|Publisher||Society of Petroleum Engineers|
|Content Type||Conference Paper|
|Title||Remediation of Proppant Flowback-Laboratory and Field Studies|
Philip D. Nguyen, Jimmie D. Weaver, Richard D. Rickman, and Michael W. Sanders, Halliburton
European Formation Damage Conference, 30 May-1 June 2007, Scheveningen, The Netherlands
2007. Society of Petroleum Engineers
5.3.5 Scale, Sand, Corrosion, and Clay Migration Control
5.3.6 Produced Water Management and Control
1.5.4 Completion Equipment
Laboratory flow testing indicates that the proppant pack in a fracture model
under closure stress only requires low-strength bonds between proppant grains
to withstand high production flow rates. The consolidation treatment transforms
the loosely packed proppant in the fractures and the formation sand close to
the wellbore into a cohesive, consolidated, yet highly permeable pack. Field
case histories are presented and the treatment procedures, precautions, and
recommendations for implementing the treatment process are discussed. One major
advantage of this remedial treatment method is the ability to place the
treatment fluid into the propped fractures, regardless of the number of
perforation intervals and the length of the perforated intervals without
mechanical isolation between the intervals. The fluid placement efficiency of
this process makes remediation economically feasible, especially in wells with
Low production rates directly affect potential revenue for the operator. Frequent workovers required for cleanup or sand removal, including shut-in time, also factor into the revenue losses caused by proppant flowback or sand infill. However, the problem will return and the loss of revenue will continue to stack up unless a treatment can be found that will remediate the problem at its source and not simply clean up the wellbore.
After an initial completion, it is often very difficult to conduct cost-effective remedial treatments to treat proppant production problems. Conventional remedial treatments are usually inadequate without some type of mechanical isolation technique. Conventional methods with a good chance of effective treatment usually either pose too high of a risk for subsequent well problems or are too costly to consider for low-return reservoir conditions (or both).
Consolidation fluid treatments have been applied remedially to treat proppant flowback. However, a key problem with using these materials has been an inability to achieve uniform placement of the consolidation fluid treatment into the propped fractures such that the entire perforated interval is adequately treated. This problem is amplified by the presence of variable permeability, perforation debris, formation damage in the near-wellbore region, and the high viscosity of many resin materials.
A system that attacks the problem at its source is a better approach to this problem. Using a system of precisely placed treatment fluids into propped fractures conveyed by coiled tubing can turn many marginal wells into excellent producers, and do so cost-effectively. The treatment chemicals introduced into the formation form a consolidated, highly permeable pack that can withstand the high drawdown associated with the production. This paper discusses such a system.
Problems of Proppant Flowback
|File Size||1,322 KB|