1. (a) No Class II disposal or EOR well, as defined in 15 CAR § 275-801(a)(2), hereinafter referred to as “Class II well” for purposes of this section, for which a permit has been issued in accordance with 15 CAR § 275-801, shall be operated until:

   1. (1) Well internal mechanical integrity has been established in accordance with subsection (o) of this section, below; and
   2. (2) An authority for initial commencement of injection operations is issued by the Director of Production and Conservation.

2. (b)

   1. (1) The permit holder shall provide notice to the Oil and Gas Commission regional office where the Class II well is located, prior to performing any well servicing activity, cementing, or any wireline logging activities, so as to allow commission staff to be present to observe the activity.
   2. (2) Any well servicing which requires the resetting of the packer shall require an internal mechanical integrity test be run in accordance with subsection (o) of this section, below, prior to recommencement of injection.

3. (c)

   1. (1) All well records for newly drilled Class II wells shall be submitted in accordance with 15 CAR § 275-205.
   2. (2) Completion or recompletion reports and wireline logs for all subsequent well servicing, cementing, or wireline logging activity performed on the well shall be filed no later than fifteen (15) days after completion of these activities.
4. (d) Following issuance of the permit to drill and/or operate a Class II well, an annual fee of one hundred dollars ($100) per well shall be due each July 1 for the life of the well until the well is plugged.

5. (e) Surface and production casing requirements.

   1. (1) Class II wells shall be cased and cemented in such manner that damage will not be caused to any USDW, as defined in 15 CAR § 275-801(a)(5), hereinafter referred to as “USDW”, or oil and gas resources.

   2. (2) For newly drilled Class II wells:

      1. (A) Set and cement surface casing two hundred fifty feet (250’) below the base of the lowermost USDW, and cement production casing to at least two hundred fifty feet (250’) above the proposed disposal zone; or
      2. (B) Set and cement surface casing fifty feet (50’) below the base of the lowermost formation utilized for a public water system (see 40 C.F.R.) in the area of the Class II well, with a minimum of five hundred feet (500’) of surface casing required, and cement production casing back to the surface.

   3. (3) For existing wells converted to Class II wells:

      1. (A)

6. (i) Unless otherwise approved by the director, production casing in the existing well is required to be cemented to at least two hundred fifty feet (250’) above the proposed disposal zone.

   1. (ii) A cement bond (CBL), gamma ray (GR), and density log (VDL) shall be required to verify the presence of the required casing cement.

      1. (iii) The CBL should indicate at a minimum an eighty percent (80%) bond index over the two-hundred-fifty-foot cemented interval; and
      2. (B) If a casing liner is required to provide well bore integrity above the required production cementing requirements in subdivision (e)(3)(A) of this section, above, the liner must be set, at a minimum, below the cemented portion of the production casing and cemented back to the surface.

7. (f) Tubing and packer requirements.

   1. (1)

      1. (A) All injections shall be through tubing and packer.
      2. (B) The packer shall be placed no higher than one hundred feet (100’) above the uppermost perforations or the casing seat in an open hole completion, provided the packer is within the cemented portion of the production casing, provided the packer is no less than five hundred feet (500’) below the base of the USDW.

   2. (2)

      1. (A) If the tubing and packer cannot be set or utilized in accordance with subdivision (f)(1) of this section, above, due to existing well construction conditions, the permit holder may request the director to authorize an alternative packer setting depth or well construction.

      2. (B) In determining an alternative packer setting depth or alternative well construction, the director shall take into consideration the:

         1. (i) Current construction of the well;
         2. (ii) Depth of the USDWs; and
         3. (iii) Nature of the obstruction.

      3. (C) If an alternative packer setting depth or well construction is authorized, the director may require:

         1. (i) Additional or more frequent internal mechanical integrity tests be performed on the well; or
         2. (ii) Additional remedial or corrective work to assure that injection does not endanger USDWs.
   3. (3) The permit holder shall contact the regional office in which the well is located at least twenty-four (24) hours prior to the initial setting or any resetting of the packer in a Class II disposal well to enable an inspector to be present when the packer is set.

8. (g)

   1. (1) The wellhead shall be maintained in a leak-free condition, and must have a working pressure gauge in excess of the maximum discharge pressure of the pump.
   2. (2) The wellhead shall be configured to include a one-half-inch female fitting, with shut-off valve, to allow monitoring of the annulus between the production casing and the injection tubing and a one-half-inch female fitting, with shut-off valve, installed on the tubing to measure the injection pressure.

9. (h) The injection pressure shall not exceed the maximum injection pressure established in accordance with 15 CAR § 275-801(j)(8).

   1. (i) No change shall be made in the permitted injection zone unless the new zone is permitted in accordance with 15 CAR § 275-801.

