How successful is Immiscible CO2 flooding is for heavy oils (10-20 API) ? Is asphaltene dropout is significant from immiscible flood compared to miscible one ? Is it difficult to achieve the miscibility between Heavy oil and CO2 ?
How feasible is Polymer Alternate Co2 Gas flooding for heavy oils In case of limited Co2 supplies where using polymer to maintain the pressure needed for solubilization of Co2 in oil is achievable ?
The answers to your first three questions are all "yes."
I don't have experience with a polymer wag.
Here are a couple of references for heavy oil CO2 EOR which I found to be very useful:
Multiple-Contact Phase BehaviorMeasurement and Application With Mixtures of Highly Asphaltic CrudeD.W. Bryant,* SPE, Louisiana State U.T.G. Monger, SPE, Louisiana State U.
OIL RECOVERY BY IMMISCIBLE C02 FLOODINGTopical ReportBy Frank T. H. ChungMarch 1988NIPER-297(DE88001220)
Thanks Mr. Lamar
A lot of work has been done on this in Western Canada, including a number of pilot projects.
Gokhan Coskuner has promised to do a talk for the CCUS Section in 1Q2024.
He is currently on vacation, but I am sure he'll join this discussion in due course.
The oil swelling effects are magic and do not require miscibility.
Looks very promising as a post-CHOPS process.
Lab work is required on asphaltene management but lots of specialized labs have the capacity to do the work.
Hello Mr Robert,
I'm glad you shared updates with me, here I want to know more about this Polymer Alternate Gas flooding method and it's related pilot scale field projects or lab work.
Can you please share the related articles had you came across before.
Thanks & Regards
CO2 Injection into Heavy Oils isn't new. CO2 Pilot Injection into Heavy Oils was conducted in the Wilmington field in California during the period from 1981 to 1986 in three pilots. The Pilot programs injected CO2 into 14 API Gravity Crude with Formation depth 2500 ft, Reservoir Pressure of 1,000 psi and Reservoir Temperature of 123 F degrees, way below Minimum Miscibility Pressure. The CO2 didn't blow through the formation with Oil Rate Increasing from the Champlain Pilot rose from 47 BOPD To 200 BOPD. The FB five pilot Oil Production increased from 1150 BOPD to 1550 BOPD. The THUMS unit in Long Beach Harbor has GOOD CO2 Potential. However, it's located in California and will never be CO2 flooded. There are other Heavy Oil projects along with both Un-conventional and Conventional CO2/EOR projects located around the World that have been analyzed by Merchant Consulting. More can be found out on my website at www.CO2StorageSolutions.com or email me at email@example.com
I just saw this thread now. Thank you Bob for mentioning some of my previous work. This is the response I wrote to the miscibility question, also applies here. While it may be difficult to achieve miscibility with heavy oils, this does not preclude injecting CO2 immiscibly to increase recovery. This has been shown for <100 cp oil (Wilmington Field as per the previous discussion in this thread), for <1000 cp oil (Bati Raman Field in Turkey, e.g. SPE-20883-PA) and for up to 35,000 cp oil in Lloydminster, Canada (SPE-199947-MS).