Current development and application of chemical combination flooding technique

Zhu, Yongfa; Hou, Qingfeng; Jian, Guoqing; Ma, Dawei; Wang, Zhe

doi:10.1016/s1876-3804(13)60009-9

Cited by 108 publications

(60 citation statements)

References 15 publications

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“…Among them, four production Wells originally used for first polymer flooding wells locate in the main streamline of polymer flooding well pattern and the water cut rises from 92.6% before the field test to 95.7%, another 12 wells originally used for water flooding wells locate in the distributary streamline of polymer flooding well pattern and the water cut of four central wells decreases from 96.5% before the field test to 90.5% and the water cut of another 8 edge wells decreases from 95.5% before the field test to 92.4% (Seen in Fig.13). A better development effect has been seen in the production wells located at distributary streamline, its average single well accumulative oil increase is 1788t more than that of production wells located at main streamline, so remaining oil distribution are the main factor influencing on the development effect after polymer flooding [25][26][27][28][29] .…”

Section: Remaining Oil Distribution After Polymer Flooding Is a Majormentioning

confidence: 99%

High Concentration Polymer Flooding Field Test With Well Infilling to Change Fluid Flowing Direction After Polymer Flooding

Gao

Jiang

Zhang

et al. 2016

Day 2 Tue, March 22, 2016

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There are about half reserves remaining underground after polymer flooding, which are huge reserves for further tapping. So how to enhance oil recovery greatly after polymer flooding has been a major technical challenge in china or abroad. According to the data of 20 pressure coring wells after polymer flooding, the places where remaining oil locate are precisely described in this paper and on the basis of laboratory research and numerical simulation and geological study, a new method has been developed that combines well pattern restructuring for changing fluid flowing direction and high concentration polymer flooding so as to tap remaining oil which scatters highly and enriches relatively in distributary streamline after polymer flooding. Field test which used this new method has been carried out at B2D block in Daqing oilfield after polymer flooding. In order to get optimum mobility control, a reasonable formula of high concentration polymer system is optimized and the molecular weight and concentration of polymer are respectively 25 million and 2500 mg/L. Some good responses have been obtained in this field test. The injection pressure has increased by 4.3 MPa and the fluid absorption thickness ratio has increased by 26.3% and water cut drop maximum of central well has reached 16% and its incremental oil recovery is 5%. Based on this field test, it can be concluded that whether a field test after polymer flooding can get a good development effect, well pattern infilling is a premise and remaining oil distribution is a major influential factor and reasonable mobility ratio and injection-production ratio are important safeguards. High concentration polymer flooding with well infilling to change fluid flowing direction is a very effective technology to enhance oil recovery after polymer flooding. This technology has gain very good technological and economic effect, its final incremental oil recovery is 6.77% predicted by numerical simulation and its internal rate of return is 21.9%. This technology has wide application prospects and can be widely applied in blocks of Daqing oilfield after polymer flooding.

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Section: Remaining Oil Distribution After Polymer Flooding Is a Majormentioning

confidence: 99%

High Concentration Polymer Flooding Field Test With Well Infilling to Change Fluid Flowing Direction After Polymer Flooding

Gao

Jiang

Zhang

et al. 2016

Day 2 Tue, March 22, 2016

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“…In this technique, the IFT is synergistically reduced by the added surfactants and those produced in situ by the reaction of alkalis with organic acids in crude oil (Neustadter, ; Olajire, ; Zhang et al, ; Zhu et al, ). To increase the sweep efficiency, the viscosity of the fluid is increased by dissolving polymers such as polyacrylamide (PAM) (Wever et al, ; Zhu et al, ). In addition, wettability alternation of rock surfaces from oil‐wet to water‐wet (Fletcher et al, ; Pu et al, ; Standnes and Austad, ) and formation of crude oil‐in‐water emulsion can be realized by means of synergistic effects between surfactants and alkalis (Guo et al, ; Liu et al, ) which are beneficial for achieving high oil recovery (Neustadter, ).…”

Section: Introductionmentioning

confidence: 99%

A New Series of Double‐Chain Single‐Head Sulfobetaine Surfactants Derived from 1,3‐Dialkyl Glyceryl Ether for Reducing Crude Oil/Water Interfacial Tension

Yan

Cui

et al. 2018

J Surfact & Detergents

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A new series of sulfobetaine surfactants with double‐chain single‐head structure were derived from 1,3‐dialkyl glyceryl ethers and their performances in reducing Daqing crude oil/connate water interfacial tension (IFT) in the absence of alkali were studied. With a large hydrophilic head group and double hydrophobic chains, these surfactants are efficient at reducing crude oil/connate water IFT. Those with didecyl and dioctyl are good hydrophobic surfactants that can reduce Daqing crude oil/connate water to ultra‐low IFT by mixing with a small molar fraction of various conventional single‐chain hydrophilic surfactants, such as α‐olefin sulfonates, dodecyl polyoxyethylene (10) ether, and cetyl dimethyl hydroxypropyl sulfobetaine. The asymmetric double‐chain sulfobetaine derived from 1‐decyl‐3‐hexyl glyceryl ether can reduce Daqing crude oil/connate water IFT to ultra‐low solely over a wide concentration range (0.03–10 mM or 0.0017–0.58 wt.%), which allows for use of an individual surfactant instead of mixed surfactants to avoid chromatographic separation in the reservoir. In addition, formulations rich in sulfobetaine surfactants show low adsorption on sandstone, keeping the negatively charged solid surface water‐wet, and forming crude oil‐in‐water emulsions. These new sulfobetaine surfactants are, therefore, good candidates for surfactant‐polymer flooding free of alkali.

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“…Therefore, generally, the use of alkaline chemicals must be considered carefully before application. Zhu et al [13][14][15] has demonstrated that the combinations of chemical agents such as ASP or SP flooding perform the higher efficiency than single agent injection, particularly SP flooding might give the better results than that of ASP flooding in either technical or economic view point. Furthermore, they figured out the main factors affecting to the success of SP flooding process including connectivity between injector and producer, the designed properties of SP system, and the injected chemical volume.…”

Section: Introductionmentioning

confidence: 99%

Numerical studies on the effects of various complicated barrier configurations on sweep efficiency in surfactant/polymer flooding

Van

Chon

2016

Journal of Industrial and Engineering Chemistry

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Current development and application of chemical combination flooding technique

Cited by 108 publications

References 15 publications

High Concentration Polymer Flooding Field Test With Well Infilling to Change Fluid Flowing Direction After Polymer Flooding

High Concentration Polymer Flooding Field Test With Well Infilling to Change Fluid Flowing Direction After Polymer Flooding

A New Series of Double‐Chain Single‐Head Sulfobetaine Surfactants Derived from 1,3‐Dialkyl Glyceryl Ether for Reducing Crude Oil/Water Interfacial Tension

Numerical studies on the effects of various complicated barrier configurations on sweep efficiency in surfactant/polymer flooding

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