Comparative Study on the Performance of Different Stand-Alone Sand Control Screens in Thermal Wells
- V. Fattahpour (RGL Reservoir Management) | M. Mahmoudi (RGL Reservoir Management) | C. Wang (University of Alberta) | O. Kotb (University of Alberta) | M. Roostaei (University of Alberta) | A. Nouri (University of Alberta) | B. Fermaniuk (RGL Reservoir Management) | A. Sauve (RGL Reservoir Management) | C. Sutton (RGL Reservoir Management)
- Document ID
- Society of Petroleum Engineers
- SPE International Conference and Exhibition on Formation Damage Control, 7-9 February, Lafayette, Louisiana, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 7.2.1 Risk, Uncertainty and Risk Assessment, 7.2 Risk Management and Decision-Making, 3 Production and Well Operations, 2.1.3 Completion Equipment, 7 Management and Information, 2.4 Sand Control, 2 Well completion, 3.2 Well Operations and Optimization, 2.2 Installation and Completion Operations, 3 Production and Well Operations, 3 Production and Well Operations, 3.2.3 Produced Sand / Solids Management and Control
- Open to flow area, Skin Factor, Screen aperture size, Plugging tendency, Stand-alone screen
- 4 in the last 30 days
- 216 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Stand-alone sand screen (SAS) is proven to be effective for sand control in unconsolidated sands in thermal wells. The characteristic design parameter to specify SAS is the aperture size, while the Open to Flow Area (OFA) is chosen to balance between the mechanical integrity of the screen, the completion cost, and the plugging risk. The objective of this study is to compare the performance of common SAS types for a certain geological condition.
A series of three-phase large-scale sand retention tests (SRTs) is performed on slotted liner, wire-wrapped screen, and punched screen coupons. The tests are performed using two common representative PSDs of the McMurray Formation. The test matrix includes the common aperture sizes and OFA for each screen and PSD based on the current best practices in the industry. The test procedure is designed to mimic the near wellbore flow velocities, with three-phase flow ranging from 0%-100% water cut and produced gas-oil ratio ranging from 0-277 scf/bbl. The gas flow was supposed to simulate the steam breakthrough incidents. Live measurements are obtained of the sanding amount and pressure drops along the sand-pack and across the screen. Screen plugging is assessed after the completion of each test.
The sanding and flow performance are shown to be a function of the aperture size, PSD, near-wellbore flow velocities, and the water cut. In low fluid flow rates, all the screen types show minimal pressure drops and perform similarly. As near-wellbore velocities increase or gas flow occurs, pressure drops show a significant increase for all devices. Results show OFA, aperture size, and screen type affect the pressure drop and sanding. In all cases, the produced sand in three-phase flow is the determining design parameter for the upper-bound acceptable aperture. The gas flow is observed to accompany large amounts of sanding for larger aperture sizes. Further, test results indicate high pressure drops for three-phase flow conditions. Test results reveal the complexity of the interaction between different design parameters, which affect the sand and flow performance, hence, necessitating an SRT test for each specific case.
This paper presents the results of physical model testing of different standalone screens in terms of flow performance and sand control. This will help to identify the main factors that influence the performance of each specific screen type and develop the rationale for the screen type selection in new developments.
|File Size||923 KB||Number of Pages||15|
Adams, P.R., Davis, E.R., Hodge, R.M., Burton, R.E., Ledlow, L.B., Procyk, A.D., and Crissman, S.C. 2009. Current State of the Premium Screen Industry; Buyer Beware. Methodical Testing and Qualification Shows You Don't Always Get What You Paid for. SPE Drilling and Completion, 24(3): 362–372. SPE-110082-PA.
Fattahpour, V., Azadbakht, S., Mahmoudi, M., Guo, Y., Nouri, A., and Leitch, M. 2016b. Effect of Near Wellbore Effective Stress on the Performance of Slotted Liner Completions in SAGD Operations, SPE Thermal Well Integrity and Design Symposium, Banff, Alberta, Canada, 29 November – 1 December. SPE-182507-MS
Fattahpour, V., Maciel, V., Mahmoudi, M., Chen, K., Nouri, A., and Leitch, M. 2017. Classification of Alberta Oil Sands Based on Particle Size Distribution for Sand Control Design and Experimental Applications, SPE Canada Heavy Oil Technical Conference, Calgary, Alberta, Canada, 15—16 February. SPE-185000-MS
Fermaniuk, B., Claerhout, M., and Zhu, D. 2015. In-Situ SAGD Thermal-Chemical Effects and Metal-Bond Coated Slotted Liner Design for Enhanced Sand Control, Flow and Long Term Performance. Presented at the SPE Thermal Well Integrity and Design Symposium, 23-25 November, Banff, Alberta, Canada. SPE-178465-MS.
Mahmoudi, M., Roostaei, M., and Ghalambor, A. 2016a. Sand Screen Design and Optimization for Horizontal Wells Using Reservoir Grain Size Distribution Mapping. Presented at the SPE International Conference and Exhibition on Formation Damage Control, 24-26 February, Lafayette, Louisiana, SPE-179036-MS.
Spronk, E.M., Doan, L.T., Matsuno, Y., and Harschnitz, B. 2015. SAGD Liner Evaluation and Liner Test Design for JACOS Hangingstone SAGD Development. Society of Petroleum Engineer. doi:10.2118/174503-MS.