Internal Viscoelastic Surfactant Breakers from In-Situ Oligomerization
- Christopher Daeffler (Schlumberger) | Dominic Perroni (Schlumberger) | Sergey Makarychev-Mikhailov (Schlumberger) | Andrey Mirakyan (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE International Conference on Oilfield Chemistry, 8-9 April, Galveston, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Diversion, Hydraulic fracturing, Internal breaker, Viscoelastic surfactant
- 5 in the last 30 days
- 116 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Viscoelastic surfactants (VES) are important gelling agents in well stimulation treatments. Proper job design requires that the additives create the desired viscosity for effective proppant or gravel pack sand transport. Post-stimulation production enhancement partially relies on the thoroughness of gelling agent destruction or removal, known as "breaking" the gel. VES gels are non-damaging and do not create a filter cake, and thus are prone to high leak-off. The leak-off fluid potentially has a high zero-shear viscosity and can be challenging to remove from the formation. We propose a breaker system that comprises a monomer and radical initiator that will travel into to the formation with the VES gel. The resulting polymer will disrupt the worm-like micelles of the VES, creating spherical micelles and reducing the viscosity of the fluid. The breaker system presented here is operable at 200 °F. Rheology measurements show that the VES fluid with monomer and initiator has reduced viscosity and becomes less shear-thinning. Optical transmission and backscattering measurements show that the presence of breaker does not greatly accelerate proppant settling. The reduced viscosity would not adversely affect proppant transport. Core flow experiments compared retained permeability of cores treated with VES and VES with reacted monomer and initiator. The core flushed with broken fluid possessed a retained permeability of 79%, while the unmodified VES left only 44% retained permeability.
|File Size||1 MB||Number of Pages||9|
Lungwitz, B.; Fredd, C.; Brady, M.; Miller, M.; Ali, S.; Hughes, K. "Diversion and Cleanup Studies of Viscoelastic Surfactant-Based Self-Diverting Acid" SPE 86504 presented at the SPE Interntaional Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, USA, 18-20 February, 2004.
Samuel, M.; Polson, D.; Graham, D.; Kordziel, W.; Waite, T.; Waters, G.; Vinod, P. S.; Fu, D.; Downey, R. "Viscoelastic Surfactant Fracturing Fluids: Applications in Low Permeability Reservoirs" SPE 60322 presented at the SPE Rocky Mountain Regional/Low Permeability Reservoirs Symposium and Exhibition, Denver, Colorado, USA, 12-15 March 2000.
Stewart, B. R.; Mullen, M. E.; Howard, W. J.; Norman, W. D. "Use of a Solids-free Viscous Carrying Fluid in Fracturing Applications: An Economic and Productivity Comparison in Shallow Completions" SPE 30114 presented at the European Damage Control Conference, The Hague, The Netherlands, 15-16 May 1995.
Sullivan, P. F.; Gadiyar, B.; Morales, R. H.; Hollicek, R.; Sorrells, D.; Lee, J.; Fischer, D. "Optimization of a Viscoelastic Surfactant (VES) Fracturing Fluid for Application in High Permeability Formations" SPE 98338 presented at the SPE International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, USA, 15-17 February 2006.
Taylor, D.; Kumar, P. S.; Fu, D.; Jemmali, M.; Helou, H.; Chang, F.; Davies, S.; Al-Mutawa, M. "Viscoelastic Surfactant based Self-diverting Acid for Enhanced Stimulation in Carbonate Reservoirs" SPE 82263 presented at SPE European Damage Control Conference, The Hague, The Netherlands, 14-15 May 2003.