The UIC program for Class II wells in the State of Alaska, other than those on Indian lands, is the program administered by the Alaska Oil and Gas Conservation Commission approved by EPA pursuant to section 1425 of the SDWA. Notice of this approval was published in the Federal Register [May 6, 1986]; the effective date of this program is June 19, 1986. This program consists of the following elements, as submitted to EPA in the State's program application.

(a) Incorporation by reference. The requirements set forth in the State statutes and regulations cited in this paragraph are hereby incorporated by reference and made a part of the applicable UIC program under the SDWA for the State of Alaska. This incorporation by reference was approved by the Director of the Federal Register effective June 19, 1986.

(1) Alaska Statutes, Alaska Oil and Gas Conservation Act, Title 31, §§ 31.05.005 through 31.30.010 (1979 and Cum. Supp. 1984);

(2) Alaska Statutes, Administrative Procedures Act, Title 44, §§ 44.62.010 through 44.62.650 (1984);

(3) Alaska Administrative Code, Alaska Oil and Gas Conservation Commission, 20 AAC 25.005 through 20 AAC 25.570 (Supp. 1986).

(b) Memorandum of Agreement. The Memorandum of Agreement between EPA Region 10, and the Alaska Oil and Gas Conservation Commission, signed by the EPA Regional Administrator on January 29, 1986, as amended on June 21, 1988.

(c) Statement of Legal Authority. Statement from the Attorney General of the State of Alaska, signed by the Assistant Attorney General on December 10, 1985.

(d) The Program Description and any other materials submitted as part of the original application or as supplements thereto.

[51 FR 16684, May 6, 1986, as amended at 56 FR 9411, Mar. 6, 1991]

(a) Contents. The UIC program in the State of Alaska for Class I, III, IV, and V wells, and for all classes of wells on Indian lands, is administered by EPA. This program consists of the UIC program requirements of 40 CFR parts 124, 144, 146, 148, and any additional requirements set forth in the remainder of this subpart. Injection well owners and operators, and EPA shall comply with these requirements.

(b) Effective dates. The effective date of the UIC program for all non-Class II wells in Alaska and for all wells on Indian lands, is June 25, 1984.

[52 FR 17680, May 11, 1987, as amended at 56 FR 9412, Mar. 6, 1991]

(a) This section identifies any aquifers or their portions exempted in accordance with §§ 144.7(b) and 146.4 of this chapter at the time of program promulgation. EPA may in the future exempt other aquifers or portions, according to applicable procedures, without codifying such exemptions in this section. An updated list of exemptions will be maintained in the Regional office.

(b) The following aquifers are exempted in accordance with the provisions of §§ 144.7(b) and 146.4 of this chapter for Class II injection activities only:

(1) The portions of aquifers in the Kenai Peninsula, greater than the indicated depths below the ground surface, and described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields:

(i) Swanson River Field—1700 feet.

(ii) Beaver Creek Field—1650 feet.

(iii) Kenai Gas Field—1300 feet.

(2) The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields:

(i) Granite Point.

(ii) McArthur River Field.

(iii) Middle Ground Shoal Field.

(iv) Trading Bay Field.

(3) The portions of aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field.

Maximum injection pressure. The owner or operator shall limit injection pressure to the lesser of:

(a) A value which will not exceed the operating requirements of § 144.28(f)(3) (i) or (ii) as applicable; or

(b) A value for well head pressure calculated by using the following formula:

Pm = (0.733-0.433 Sg)d where: Pm = injection pressure at the well head in pounds per square inch Sg = specific gravity of inject fluid (unitless) d = injection depth in feet.

(a) Maximum injection pressure. (1) To meet the operating requirements of § 144.28(f)(3)(ii) (A) and (B) of this chapter, the owner or operator:

(i) Shall use an injection pressure no greater than the pressure established by the Regional Administrator for the field or formation in which the well is located. The Regional Administrator shall establish maximum injection pressures after notice, opportunity for comment, and opportunity for a public hearing, according to the provisions of part 124, subpart A of this chapter, and will inform owners and operators in writing of the applicable maximum pressure; or

(ii) May inject at pressures greater than those specified in paragraph (a)(1)(i) of this section for the field or formation in which he is operating provided he submits a request in writing to the Regional Administrator, and demonstrates to the satisfaction of the Regional Administrator that such injection pressure will not violate the requirement of § 144.28(f)(3)(ii) (A) and (B). The Regional Administrator may grant such a request after notice, opportunity for comment, and opportunity for a public hearing, according to the provisions of part 124, subpart A of this chapter.

(2) Prior to such time as the Regional Administrator establishes rules for maximum injection pressure based on data provided pursuant to paragraph (a)(2)(ii) of this section the owner or operator shall:

(i) Limit injection pressure to a value which will not exceed the operating requirements of § 144.28(f)(3)(ii); and

(ii) Submit data acceptable to the Regional Administrator which defines the fracture pressure of the formation in which injection is taking place. A single test may be submitted on behalf of two or more operators conducting operations in the same formation, if the Regional Administrator approves such submission. The data shall be submitted to the Regional Administrator within 1 year of the effective date of this program.

(b) Casing and cementing. Where the Regional Administrator determines that the owner or operator of an existing enhanced recovery or hydrocarbon storage well may not be in compliance with the requirements of §§ 144.28(e) and 146.22, the owner or operator shall comply with paragraphs (b) (1) through (4) of this section, when required by the Regional Administrator:

(1) Protect USDWs by:

(i) Cementing surface casing by recirculating the cement to the surface from a point 50 feet below the lowermost USDW; or

(ii) Isolating all USDWs by placing cement between the outermost casing and the well bore; and

(2) Isolate any injection zones by placing sufficient cement to fill the calculated space between the casing and the well bore to a point 250 feet above the injection zone; and

(3) Use cement:

(i) Of sufficient quantity and quality to withstand the maximum operating pressure;

(ii) Which is resistant to deterioration from formation and injection fluids; and

(iii) In a quantity no less than 120% of the calculated volume necessary to cement off a zone.

(4) The Regional Administrator may specify other requirements in addition to or in lieu of the requirements set forth in paragraphs (b) (1) through (3) as needed to protect USDWs.