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Introduction
CFR 146
These are the second and third of a series on the
Underground Injection Control Regulations. The
two booklets on CFR 146 have been written to help
you read the regulations. We have cut and pasted,
added the full text of some references, added sone
comments, and some questions. Please feel free to
use this booklet any way that is helpful. The
questions are not intended to be a test, but
rather indicators of some important points. The
questions and answers are not official guidance
or policy.
There will be many questions raised by reading
CFR 146 that are not answered by this pamphlet.
Guidance is being developed on many issues raised
by the Regulations, and will be available in the
future. This pamphlet is an attempt to assist
with the first step, reading and digesting the
Regulations as promulgated.
December 1980
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NOTE: Class II may be affected by pending amendments
146 C
1. New Class II wells must inject into a formation
which has confining zones that are free of known open
faults or fractures within the area of review.
True False
2. Any Class II well injection which results in the
movement of fluids into a USDW is prohibited.
True False
3. The Director need not apply the casing and
cementing requirements of 146.22(b) if the State did
not have regulatory controls prior to the submission of
a State program.
True False
4. Deviation checks are required on all Class II
wells.
True False
5. Enhanced recovery wells may be stimulated by
initiating new fractures or propagating existing
fractures in the injection zone.
True False
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6. Continuous monitoring devices are required for all
Class II wells except for monthly enhanced recovery
wells.
True False
7. Mechanical integrity must be demonstrated for
existing Class II wells at least once every five years-
True False
8. Reporting on Class II wells need not be quarterly,
True False
9. The Director need not consider an area of review
for existing Class II injection wells.
True False
10. The Director must report on each new Class II
permit every six months for the first two years of the
program.
True False
146 C
11. The Director must report on all mechanical
integrity tests conducted in the first two years.
True False
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12. The Director must require a temperature or noise
log on a sample of Class II wells only when cementing
records were submitted to establish mechanical
integrity.
True False
13. At least half of the wells tested must be existing.
True False
146 D
14. All new Class III wells must be cased and cemented.
True False
15. The diameter of all casing must be less than the
diameter of the well bore.
True False
16. When the injection zone is not a water bearing
formation, it is not necessary to determine the
chemical characteristics of the injection zone.
True False
17. When injection is into a formation which does not
contain water with less than 10,000 mg/1 TDS,
monitoring wells are required into any USDW above the
injection zone which could be affected.
True False
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Page
42507
NOTE: CLASS II MAY BE
AFFECTED BY AMENDMENTS
Subpart C—Criteria and Standards
Applicable to Class II Wells
§ 146.21 Applicability.
This subpart establishes criteria and
standards for underground injection
control programs to regulate Class II
wells.
§ 146.22 Construction requirements.
(a) All new Class II wells shall be
sited in such a fashion that they inject
into a formation which has confining
zones that are free of known open faults
or fractures within the area of review.
(b) All Class II injection wells shall be
cased and cemented to prevent
movement of fluids into or between
underground sources of drinking water.
The casing and cement used in the
construction of each newly drilled well
shall be designed for the life expectancy
of the well. In determining and
specifying casing and cementing
requirements, the following factors shall
be considered:
(1) Depth to Ihe injection zone;
(2) Injection pressure, external
pressure, internal pressure, and axial
loading;
(3) Hole size;
(4) Size and grade of all casing strings
(wall thickness, diameter, nominal
weight, length, joint specification, and
construction material);
(5) Corrosiveness of injected fluid and
formation fluids;
(6) Lithology of injection and confining
zones; and
(7) Type and grade of cement.
New
Faults - Area of Review
Cased and cemented
Life of Well
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Page
42507 (c] The requirements in paragraph (b)
of this section need not apply to existing
or newly converted Class II wells
located in existing fields if:
(I) Regulatory controls for casing and
cementing existed for those wells at the
time of drilling and those wells are in
compliance with those controls; and
(2) Well injection will not result in the
moyement of fluids into an underground
42508 source of drinking water so as to create
a significant risk to the health of
persons.
