Operational Challenges and Monitoring of a Polymer Pilot, Matzen Field, Austria
- Markus Lüftenegger (OMV) | Rainer Kadnar (OMV) | Christoph Puls (OMV) | Torsten Clemens (OMV)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- August 2016
- Document Type
- Journal Paper
- 228 - 237
- 2016.Society of Petroleum Engineers
- Surface Facilities, Polymer Pilot, Tracer, Injectivity, Monitoring
- 0 in the last 30 days
- 456 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 35.00|
Four main areas of uncertainty can be described in polymer-injection projects:
- Are we able to deliver the polymer solutions at the required quality to the wellhead?
- Are we able to inject polymers at the required quantity and quality?
- Are we producing sufficient incremental oil?
- Are we able to separate and treat oil and water cost-effectively after polymer breakthrough?
The monitoring program that was developed for the polymer-injection pilot aims to reduce the uncertainty and quickly identify operational difficulties, as described in the following:
- Polymer quality at the wellhead: The polymer concentration and viscosity of the "source" solution and injected polymer solution were measured at various locations in the surface facilities. A quality check of the delivered polymer (including a filter ratio test of the dissolved polymer) was performed, the biological activity monitored, iron content measured, and polymer solution investigated for "fish eyes." The monitoring program enabled us to identify challenges related to shearing the polymers after changing the operating envelope, to identify problems related to biological activity, and to ensure data quality for interpretation of the pilot.
- Injectivity and degradation: Monitoring involved wellhead- and bottomhole-pressure measurements, repeated falloff tests, and visual observation of the polymer solutions in the well. The results showed the mobility reduction of the polymer solutions and an indication of induced fractures. Combining the various measurements led to identification of an operational issue—the injectivity decreased more than expected from polymer rheology and prepilot water-quality assessment. The reason was the combination of fines and small oil droplets existing in the injection water with polymer- and biological-generated mass that plugged the pores during injection.
- Incremental oil: Accurate measurement of the produced-water cut, especially for those wells producing at water cuts greater than 90%, is key for reporting accurate incremental oil. In addition, water salinity at the producing wells was measured, and a repeated tracer program was instituted. The results have been used to assess the reservoir architecture and incremental oil related to polymer injection. The challenges in the interpretation of the pilot conformance could be resolved by use of these data.
- Polymer, oil, water treatment: The surface facilities are monitored constantly for separation efficiency and plugging owing to back-produced polymers. Operating challenges are seen in all treatment steps for full-field polymer-injection implementation because of both oil/water separation and handling of the polymers in water-treatment facilities.
|File Size||1 MB||Number of Pages||10|
Al Kalbani, H., Mandhari, M. S., Al-Hadhrami, H. et al. 2014. Treating Back Produced Polymer To Enable Use of Conventional Water Treatment Technologies. Presented at the SPE EOR Conference at Oil and Gas West Asia, Muscat, Oman, 31 March–2 April. SPE-169719-MS. http://dx.doi.org/10.2118/169719-MS.
Allison, J. D., Wimberly, J. W., and Ely, T. L. 1987. Automated and Manual Methods for the Determination of Polyacrylamide and Other Anionic Polymers. SPE Res Eng 2 (2): 184–188. SPE-13589-PA. http://dx.doi.org/10.2118/13589-PA.
API RP 63-5, Recommended Practices for Evaluation of Polymers Used in Enhanced Oil Recovery Operations. 1990. Washington D.C.: American Petroleum Institute.
Buciak, J. M., Sancet, G., and Del Pozo, L. 2015. Polymer-Flooding-Pilot Learning Curve: Five-Plus Years’ Experience To Reduce Cost per Incremental Barrel of Oil. SPE Res Eval & Eng 18 (1): 11–19. SPE-166255-PA. http://dx.doi.org/10.2118/166255-PA.
Cheng, H., Shook, G. M., Malik, T. et al. 2012. Interwell Tracer Tests To Optimize Operating Conditions for a Surfactant Field Trial: Design, Evaluation, and Implications. SPE Res Eval & Eng 15 (2): 229–242. SPE-144899-PA. http://dx.doi.org/10.2118/144899-PA.
Clemens, T., Deckers, M., Kornberger, M. et al. 2013. Polymer Solution Injection—Near Wellbore Dynamics and Displacement Efficiency, Pilot Test Results, Matzen Field, Austria. Presented at the EAGE Annual Conference & Exhibition incorporating SPE EUROPEC, London, 10–13 June. SPE-164904-MS. http://dx.doi.org/10.2118/164904-MS.
Dijk, H., Buijse, M. A., Nieuwerf, D. J. 2010. Salym Chemical EOR Project, Integration Leads the Way to Success. Presented at the SPE Russian Oil and Gas Technical Conference and Exhibition, Moscow, Russia, 26–28 October. SPE-136328-MS. http://dx.doi.org/10.2118/136328-MS.
