1. (a) An enhanced recovery operation involving the introduction of an extraneous form of energy into a pool by injection is prohibited, except as ordered by the commission under this section. In response to an application for injection filed by an operator, and upon the commission's determination that the requirements of this section and 20 AAC 25.412 are met, the commission will issue an order authorizing the injection of fluid that functions primarily to enhance recovery of oil and gas and is appropriate for enhanced recovery through a Class II well. Except as provided in (i) of this section, an order authorizing injection for an enhanced recovery project remains valid unless revoked by the commission.

2. (b) The operator has the burden of demonstrating that the proposed operation will not allow the movement of fluid into a source of freshwater. A Class II well for enhanced oil recovery or enhanced gas recovery must be cased, the casing cemented, and the well operated in a manner that will isolate the injection zone and protect oil, gas, and freshwater. If a well, including a freshwater well, or other boring located within a one-quarter mile radius of a Class II injection well, is a possible means for fluid to move into sources of freshwater and under the control of

   1. (1) the operator, the operator shall ensure that the well or boring is properly repaired, plugged, or otherwise modified to prevent the movement of fluid into sources of freshwater; or
   2. (2) a person other than the operator, the commission will not issue an order under (a) of this section until the operator presents evidence to the commission's satisfaction that the person who controls the well or boring has properly repaired, plugged, or otherwise modified the well or boring to prevent the movement of fluid into sources of freshwater.

3. (c) An application for injection must include

   1. (1) a plat showing the location of each proposed Class II well, abandoned or other unused well, production well, dry hole, and other well within one-quarter mile of each proposed Class II well;
   2. (2) a list of all operators and surface owners within a one-quarter mile radius of each proposed injection well;
   3. (3) an affidavit showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for injection;
   4. (4) a full description of the particular operation for which approval is requested;
   5. (5) the names, descriptions, and depths of the pools to be affected;
   6. (6) the name, description, depth, and thickness of the formation into which fluid is to be injected, and appropriate geological data on the injection zone and confining zone, including lithologic descriptions and geologic names;
   7. (7) logs of the injection wells if not already on file with the commission;

   8. (8) a description of the proposed method for demonstrating mechanical integrity of the casing and tubing under 20 AAC 25.412 and for demonstrating that no fluid will move behind casing beyond the approved injection zone, and a description of

      1. (A) the casing of an existing Class II well; or
      2. (B) the proposed casing program of a new Class II well;
   9. (9) a statement of the type of fluid to be injected, the fluid's composition, the fluid's source, the estimated maximum amounts to be injected daily, and the fluid's compatibility with the injection zone;
   10. (10) the estimated average and maximum injection pressure;
   11. (11) evidence to support a commission finding that each proposed Class II well will not initiate or propagate fractures through the confining zones that might enable the injection fluid or formation fluid to enter freshwater strata;
   12. (12) a standard laboratory water analysis, or the results of another method acceptable to the commission, to determine the quality of the water within the formation into which fluid injection is proposed;
   13. (13) a reference to any applicable freshwater exemption issued under 20 AAC 25.440;
   14. (14) the expected incremental increase in ultimate hydrocarbon recovery; and
   15. (15) a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well.
4. (d) The commission will publish notice of the enhanced recovery application and provide the opportunity for a hearing in accordance with 20 AAC 25.540.
5. (e) The mechanical integrity of a Class II well must be demonstrated under 20 AAC 25.412 before injection is begun and after a well workover affecting mechanical integrity is conducted. To confirm continued mechanical integrity, the operator shall monitor the injection pressure and rate and the pressure in the casing-tubing annulus during actual injection. The monitored data shall be reported monthly on the Monthly Injection Report (Form 10-406).
6. (f) If an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing, tubing, or packer, the operator shall notify the commission by the next working day and shall implement corrective action or increased surveillance as the commission requires to ensure protection of freshwater.
7. (g) The commission will require additional mechanical integrity tests, if the commission considers them prudent for conservation purposes or protection of freshwater.
8. (h) The commission may approve a modification to an existing or pending injection operation under 20 AAC 25.507, if the operator proves to the commission, on application containing sufficient detail for the commission to evaluate the proposed modification, that the modification will not allow the movement of fluid into sources of freshwater.
9. (i) If an injection operation is not begun within 24 months after the date of the order authorizing enhanced recovery, that order expires unless a letter of application for extension is approved by the commission.

(Eff. 4/2/86, Register 97; am 11/7/99, Register 152)

Authority: AS 31.05.030