Successful Field Implementation of CO-Foam Injection for Conformance Enhancement in the EVGSAU Field in the Permian Basin
- Amit Katiyar (The Dow Chemical Company) | Armin Hassanzadeh (The Dow Chemical Company) | Pramod Patil (Rock-Oil Consulting Group) | Michael Hand (ConocoPhillips) | Alejandro Perozo (ConocoPhillips) | Doug Pecore (ConocoPhillips) | Hosein Kalaei (ConocoPhillips) | Quoc Nguyen (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Improved Oil Recovery Conference, 31 August - 4 September, Tulsa, Oklahoma, USA
- Publication Date
- Document Type
- Conference Paper
- 2020. Society of Petroleum Engineers
- 5.7 Reserves Evaluation, 5.5.8 History Matching, 5.4.2 Gas Injection Methods, 5.5 Reservoir Simulation, 2 Well completion, 2.4 Hydraulic Fracturing, 5.7.2 Recovery Factors, 5 Reservoir Desciption & Dynamics, 2.5.2 Fracturing Materials (Fluids, Proppant), 5.4 Improved and Enhanced Recovery, 5.6.9 Production Forecasting, 5.6 Formation Evaluation & Management
- Conformance control, CO2-Foam, Gas soluble surfactants, Miscible Gas EOR, EVGSAU
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- 86 since 2007
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This paper presents the performance of a CO2 foam injection pilot implemented in the East Vacuum Grayburg San Andres Unit (EVGSAU) by ConocoPhillips in cooperation with The Dow Chemical Company. The pilot project focuses on a single CO2 injection pattern, consisting of one injector and eight producers, selected due to signs of early gas breakthrough and poor overall sweep efficiency.
To solve these conformance issues and increase overall pattern production performance, a new foaming surfactant with low adsorption and high gas partitioning characteristics was developed and experimentally tested at simulated reservoir conditions. A "water alternating surfactant-in-gas" injection strategy was created utilizing a history matched reservoir simulation model and an empirical foam model. This reservoir model was also utilized to better understand the dependency of surfactant concentration on foam generation and fluid diversion. Injection profile logs (IPLs) were also run, in both water and CO2 phases, prior to pilot implementation to establish baseline injection performance.
This paper will detail several performance indicators that illustrate sustained improvement in pattern injection and production after more than 15 cycles of alternating water, CO2+surfactant, and CO2-only injection. During each cycle, gas injectivity trends were calculated and compared to the baseline to monitor foam strength and performance. Four additional IPLs were run, which indicated continuous improvement in vertical sweep efficiency and ultimately resulted in uniform injection distribution between the upper and lower sections of the producing zone. Finally, the most significant result of the trial was the uplift in pattern oil production. It has averaged ~20% above the baseline production forecast throughout the entire pilot period and peaked within the first six months at ~60% above the baseline.
The success of this pilot illustrates the benefits of using a low adsorbing and CO2 soluble foaming surfactant to address reservoir conformance issues for CO2 floods. Further optimization of the pilot based on the simulation forecast is planned to improve long-term pilot economics.
|File Size||1 MB||Number of Pages||20|
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