(d) The requirements in paragraph (b)
of this section need hot apply to newly
drilled wells in existing fields if:
(1) They meet the requirements of the
Slate for casing and cementing
applicable to that field at the time of
submission of the State program to the
Administrator; and
(2) Well injection will not result in the
movement of fluids into an underground
source of drinking water so as to create
a significant risk to the health of
persons.
(e) Where a State did not have
regulatory controls for casing and
cementing prior to the time of the
submission of the State program to the
Administrator, the Director need not
apply the casing and cementing
requirements in paragraph (b] of this
section if he submits as a part of his
application for primacy, an appropriate
plan for casing and cementing of
existing, newly converted, and newly
drilled wells in existing fields, and the
Administrator approves the plan.
(f) Appropriate logs and other tests
shall be conducted during the drilling
and construction of new Class II wells.
A descriptive report interpreting the
results of these logs and tests shall be
prepared by a qualified log analyst and
Need not apply to
existing or newly
converted
Controls existed at time
No risk to health
of Persons
Newly drilled
Meet State
No risk to health of
Persons
Plan
Administrator Approves
Logs
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Page
42508 submitted to the Director. At a
minimum, these logs and tests shall
include:
(1) Deviation checks on all holes
constructed by first drilling a pilot hole
and then enlarging the pilot hole, by
reaming or another method. Such checks
shall be at sufficiently frequent intervals
to assure that vertical avenues for fluid
movement in the form of diverging holes
are not created during drilling.
(2) Such other logs and tests as may
be needed after taking into account the
availability of similar data in the area of
the drilling site, the construction plan,
and the need for additional information
that may arise from time to time as the
construction of the well progresses. In
determining which logs and tests shall
be required the following shall be
considered by the Director in setting
logging and testing requirements:
(i) For surface casing intended to
protect underground sources of drinking
water:
(A) Resistivity, spontaneous potential,
and caliper logs before the casing is
installed; and
(B) A cement bond, temperature, or
density log after the casing is set and
cemented.
(ii) For intermediate and long strings
of casing intended to facilitate injection:
(A) Resistivity, spontaneous potential,
porosity, and gamma ray logs before the
casing is installed;
(B) Fracture finder logs; and
(C) A cement bond, temperature, or
density log after the casing is set and
cemented.
(g) At a minimum, the following
information concerning the injection
formation shall be determined or
calculated for new Class II wells:
(1) Fluid pressure;
Deviation
Pilot hole
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Page
42508
(2) Temperature;
(3) Fracture pressure;
(4) Other physical and chemical
characterislics of the injection zone; and
(5) Physical and chemical
characteristics of the formation fluids.
§ 146.23 Operating, monitoring, and
reporting requirements.
(a) Operating Requirements.
Operating requirements shall, at a
minimum, specify that:
[I] Except during well stimulation for
enhanced recovery wells, injection
pressure at the wellhead shall not
exceed a maximum which shall be
calculated so as to assure that the
pressure in the injection zone during
injection does not initiate new fractures
or propagate existing fractures in the
injection zone. In no case, shall injection
pressure initiate fractures in the
confining zone or cause the njo^gnjgjjt
of injection or formation fluids into an
underground source o" drinking water.
(2) Injection between the outermost
casing protecting underground sources
of drinking water and the well bore shall
be prohibited.
(b) Monitoring Requirements.
Monitoring requirements shall, at a
minimum, include:
(1) Monitoring of the nature of
injected fluids at time intervals
sufficiently frequent to yield data
representative of their characteristics;
(2) Monitoring of injection pressure,
flow rate, and cumulative volume at
least with the following frequencies:
(i) Weekly for produced fluid disposal
operations;
(ii) Monthly for enhanced recovery
operations;
(iii) Daily during the injection of liquid
hydrocarbons and injection for
withdrawal of stored hydrocarbons; and
Fracture pressure
Well stimulation -
Enhanced recovery
Initiate
Propagate
No movement into USDW
Outside casing
Injected Fluids
Sufficiently Frequent
Pressure, rate, volume
Weekly
Monthly
Daily
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Page
42508
(iv) Daily during the injection phase of
cyclic steam operations;
(3) A demonstration of mechanical
integrity pursuant to § 14&IW al Iffasl
once every five years during the life of
the injection well;
(4) Maintenance of the results of all
monitoring until the next permit review
(see 40 CFR 122.42(e)); and
(e) Monitoring and reporting
requirements as set forth in 40 CFR Part
146. The permittee shall be required to
identify types of tests and methods used
to generate the monitoring data.
