# US 10,309,202 B2 · Fracturing treatment of subterranean formations using shock waves

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- Number: US 10,309,202 B2
- Document ID: US10309202B2
- Status: Granted
- Kind: B2
- Application number: 14/932,981
- Filed: 2015-11-05
- Published: 2017-05-11
- Granted: 2019-06-04
- Earliest claimed: 2015-11-05
- Applicants: Petro Research and Analysis Corp
- Inventors: Mohamed Yousef Soliman
- Web page: https://patentgrep.com/patent/US10309202B2

## CPC

- E21B 43/26: by forming crevices or fractures
- E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS

## Abstract

Applying shock waves using a plasma pulse generation system or other comparable systems, including an acoustic/pressure oscillatory system, would help to enhance the complexity of the far field hydraulic fracture during fracturing shale formation. It would also help in avoiding pre-mature screen out. The critical factor to maximize the desired results is to apply the shock waves at the correct time. By combining shock wave technology with the newly developed fracturing pressure data analysis, it is possible to achieve maximum results.

## Claims

### Claim 1

A method to influence real time propagation of a hydraulic fracture of a wellbore as injection of fracturing fluid occurs during a hydraulic fracturing treatment, the method comprising the steps of:
commencing injection of fracturing fluid into a wellbore to initiate and propagate a hydraulic fracture;
monitoring, as the injection of fracturing fluid occurs, hydraulic fracturing treatment pressure or one or more microseismic events generated by the propagating hydraulic fracture;
analyzing pressure-time data or microseismic event data of the propagating hydraulic fracture;
determining status of hydraulic fracture propagation from said pressure-time data or microseismic event data;
creating one or more shock waves from electrical energy; and
applying said shock waves into the injected fracturing fluid inside the wellbore, as the injection of fracturing fluid occurs, for the purpose of creating a longer propped hydraulic fracture and/or enlarging one or more natural fractures intersecting the hydraulic fracture, the number of applications of said shock waves and timing of each application of said shock waves determined by said status of the hydraulic fracture propagation;
adding one or more metal filament, metal particles, or nanoparticles of element into the fracturing fluid to create one or more secondary shock waves by chemical thermite reaction for the purpose of enhancing far field hydraulic fracture complexity; and
adjusting an amount and type of filament, metal particles, or nanoparticles to control amplitudes of pressure peaks of shock waves created by chemical thermite reaction and distance between pressure peaks of shock waves created by electrical energy and shock waves created by chemical thermite reaction.

### Claim 2 (depends on 1)

The method of claim 1, wherein time at which metal particles or nanoparticles are delivered into a downhole assembly is controlled by a storage release mechanism.

### Claim 3 (depends on 1)

The method of claim 1, wherein a storage release mechanism may be initiated from a surface by electric wireline, telemetry, or other mechanisms.

### Claim 4 (depends on 1)

The method of claim 1, wherein the secondary shock waves are controlled from the surface of the wellbore by adjusting an amount and type of filament, metal particles, or nanoparticles.

### Claim 5 (depends on 1)

The method of claim 1, wherein said pressure-time data and/or microseismic event data of the propagating hydraulic fracture are analyzed as the injection of fracturing fluid occurs.

### Claim 6 (depends on 1)

The method of claim 1, wherein multiple charging and discharging of capacitors may be used during creation and propagation of the hydraulic fracture.

### Claim 7 (depends on 1)

The method of claim 1, wherein distance between pressure peaks of created shock waves and/or amplitude of said peaks is controlled by distance between electrodes of capacitors, time of capacitor discharge, and level of electrical charge in said capacitors prior to said discharge.

### Claim 8 (depends on 1)

The method of claim 1, wherein application of one or more shock waves as the injection of fracturing fluid occurs dislodge proppant of said hydraulic fracture or open said natural fractures.

### Claim 9 (depends on 1)

The method of claim 1, wherein event of an impending sand out, application of one or more shock waves into the fracturing fluid as the injection of fracturing fluid occurs causes further propagation of the hydraulic fracture.

### Claim 10 (depends on 1)

The method of claim 1, wherein the event of said hydraulic fracture intersecting said natural fractures, application of one or more shock waves into the fracturing fluid as the injection of fracturing fluid occurs increases conductivity of said natural fractures.

### Claim 11 (depends on 1)

The method of claim 1, wherein the injection of fracturing fluid into a horizontal wellbore creates one or more simultaneous hydraulic fractures.