Alternative Injection and Its Seepage Mechanism of Polymer Flooding in Heterogeneous Reservoirs

Han, Peng; Liu, Hai-Bo; Han, Xu; Cao, Renyi; Zhang, Yuwei; Liu, Xiaoyang

doi:10.2118/174586-ms

Cited by 4 publications

(4 citation statements)

References 1 publication

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“…The exact number of polymer slugs which provides the best result will be investigated in this section. A number of alternative cycles starting from 1 to 5 cycles as recommended by previous literature [5] are simulated with the same polymer mass and bulk polymer slug is segregated equally as illustrated in Fig. 7.…”

Section: E Number Of Alternative Cyclesmentioning

confidence: 99%

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

Tuncharoen¹,

Srisuriyachai²

2018

MATEC Web Conf.

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Polymer flooding is widely implemented to improve oil recovery since polymer can increase sweep efficiency and smoothen heterogeneous reservoir profile. However, polymer solution is somewhat difficult to be injected due to high viscosity and thus, water slug is recommended to be injected before and during polymer injection in order to increase an ease of injecting this viscous fluid into the wellbore. In this study, numerical simulation is performed to determine the most appropriate operating parameters to maximize oil recovery. The results show that pre-flushed water should be injected until water breakthrough while alternating water slug size should be as low as 5% of polymer slug size. Concentration for each polymer slugs should be kept constant and recommended number of alternative cycles is 2. Combining these operating parameters altogether contributes to oil recovery of 53.69% whereas single-slug polymer flooding provides only 53.04% which is equivalent to 8,000 STB of oil gain.

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Section: E Number Of Alternative Cyclesmentioning

confidence: 99%

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

Tuncharoen¹,

Srisuriyachai²

2018

MATEC Web Conf.

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“…The reserves of heavy oil resources in China are also considerable [1]. The heavy oil resources with underground crude oil viscosity of 150~1000 mPa•s in the Bohai oilfield are of great percentage [2,3]. At present, the heavy oil reservoirs in Bohai oilfield are mainly developed by conventional water flooding, which generally has poor development effect and low reserve recovery.…”

Section: Introductionmentioning

confidence: 99%

Adaptability Study of Hot Water Chemical Flooding in Offshore Heavy Oilfields

et al. 2022

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As a new heavy oil development technology, hot water chemistry flooding has great potential in offshore heavy oil fields development. In this paper, the adaptability of hot water chemical flooding was studied based on the typical model of offshore heavy oil fields. The main controlling factors affecting the hot water chemical flooding were analyzed and evaluated by single factor analysis. The technical boundary was established for offshore heavy oil fields. In addition, the hot water chemical flooding scheme was designed by a case study of a well group oilfield D. The results indicate that crude oil viscosity and well spacing have great influences on hot water chemical flooding performance. Hot water chemical flooding is favorable when the crude oil viscosity is between 300 and 1000 mPa·s and well spacing is around 200~400 m. The hot water chemical flooding scheme of the target well group results in 40.2 × 10 4 tons of incremental oil, and 6.3% of recovery factor being enhanced, which shows strong evidence that hot water chemical flooding enables great oilfield development performance.

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“…Peihui and Haibo [5] performed laboratory experiment to identify the effect of alternative polymer injection comparing to single-slug injection in aspects of overcoming profile reverse and ineffective polymer circulation in high permeability layer. Two scenarios were designed; single-slug injection was performed to inject only one polymer slug as a base case, alternative injection was accomplished by injecting alternative polymer slugs of high viscosity and low viscosity; more cycles, less polymer viscosity.…”

Section: Polymer Flooding In Multilayered Reservoirmentioning

confidence: 99%

“…Since a bulk polymer slug can be separated into several smaller slugs with water slug in between to increase polymer injectivity, the exact number of polymer slugs which provides the best result will be investigated in this section. A number of alternative cycles starting from 1 to 5 cycles as recommended by previous literature [5] are simulated with the same polymer mass and bulk polymer slug is separated equally as illustrated in Figure 5.24. From the results of 1,250 ppm cases, it can be observed that to select either three, four or five cycles provides very similar oil recovery of 52.34%, 52.3% and 52.28% respectively also, with the same production time of 1,886 days.…”

Section: Effect Of Number Of Alternative Cyclesmentioning

confidence: 99%

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

Tuncharoen

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Polymer flooding is widely implemented to improve oil recovery since it can increase sweep efficiency and smoothen reservoir profile. However, polymer solution is somewhat difficult to be injected due to high viscosity thus, water slug is recommended to be injected before and during polymer injection in order to increase an ease of injecting this viscous fluid into the wellbore. Numerical simulation is performed to determine the most appropriate operating parameters to maximize oil recovery. Firstly, pre-flushed water should be injected until water breakthrough since not only it can increase polymer injectivity by flushing the oil around wellbore away, but also it ensures the connectivity between injector and producer. The smallest alternating water slug size which is 5 percent of polymer slug size is sufficient to increase injectivity of polymer slug and should be selected since large water slug setbacks time to inject the following polymer slug; however, slug size of alternating water is dependent on polymer desorption degree; with less degree of polymer desorption, slug size of alternating water should be increased. Concentration sorting does not show any significant benefit due to imbalance between polymer injectivity and displacement efficiency. Number of appropriate alternating water slug depends on polymer concentration; more alternative cycles should be implemented in case of high polymer concentration. In this study, three alternative cycles provide higher oil recovery than single-slug polymer in every polymer concentration. Residual resistance factor (RRF) dominates polymer injectivity when using low polymer concentration; oil production increases as RRF increases. Lastly, multi-slug polymer flooding yields better results compared to single-slug in all range of heterogeneity index when depositional sequence is coarsening upward. Oppositely, fining upward sequence has already obtained the benefit in terms of polymer injectivity from high permeability zone at the bottom of reservoir together with gravitational effects, consequently, multi-slug polymer flooding does not yield benefit over single-slug.

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Alternative Injection and Its Seepage Mechanism of Polymer Flooding in Heterogeneous Reservoirs

Cited by 4 publications

References 1 publication

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

Adaptability Study of Hot Water Chemical Flooding in Offshore Heavy Oilfields

Evaluation of Polymer Alternating Waterflooding in Multilayered Heterogeneous Waterflooded Reservoir

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