1. 1. Before operating a new injection well, the casing shall be tested to a pressure not less than the maximum authorized injection pressure, or to a pressure of 300 psi, whichever is greater.
2. 2. Before operating an existing well newly converted to an injection well, the casing outside the tubing shall be tested to a pressure not less than the maximum authorized injection pressure, or to a pressure of 1,000 psi, whichever is lesser, provided that each well shall be tested to a minimum pressure of 300 psi.

3. 3. In order to demonstrate continuing mechanical integrity after commencement of injection operations, all injection wells shall be pressure tested or monitored as follows:

   3.1. Pressure Test. The casing-tubing annulus above the packer shall be pressure tested not less than once each five years to a pressure equal to the maximum authorized injection pressure or to a pressure of 1,000 psi, whichever is lesser, provided that no test pressure shall be less than 300 psi. A report documenting the test results shall be submitted to the division.

   3.2. Monitoring. If approved by the director, and in lieu of the pressure testing requirement, the operator may monitor the pressure of the casing-tubing annulus monthly during actual injection operations and report the results to the division.

   3.3. Other test procedures or devices such as tracer surveys, temperature logs or noise logs may be required by the division on a case-by-case basis.

   3.4. The operator shall sample and analyze the fluids injected in each disposal well or enhanced recovery project at sufficiently frequent time intervals to yield data representative of fluid characteristics, and no less frequently than every year.

   3.5. The operator shall submit a copy of the fluid analysis to the division with the Annual Fluid Injection Report, UIC Form 4.

KEY: oil and gas law

Date of Last Change: February 24, 2022

Notice of Continuation: June 30, 2025

Authorizing, and Implemented or Interpreted Law: 40-6-1 et seq.