Development of Marginal/Mature Oil Fields: A Case Study of the Sinclair Field
- P. Resnyanskiy (University of Alberta) | T. Babadagli (University of Alberta)
- Document ID
- Society of Petroleum Engineers
- Journal of Canadian Petroleum Technology
- Publication Date
- April 2010
- Document Type
- Journal Paper
- 29 - 35
- 2010. Society of Petroleum Engineers
- 5.1.1 Exploration, Development, Structural Geology, 5.3.2 Multiphase Flow, 4.3.4 Scale, 5.1 Reservoir Characterisation, 3.3 Well & Reservoir Surveillance and Monitoring, 2.4.3 Sand/Solids Control, 5.5 Reservoir Simulation, 6.5.2 Water use, produced water discharge and disposal, 1.6.9 Coring, Fishing, 5.6.1 Open hole/cased hole log analysis, 5.5.8 History Matching, 5.1.5 Geologic Modeling, 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex), 1.2.3 Rock properties, 5.7.2 Recovery Factors, 5.4.1 Waterflooding, 2.5.2 Fracturing Materials (Fluids, Proppant)
- mature fields, Sinclair field, marginal fields
- 2 in the last 30 days
- 1,156 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 12.00|
|SPE Non-Member Price:||USD 35.00|
Development of marginal/mature fields has become popular because of a significant decline in new field discoveries and high oil prices. In particular, small size fields of this kind are more challenging because of limited options for development. This paper presents a study on the Sinclair field located in Alberta, Canada. The field has 19 wells, six of which are horizontal, and have been in production for more than 20 years. Despite the quality of oil (40°API, 1.5 cp) and rock properties (20% average porosity, water-wet sandstone), the current production is less than 100 bbl/D for the whole field. The field is now undergoing waterflooding. The main challenges are the thin pay zone (~4 m), severe water production and a puzzling recovery factor of approximately 10%.
The current study consists of three phases: numerical reservoir modelling and history match to understand the reasons for low oil production and to analyze the hydrodynamic characteristics of the field, characterization of reservoir and interwell connectivity using static and production data and proposing an enhanced oil recovery technique supported by field scale numerical simulation. After modelling and history matching stages, potential reserves locations are estimated for possible dilute surfactant injection. Based on interwell connectivity, different injection schemes that use some producers as injectors are tested. The obtained results are subject to further evaluation and analysis to derive the economic viability of the field.
|File Size||1 MB||Number of Pages||7|
1. Babadagli, T. 2005. MatureField Development—A Review. 2005. Paper SPE 93884 presented at the SPEEUROPEC/EAGE Annual Conference, Madrid, Spain, 13-16 June. doi:10.2118/93884-MS.
2. Coste, J.-F. 2000. AnInnovative Approach for the Analysis of Production History in Mature Fields: AKey Stage for Field Re-engineering. Paper SPE 62880 presented at the SPEAnnual Technical Conference and Exhibition, Dallas, 1-4 October. doi:10.2118/62880-MS.
3. Webber, K.J. and Dronkert, H. 1999. Screening Criteria to Evaluate theDevelopment Potential of Remaining Oil in Mature Fields. SPE Res Eval& Eng 2 (5): 405-411. SPE-57873-PA. doi: 10.2118/57873- PA.
4. Suárez, A.F, Hocol, S.A., Gaviria, W., Pavas, J., and Frorup, M. 2005. Beating the Marginal Well Performancein a Mature Field: San Francisco Field in Colombia. Paper SPE 94987presented at the SPE Latin American and Caribbean Petroleum EngineeringConference, Rio de Janeiro, 20-23 June. doi: 10.2118/94987-MS.
5. Graf, T., Henrion, H., Bellavance, R., and Fernandes, J. 2005. Shifting the Gaussian Curve to theRight—A Fully Stochastic Approach to Marginal Offshore Field Development.Paper SPE 94206 presented at the SPE EUROPEC/EAGE Annual Conference, Madrid,Spain, 13-16 June. doi: 10.2118/94206-MS.
6. Marquez, L.J., Gonzalez, M., Gambler, S., Gomez, E., Vivas, M.A.,Bressler, H.M., Jones, L.S., Ali, S.M., and Forrest, G.S. 2001. Improved Reservoir Characterizationof a Mature Field Through an Integrated Multi-Disciplinary Approach. LL-04Reservoir, Tia Juana Field, Venezuela. Paper SPE 71355 presented at the SPEAnnual Technical Conference and Exhibition, New Orleans, 30 September-3October. doi: 10.2118/71355-MS.
