), and (ii) low carbonate cement (LCC) core sample with lower carbonate cement (calcite = 0.5% and dolomite 0%). The study reveals that the mineralogy of sandstone reservoir rocks especially the carbonate minerals affects the brine‐rock interactions including wettability alternation and surfactant adsorption. Notable differences (2° to 8°) in contact angles for the two rock types at different salinities revealed that carbonate cement in sandstone thus impacts brine‐rock interactions. Further, low salinity surfactant (LSS) could positively alter the wettability of both rock types to water‐wet conditions (contact angle <60°). The most favorable wettability alterations (up to 30°) were achieved with cationic LSS solutions for both core types. Using LSS solutions also reduced the adsorption of anionic surfactant by around 40% and 33% for HCC and LCC rock samples, respectively. The study's novelty emanates from investigating the impact of sandstone reservoir rock mineralogy with varying amounts of carbonate cements on the adsorption behavior of surfactants under low‐salinity conditions. Moreover, this study provides a better understanding of the interrelationship existing between the degree of wettability alteration and the amount of surfactant adsorbed by sandstone rocks.

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Sensitivity analysis and optimization on effective parameters during chemical enhanced oil recovery (CEOR) using experimental design and numerical simulation

Cited by 9 publications

References 21 publications

Updated Perceptions on Polymer-Based Enhanced Oil Recovery toward High-Temperature High-Salinity Tolerance for Successful Field Applications in Carbonate Reservoirs

Updated Perceptions on Polymer-Based Enhanced Oil Recovery toward High-Temperature High-Salinity Tolerance for Successful Field Applications in Carbonate Reservoirs

Study on Main Factors Controlling Development Performance of Heterogeneous Composite Flooding in Post-Polymer Flooding Reservoir

Adsorption behavior of surfactants on sandstone reservoir rocks with carbonate cements and its influence on wettability alteration

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