Well connectivity analysis using pressure pulse

1 . A method comprising:

inducing, via one or more hydraulic fracturing components, a first signal in hydraulic fracturing fluid in a treatment well while hydraulically fracturing the treatment well, wherein the treatment well is formed in a subsurface formation;

detecting, via one or more sensors, a response signal in one or more offset wells formed in the subsurface formation based on the first signal, wherein the response signal indicates well connectivity between the treatment well and the one or more offset wells;

generating a multi-well model that represents a relationship between the treatment well, a fracture system, and the one or more offset wells, wherein the multi-well model is configured to determine one or more fracture properties based on the first signal and the response signal; and

determining a fluid loss rate based on the one or more fracture properties.

2 . The method of claim 1 , wherein the one or more fracture properties include fracture length and fracture system conductivity.

3 . The method of claim 2 further comprising:

determining a first travel time of the first signal in the treatment well based on wellbore dimensions of the treatment well and a wave speed of the first signal in the treatment well;

determining a second travel time of the response signal in the one or more offset wells well based on wellbore dimensions of the one or more offset wells and the wave speed of the response signal in the one or more offset wells; and

determining a subsurface formation travel time of a pressure pulse based on the first travel time and the second travel time.

4 . The method of claim 3 further comprising;

determining the wave speed of the pressure pulse in the subsurface formation; and

determining the fracture length based on the wave speed of the pressure pulse in the subsurface formation and the subsurface formation travel time.

5 . The method of claim 2 further comprising:

determining, via an inversion process, a fracture system resistance via the multi-well model; and

determining the fracture system conductivity based on fracture system resistance.

6 . The method of claim 1 further comprising:

determining the fluid loss rate based on a fracture length and a fracture conductivity; and

performing a hydraulic fracturing operation when the fluid loss rate exceeds a threshold.

7 . The method of claim 6 further comprising:

determining an effectiveness of the hydraulic fracturing operation based on a pressure signature measured on the one or more offset wells when the hydraulic fracturing operation is performed.

8 . The method of claim 1 , wherein the first signal is a pressure pulse in the hydraulic fracturing fluid, and wherein the one or more hydraulic fracturing components includes one or more frac pumps.

9 . A system comprising;

a treatment well formed in a subsurface formation;

one or more offset wells formed in the subsurface formation;

a processor; and

a computer-readable medium having instructions stored thereon that are executable by the processor, the instructions including,

instructions to induce, via one or more hydraulic fracturing components, a first signal in hydraulic fracturing fluid in the treatment well while hydraulically fracturing the treatment well; and

instructions to detect, via one or more sensors, a response signal in the one or more offset wells based on the first signal, wherein the response signal indicates well connectivity between the treatment well and the one or more offset wells;

instructions to generate a multi-well model that represents a relationship between the treatment well, a fracture system, and the one or more offset wells, wherein the multi-well model is configured to determine one or more fracture properties based on the first signal and the response signal; and

instructions to determine a fluid loss rate based on the one or more fracture properties.

10 . The system of claim 9 , wherein the one or more fracture properties include fracture length and fracture system conductivity.

11 . The system of claim 10 further comprising:

instructions to determine a first travel time of the first signal in the treatment well based on wellbore dimensions of the treatment well and a wave speed of the first signal in the treatment well;

instructions to determine a second travel time of the response signal in the one or more offset wells well based on wellbore dimensions of the one or more offset wells and the wave speed of the response signal in the one or more offset wells; and

instructions to determine a subsurface formation travel time of a pressure pulse based on the first travel time and the second travel time.

12 . The system of claim 11 further comprising;

instructions to determine the wave speed of the pressure pulse in the subsurface formation; and

instructions to determine the fracture length based on the wave speed of the pressure pulse in the subsurface formation and the subsurface formation travel time.

13 . The system of claim 10 further comprising:

instructions to determine, via an inversion process, a fracture system resistance via the multi-well model; and

instructions to determine the fracture system conductivity based on fracture system resistance.

14 . The system of claim 9 further comprising:

instructions to determine the fluid loss rate based on a fracture length and a fracture conductivity; and

instructions to perform a hydraulic fracturing operation when the fluid loss rate exceeds a threshold.

15 . A non-transitory, computer-readable medium having instructions stored thereon that are executable by a processor, the instructions comprising:

instructions to induce, via one or more hydraulic fracturing components, a first signal in hydraulic fracturing fluid in a treatment well while hydraulically fracturing the treatment well, wherein the treatment well is formed in a subsurface formation;

instructions to detect, via one or more sensors, a response signal in one or more offset wells formed in the subsurface formation based on the first signal, wherein the response signal indicates well connectivity between the treatment well and the one or more offset wells; and

instructions to generate a multi-well model that represents a relationship between the treatment well, a fracture system, and the one or more offset wells, wherein the multi-well model is configured to determine one or more fracture properties based on the first signal and the response signal; and

instructions to determine a fluid loss rate based on the one or more fracture properties.

16 . The non-transitory, computer-readable medium of claim 15 , wherein the one or more fracture properties include fracture length and fracture system conductivity.

17 . The non-transitory, computer-readable medium of claim 16 further comprising:

instructions to determine a first travel time of the first signal in the treatment well based on wellbore dimensions of the treatment well and a wave speed of the first signal in the treatment well;

instructions to determine a second travel time of the response signal in the one or more offset wells well based on wellbore dimensions of the one or more offset wells and the wave speed of the response signal in the one or more offset wells; and

instructions to determine a subsurface formation travel time of a pressure pulse based on the first travel time and the second travel time.

18 . The non-transitory, computer-readable medium of claim 17 further comprising:

instructions to determine the wave speed of the pressure pulse in the subsurface formation; and

instructions to determine the fracture length based on the wave speed of the pressure pulse in the subsurface formation and the subsurface formation travel time.

19 . The non-transitory, computer-readable medium of claim 16 further comprising:

instructions to determine, via an inversion process, a fracture system resistance via the multi-well model; and

instructions to determine the fracture system conductivity based on fracture system resistance.