Daily
Mechanical Integrity
(5) Hydrocarbon storage and
enhanced recovery may be monitored
on a field or project basis rather than on
an individual well basis by manifold
monitoring. Manifold monitoring may be
used in cases of facilities consisting of
more than one injection well, operating
with a common manifold. Separate
monitoring systems for each well are not
required provided the owner/operator
demonstrates that manifold monitoring
is comparable to individual well
monitoring.
(c) Bcporting Requirements.
(1) Reporting requirements shall, at a
minimum include an annual report to the
Director summarizing the results of the
monitoring required under paragraph (b)
of this section. Previously submitted
information may be included by
reference.
(2) Owners or operators of
hydrocarbon storage and enhanced
recovery projects may report on a field
or project basis rather than an
individual well basis where manifold
monitoring is used.
Manifold monitoring
Annual
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Field or project basis
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Page
42508
§ 146.24 Information to be considered by
the director.
This section sets forth the information
winch must be considered by the
Director in authorizing Class II wells.
Certain maps, cross-sections,
tabulations of wells within the area of
review, and other data may be included
in the application by reference provided
they are current, readily available to the
Director (for example, in the permitting
agency's files) and sufficiently identified
to be retrieved. In cases where EPA
issues the permit, jjlHhe informafloh in
this Section is to be submitted to the
Administrator.
(a) Prior to the issuance of a permit for
an existing Class II well to operate or
the construction or conversion of a new
Class II well the Director shall consider
the following:
(1) Information required in 40 CFR
122.4 and 122.38(c);
(2) A map showing the injection
well(s) for which a permit is sought and
the applicable area of review. Within
the area of review, the map must show
the number, or name, and location of all
producing wells, injection wells,
abandoned wells, dry holes and water
wells. The map should also show faults,
if known or suspected. Only wells of
public record are required to be
included on this map. This requirement
does not apply to existing Class II wells;
and -
(3) A tabulation of data on all wells
within the area of review which
penetrate the proposed injection zone.
Such data shall include a description of
each well's type, construction, date
drilled, location, depth, record of
plugging and/or completion, and any
additional information the Director may
require. This requirement does not apply
to existing Class II wells.
Area of Review
Faults
Not existing
Penetrate
Not existing
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Page
42509 (4) Proposed operating data:
(i) Average and maximum daily rate
and volume of fluids to be injected;
fii) Average and maximum injection
pressure; and
(iii) Soijrce, and an analysis of the
chemical, physical, radiological and
biological characteristics of the injection
fluid;
|.i) Appropriate geological data on the
injection zone and confining zones
including lithologic description,
geological name, thickness, depth and
lateral extent;
(6) Geologic name, lateral extent and
depth to top and bottom of all
underground sources of drinking water
which may be affected by the injection;
(7) Engineering drawings of the
surface and subsurface construction
details of the system;
(8) Proposed formation testing
program;
(9) Proposed stimulation program;
(10) Proposed injection procedure;
(11) Contingency plans to cope with
all shut-ins or well failures so as to
prevent migration of contaminating
fluids into any underground source of
drinking water;
(12) Plans for meeting the monitoring
requirements of § 146.23{b);
(13) In the case of new injection wells,
the corrective action proposed to be
taken by the applicant under 40 CFR
122.44;
(14) A certificate that the applicant
has assured, through a performance
bond or other appropriate means, the
resources necessary to close, plug or
abandon the well as required by 40 CFR
122,42(g).
