Illinois Administrative Code
Title 35 - ENVIRONMENTAL PROTECTION
Part 730 - UNDERGROUND INJECTION CONTROL OPERATING REQUIREMENTS
Subpart H - CRITERIA AND STANDARDS APPLICABLE TO CLASS VI WELLS
Section 730.186 - Injection Well Construction Requirements
Universal Citation: 35 IL Admin Code ยง 730.186
Current through Register Vol. 48, No. 38, September 20, 2024
a) General. The owner or operator must ensure that its Class VI injection wells are constructed and completed to fulfill the following requirements:
1) The well
construction and completion must prevent the movement of fluids into or between
USDWs or into any unauthorized zone;
2) The well construction and completion must
permit the use of appropriate testing devices and workover tools; and
3) The well construction and completion must
permit continuous monitoring of the annulus space between the injection tubing
and long-string casing.
b) Casing and cementing of Class VI injection wells.
1) The casing, cement, and other
materials used in the construction of each Class VI injection well must have
sufficient structural strength and be designed to last for the life of the
geologic sequestration project. All well materials must be compatible with
fluids with which the materials may be expected to come into contact, and the
owner or operator must submit sufficient documentation to the Agency to support
a determination that the casing, cement, and other materials meet or exceed
standards developed for these materials by the American Petroleum Institute,
ASTM International, or a comparable industry standards organization. The casing
and cementing program must be designed to prevent the movement of fluids into
or between USDWs. In order to allow the Agency to determine and specify casing
and cementing requirements, the owner or operator must provide the following
information to the Agency:
A) The depth to
the injection zones;
B) The
injection pressure, external pressure, internal pressure, and axial
loading;
C) The hole
size;
D) The size and grade of all
casing strings (the wall thickness, external diameter, nominal weight, length,
joint specification, and construction material);
E) The corrosiveness of the carbon dioxide
stream and formation fluids;
F) The
down-hole temperatures;
G) The
lithology of the injection and confining zones;
H) The type or grade of cement and cement
additives; and
I) The quantity,
chemical composition, and temperature of the carbon dioxide stream.
2) The surface casing must extend
through the base of the lowermost USDW and be cemented to the surface through
the use of a single or multiple strings of casing and cement.
3) At least one long-string casing, using a
sufficient number of centralizers, must extend to the injection zone and must
be cemented by circulating cement to the surface in one or more
stages.
4) The circulation of
cement may be accomplished by staging. The Agency must approve an alternative
method of cementing when it determines that the cement cannot be recirculated
to the surface, provided the owner or operator can demonstrate, by using logs,
that the cement does not allow fluid movement behind the well bore.
5) The cement and cement additives must be
compatible with the carbon dioxide stream and formation fluids and of
sufficient quality and quantity to maintain integrity over the design life of
the geologic sequestration project. The integrity and location of the cement
must be verified that uses technology capable of evaluating cement quality
radially and which identifies the location of channels to ensure that USDWs are
not endangered.
c) Tubing and packer.
1) The tubing and packer
materials used in the construction of a Class VI injection well must be
compatible with fluids with which the materials may be expected to come into
contact, and the owner or operator must submit sufficient documentation to the
Agency to support a determination that the tubing and packer meet or exceed
standards developed for these materials by the American Petroleum Institute,
ASTM International, or a comparable industry standards organization.
2) The owner or operator of a Class VI
injection well must inject fluids through tubing with a packer set at a depth
opposite a cemented interval at the location approved by the Agency.
3) In order for the Agency to determine and
specify requirements for tubing and packer, the owner or operator must submit
the following information to the Agency:
A)
The depth of setting;
B) The
characteristics of the carbon dioxide stream (the chemical content,
corrosiveness, temperature and density) and formation fluids;
C) The maximum proposed injection
pressure;
D) The maximum proposed
annular pressure;
E) The proposed
injection rate (intermittent or continuous) and the volume or mass of the
carbon dioxide stream;
F) The size
of the tubing and casing; and
G)
The tubing tensile, burst and collapse strengths.
BOARD NOTE: This Section corresponds with 40 CFR 146.86(2011).
Disclaimer: These regulations may not be the most recent version. Illinois may have more current or accurate information. We make no warranties or guarantees about the accuracy, completeness, or adequacy of the information contained on this site or the information linked to on the state site. Please check official sources.
This site is protected by reCAPTCHA and the Google
Privacy Policy and
Terms of Service apply.