scholarly journals South Louisiana Enhanced Oil Recovery/Sequestration R&D Project Small Scale Field Tests of Geologic Reservoir Classes for Geologic Storage

2016 ◽  
Author(s):  
Roger Hite
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Field Tests ◽  
Small Scale ◽  
Geologic Storage ◽  
Scale Field ◽  
South Louisiana

scholarly journals Alkali Effect on Alkali-Surfactant-Polymer (ASP) Flooding Enhanced Oil Recovery Performance: Two Large-Scale Field Tests’ Evidence

2020 ◽  
Vol 2020 ◽  
pp. 1-22 ◽  
Author(s):  
Chen Sun ◽  
Hu Guo ◽  
Yiqiang Li ◽  
Guipu Jiang ◽  
Ruicheng Ma
Keyword(s):  
Enhanced Oil Recovery ◽  
Field Test ◽  
Oil Recovery ◽  
Large Scale ◽  
Field Tests ◽  
Oil Prices ◽  
Asp Flooding ◽  
Scale Field ◽  
Large Scale Field ◽  
Better Than

Alkali-surfactant-polymer (ASP) flooding is very promising chemical enhanced oil recovery (EOR) technology which can make an incremental oil recovery factor (IORF) of 30% original oil in place (OOIP). How to choose alkali in ASP flooding remains a question for a long time. As the world’s only and largest ASP flooding application place, Daqing Oilfield has always adhered to the strategy of parallel development of strong alkali ASP flooding (SASP) and weak alkali ASP flooding (WASP), but SASP is in a dominant position, indicated by more investments and more project numbers. This leaves an impression that SASP is better than WASP. However, WASP is drawing more interest than SASP recently. Moreover, as the ASP flooding in Daqing went from field tests to commercial applications since 2014, how to comprehensively consider the benefit and cost of ASP flooding has become a new focus at low oil prices. This paper compares two typical large-scale field tests (B-1-D SASP and B-2-X WASP) completed in Daqing Oilfield and analyzes and discusses the causes of this difference. The injection viscosity and interfacial tension (IFT) for the two field test areas are substantially equivalent under the conditions of Daqing Oilfield, and WASP is better than SASP when reservoir geological conditions are considered. WASP exhibits the same IORF of 30% as SASP while having a much better economic performance. For the SASP field test, the injected strong alkali NaOH makes the test behave unlike a typical strong ASP flooding due to the presence of CO2 in the formation fluid, which well explains why IORF is much higher than all the other SASPs but scaling is less severe than others. This paper confirms that under Daqing Oilfield reservoir conditions, it is the alkali difference that caused the performance difference of these two tests, although some minor uncertainties exist. WASP is better than the SASP providing the same conditions . In addition, the detailed information of the two ASP field tests provided can give reference for the implementation of ASP flooding in other oilfields. After all, the study of ASP flooding enhanced oil recovery technology under low oil prices requires great foresight and determination.

Lessons Learned from Small Scale Field Test Demonstrating CO2 EOR and Geologic Storage at Wellington Field in Southern Kansas

2019 ◽  
Author(s):  
Yevhen Holubnyak ◽  
Willard Watney ◽  
Tiraz Birdie ◽  
Dana Wreath ◽  
George Tsoflias ◽  
...  
Keyword(s):  
Field Test ◽  
Lessons Learned ◽  
Small Scale ◽  
Geologic Storage ◽  
Scale Field ◽  
Co2 Eor

scholarly journals Evaluation of Energy Recovery from Laboratory Experiments and Small-scale Field Tests of Underground Coal Gasification (UCG)

2015 ◽  
Vol 131 (5) ◽  
pp. 203-218 ◽  
Author(s):  
Faqiang SU ◽  
Ken-ichi ITAKURA ◽  
Gota DEGUCHI ◽  
Koutarou OHGA ◽  
Mamoru KAIHO
Keyword(s):  
Energy Recovery ◽  
Laboratory Experiments ◽  
Coal Gasification ◽  
Field Tests ◽  
Small Scale ◽  
Underground Coal Gasification ◽  
Scale Field

scholarly journals Recent Advances of Surfactant-Polymer (SP) Flooding Enhanced Oil Recovery Field Tests in China

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-16
Author(s):  
Chen Sun ◽  
Hu Guo ◽  
Yiqiang Li ◽  
Kaoping Song
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Large Scale ◽  
Petroleum Industry ◽  
Field Tests ◽  
Industrial Applications ◽  
Polymer Flooding ◽  
Commercial Application ◽  
Surfactant Adsorption ◽  
Asp Flooding

Recently, there are increasing interests in chemical enhanced oil recovery (EOR) especially surfactant-polymer (SP) flooding. Although alkali-surfactant-polymer (ASP) flooding can make an incremental oil recovery factor (IORF) of 18% original oil in place (OOIP) according to large-scale field tests in Daqing, the complex antiscaling and emulsion breaking technology as well as potential environment influence makes some people turn to alkali-free SP flooding. With the benefit of high IORF in laboratory and no scaling issue to worry, SP flooding is theoretically better than ASP flooding when high quality surfactant is available. Many SP flooding field tests have been conducted in China, where the largest chemical flooding application is reported. 10 typical large-scale SP flooding field tests were critically reviewed to help understand the benefit and challenge of SP flooding in low oil price era. Among these 10 field tests, only one is conducted in Daqing Oilfield, although ASP flooding has entered the commercial application stage since 2014. 2 SP tests are conducted in Shengli Oilfield. Both technical and economic parameters are used to evaluate these tests. 2 of these ten tests are very successful; the others were either technically or economically unsuccessful. Although laboratory tests showed that SP flooding can attain IORF of more than 15%, the average predicted IORF for these 10 field tests was 12% OOIP. Only two SP flooding tests in (SP 1 in Liaohe and SP 7 in Shengli) were reported actual IORF higher than 15% OOIP. The field test in Shengli was so successful that many enlarged field tests and industrial applications were carried out, which finally lead to a commercial application of SP flooding in 2008. However, other SP projects are not documented except two (SP7 and SP8). SP flooding tests in low permeability reservoirs were not successful due to high surfactant adsorption. It seems that SP flooding is not cost competitive as polymer flooding and ASP flooding if judged by utility factor (UF) and EOR cost. Even the most technically and economically successful SP1 has a much higher cost than polymer flooding and ASP flooding, SP flooding is thus not cost competitive as previously expected. The cost of SP flooding can be as high as ASP flooding, which indicates the importance of alkali. How to reduce surfactant adsorption in SP flooding is very important to cost reduction. It is high time to reevaluate the potential and suitable reservoir conditions for SP flooding. The necessity of surfactant to get ultra-low interfacial tension for EOR remains further investigation. This paper provides the petroleum industry with hard-to-get valuable information.

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