Dugstad, O. 2007. Well-to-Well Tracer Tests. In Petroleum Engineering Handbook, Vol. 5—Reservoir Engineering and Petrophysics, ed. E. D. Holstein, Chapter 6, 651–683, Richardson, Texas: Society of Petroleum Engineers.
Gumpenberger, T., Deckers, M., Kornberger, M. et al. 2012. Experiments and Simulation of the Near-Wellbore Dynamics and Displacement Efficiencies of Polymer Injection, Matzen Field, Austria. Presented at the Abu Dhabi International Petroleum Conference and Exhibition, Abu Dhabi, UAE, 11–14 November. SPE-161029-MS. http://dx.doi.org/10.2118/161029-MS.
Hernandez, C., Chacon, L., Anselmi, L. et al. 2002. Single Well Chemical Tracer Test To Determine ASP Injection Efficiency at Lagomar VLA-6/9/21 Area, C4 Member, Lake Maracaibo, Venezuela. Presented at the SPE/DOE Improved Oil Recovery Symposium, Tulsa, 13–17 April. SPE-75122-MS. http://dx.doi.org/10.2118/75122-MS.
Hirasaki, G. J., Miller, C. A., and Puerto, M. 2011. Recent Advances in Surfactant EOR. SPE J. 16 (4): 889–907. SPE-115386-PA. http://dx.doi.org/10.2118/115386-PA.
Hite, J. R., Avasthi, S. M., and Bondor, P. L. 2004. Planning EOR Projects. Presented at the SPE International Petroleum Conference, Puebla Pue., Mexico, 7–9 November. SPE-92006-MS. http://dx.doi.org/10.2118/92006-MS.
Kaminsky, R. D., Wattenbarger, R. C., Szafanski, R. C. et al. 2007. Guidelines for Polymer Flooding Evaluation and Development. Presented at the International Petroleum Technology Conference, Dubai, 4–6 December. IPTC-11200-MS. http://dx.doi.org/10.2523/IPTC-11200-MS.
Laoroongroj, A., Zechner, M., Clemens, T. et al. 2012. Determination of the In-Situ Polymer Viscosity from Fall-Off Tests. Presented at the SPE EUROPEC/EAGE Annual Conference, Copenhagen, Denmark, 4–7 June. SPE-154832-MS. http://dx.doi.org/10.2118/154832-MS.
Laoroongroj, A., Lüftenegger, M., Kadnar, R. et al. 2015. Using Tracer Data to Determine Polymer Flooding Effects in a Heterogeneous Reservoir, 8 TH Reservoir, Matzen Field, Austria. Presented at EUROPEC 2015, Madrid, Spain, 1–4 June. SPE-174349-MS. http://dx.doi.org/10.2118/174349-MS.
Levitt, D. B., Slaughter, W., Pope, G. A. et al. 2011. The Effect of Redox Potential and Metal Solubility on Oxidative Polymer Degradation. SPE Res Eval & Eng 14 (3): 287–298. SPE-129890-PA. http://dx.doi.org/10.2118/129890-PA.
Maerker, J. M. 1975. Shear Degradation of Partially Hydrolyzed Polyacrylamide Solutions. Society of Petroleum Engineers Journal 15 (4): 311–322. SPE-5101-PA. http://dx.doi.org/10.2118/5101-PA.
Manichand, R. N., Moe Soe Let, K. P., Gil, L. et al. 2013. Effective Propagation of HPAM Solutions Through the Tambaredjo Reservoir During a Polymer Flood. SPE Prod & Oper 28 (4): 358–368. SPE-164121-PA. http://dx.doi.org/10.2118/164121-PA.
Manichand, R. N. and Seright, R. S. 2014. Field vs. Laboratory Polymer-Retention Values for a Polymer Flood in the Tambaredjo Field. SPE Res Eval & Eng 17 (3): 314–325. SPE-169027-PA. http://dx.doi.org/10.2118/169027-PA.
Martin, F. D. 1986. Mechanical Degradation of Polyacrylamide Solutions in Core Plugs From Several Carbonate Reservoirs. SPE Form Eval 1 (2): 139–150. SPE-12651-PA. http://dx.doi.org/10.2118/12651-PA.
Moreau, P., Morvan, M., Rivoal, P. et al. 2010. An Integrated Workflow for Chemical EOR Pilot Design. Presented at the SPE Improved Oil Recovery Symposium, Tulsa, 24–28 April. SPE-129865-MS. http://dx.doi.org/10.2118/129865-MS.
Prasad, D., Pandey, A., Kumar, S. M. et al. 2014. Pilot to Full-Field Polymer Application in One of the Largest Onshore Field in India. Presented at the SPE Improved Oil Recovery Symposium, Tulsa, 12–16 April. SPE-169146-MS. http://dx.doi.org/10.2118/169146-MS.
Putz, A. G., Lecourtier, J. M., and Bruckert, L. 1988. Interpretation of High Recovery Obtained in a New Polymer Flood in the Chateaurenard Field. Presented at the SPE Annual Technical Conference and Exhibition, Houston, 2–5 October. SPE-18093-MS. http://dx.doi.org/10.2118/18093-MS.
