Using Tracer Data to Determine Polymer Flooding Effects in a Heterogeneous Reservoir, 8 TH Reservoir, Matzen Field, Austria
- Ajana Laoroongroj (OMV) | Markus Lüftenegger (OMV) | Rainer Kadnar (OMV) | Christoph Puls (OMV) | Torsten Clemens (OMV)
- Document ID
- Society of Petroleum Engineers
- EUROPEC 2015, 1-4 June, Madrid, Spain
- Publication Date
- Document Type
- Conference Paper
- 2015. Society of Petroleum Engineers
- 7.1 Asset and Portfolio Management, 7.2.1 Risk, Uncertainty and Risk Assessment, 7 Management and Information, 6.5.2 Water use, produced water discharge and disposal, 1.6 Drilling Operations, 5.6.2 Core Analysis, 1.6.9 Coring, Fishing, 7.2 Risk Management and Decision-Making, 7.1.8 Asset Integrity, 5.4 Enhanced Recovery, 5.6 Formation Evaluation & Management, 5.7.2 Recovery Factors, 5 Reservoir Desciption & Dynamics, 5.7 Reserves Evaluation, 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex)
- Surveillance, Polymer Flooding, Field Test, Tracer, Heterogeneous Reservoir
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- 238 since 2007
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Polymer injection pilot projects aim at reducing the uncertainty and risk of full-field polymer flood implementation. The interpretation of polymer pilot projects is challenging owing to the complexity of the process and fluids moving out of the polymer pilot area. The interpretation is increasingly more complicated with the heterogeneity of the reservoir.
In the polymer pilot performed in the 8 TH reservoir of the Matzen Field in Austria, a polymer injection well surrounded by a number of production wells was selected. A tracer was injected one week prior to polymer injection. The tracer showed that the flow-field in the reservoir was dramatically modified with increasing amounts of polymers injected. Despite short breakthrough times of 4-10 weeks observed for the tracer, polymer breakthrough occurred only after more than 12 months although injection and production rates have not been substantially changed.
The tracer signal indicated that the reservoir is heterogeneous with high flow velocities occurring in high permeable layers. By injecting polymers, the mobility of the polymer augmented water was reduced compared with water injection and lead to flow diversion into adjacent layers. The tracer response showed that the speed of the tracer moving from injection to production wells was reduced with increasing amount of polymers injected.
This response was used to assess the changes of the amount of water flowing from injection to production well. After a match for the tracer curve was obtained, adsorption, residual resistance factor and dispersivity were calculated. The results showed that even for heterogeneous reservoirs without having good conformance of the pilot, the critical parameters for polymer injection projects can be assessed by analyzing tracer and polymer response. These parameters are required to determine whether implementation of polymer injection at field scale is economically attractive.
Along the flow path, an incremental recovery of about 8 % was achieved. The polymer retention and inaccessible pore volume in the reservoir was in the same range as in core floods. Incremental oil recovery owing to acceleration along the flow path was estimated at contributing to about 30 % to the overall incremental oil production due to polymer injection and 70 % to improved sweep efficiency.
|File Size||2 MB||Number of Pages||15|
De Melo, M.A.; Holleben, C.R.C.; da Silva, I.P.G.; de Barros Correia. A.; da Silva, G.A.; Rosa, A.J.; Lins, A.G. and de Lima, J.C. 2005. Evaluation of Polymer Injection Projects in Brazil. Paper SPE 94898 presented at the SPE Latin American and Caribbian Petroleum Engineering Conference. Rio de Janeiro. Brazil. 20-23 June 2005.
Zechner, M.; Clemens, T.; Suri, A.; and Sharma, M.M. 2014. Simulation of Polymer Injection under Fracturing Conditions - A Field Pilot in the Matzen Field, Austria. Paper SPE 169043 presented at the SPE Improved Oil Recovery Symposium. Tulsa. Oklahoma. USA. 12-16 April 2014. Under review for publication in SPEREE.