Instow a Full Field, Multi-Patterned Alkaline-Surfactant-Polymer Flood – Analyses and Comparison of Phases 1 and 2
- Malcolm J. Pitts (Surtek, Inc.) | Elio Dean (Surtek, Inc.) | Kon Wyatt (Surtek, Inc.) | Elii Skeans (Surtek, Inc.) | Dalbir Deo (Crescent Point Energy) | Angela Galipeault (Crescent Point Energy) | Dallas Mohagen (Crescent Point Energy) | Colby Humphry (Crescent Point Energy)
- 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
- 2 Well completion, 2.4 Hydraulic Fracturing, 5.4 Improved and Enhanced Recovery, 5.7 Reserves Evaluation, 5 Reservoir Desciption & Dynamics, 5.5.2 Core Analysis, 2.5.2 Fracturing Materials (Fluids, Proppant), 5.3.6 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex)
- Field Project, Alkaline-Surfactant-Polymer Flood, Economic Analysis, Operational Issues, Production Analysis
- 62 in the last 30 days
- 64 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
An Alkaline-Surfactant-Polymer (ASP) project in the Instow field, Upper Shaunavon formation in Saskatchewan Canada was planned in three phases. The first two multi -well pattern phases are nearing completion. Beginning in 2007, an ASP solution was injected into Phase 1. Phase 1 polymer drive injection began in 2011 after injection of 35% pore volume (PV) ASP solution. Coincident with the polymer drive injection into Phase 1, Phase 2 ASP solution injection began. Phase 2 polymer drive began in 2016 after injection of 47% PV ASP solution. Polymer drive continues in both phases with Phase 1 and Phase 2 injected volume being 55% PV and 35% PV, respectively. Phase 1 and Phase 2 oil cut response to ASP injection showed an increase of approximately four times from 3.5% to 12 to 16% and an increase in oil rate from approximately 3,200 m3/m (20,000 bbl/m) to 8,300 m3/m (52,000 bbl/m) in Phase 1 and from 2,200 m3/m (14,000 bbl/m) to 7,800 m3/m (49,000 bbl/m) in Phase 2. Phase 1 pattern analysis indicates the pore volumes of ASP solution injected varied from 13% to 54% PV of ASP with oil recovery percentage increasing with increasing injected volume. Oil recoveries in the different patterns ranged from 3% OOIP up to 21% OOIP with lower oil recoveries correlating with lower volume of ASP injected. The response from some of the patterns correlates with coreflood results. Wells in common to the two phases show increase oil cut and oil rate responses to chemical injection from both Phases 1 and 2. Oil recovery as of August 2019 is 60% OOIP for Phase 1 and 57% OOIP for Phase 2. Phase 1 economic analysis indicated chemical and operation cost would be approximately C$26/bbl resulting in the decision to move forward with Phase 2.
|File Size||983 KB||Number of Pages||18|
Saskatchewan Ministry of the Economy (2011): Stratigraphic Correlation Chart; Saskatchewan Ministry of the Economy, http://publications.saskatchewan.ca/#/products/81737.
Fockler, M. (2015). Shaunavon Regional Geology Map The Shaunavon Oolite: It's so Last Year! Eastend, SK. Accessed August 2016. http://spark.canadiandiscovery.com/activity-review/shaunavon-oolite-it-s-so-last-year @ Canadian Discovery Ltd.
Pitts, M.J., Campbell, TA, Surkalo, H. and Wyatt, K. 1995. Polymer Flood of the Rapdan Pool, SPE Reservoir Engineering 10: 185-188. SPE-27820-PA 10.2118/27820-PA
Ansarizadeh, M.M., Weatherstone, P.M., and Strong, J.B. 2012. Alkaline Surfactant Polymer Flooding to Revialize Oil Production from a Mature Water Flooded Field. Presented at the SPE EOR Conference at Oil and Gas West Asia held in Muscat, Oman 16-18 April. SPE 155541-MS. 10.2118/155541-MS.