Oklahoma Administrative Code › Title 165 - Corporation Commission › Chapter 10 - Oil And Gas Conservation › Subchapter 5 - Underground Injection Control › Section 165:10-5-6 - Testing and monitoring requirements for injection wells and disposal wells

Current through Vol. 41, No. 20, July 1, 2024
(a)
Mechanical integrity during injection.
The operator of an
				injection, disposal or commercial disposal well must maintain mechanical
				integrity in order to continue operation of the well.
(b)
Initial pressure test requirements
				for wells permitted on or after December 2, 1981.
(1)
Mandatory initial mechanical
				test.
Before commencement of operation, each well authorized for
				injection or disposal by a Commission order issued on or after December 2,
				1981, must pass an initial pressure test of the casing tubing annulus according
				to the minimum testing standards of (2) of this subsection, unless a Commission
				order or permit authorizes other test procedures of the mechanical integrity of
				the well. Any operator failing to comply with initial mechanical integrity
				testing and reporting requirements may be fined up to $500.00.
(2)
Minimum testing standards for
				initial tests.
For each initial test required by (1) of this subsection,
				the minimum testing standards are:
(A)
Witnessing of the test.
The test shall be witnessed by an
				authorized representative of the Conservation Division. It shall be the
				responsibility of the well operator to secure the presence of the Conservation
				Division representative.
(B)
Down-hole equipment.
Injection and disposal shall be through
				adequate tubing and packer.
(C)
Aboveground extensions and fittings.
Adequate aboveground
				extensions shall be installed in each annulus in the well. In addition, the
				operator shall install an adequate working pressure gauge with a cutoff valve
				to the tubing, so that the amount of injection pressure may be measured by the
				Conservation Division representative. An operator is required to keep adequate
				working gauges on the tubing and annulus of the well.
(D)
Packer setting depth under the
				order.
The mechanical packer shall be set within 40 feet of the packer
				setting depth prescribed by the order permitting the well for injection or
				within 75 feet of the perforations of the injection zone(s) opened.
(E)
Verification of packer setting
				depth.
The Conservation Division District Manager may require the
				operator of the well to verify the packer setting depth by running a wireline
				or other method approved by the Manager of the Underground Injection Control
				Department.
(F)
Minimum
				testing pressure for noncommercial disposal and injection wells.
Noncommercial disposal and injection wells shall be tested as follows:
(i) If the maximum authorized injection
				pressure for the well is less than 300 psig under the order or permit
				authorizing the well for injection, the minimum testing pressure shall be 300
				psig.
(ii) If the maximum authorized
				injection pressure is greater than 300 psig under the order or permit
				authorizing the well for injection, the minimum testing pressure shall be the
				lesser of 1000 psig or the maximum authorized injection pressure under the
				order permitting the well.
(G)
Minimum testing pressure for
				commercial disposal wells.
Commercial disposal wells shall be tested at
				the maximum injection pressure authorized in the order or permit authorizing
				the well for injection, but not less than 300 psig.
(H)
Thirty minute minimum testing
				period.
The minimum testing period shall be 30 minutes at the testing
				pressure.
(I)
Ten percent
				maximum permitted bleed-off.
The maximum permitted change in pressure
				during the testing period shall be ten percent of the maximum testing pressure
				used.
(J)
Test report on Form
				1075.
The Field Inspector shall submit the results of the mechanical
				integrity test on Form 1075 within 30 days from the date the test is
				performed.
(K)
Cement
				circulated above injection zone.
The production casing must be set and
				cemented through the injection or disposal zone with the cement circulated
				behind the casing to a height at least two hundred fifty (250) feet above the
				injection or disposal zone. If a cement squeeze is necessary to raise annular
				cement to the minimum height of two hundred fifty (250) feet, a cement bond log
				showing quality and placement of the cement must be furnished to and acceptable
				to the Conservation Division before the well may be used for injection or
				disposal.
(L)
Packer setting
				depth.
The packer must be set at a depth which is at least 50 feet below
				the depth of the top of cement behind the production casing.
(3)
Alternative testing
				procedures.
Operators can test at a maximum of 500 psi if there is in
				place an automatic and continuous pressure monitor on the tubing-casing annulus
				that will shut-in the well if there is a pressure increase of 250 psi on the
				annulus. Application for this alternative test procedure shall be made in
				writing to the Manager of the UIC Department. The Manager of the UIC Department
				may allow the alternative test procedure to be used as the initial mechanical
				integrity test, which permission shall be reflected in the order or permit
				regarding the well.
(4)
Use of
				fluid seal without a mechanical packer.
Use of a fluid seal without a
				mechanical packer is prohibited.