7. Babadagli, T., Al-Bemani, A., Boukadi, F., and Iyoho, A.W. 2001. EOR Possibilities for Development ofa Mature Light-Oil Reservoir in Oman. Paper SPE 72110 presented at the SPEAsia Pacific Improved Oil Recovery Conference, Kuala Lumpur, 6-9 October. doi:10.2118/72110-MS.
8. Mohaghegh, S.D., Gaskari, R., and Jalali, J. 2005. A New Method for Production DataAnalysis To Identify New Opportunities in Mature Fields: Methodology andApplication. Paper SPE 98010 presented at the SPE Eastern Regional Meeting,Morgantown, West Virginia, USA, 14-16 September. doi: 10.2118/98010-MS.
9. Agarwal, R.G., Gardner, D.C., Kleinsteiber, S.W., and Fussell, D.D. 1998.Analyzing Well Production DataUsing Combined Type Curve and Decline Curve Analysis Concepts. Paper SPE49222 prepared for presentation at the SPE Annual Technical Conference andExhibition, New Orleans, 27-30 September. doi: 10.2118/49222-MS.
10. Mattar, L. and Anderson, D.M. 2003. A Systematic and ComprehensiveMethodology for Advanced Analysis of Production Data. Paper SPE 84472presented at the SPE Annual Technical Conference and Exhibition, Denver, 5-8October. doi: 10.2118/84472-MS.
11. Jansen, F.E. and Kelkar, M.G. 1997. Non-Stationary Estimation ofReservoir Properties Using Production Data. Paper SPE 38729 presented atthe SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA,5-8 October. doi: 10.2118/38729-MS.
12. Haddad, S., Proano, E., and Patel, Y. 2004. A Method to Diagnose Depletion, Skin,kh, and Drive Mechanism Effects Using Reservoir Monitoring Data. Paper SPE90032 presented at the SPE Annual Technical Conference and Exhibition, Houston,26-29 September. doi: 10.2118/90032-MS.
13. Kabir, C.S. and Young, N.J. 2001. Handling Production Data Uncertaintyin History Matching: The Meren Reservoir Case Study. Paper SPE 71621presented at the SPE Annual Technical Conference and Exhibition, New Orleans,30 September-3 October. doi: 10.2118/71621-MS.
14. Yortsos, Y.C., Choi, Y., Yang, Z., and Shah, P.C. 1999. Analysis and Interpretation ofWater/Oil Ratio in Waterfloods. SPE J. 4 (4): 413- 424.SPE-59477-PA. doi: 10.2118/59477-PA.
15. Guan, L., Du, Y., and Li, L. 2004. Wavelets in Petroleum Industry: Past,Present and Future. Paper SPE 89952 presented at the SPE Annual TechnicalConference and Exhibition, Houston, 26-29 September. doi: 10.2118/89952-MS.
16. Panda, M.N., Mosher, C.C., and Chopra, A.K. 2000. Application of Wavelet Transforms toReservoir-Data Analysis and Scaling. SPE J. 5 (1): 92-101.SPE-60845-PA. doi: 10.2118/60845-PA.
17. Jansen, F.E. and Kelkar, M.G. 1997. Application of Wavelets to ProductionData in Describing Inter-Well Relationships. Paper SPE 38876 presented atthe SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA,5-8 October. doi: 10.2118/38876-MS.
18. Foster, W.R. 1973. A LowTension Waterflooding Process. J Pet Technol 25 (2): 205-210;Trans., AIME, 255. SPE-3803-PA. doi: 10.2118/3803-PA.
19. Bae, J.H. and Syed, E.U. 1988. Glenn Pool Surfactant Flood PilotTests: Part 2—Field Operations. SPE Res Eng 3 (3): 771-777.SPE- 15551-PA. doi: 10.2118/15551-PA.
20. Bae, J.H. 1995. Glenn PoolSurfactant Flood Expansion Project: A Technical Summary. SPE Res Eng10 (2): 123-128. SPE-27818-PA. doi: 10.2118/27818-PA.
21. Maerker, J.M. and Gale, W.W. 1992. Surfactant Flood Process Design forLoudon. SPE Res Eng 7 (1): 36-44; Trans., AIME,293. SPE-20218-PA. doi: 10.2118/20218-PA.
22. Michels, A.M., Djojosoeparto, R.S., Haas, H., Mattern, R.b., van derWeg, P.B., and Schulte, W.M. 1996. Enhanced Waterflooding Design WithDilute Surfactant Concentrations for North Sea Conditions. SPE Res Eng11 (3): 189-195. SPE-35372-PA. doi: 10.2118/35372- PA.