Current through Register 2024 Notice Reg. No. 38, September 20, 2024
(a) Operators shall monitor each well that has had a well stimulation treatment as specified in subdivision (d) to identify any indication of a well breach. If monitoring indicates that a well breach may have occurred, then the operator shall perform diagnostic testing on the well to determine whether a breach has occurred. Diagnostic testing shall be done as soon as is reasonably practical. The Division shall be notified when diagnostic testing is being done so that Division staff may witness the testing. All diagnostic testing results shall be immediately provided to the Division.
(b) If diagnostic testing reveals that a breach has occurred, then the operator shall immediately shut-in the well, isolate the perforated interval, and notify the Division and the Regional Water Board with all of the following information:
(1) A description of the activities leading up to the well breach.
(2) Depth interval of the well breach and methods used to determine the depth interval.
(3) An exact description of the chemical constituents of the fluid that is most representative of the fluid composition in the well at the time of the well breach.
(c) The operator shall not resume operation of a well that has been shut-in under subdivision (b) without first obtaining approval from the Division.
(d) Operators shall adhere to the following requirements for a well that has had a well stimulation treatment:
(1) The production pressure of the well shall be monitored at least once every two days for the first thirty days after the well stimulation treatment and on a monthly basis thereafter. Information regarding production pressures shall be reported to the Division on a monthly basis.
(2) The annular pressures of the well shall be reported to the Division annually, unless it has been demonstrated to the Division's satisfaction that there are no voids in the annular space. It shall be immediately reported to the Division if annular pressure exceeds 70% of the API rated minimum internal yield or collapse strength of casing, or if surface casing pressures exceed a pressure equal to: 0.70 times 0.433 times the true vertical depth of the surface casing shoe (expressed in feet).
(3) The annular valve shall be kept accessible from the surface or left open and plumbed to the surface with a working pressure gauge unless it has been demonstrated to the Division's satisfaction that there are no voids in the annular space.
(4) A properly functioning pressure relief device shall be installed on the annulus between the surface casing and the production casing, or, if intermediate casing is set, on the annuli between the surface casing and the intermediate casing and the production casing. This requirement may be waived by the Division, if the operator demonstrates to the Division's satisfaction that the installation of a pressure relief device is unnecessary based on technical analysis and/or operating experience in the area.
(5) If a pressure relief device is installed, then all pressure releases from the device shall be immediately reported to the Division. The maximum set pressure of a surface casing pressure relief device shall be the lowest of the following:
(A) A pressure equal to: 0.70 times 0.433 times the true vertical depth of the surface casing shoe (expressed in feet);
(B) 70% of the API rated minimum internal yield for the surface casing; or
(C) A pressure change that is 20% or greater than the calculated pressure increase due to pressure and/or temperature expansion
1. New section filed 12-30-2014; operative 7-1-2015 pursuant to Public Resources Code section 3161(a), as amended by SB 4, Stats. 2014, c. 313 (Register 2015, No. 1).
2. Editorial correction of HISTORY 1 (Register 2017, No. 24).
Note: Authority cited: Sections 3013 and 3160, Public Resources Code. Reference: Sections 3106 and 3160, Public Resources Code.
