An Optimized-Hybrid In-Situ-Upgrading and Steam-Injection Process for Enhanced-Heavy-Oil Recovery in a Naturally Fractured Reservoir

SPE Journal ◽  
2020 ◽  
Vol 25 (06) ◽  
pp. 3386-3411
Author(s):  
Faruk O. Alpak ◽  
John M. Karanikas
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Steam Injection ◽  
Heavy Oil Recovery ◽  
Fractured Reservoir ◽  
Naturally Fractured Reservoir ◽  
Injection Process ◽  
Naturally Fractured

Simulation of Steam Injection Process for Horizontal Well with Heavy Oil Recovery

2017 ◽  
Vol 39 (13-14) ◽  
pp. 1283-1295
Author(s):  
Chun-sheng Guo ◽  
Fang-yi Qu ◽  
Yong Liu ◽  
Jing-ran Niu ◽  
Yong Zou
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Horizontal Well ◽  
Steam Injection ◽  
Heavy Oil Recovery ◽  
Injection Process

Experimental Investigation of In-Situ Emulsion Formation To Improve Viscous-Oil Recovery in Steam-Injection Process Assisted by Viscosity Reducer

SPE Journal ◽  
2016 ◽  
Vol 22 (01) ◽  
pp. 130-137 ◽  
Author(s):  
Chuan Lu ◽  
Huiqing Liu ◽  
Wei Zhao ◽  
Keqin Lu ◽  
Yongge Liu ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Steam Injection ◽  
Viscosity Reduction ◽  
Injection Process ◽  
Viscous Oil ◽  
Viscosity Reducer ◽  
High Temperature Steam

Summary In this study, the effects of viscosity-reducer (VR) concentration, salinity, water/oil ratio (WOR), and temperature on the performance of emulsions are examined on the basis of the selected VR. Different VR-injection scenarios, including single-VR injection and coinjection of steam and VR, are conducted after steamflooding by use of single-sandpack models. The results show that high VR concentration, high WOR, and low salinity are beneficial to form stable oil/water emulsions. The oil recoveries of steamflooding for bitumen and heavy oil are approximately 31 and 52%, respectively. The subsequent VR flooding gives an incremental oil recovery of 5.2 and 6.4% for bitumen and heavy oil, respectively. Flooding by steam/VR induces an additional oil recovery of 8.4–11.0% for bitumen and 12.1% for heavy oil. High-temperature steam favors the peeling off of oil and improving its fluidity, as well as the in-situ emulsions. VR solution is beneficial for the oil dispersion and further viscosity reduction. The coinjection of high-temperature steam and VR is much more effective for additional oil production in viscous-oil reservoirs.

Sequential deep eutectic solvent and steam injection for enhanced heavy oil recovery and in-situ upgrading

Fuel ◽  
2017 ◽  
Vol 187 ◽  
pp. 417-428 ◽  
Author(s):  
A. Mohsenzadeh ◽  
Y. Al-Wahaibi ◽  
R. Al-Hajri ◽  
B. Jibril ◽  
N. Mosavat
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Deep Eutectic Solvent ◽  
Steam Injection ◽  
Heavy Oil Recovery

Tertiary Recovery Improvement of Steam Injection Using Chemical Additives: Pore Scale Understanding of Challenges and Solutions Through Visual Experiments

2021 ◽  
Author(s):  
Randy Agra Pratama ◽  
Tayfun Babadagli
Keyword(s):  
Porous Media ◽  
Phase Change ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Phase Distribution ◽  
Steam Injection ◽  
Hot Water ◽  
Heavy Oil Recovery ◽  
Residual Oil ◽  
Tertiary Recovery

Abstract Our previous research, honoring interfacial properties, revealed that the wettability state is predominantly caused by phase change—transforming liquid phase to steam phase—with the potential to affect the recovery performance of heavy-oil. Mainly, the system was able to maintain its water-wetness in the liquid (hot-water) phase but attained a completely and irrevocably oil-wet state after the steam injection process. Although a more favorable water-wetness was presented at the hot-water condition, the heavy-oil recovery process was challenging due to the mobility contrast between heavy-oil and water. Correspondingly, we substantiated that the use of thermally stable chemicals, including alkalis, ionic liquids, solvents, and nanofluids, could propitiously restore the irreversible wettability. Phase distribution/residual oil behavior in porous media through micromodel study is essential to validate the effect of wettability on heavy-oil recovery. Two types of heavy-oils (450 cP and 111,600 cP at 25oC) were used in glass bead micromodels at steam temperatures up to 200oC. Initially, the glass bead micromodels were saturated with synthesized formation water and then displaced by heavy-oils. This process was done to exemplify the original fluid saturation in the reservoirs. In investigating the phase change effect on residual oil saturation in porous media, hot-water was injected continuously into the micromodel (3 pore volumes injected or PVI). The process was then followed by steam injection generated by escalating the temperature to steam temperature and maintaining a pressure lower than saturation pressure. Subsequently, the previously selected chemical additives were injected into the micromodel as a tertiary recovery application to further evaluate their performance in improving the wettability, residual oil, and heavy-oil recovery at both hot-water and steam conditions. We observed that phase change—in addition to the capillary forces—was substantial in affecting both the phase distribution/residual oil in the porous media and wettability state. A more oil-wet state was evidenced in the steam case rather than in the liquid (hot-water) case. Despite the conditions, auspicious wettability alteration was achievable with thermally stable surfactants, nanofluids, water-soluble solvent (DME), and switchable-hydrophilicity tertiary amines (SHTA)—improving the capillary number. The residual oil in the porous media yielded after injections could be favorably improved post-chemicals injection; for example, in the case of DME. This favorable improvement was also confirmed by the contact angle and surface tension measurements in the heavy-oil/quartz/steam system. Additionally, more than 80% of the remaining oil was recovered after adding this chemical to steam. Analyses of wettability alteration and phase distribution/residual oil in the porous media through micromodel visualization on thermal applications present valuable perspectives in the phase entrapment mechanism and the performance of heavy-oil recovery. This research also provides evidence and validations for tertiary recovery beneficial to mature fields under steam applications.

Investigation of Cyclic Solvent Injection Process for Heavy Oil Recovery

2010 ◽  
Vol 49 (09) ◽  
pp. 22-33 ◽  
Author(s):  
John Ivory ◽  
Jeannine Chang ◽  
Roy Coates ◽  
Ken Forshner
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Heavy Oil Recovery ◽  
Solvent Injection ◽  
Injection Process
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