Rambeau, O., Jacob, M., Rondon, M. et al. 2014. A Tool to Tackle the Challenges of the Treatment of the Back Produced Viscosified Water. Presented at the International Petroleum Technology Conference, Doha, Qatar, 19–22 January. IPTC-17626-MS. http://dx.doi.org/10.2523/IPTC-17626-MS.
Seright, R. S., Seheult, J. M., and Talashek, T. 2009. Injectivity Characteristics of EOR Polymers. SPE Res Eval & Eng 12 (5): 783–792. SPE-115142-PA. http://dx.doi.org/10.2118/115142-PA.
Shook, G. M., Pope, G. A., and Asakawa, K. 2009. Determining Reservoir Properties and Flood Performance From Tracer Test Analysis. Presented at the SPE Annual Technical Conference and Exhibition, New Orleans, 4–7 October. SPE-124614-MS. http://dx.doi.org.10.2118/124614-MS.
Sjöblom, J. 2005. Emulsions and Emulsion Stability, second edition, Chapter 14, 534–537. Boca Raton, Florida: CRC Press.
Sorbie, K. S. and Roberts, L. J. 1984. A Model for Calculating Polymer Injectivity Including the Effects of Shear Degradation. Presented at the SPE Enhanced Oil Recovery Symposium, Tulsa, 15–18 April. SPE-12654-MS. http://dx.doi.og/10.2118/12654-MS.
Shuaili, K. H., Cherukupalli, P. K., Al-Saadi, F. S. et al. 2012. Fracture Growth Monitoring in Polymer Injectors—Field Examples. Presented at the Abu Dhabi International Petroleum Conference and Exhibition, Abu Dhabi, UAE, 11–14 November. SPE-160967-MS. http://dx.doi.org/10.2118/160967-MS.
Suri, A., Sharma, M. M., and Peters, E. J. 2011. Estimates of Fracture Lengths in an Injection Well by History Matching Bottomhole Pressures and Injection Profile. SPE Res Eval and Eng 14 (4): 385–397. SPE-132524-PA. http://dx.doi.org/10.2118/132524-PA.
Taber, J. J., Martin, F. D., and Seright, R. S. 1997. EOR Screening Criteria Revisited - Part 1: Introduction to Screening Criteria and Enhanced Recovery Field Projects. SPE Res Eng 12 (3): 189–198. SPE-35385-PA. http://dx.doi.org/10.2118/35385-PA.
Teletzke, G. F., Wattenbarger, R. C., and Wilkinson, J. R. 2010. Enhanced Oil Recovery Pilot Testing Best Practices. SPE Res Eval & Eng 13 (1): 143–154. SPE-118055-PA. http://dx.doi.org/10.2118/118055-PA.
van den Hoek, P. J. 2004. Impact of Induced Fractures on Sweep and Reservoir Management in Pattern Floods. Presented at the SPE Annual Technical Conference and Exhibition, Houston, Texas, USA, 26-29 September. SPE-90968-MS. http://dx.doi.org/10.2118/90968-MS.
van den Hoek, P. J., Mahani, H., Sorop, T. et al. 2012. Application of Injection Fall-Off Analysis in Polymer Flooding. Presented at the SPE EUROPEC/EAGE Annual Conference, Copenhagen, Denmark, 4–7 June. SPE-154376-MS. http://dx.doi.org/10.2118/154376-MS.
Wylde, J. J., Slayer, J. L., and Barbu, V. 2013. Polymeric and Alkali-Surfactant Polymer Enhanced Oil Recovery Chemical Treatment: Chemistry and Strategies Required After Breakthrough into the Process. Presented at the SPE International Symposium on Oilfield Chemistry, The Woodlands, Texas, USA, 8–10 April. SPE-164078-MS. http://dx.doi.org/10.2118/164078-MS.
Zechner, M., Clemens, T., Suri, A. et al. 2015. Simulation of Polymer Injection Under Fracturing Conditions—An Injectivity Pilot in the Matzen Field, Austria. SPE Res Eval & Eng 18 (2): 236–249. SPE-169043-PA. http://dx.doi.org/10.2118/169043-PA.
Zheng, F., Quiroga, P., and Sams, G. W. 2011. Challenges in Processing Produced Emulsion from Chemical Enhanced Oil Recovery - Polymer Flood Using Polyacrylamide. Presented at the SPE Enhanced Oil Recovery Conference, Kuala Lumpur, Malaysia, 19–21 July. SPE-144322-MS. http://dx.doi.org/10.2118/144322-MS.
Zwaan, M., Hartmans, R., Schoofs, S. et al. 2012. EOR Field Management Through Well-Planned Surveillance. Presented at the SPE EOR Conference at Oil and Gas West Asia, Muscat, Oman, 16–18 April. SPE-154620-MS. http://dx.doi.org/10.2118/154620-MS.