(b) Prior to granting approval for the
operation of a Class II well the Director
shall consider the following information:
(1) All available logging and testing
program data on the well;
Which may be affected
Stimulation program
Corrective action
Certif icate
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Page
42509 (2) A demonstration of mechanical
integrity pursuant to 1146.08;
(3) The actual operating data;
(4) The results of the formation testing
program;
(5) The actual injection procedure;
and
(6) For new wells the status of
corrective action on defective wells in
the area of review.
(c) Prior to granting approval for the
plugging and abandonment of a Class II
well the Director shall consider the
following information:
(1) The type, and number of plugs to
be used;
(2) The placement of each plug
including the elevation of top and
bottom;
'. (3) The type, grade, and quantity of
cement to be used;
(4) The method of placement of the
plugs; and
(5) The procedure to be used to meet
the requirements of § 146.10(c).
§ 146.25 Mid-course evaluation
requirements.
(a) In compliance with 40 CFR
122.18(c)(4)(C)(ii) the data to be
submitted on each new Class II permit
at six months intervals during the Erst
two years of operation of the State
program shall at a minimum include the
following;
(1) The data required in § 146.24(a)(l);
(2) The data required in § 146.24(a)(3)
including, under location, the distance
and direction from the injection well;
(3) The depth to the top and bottom of
any USDW;
(4) The distance to the nearest down-
gradient water supply well;
(5) A description of the geology and
hydrology of the area;
(6) The construction characteristics of
the well;
New wells
Static equilibrium, etc,
(ii) In addition to complying with the
requirements of paragraph [c)(4](i) of
this section the State Director shall
provide the Administrator within 3
months of the completion of the second
full year of State operation of the UIC
program a supplemental report
containing the information required in 40
CFR Part 146 on corrective actions taken
by operators of new Class II wells based
upon these regulations.
Water supply well
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42509
33440
(7) The corrective action proposed as
well as that performed; and
(8) Any reporting to the Director under
§ 122.41{d).
(d) The following shall be included as
information which must be reported
within 24 hours under § 122.7(1)(5):
(1) Any monitoring or other
information which indicates that any
contaminant may cause an
endangerment to a USDW.
(2) Any noncompliance with a permit
condition or malfunction of the injection
system which may cause fluid migration
into or between USDWs.
(ej The permittee shall notify the
Director at least 180 days before
conversion or abandonment of the well.
Corrective action
42509
(b) The Director shall also submit the
type and results of all Mechanical
Integrity tests reported on existing wells
and new (conversion only) wells during
h« first two >ears of operation.
(c) The Director shall require a
temperature log or ro:se log, on a
sample of Class II '.veils in cases where
operators submitted cementing records
to mpet the requirement of § 146.0o(c).
The wells to be tested shciM It: chosen
by a formal random selection procedure.
The sampling shall be done on .1 field ui
pool basis and be statistically
representative of the wells in that field
or pool. At a minimum, the sample size
for each State ahall be TOO wells or 5
percent of the number of Class 11
injection wells in the State whichever is
smaller. At least half of the wells tested
must be existing wells.
Logs
Sample
Cenenting record;
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146 D
18. In an area subject to subsidence and catastrophic
collapse, monitoring wells are not required in the
USDW.
True False
19. In determining monitoring requirements for Class
III wells, the Director shall consider the distance to
the points of withdrawal of drinking water.
True False
(146.33)
20. Continuous recording devices to monitor injection
pressure, flow rate, and volume are required for Class
III wells.
True False
21. A demonstration of mechanical integrity is required
at least once every five years for Class III wells.
True False
22. Quarterly monitoring of fluid level and water
quality in the injection zone is required for Class III
welIs.
True False
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23. Separate monitoring systems for each well are not
required when more than one well operates with a common
manifold.
True False
24. Quarterly reports must be submitted to the
Director.
True False
25. Reports on the results of mechanical integrity
tests may be delayed until the next quarterly report
True False
26. A mechanical integrity test is required of all new
Class III wells.
