Evaluation of Manson Lease Oil Field for Improved Oil Recovery Process

2008 ◽  
Author(s):  
Jyun-Syung Tsau ◽  
Victor Osvaldo Vaca Bustamante ◽  
Don W. Green ◽  
G. Bob Barnett ◽  
Jeff Dale
Keyword(s):  
Oil Recovery ◽  
Recovery Process ◽  
Oil Field ◽  
Improved Oil Recovery

Visco-Elastic Property Studies on Polymer Flooding Systems with High Concentrations

2012 ◽  
Vol 550-553 ◽  
pp. 834-837
Author(s):  
Ji Gang Wang ◽  
Quan Qing Du ◽  
Peng Wu ◽  
Shao Li Hu ◽  
Pan Niu
Keyword(s):  
Elastic Property ◽  
Oil Recovery ◽  
Elastic Characteristic ◽  
Polymer Flooding ◽  
Oil Field ◽  
High Concentration ◽  
Improved Oil Recovery ◽  
High Molecular Weight Polymer ◽  
Molecular Weight Polymer ◽  
Asp Flooding

Keywords: Visco-elastic property; polymer flooding; oil recovery Abstract. Polymer flooding and ASP flooding has improved oil recovery a lot in Daqing oil field. In ASP flooding, the existence of alkali decreases the visco-elastic characteristic of polymer, which decreases the oil recovery of polymer flooding. The aim of this paper was to study the visco-elastic characteristic, shear resistance in high concentration and high molecular weight polymer flooding, and analyzed the suitable parameter of it .They can provide the theory of polymer flooding development and application research.

scholarly journals Enhancing the spontaneous imbibition process using biosurfactants produced from bacteria isolated from Al-Rafidiya oil field for improved oil recovery

2020 ◽  
Vol 10 (8) ◽  
pp. 3767-3777
Author(s):  
Asaad Faraj Hamzah ◽  
Mohammed Idrees Al-Mossawy ◽  
Wijdan Hussein Al-Tamimi ◽  
Fahad M. Al-Najm ◽  
Zainab Mohsen Hameed
Keyword(s):  
Bacillus Cereus ◽  
Oil Recovery ◽  
Agar Plate ◽  
Enterobacter Aerogenes ◽  
Oil Field ◽  
Spontaneous Imbibition ◽  
Formation Water ◽  
Rock Permeability ◽  
Phenotypic Properties ◽  
Improved Oil Recovery

Abstract Among 64 bacterial strains isolated in this study, the best two of biosurfactant-producing bacteria were selected and identified based on the phenotypic properties and molecular approach based on 16S rRNA having 100% similarity to the gram-negative Enterobacter aerogenes B19 strain bacteria and rode gram-positive strain Bacillus cereus ISU-02 in the Nucleotide database of the National Center for Biotechnology Information. The study showed that two selected isolates gave the highest positive results that were used to investigate the biosurfactant production including: interfacial reduction, foaming activity, hemolytic activity, CTAB agar plate, drop collapse assay, oil displacement test and emulsification index E24%. Both Bacillus cereus ISU-02 strain and Enterobacter aerogenes B19 strain have reduced the interfacial tension to 27.61 and 28.93, respectively. Biosurfactants produced from both isolates were tested for oil recovery using spontaneous imbibition process. Bacillus cereus ISU-02 strain gave the highest oil recovery of 66.9% for rock permeability of 843 mD, followed by Enterobacter aerogenes B19 strain with oil recovery of 34% for rock permeability 197 mD, while the lowest rate of oil recovery was 12.1% for FW with permeability of 770 mD. An additional oil rate reached to 7.9% has been recovered from the residual oil when the core plug that was treated with formation water alone was retreated with the cell free biosurfactant supernatant. Use of the new biosurfactants has improved oil recovery better than use of formation water alone or formation water with the commercial surfactant SDS.

