This article covers Vortex’s downhole testing with Texas A&M and in 25 Rocky Mountain and Mid-Continent oil and gas wells (see pages 4-5). Results of Vortex tool installations with BP and Marathon Oil are included. PDF

This paper covers the Rocky Mountain Oilfield Testing Center’s testing of the Vortex tools in improving flow efficiencies of single-phase high-rate liquid, decreasing paraffin build-up, sweeping out liquids and preventing freezing in gathering lines. A follow-up article in World Oil is also available. PDF

This paper provides a summary of various testing conducted from 2002 through 2006 with the Department of Energy (DoE), Rocky Mountain Oilfield Testing Center (RMOTC), Stripper Well Consortium (SWC) and various universities. This testing covered deliquification (as opposed to artificial lift) applications to extend the flowing life of gas wells and lowering the critical flow requirements to unload wells. Additionally, tests were performed to evaluate the Vortex tools’ effectiveness on mitigating paraffin and line freezing, as well as removing stagnant fluids and preventing associated corrosion problems. PDF

This SPE White Paper (drawn from a graduate MS thesis by Ahsan Ali) covers the Vortex method for unloading and restoring continuous production of low-rate (stripper) gas wells. The performance of the Vortex tool was examined using a 125-ft. vertical flow loop of two-inch diameter clear PVC at the Texas A&M Petroleum Engineering school. The Vortex tool was found to alter the basic flow structure in the pipe, resulting in improved liquid flow and reduced friction, lower slugging and a reduced critical rate. The tool was observed to reduce tubing pressure loss by up to 17% and to lower the minimum gas velocity required to lift liquids up the tubing string below Turner/Coleman theories. PDF

This technical paper covers a 15-month study (through March 2011) on the value of the Vortex surface tools in substantially increasing natural gas liquid (NGL) recovery with marginal change to the value of the gas (7-12 BTU). A major E. Texas independent recovered over 1.2 million gallons of additional NGLs from 10 Vortex tools installed in three gathering lines with the Vortex tools in a single year, translating to over $2 million in additional revenues. An average well line with Vortex paid for itself in less than 60 days (including the cost of the Vortex tool and associated tanks and installation). There were also additional “non-revenue” benefits like reduced pigging, lower methanol use, reduced hydrate formation and zero line freeze-ups on gathering lines with Vortex.PDF

From 2013 to 2015, a major U.S.-based oil and gas independent installed Vortex tools to increase condensate recovery. In each application, the Vortex tools (and associated equipment) had an ROI of mere days, lowered the recovery costs, and stabilized/increased the condensate recovered by up to 3x (with increases in both summer and winter alike). These valuable liquids were then sold to create an additional lucrative revenue stream for the operator without any increase in OpEx. PDF

This paper covers when a publicly-held oil and gas operator landed Vortex DX-I tools at the end of tubing, inside the liner, and in the horizontal lateral (typically set at 80° of deviation). In each case with Vortex, the oil production increased significantly (and in one case, the oil production increased from 80 barrels/day to over 400 barrels/day). Vortex tools also permitted the tubing to be set deeper in the lateral over 200 feet on average (measured depth), thereby increasing efficiency and, in some cases, gained over 400 feet of measured depth. The 10-day increased production from this one reported well was 3,200 barrels of oil (or $345,000 in production values). The Vortex tools for all five wells were paid for in less than one day. PDF