A completions solution that cost effectively transitions from frac-flowback to natural flow to artif

Tuesday, March 7, 2017, 11:30 AM - 1:00 PM MT

Drilling & Completions:
A completions solution that cost effectively transitions from frac-flowback to natural flow to artificial lift

Date: Tuesday, 7 March 2017
Speaker: Jeff Saponja, Production Plus Energy Services Inc.


Location: Calgary Petroleum Club

Time: 11:30 - 1:00 pm
Cost: $45 SPE Members, $55 Non-members, $15 Students 

Abstract:

Production Plus Energy Services Inc. has learned that the root cause of gas interference and solids damage to pumps, common in horizontal wells, is not poor equipment performance, but sluggy, intermittent production from the horizontal. Large variations in gas and oil rates long with periods of only gas production from the horizontal overwhelm downhole artificial lift pumps. By conditioning the downhole flow, artificial lift pumps can operate efficiently and reliably.

This presentation reviews the technical basis of slug flow and overviews a downhole flow-conditioning completions system that benefits the frac-flowback phase, extends the natural flow phase and enhances the artificial lift phase. Slug flow mitigation during frac-flowback has the potential to significantly reduce proppant flowback and other solids related issues. Extending the natural flow period has the attractive features of lower OPEX production and lowering the capital cost of the artificial lift system. Mitigating slug flows during the artificial lift phase has the production enhancing benefit of maximizing drawdown over the life of the well while improving reliability of the artificial lift system (reducing workovers).

Simpler, less costly transitions between production phases reduce total well cost. Case studies will demonstrate that a slug flow mitigation strategy can significantly benefit a well’s NPV (Net Present Value). This is achieved through a combination of increased pump efficiency and increased drawdown that allows the pump to be positioned in vertical inclinations and at shallower depths. Shallower pump placement and smaller artificial lift equipment, can reduce CAPEX and OPEX. As a result smaller pumping equipment can efficiently achieve higher production rates while simultaneously maximizing drawdown and reducing unit lifting costs over the life of the well.

Speaker Bio:

As Chief Executive Officer of Production Plus Energy Services Inc., Jeff Saponja is an entrepreneurial leader in the oil and gas industry. It was during Jeff’s tenure at TriAxon Oil Corp. that he and his team at TriAxon were able to identify the root cause of horizontal artificial lift challenges. Their drive for innovation resulted in the design and development of the HEAL System™ and the subsequent creation of Production Plus Energy Services Inc. With over 18 months of field use, the HEAL System has over 100 installs across North America.

Jeff’s executive career was prefaced by an accomplished work history including positions with Weatherford Canada, Shell (UK) in the North Sea, and Husky Energy (Canada). In senior engineering positions Jeff acquired extensive technical experience in horizontal underbalanced drilling, multi-stage fracture stimulation, and artificial lift.

Jeff holds a B.Sc. in Mechanical Engineering from the University of Calgary and completed an MBA at the University of East Anglia in the United Kingdom.

The SPE would like to thank our sponsor: Energy Navigator

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