ProductionWave Solution Increased Oil Production 78% in Bakken ...
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CASE HISTORY
ProductionWave Solution Increased Oil Production 78% in Bakken Shale Well Location: North Dakota
Results Eliminated
gas-related shutdowns
Production
increased from 96 BOPD to 171 BOPD and 127 BWPD to 243 BWPD
This
ESP system pulled the pump intake pressure down from 800 psi to 400 psi
Challenges Resource
Drilling, LLC had a well in North Dakota that used a larger volume ESP during the initial production phase of the well
Well
deliverability declined, which required down sizing the ESP
Resource
Resource Drilling, LLC operated an electrical submersible pumping (ESP) system in a North Dakota Bakken well. This ESP worked well initially during post-frac and flowback operations, but a declining production rate, combined with shutdowns due to gas interference, required switching out the existing system. The management group at Resource Drilling, LLC discussed alternative artificial lift options, including sucker rod lift and the new FLEX™ pump from Baker Hughes. They met with representatives from Baker Hughes and decided on an ESP system changeout to the ProductionWave™ FLEXible production solution. “Our company had developed an excellent working relationship with personnel from Baker Hughes at both the Denver office and in the field in North Dakota,” said Butch Butler, president of Resource Drilling, LLC.
“We are a small company and the concern from the Baker Hughes people for our company’s issues was superb. I was well aware of the newly developed FLEX3.2 technology and felt it was worth testing.”
Drilling’s management group considered two options: rod lift or the newly developed FLEX3.2 pump as part of the ProductionWave FLEXible production solution
Baker Hughes solution Resource
The team completed an efficient system changeout and installed the FLEX3.2 pump, vortex gas separator, MVP™ charge pump, and additional ProductionWave components. The new equipment pulled the pump intake pressure (PIP) down from 800 psi to 400 psi with zero gas-related shutdowns. “The shroud installed on the pump/motor assembly allowed us to perform our chemical/ freshwater treatments without any increase in temperature as the shroud forced all fluid flow past the motor, keeping it cool,” said Butler.
Drilling and Baker Hughes decided the FLEX3.2 pump, vortex gas separator, MVP charge pump, and additional ProductionWave components would efficiently handle this well’s lower flow rates of 300 to 400 BFPD
Baker
Hughes kept the original system’s surface equipment and did an ESP system changeout to the new ProductionWave solution with FLEX3.2 pump
CASE HISTORY The operator was pleased with the 78% increase in oil production achieved by the ProductionWave solution. Production averaged 96 BOPD and 127 BWPD before installation of the ProductionWave system. Production increased to an average of 171 BOPD and 243 BWPD, or a 78% increase. The ProductionWave solution included the latest ESP technology, systems for gas handling, and knowledgeable field support from Baker Hughes.
FLEX, ProductionWave, and MVP are trademarks of Baker Hughes Incorporated. Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2013 Baker Hughes Incorporated. All rights reserved. 39754 11/2013
CASE HISTORY
ProductionWave Solution Increased Oil Production 78% in Bakken Shale Well Location: North Dakota
Results Eliminated
gas-related shutdowns
Production
increased from 96 BOPD to 171 BOPD and 127 BWPD to 243 BWPD
This
ESP system pulled the pump intake pressure down from 800 psi to 400 psi
Challenges Resource
Drilling, LLC had a well in North Dakota that used a larger volume ESP during the initial production phase of the well
Well
deliverability declined, which required down sizing the ESP
Resource
Resource Drilling, LLC operated an electrical submersible pumping (ESP) system in a North Dakota Bakken well. This ESP worked well initially during post-frac and flowback operations, but a declining production rate, combined with shutdowns due to gas interference, required switching out the existing system. The management group at Resource Drilling, LLC discussed alternative artificial lift options, including sucker rod lift and the new FLEX™ pump from Baker Hughes. They met with representatives from Baker Hughes and decided on an ESP system changeout to the ProductionWave™ FLEXible production solution. “Our company had developed an excellent working relationship with personnel from Baker Hughes at both the Denver office and in the field in North Dakota,” said Butch Butler, president of Resource Drilling, LLC.
“We are a small company and the concern from the Baker Hughes people for our company’s issues was superb. I was well aware of the newly developed FLEX3.2 technology and felt it was worth testing.”
Drilling’s management group considered two options: rod lift or the newly developed FLEX3.2 pump as part of the ProductionWave FLEXible production solution
Baker Hughes solution Resource
The team completed an efficient system changeout and installed the FLEX3.2 pump, vortex gas separator, MVP™ charge pump, and additional ProductionWave components. The new equipment pulled the pump intake pressure (PIP) down from 800 psi to 400 psi with zero gas-related shutdowns. “The shroud installed on the pump/motor assembly allowed us to perform our chemical/ freshwater treatments without any increase in temperature as the shroud forced all fluid flow past the motor, keeping it cool,” said Butler.
Drilling and Baker Hughes decided the FLEX3.2 pump, vortex gas separator, MVP charge pump, and additional ProductionWave components would efficiently handle this well’s lower flow rates of 300 to 400 BFPD
Baker
Hughes kept the original system’s surface equipment and did an ESP system changeout to the new ProductionWave solution with FLEX3.2 pump
CASE HISTORY The operator was pleased with the 78% increase in oil production achieved by the ProductionWave solution. Production averaged 96 BOPD and 127 BWPD before installation of the ProductionWave system. Production increased to an average of 171 BOPD and 243 BWPD, or a 78% increase. The ProductionWave solution included the latest ESP technology, systems for gas handling, and knowledgeable field support from Baker Hughes.
FLEX, ProductionWave, and MVP are trademarks of Baker Hughes Incorporated. Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2013 Baker Hughes Incorporated. All rights reserved. 39754 11/2013