Formation resistivity variation due to steam flooding: A log study

Geophysics ◽  
1992 ◽  
Vol 57 (3) ◽  
pp. 488-494 ◽  
Author(s):  
R. P. Ranganayaki ◽  
S. E. Akturk ◽  
S. M. Fryer
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Recovery Process ◽  
Oil Field ◽  
Steam Flooding ◽  
Resistivity Logs ◽  
Resistivity Variation ◽  
Steam Flood ◽  
Formation Resistivity ◽  
Production Pattern

An investigation of the pre‐ and poststeam resistivity logs, in a production pattern in a heavy‐oil field in Southern California, shows that the formation resistivity in steamed formations decreases by a factor of two to three. Shales as well as sands are affected by the steam flood. The observed drop in the resistivity of the reservoir correlates well with the increase in temperature. The study shows the potential of using resistivity variations to map and monitor thermal enhanced oil recovery process.

Aplicability of an Innovative and Light Seismic Approach to Monitor SAGD Operations in Surmont: A Blind Test

2021 ◽  
Author(s):  
Victoria Brun ◽  
Elodie Morgan ◽  
Brad Gerl ◽  
Luis Cardozo ◽  
Jeremie Batias
Keyword(s):  
Oil Recovery ◽  
Joint Venture ◽  
Cost Effective ◽  
Recovery Process ◽  
Oil Field ◽  
Time Shift ◽  
Blind Test ◽  
Steam Chamber ◽  
Steam Assisted Gravity Drainage ◽  
4D Seismic

Abstract Surmont is a heavy oil field located in northeast Alberta which is currently being developed by a joint venture between ConocoPhillips and Total using Steam Assisted Gravity Drainage (SAGD). To monitor the enhanced oil recovery process and caprock integrity, highly repeatable 4D seismic surveys using dynamite have been completed over the years. In order to maximize the value of information while controlling costs, a novel light seismic monitoring approach has been "blind-tested" on existing 4D data. The concept requires the use of only one source and one receiver couple, optimally placed in the field to monitor one or several subsurface spots, using time redundancy to detect 4D changes in these zones of interest. Three spot locations have been defined by the client on a well pad for which the history was not provided. For each of these spots, specific series of seismic processing steps have enabled the identification of the optimum source/receiver locations. Then, these optimum raw seismic traces extracted from different 4D campaigns have been analysed to detect potential time shift changes in the selected horizon induced by the growth of the steam chamber. Time-shift changes were plotted for all 3 spots. An increase was observed for one of the spots (Spot 3) from the first 4D monitor in 2010 up to the last monitor in 2015. An increase was also plotted between March 2013 and September 2013 for another spot (Spot 1), changes attributed to the dynamics of the steam chamber. On the contrary, spot 1 did not see any effect of the steam. These time-shift changes were then successfully cross-checked with temperature data from observation wells, confirming the qualitative variations attributed to the effects of the steam chamber evolution. It demonstrated the viability of this innovative seismic and focused monitoring approach to monitor the evolution of the steam chamber in Surmont. This also paves the way for a simpler and yet reliable and cost-effective way of monitoring the evolution of the steam chamber to further optimize production and increase rentability.

Feasibility of Waterflooding for a Carbonate Oil Field Through Whole-Field Simulation Studies

2015 ◽  
Vol 137 (6) ◽  
Author(s):  
Wenting Yue ◽  
John Yilin Wang
Keyword(s):  
Oil Recovery ◽  
Injection Rate ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Improved Oil Recovery ◽  
Smackover Formation ◽  
Artificial Lift ◽  
Production History ◽  
Current Production ◽  
The Impact

The carbonate oil field studied is a currently producing field in U.S., which is named “PSU” field to remain anonymity. Discovered in 1994 with wells on natural flow or through artificial lift, this field had produced 17.8 × 106 bbl of oil to date. It was noticed that gas oil ratio had increased in certain parts and oil production declined with time. This study was undertaken to better understand and optimize management and operation of this field. In this brief, we first reviewed the geology, petrophysical properties, and field production history of PSU field. We then evaluated current production histories with decline curve analysis, developed a numerical reservoir model through matching production and pressure data, then carried out parametric studies to investigate the impact of injection rate, injection locations, and timing of injection, and finally developed optimized improved oil recovery (OIR) methods based on ultimate oil recovery and economics. This brief provides an addition to the list of carbonate fields available in the petroleum literature and also improved understandings of Smackover formation and similar analogous fields. By documenting key features of carbonated oil field performances, we help petroleum engineers, researchers, and students understand carbonate reservoir performances.

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