Uttam,
The History of CO2/EOR goes back 51 years with Commercial Injection of CO2 into the Sacroc field. The majority of Conventional CO2 floods today utilize Tapered WAG to control conformance, thus improving Conventional Constant WAG from 8%-12% Tertiary Oil Recovery in the 1980s to today's 18%-26% Tertiary Oil Recovery. Water Injection with Tapered WAG controlled Gas Breakthrough by Level Loading Gas Production to a Plant's Inlet Gas Rate, thus controlling the CO2 Flood with Cheap Water, rather than let Mother Nature dictate recovery without any injection controls. As for Surfactants and Polymers, there are several field examples where Surfactants were included to improve Overall Conformance where breakthrough problems exist. Many were successful, but the bottom line in Conformance Control has been Tapered WAG with Water due to cost.
As for Heavy Oil Reservoirs, such as found in the Wilmington field in Los Angeles, BP had plans to recover CO2 from its downtown LA Oil Refinery Plant, transport 6 miles to Longbeach Harbor, and inject the CO2 into the very large (Heavy Oil - 14 API Gravity) Wilmington field. The concept is Proven. However, Los Angeles with not only a very large Population, but also a highly faulted area (good for trapping oil, but also near San Andreas fault line) represents a risk. In addition, I'm sure California Politics played a role in the decision-making process.
As for Polymer or Surfactants in Heavy Oil, the World is Compositional. Any means to Improve Recovery can be an Economic Nightmare, or Advance CO2/EOR for Future Generations to come.
Good Luck with your efforts. If you would like to understand more about Historical CO2/EOR Development, in both Conventional and un-Conventional Tertiary Oil Recovery areas, then send me an email to merchantconsulting@comcast.net and I will send you a Library Set of my SPE and CMTC papers as listed below:
SPE 26624 "Reservoir Management in Tertiary CO2 Floods", Merchant, D.H., and Thakur, S.C.: paper presented at 68th Annual Technical Conference and Exhibition of the Society of Petroleum Engineers , 3-6 October, 1993, Houston, Texas.
SPE 139516 "Life beyond 80 – A look at Conventional WAG Recovery beyond 80% HCPV Injection in CO2 Floods", Merchant, D.H., paper presented at the International Conference on CO2 Capture, Storage, and Utilization, Nov, 2010,New Orleans
CMTC-440223-MS "The Energy Gap – How CO2 Tertiary Oil Recovery will mark its place in the 21st Century".
SPE-139516-PP "Life beyond 80 - A look at Conventional WAG Recovery beyond 80% HCPV Injection in CO2 Tertiary Floods".
CMTC-440075-MS (SPE-139516) "Life beyond 80 – A Look at Conventional WAG Recovery beyond 80% HCPV Injection in CO2 Tertiary Floods".
CMTC-502866-MS "Enhanced Oil Recovery – The History of CO2 Conventional WAG Injection techniques developed from Lab in the 1950's to 2017".
CMTC-554157-MS CO2 Sequestration - Unconventional Enhanced Oil Recovery - CO2/EOR "Huff-n-Puff" in the 21st Century.
Thanks,
David
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David Merchant
Merchant Consulting
merchantconsulting@comcast.net------------------------------
Original Message:
Sent: 09-09-2023 02:00 AM
From: Uttam Gupta
Subject: Heavy oil and Co2 Miscibility
Hello Mr David,
I assume limited CO2 Supply could have been a reason for not execution of CO2 flooding project in those potential heavy oil reservoirs in California.
I'd like to note your views on Polymer Alternate Gas led Improved heavy oil recovery that includes limited supply of CO2 compared to continuous Injection.
Also, What's heavy oil fields response over Asphaltene Flocculation & Deposition, often recorded in producing wells.
Thanks & Regards
Uttam Gupta
Original Message:
Sent: 09-07-2023 10:07 AM
From: David Merchant
Subject: Heavy oil and Co2 Miscibility
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 merchantconsulting@comcast.net
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David Merchant
Merchant Consulting
merchantconsulting@comcast.net
Original Message:
Sent: 09-06-2023 02:18 AM
From: Karen Schou Pedersen
Subject: Heavy oil and Co2 Miscibility
1. Yes, it is possible to achieve miscibility between CO2 and a heavy oil at a temperature higher than the critical temperature (Tc) of CO2. In fact, miscibility is more likely to develop if the temperature is somewhat higher than the Tc of CO2 (31°C/87.9°F). At temperatures approaching (or lower than) the Tc of CO2, a liquid-liquid split can develop which will persist no matter how much the pressure is increased.
2. SPE paper 15599 (Lindeloff et al., "Investigating miscibility behavior of CO2 rich hydrocarbon systems - with application to gas injection EOR", 2013) has an example of CO2 miscibility with a relatively heavy oil and another example of CO2 immiscibility.
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Karen Schou Pedersen
Original Message:
Sent: 09-05-2023 05:41 PM
From: Uttam Gupta
Subject: Heavy oil and Co2 Miscibility
- Can miscibility between oil and CO2 be only achieved above supercritical Conditions of Co2 or it can either be attained with High Pressure CO2 liquids (below Supercritical conditions)
- Are there cases of CO2 injection into Heavy oil reservoirs to attain miscibility at Reservoir P & T ?
Thanks & Regards