Plus Minus Delay Time Refraction Method Tool

Intercept/delay-time method: recover interface depth from the reversed-profile intercept time t_i = 2h·cos(i_c)/V₁.

Description

Intercept/delay-time method: recover interface depth from the reversed-profile intercept time t_i = 2h·cos(i_c)/V₁.

Plus Minus Delay Time Refraction Method Tool is a focused tool for the following task. Intercept/delay-time method: recover interface depth from the reversed-profile intercept time t_i = 2h·cos(i_c)/V₁. It reports h, τ from the values you provide rather than inventing measurements, coefficients, or professional judgment that are not part of the input.

When to use Plus Minus Delay Time Refraction Method Tool

Use this seismology calculation to reproduce a stated convention, screen observations, or compare scenarios whose units, coordinate conventions, catalog selection, and model assumptions are known.

t_i (s)
Required number in s. Head-wave intercept time.
V₁ (m/s)
Required number in m/s. Overburden velocity.
V₂ (m/s)
Required number in m/s. Refractor velocity.

The cited overview of Seismic tomography supplies background for the terminology and domain context used by this tool.1

How Plus Minus Delay Time Refraction Method Tool works

Intercept/delay-time method: recover interface depth from the reversed-profile intercept time t_i = 2h·cos(i_c)/V₁. Inputs are interpreted exactly in the displayed units and the calculation returns the following fields without presentation rounding.

h (m)
Returned number in m. Interface depth beneath the shot.
τ (s)
Returned number in s. One-way delay time.

Limitations and assumptions

  • Earth structure, source geometry, path effects, site response, instrument response, catalog completeness, uncertainty, and the fitted range can dominate the accuracy of simplified seismic calculations.
  • t_i must be at least 0.
  • V₁ must be at least 0.
  • V₂ must be at least 0.
  • Use finite inputs in the displayed units, preserve source measurements and assumptions, and independently verify consequential decisions.

Alternative or Complementary approaches

For analysis or hazard decisions, retain uncertainty and provenance and compare the result with waveform processing, calibrated regional models, and guidance from qualified seismologists or the responsible agency.

References

  1. Seismic tomography — Wikipedia contributors

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