Tubless proppant blending system for high and low pressure blending

Abstract

Fracturing slurries are prepared on the fly using a solids pump to feed the solid such as a gel into a liquid stream of normally water for pumping downhole with a large capacity triplex pump. The solids pump is preferably a Posimetric® style which delivers the solid into the fluid pipeline in a manner that keeps fluid from backing into the solids hopper above the solids pump. A separate fluid tank is connected to a fluid pump to pressurize a suction line to a boost pump before reaching the triplex pump and pumping into the subterranean formation. The solids pump can deliver between the fluid and boost pumps in which case the solids go through the triplex pump or alternatively the solids can be delivered into the higher pressure discharge line of the triplex pump.

Claims

1. A borehole treating method, comprising: making a slurry on the fly by injecting a solid in a dry state with a solids pump into a pressurized fluid pipe for initial fluid mixing in said pipe on a discharge side of an injection pump without an intervening blending tank; pumping said slurry with said injection pump to a subterranean formation; and treating in or from the borehole.

2. The method of claim 1, comprising: using a Posimetric® pump as said solids pump.

3. The method of claim 1, comprising: using water, a polymer based gel, non-aqueous fluid, foam, nitrogen gas, liquid CO2, or LNG as said fluid.

4. The method of claim 1, comprising: using sand, powdered dry cement, diverters, breakers, or a dry chemical additive as said solid.

5. The method of claim 1, comprising: performing as said treating at least one selected from the group consisting of cementing, acidizing, gravel packing, sand control, and solids disposal of drill cuttings.

6. The method of claim 1, comprising: providing a fluid storage vessel and associated fluid pump to remove the fluid from the vessel; and directing the discharge of said fluid pump to the suction of a booster pump; directing a discharge of said booster pump to a suction of said injection pump.

7. The method of claim 6, comprising: injecting the solid into a pressurized conduit between said fluid and booster pumps.

8. The method of claim 7, comprising: providing a line from a solids pump discharge connection into the pressurized conduit between said fluid and booster pumps.

9. The method of claim 7, comprising: discharging solids from said discharge connection on the solids pump at the pressurized conduit between said fluid and booster pumps.

10. The method of claim 1, comprising: using a treating pump at a surface location for said pumping.

11. The method of claim 10, comprising: injecting said solid downstream of said treating pump.

12. The method of claim 11, comprising: using a booster pump upstream of said treating pump to pressurize fluid from a storage vessel.

13. The method of claim 11, comprising: connecting the discharge of said solids pump directly or indirectly to the pressurized fluid conduit downstream of said treating pump.

14. The method of claim 13, comprising: using a Posimetric® pump as said solids pump.

15. The method of claim 10, comprising: injecting said solid upstream of said treating pump.

Description

BRIEF DESCRIPTION OF THE DRAWING

(1) The FIGURE is a schematic representation of one possible configuration for the system of the present invention and illustrates a possible alternate arrangement.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT

(2) A fluid supply 10 holds water or other liquids and is connected to a storage tank 12 by line 14. The water supply is in many cases brought to a well site with 18 wheelers. Fluid pump 16 is connected by line 18 to bring the water through discharge line 20. The line 22 connects with discharge line 20 for delivery of solids, semisolids or other materials from the storage vessel 24. The solids pump 26 can deliver from the vessel 24 through line 22 or line 22 can be eliminated and the discharge from pump 26 can go directly into line 20. In an alternative embodiment the solids can be fed into line 28 that goes to the wellhead (not shown). The frac pump 30 is fed by boost pump 32 through line 34. Line 20 extends on one end to the boost pump 32. If the solids pump 26 delivers into line 20 then boost pump 32 and frac pump 30 both handle slurry. On the other hand if the solids are delivered through line 22′ then pumps 30 and 32 do not see solids but the tradeoff is that the pump 26 horsepower requirement goes up substantially as the solids must be injected into a line that has orders of magnitude higher pressure than line 20. On the other hand, one of the pumps 16 or 32 can be eliminated if the solids are delivered downstream of frac pump 30.

(3) Instead of water the fluid 10 can be a polymer based gel or non-aqueous fluid, foams, gases such as nitrogen and liquid CO2, LNG, etc. The solid material in vessel 24 can be sand, powdered cement or a dry chemical additive.

(4) Those skilled in the art will appreciate that a fracturing or cementing system and method is described that removes the need to premix solids with a carrier fluid in an agitated tank before pumping the slurry into the subterranean location. Instead the solids are delivered to the pressurized liquid line either before or after the frac pump. Preferably the solids are directly delivered to line 20 that works at fairly low pressures as the capacities of the pumps 16 and 32 are evenly matched. Injection of solids into a lower pressure line also takes less horsepower driving the solids pump 26. Although a Posimetric® pump is preferred other solids delivery devices that compress the solid delivered near the point of discharge to prevent fluid backup into the solids pump are also contemplated. The advantages are space and reliability gains as an agitated mix tank is eliminated along with agitator horsepower requirements. in the alternative embodiment of injecting the solids downstream of frac pump 30 one of the two pumps 16 or 32 can be eliminated and less wear on the frac pump 30 is experienced as the solids bypass that pump altogether.

(5) The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers, dry additives such as diverters, breakers or dry cement etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, gravel packing, sand control, cleaning, acidizing, steam injection, water flooding, cementing, solids disposal of drill cuttings etc. The term “treat” or “treating” when used in this application is intended to encompass any one or more of the listed materials or procedures and their equivalents.

(6) The above description is illustrative of the preferred embodiment and many modifications may be made by those skilled in the art without departing from the invention whose scope is to be determined from the literal and equivalent scope of the claims below: