Baker Hughes announced Monday its commercial release of Sorb Ultra solid inhibitors. Delivered and mixed with the proppant as part of StimPlus stimulation treatment, Sorb Ultra inhibitors can minimize the risk of expensive interventions and lost production in offshore wells.
The solid substrate on which the inhibitor is applied is engineered to help ensure reliable applications in deepwater environments, and can be customized to treat a range of downhole conditions including scale, paraffin and asphaltene deposition.
The treatment begins in the propped zone as soon as produced fluids contact the SorbUltra inhibitors. This process occurs before the produced fluids reach the near wellbore, where temperature or pressure changes commonly cause flow-assurance problems. The treatments have lasted longer than conventional liquid flow assurance chemistry, and, depending on the well production, can remain in production fluids at effective levels long after they are pumped.
The inhibitors are applied as part of the well stimulation to obstruct deposition in the near-wellbore environment and formation. It can be run in new or existing wells, as part of a propped stimulation such as a gravel pack or frac pack, and is ideal for wells with closure-rates in excess of 8,000 psi.
The SorbUltra solid inhibitors have been evaluated and qualified using the company’s SmartCare environmentally responsible chemical solutions. The SmartCare evaluation process was designed to ensure technical performance and environmental priorities are mutually achieved.
The cost of a well intervention for a deepwater well can exceed several million dollars. By placing a long lasting inhibitor into the propped zone, the operator could realize an economic benefit far in excess of the cost of the application. By extending or possibly eliminating the need for a future intervention, the application of this technology can have a significant impact on well economics.
During a completion operation, an operator in the Gulf of Mexico identified barium scale deposition as a possible flow assurance issue. Baker Hughes proactively treated the well by mixing the inhibitor on the fly and injecting it into the frac pack along with the proppant.The well was put on production and immediately flowed both oil and water. After two months and two fluid sample tests, analysis of the residual scale inhibitor found in the produced water demonstrated that the scale inhibitor was still present and was still inhibiting scale in the formation.
WHAT DO YOU THINK?
Click on the button below to add a comment.
Generated by readers, the comments included herein do not reflect the views and opinions of Rigzone. All comments are subject to editorial review. Off-topic, inappropriate or insulting comments will be removed.
Most Popular Articles
From the Career Center
Jobs that may interest you