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Federal Register / Vol. 86, No. 52 / Friday, March 19, 2021 / Rules and Regulations
TABLE 1 TO PARAGRAPH aEPA-APPROVED STATE OF MICHIGAN SDWA SECTION 1425 UNDERGROUND INJECTION
CONTROL PROGRAM STATUTES AND REGULATIONS FOR WELL CLASS IIContinued State citation
Title/subject
State effective date
EPA approval date
Michigan Department of Licensing and Regulatory Affairs Contested Case Procedures for Department of Environmental Quality Administrative Rules, MAC, R
324.81.

Declaratory Rulings
administrative rules

Effective 2003

March 19, 2021 Insert FR
citation of the final rule.

b Memorandum of Agreement MOA. The MOA between EPA Region 5 and the State of Michigan Department of Environment, Great Lakes, and Energy signed by EPA Regional Administrator on October 13, 2020.
c Statements of legal authority.
Underground Injection Control Program, Attorney Generals Statement, signed by the Chief of the Environment, Natural Resources, and Agriculture Division of the Michigan Department of Attorney General on September 1, 2020.
d Program description. The program description submitted as part of Michigans application, and any other materials submitted as part of this application or as a supplement thereto.
3. Amend 147.1151 by revising the section heading and the first sentence of paragraph a to read as follows:
147.1151 EPA-administered program Class I, III, IV, V, and VI wells and Indian country.

a The UIC program for Class I, III, IV, V and VI wells and all wells in Indian country in the State of Michigan is administered by the EPA.

4. Revise 147.1153, 147.1154, and 147.1155 to read as follows:
147.1153 Existing Class II disposal wells authorized by rule in Indian country.

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The owner or operator shall limit injection pressure to the lesser of:
a A value which will not exceed the operating requirements of 144.28f3i or ii of this chapter as applicable; or b A value for well head pressure calculated by using the following formula: Pm = 0.8000.433 Sgd, where: pm = injection pressure at the well head in pounds per square inch, sg = specific gravity of injected fluid unitless, and d = injection depth in feet.
147.1154 Existing Class II enhanced recovery and hydrocarbon storage wells authorized by rule in Indian country.

a Maximum injection pressure. 1
To meet the operating requirements of 144.28f3iiA and B of this chapter, the owner or operator:

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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 such a maximum pressure 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 a1i 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 144.28f3iiA and B of this chapter. 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 field rules for maximum injection pressure based on data provided pursuant to paragraph a2ii of this section the owner or operator shall:
i Limit injection pressure to a value which will not exceed the operating requirements of 144.28f3ii of this chapter; 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 one 1 year following June 17, 2021, 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 may not be in compliance with the requirements of 144.28e and 146.22 of this chapter, the owner or
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operator shall comply with paragraphs b1 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 b1 through 3 of this section, as needed to protect USDWs.
147.1155 Requirements for all EPAadministered wells.

a Area of review. Notwithstanding the alternatives presented in 146.6 of this chapter, the area of review for Class II wells shall be a fixed radius as described in 146.6b of this chapter.
b Tubing and packer. The owner or operator of an injection well injecting salt water for disposal shall inject through tubing and packer. The owner of an existing well must comply with this paragraph b within one 1 year of June 17, 2021, the effective date of this program.
FR Doc. 202105435 Filed 31821; 8:45 am BILLING CODE 656050P

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