Bernoulli 2.0

The result is a Venturi effect that produces formation fluid much faster and more economically.


Call Thomas Martino (701) 651-4838


Illustration of Diverse Energy & Tech Flo Jet Pump


Innovative Technology

“Get to the pay quicker”

The new design of the proprietary Diverse/Tech-Flo Jet Pump is specific to the needs of the Bakken operator and leverages the power of the Venturi effect to produce a vacuum that brings formation fluids up to the surface… faster and far more economically.

Jet Pump Comparison Matrix
Rod Pump New Diverse/TF Jet Pump
Capital Cost Low to moderate. Cost increase with depth and larger surface units. Relatively low to moderate. Cost increases with higher horsepower. Wellhead equipment has low profile. Requires surface treating and high pressure pumping equipment.
Operating Cost Moderate for shallow to medium depth (<7000 ft) and low production (<400 bfpd). Units easily changed to other wells (re-use) with minimum cost. Higher costs for wells with deviation. Low power cost of surface unit due to increase jet pump efficiency. Low pump maintenance cost with properly sized throat and nozzle for long run life. No moving parts in pump, simple repair procedures.
Operating Efficiency Artificial lift efficiency is traditionally measured by percentage rates which is not the best metric due to all variables involved. The best way to compare efficiency is HP per barrel produced; the jet pump is as good as or better than all other forms of artificial lift. Diverse’s new TF jet pump design increases critical flow areas to increase efficiency dramatically over traditional jet pump designs as well as the other forms of artificial lift.
DownHole Equipment Reasonably good rod design and operating practices needed. Good selection operating and repair practices needed for rods and pumping. Requires computer design programs for sizing. Tolerant of high solids in power fluid. No moving parts in pump, long service lift. Simple repair procedures to run and retrieve pump downhole.
Facilities Footprint Small footprint on surface. Facilities often have power generation already installed; hence the addition of power for a rod pump unit does not have as large an impact as for gas compression. Small footprint of surface pumps. Can use customer’s facility for pump suction. One surface pump is able to produce multiple wells manifolded together.
Flexibility Good, can control production rate to a certain extent. Excellent, power fluid rates and pressure adjusts the production rate and lift capacity from no-flow to full design capacity of installed pump selection of throat and nozzle sizes extend range of volume and capacity.
Reliability Excellent: run time efficiency >95% if good rod practices followed. Excellent due to enhanced jet pump software and system sizing. No moving parts downhole.
Usage/Outlook Excellent, used on about 85% of USA artificial lift wells. The normal standard artificial lift method. Good for low-high volume and wells requiring flexible operation, wide depth range, high temperature, high corrosion, high GOR, significant sand production. Awareness increasing due to many applications including permanent production, frac flowbacks, well testing/DST, gas well dewatering, slimhole capabilities, etc.
Volume Low Lift Capabilities Excellent, most commonly used method for wells producing <100 bfpd. Excellent at rates down to 20bpd.
Flowing Bottom Hole Pressure The pump depth and the dynamic head restrict achieving a low FBHP. The excellent result can obtain at intake pressure less than 25 psig providing adequate displacement and gas venting, typically about 50 to 100 psig FBHP. Good for wells with flowing bottom hole pressure of 25psi and up.
Gas Liquid Ratio SCF/BBL Feasible for low rate and low GLR (<500 scf/stb). For range 500 to 2000, Gassy wells usually have lower volumetric efficiency. Gas handling ability is rather poor if one has to pump >50% free gas. If the gas anchor or natural separation is used and free gas is venting, the volumetric efficiency can be significantly improved. Not recommended for GLR greater than 2000 scf/stb. Target design is less than 1000 GLR. Not recommended for GOR greater than 2000. Gas above 2000 scf/stb substantially reduces efficiency but helps lift. Vent free gas if possible. The producing of free gas through the pump causes reduction in ability to handle liquids.
Reservoir Access No reservoir access. Cannot run any type of surveillance log. Excellent, new design allows for full bore access to reservoir.
Number of Wells Recommended for single or more. Single wells are the most common. Multiple wells operating from one single surface hydraulic package greatly reduces lift cost.
Well Intervention Workover or pulling rig. Run time efficiency is greater than 90% if good operating practices are followed and if corrosion, wax, asphatenes, solid, etc.. Are controlled. Can be circulated to the surface without pulling the tubing or it can be retrieved by wireline.
Well Inclination Well suited to vertical wells. Not highly recommended for deviated. Slanted and crooked wells present a friction problem. There are increased load and wear problems in high angle deviated holes (>70^). Not recommended for horizontal well. Excellent, for vertical or deviated completion.
Duals Completion Not recommended. With new SlimHole jet pump technology, dual completions are possible in casing as
[3] small as 4.5″.
Depth Limit For less than 2500 ft, pump must be landed below dynamic fluid level. Optimal to have intake below perforations, which allow natural gas separation and vent to annulus. Depth is tied to dynamic fluid level. Maximum depth is 14,000 ft TVD. Due to excessive polished rod load, depth is limited. Rods or structure may limit rate at depth. Not restricted by well depth. However limited by power fluid pressure or horsepower as depth increases. Practical depth 20,000 ft.
Tubing and Casing Limitations Problems only if high rate wells requiring large plunger pumps. Small casing sizes (4.5″ & 5.5″) may limit free gas separation. There is a limitation of downhole pump design in of downhole pump design in small diameter casing. Casing sizes as small as 2-3/8″ and up.
Corrosive Fluid (Corrosion Handling Ability) Good, using corrosion-resistant materials in the construction of subsurface pumps. Good/excellent, using special metallurgy and/or chemical treatment. Chemical in the power fluid can treat the tubular for corrosion. Inhibitor fluid mixes with produced fluid at entry of jet pump throat.
Sand & Solids Handling Ability High solids and sand production is troublesome for low oil viscosity (<10 cp) Improved performance can obtain for high-viscosity (>200 cp) cases. May be able to handle up to 0.1% sand with special pumps. Excellent due to increased flow areas, robust parts, special metallurgy and coatings.
Treatment (Scale & Corrosion Inhibitor) Corrosion and scale treatments easy to perform. Good batch treating inhibitor down annulus used frequently for both corrosion and scale control. Corrosion/scale ability is excellent. Inhibitor with power fluid mixes with produced fluid at entry of jet pump throat. Batch treat down annulus feasible. Tech-Flo’s jet pump system is one of the best ways to chemically treat a well.
Field Power Can use electricity as power source. Prime mover flexibility is good: either engines or motors can be used easily (motors more reliable and flexible). Natural gas engine can be used when electricity is not available. Can use electricity as a power source. A diesel or gas engine can be used where electricity is n ot available. Because of the low power usage, NGL from the well can be used for power generation, dramatically lowering costs.

Download the full Jet Pump Comparison Matrix