10. (j)

    1. (1) Injection fluids shall be confined to the permitted injection zone.
    2. (2) If the director has reason to believe, based upon well records or field observations, that injection fluids are migrating into zones not permitted for injection or into USDWs or to the surface or is causing fluid migration into the USDWs, due to the operation of any Class II well or resulting from a failure of internal or external mechanical integrity of the well, the permit holder shall be required to shut in the well until all necessary corrective work, which may include plugging of the well, is completed.

11. (k) Internal mechanical integrity shall be maintained in accordance with subsection (o) of this section, below.

    1. (l) Only Class II fluids, as defined in 15 CAR § 275-801(a)(3), and/or freshwater can be injected into a Class II well.

       1. (m) Each well shall have a legible sign placed near the well showing the permit holder and the well name and number and permit number and section, township, and range as shown on the permit in the commission records.

12. (n)

    1. (1) The permit holder of each Class II well shall file a Quarterly Well Status Report on forms prescribed by the director.
    2. (2) The report shall be filed within thirty (30) days after the end of each quarter of a calendar year commencing on January 1 of each year.

    3. (3) The report shall include at a minimum:

       1. (A) Name and permit number of the well;
       2. (B) Names of all injection intervals;
       3. (C) Maximum daily injection rates and pressures; and
       4. (D) Monthly volumes of fluid injected.

13. (o) Establishment of internal mechanical integrity.

    1. (1)

       1. (A)

          1. (i) Internal mechanical integrity must be maintained at all times.
          2. (ii) If internal mechanical integrity is lost, the permit holder shall shut in the well immediately and notify the regional office where the well is located of loss of internal mechanical integrity.
       2. (B) The well shall remain shut in until the necessary remedial action necessary to restore internal mechanical integrity is completed and a new internal mechanical integrity test run and successfully passed.

    2. (2) An internal mechanical integrity test shall be performed:

       1. (A) Prior to initial injection into a newly permitted Class II well;
       2. (B) Prior to initial injection into a Class II well after a change to a newly permitted injection zone;
       3. (C) Prior to resuming injection into any Class II well after any workover of the well involving the resetting or movement of a packer;
       4. (D) Whenever the director has reason to believe, based upon well records or field observation, that the Class II wells may be leaking or improperly constructed; and
       5. (E) At least once every five (5) years measured from the date of the last successful test.

    3. (3) Internal mechanical integrity test.

       1. (A)

          1. (i) The following tests shall be performed on Class II wells to establish the internal mechanical integrity of the tubing, casing, and packer of the well.
          2. (ii) The permit holder shall contact the regional office in which the well is located at least forty-eight (48) hours prior to conducting the test to enable an inspector to be present when the test is done.
          3. (iii) Pressure test.
14. (a) (a) The casing-tubing annulus above the packer shall be tested under the supervision of a commission representative at a minimum pressure differential between the tubing and the annulus of fifty pounds per square inch gauge (50 psig) for a period of thirty (30) minutes.

15. (b) (b) The casing-tubing annulus starting test pressure shall not be less than three hundred pounds per square inch gauge (300 psig) and may vary no more than ten percent (10%) of the starting test pressure during the test.

    1. (c) (c) The pressure at which the test is to be performed shall be fifty pounds per square inch gauge (50 psig) over the permitted injection pressure, with a maximum of one thousand pounds per square inch gauge (1,000 psig).

       1. (iv) Radioactive tracer survey test. For those wells in which alternative well construction has been approved by the director in accordance with subdivision (f)(2) of this section, above, a radioactive tracer survey may be run in the well at a frequency to be determined by the director to evidence mechanical integrity of the well by demonstrating that the injected fluid is being injected into the approved disposal zone.

       2. (B)

          1. (i) Any Class II well which fails an internal mechanical integrity test, or on which an internal mechanical integrity test has not been performed when required, shall be shut in until the well is successfully tested or remedial work is commenced and completed or the well is plugged.
          2. (ii) The necessary work shall be completed and an internal mechanical integrity test successfully completed within ninety (90) days.
          3. (iii) The director may approve up to an additional ninety (90) days, with any greater length of time to be established by the commission upon application by the operator.
16. (p) If the director has reason to believe, based upon well records or field observation, that any Class II well is causing fluid migration into the USDWs resulting from a failure of internal or external mechanical integrity, the permit holder shall shut in the well until any necessary corrective work is commenced and completed and internal and external mechanical integrity is established.
17. (q) Class II wells no longer in service for periods greater than twenty-four (24) months shall be plugged or temporarily abandoned in accordance with 15 CAR § 275-207.

Codification Notes: This section as promulgated prior to codification into the Code of Arkansas Rules provided as follows: "(Source: new rule July 17, 2009; amended October 24, 2009; amended June 16, 2019)"