Changing the Way: Integrated Artificial Lift Strategy | Schlumberger
Tech Paper
Location
Oriente Basin, Ecuador, South America, Onshore
Byline
Johanna Gallegos, Luis Carlos Enriquez, and Carlos Reyes, Schlumberger, APS; Alvaro Correal and Jorge Villalobos, Schlumberger, ALS; Byron Fun Sang, Richard Torres, Carlos Villa, and Christian Bonilla, Schlumberger, APS
Society
SPE
Paper Number
201631
Presentation Date
5–7 October 2020
Products Used
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Changing the Way

Integrated artificial lift strategy overcomes waterflooding and mature field challenges increasing 58% of total oil production



Abstract

The artificial lift strategy described in this document addresses new challenges resulting from an accelerated implementation of secondary recovery in a mature oilfield. New technologies and best operational practices were implemented to handle challenges such as high pressure and water flowrates in source water wells, extended-life ESP to enable production across a wide production range to cover the response of the waterflooding, increasing solids production, heavy oil, and installations of ESP in deep and tortuous wells.

This technical and strategic approach covers artificial lift designs for water injection in well-to-well configurations located in the same platform. This approach reduces the requirements for surface facilities. For oil producers, ESP robustness must be enhanced to handle wide range and aggressive reservoir conditions. Slim ESP applications to allow taking full advantage of waterflooding. A novel concept applied to recirculate hot water making possible produce deep heavy oil reservoirs and updated workflows and equipment for remote surveillance of the ESP systems and reservoir.

The integrated approach of the strategy allows its application in either brownfield or greenfield. Putting such strategy into action resulted in an incremental production of 30,000 bopd from waterflooding using more than 60 ESP installations of wide range and reducing workover interventions representing savings of 4.5 MMUSD. Additionally, direct well-to-well injection in 22 water producer wells allowed direct injection of 100,000 bwpd at roughly 2,000 psi at the well head and savings of 14 MMUSD in surface facilities.

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