True False
27. Corrective action may be required in connection
with Class III wells.
True False
146.35
28. The Director need not report on Class III wells
authorized by rule as part of the mid-course evaluation
reports.
True False
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146 F
29. Class V wells inject non-hazardous fluids.
True False
30. Some wells which inject radioactive materials are
Class V wells.
True False
31. All Class V well owners or operators shall submit
inventory information within one year.
True False
32. Within three years the Director shall assess the
contamination potential of Class V wells.
True False
33. The Director has no responsibility to assess Class
IV wells.
True False
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42509
Subpart D—-Criteria and Standards
Applicable to Class 311 Wells
§ 14S.31
This subpart establishes criteria and
standards for underground injection
control programs to regulate Class III
wells.
§ 146.32 Construction requirements.
(a) All new Class ffl wells shall be
cased and cemented to prevent the
migration of fluids into or between
underground sources of drinking water.
The casing and cement used in the
construction of each newly drilled well
shall be designed for the life expectancy
of the well. In determining and
specifying casing and cementing
requirements, the following factors shall
be considered:
(1) Depth to the injection zone;
(2) Injection pressure, external
pressure, internal pressure, axial
loading, etc.;
(3) Hole size;
(4) Size and grade of all casing strings
(wall thickness, diameter, nominal
weight, length, joint specification, and
construction material];
(5) Corrosiveness of injected fluids
and formation fluids;
(6) Lithology of injection and confining
zones; and
(7) Type and grade of cement.
(b) Appropriate logs and other tests
shall be conducted during the drilling
and construction of new Class III wells.
A descriptive report interpreting the
results of such logs and tests shall be
prepared by a qualified log analyst and
submitted to the Director. The logs and
tests appropriate to each type of Class
III well shall be determined based on
the intended function, depth,
construction and other characteristics of
Cased and cemented
Life of well
Corros iveness
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the well, availability of similar data in
42509 the area of the drilling site and the need
for additional information that may
arise from time to time as the
construction of the well progresses. At a
minimum, such logs and tests shall
include deviation checks conducted on
all holes where pilot holes and reaming
are used, at sufficiently frequent
intervals to assure that vertical avenues
for fluid migration in the form of
diverging holes are not created during
drilling.
(c) Where the injection zone is a
water bearing formation, the following
information concerning the injection
zone shall be determined or calculated
for new Class III wells:
(1) Fluid pressure;
(2) Temperature;
(3) Fracture pressure;
(4) Other physical and chemical '
characteristics of the injection zone;
(5) Physical and chemical
characteristics of the formation fluids;
and
(6) Compatibility of injected fluids
with formation fluids.
(d) Where the injection formation is
not a water bearing formation, the
information in paragraph (c)(3) of this
section must be submitted.
(e) Where injection is into a formation
which contains water with less than
10,000 mg/1 TDS monitoring wells shall
be completed into the injection zone and
into any underground sources of
drinking water above the injection zone
which could be affected by the mining
42510 operation. These wells shall be located
in such a fashion as to detect any
excursion of injection fluids, process by-
products, or formation fluids outside the •
mining area or zone. If the operation
may be affected by subsidence or
Deviation checks
Pilot hole
Water bearing formation
Not water bearing
Monitoring wells
USDWs
Excursion
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Page
42510
catastrophic collapse the monitoring
wells shall be located so that they will
not be physically affected.
(f) Where injection is into a formation
which does not contain water with less
than 10,000 mg/1 TDS, no monitoring
wells are necessary in the injection
stratum.
(g) Where the injection wells
penetrate an USDW in an area subject
to subsidence or catastrophic collapse
an adequale number of monitoring wells
shall be completed into the USDW to
detect any movement of injected fluids,
process by-products or formation fluids
into the USDW. The monitoring wells
shall be located outside the physical
influence of the subsidence or
catastrophic collapse.
(h) In determining the number,
location, construction and frequency of
monitoring of the monitoring wells the
following criteria shall be considered:
(1) The population relying on the
USDW affected or potentially affected
by the injection operation;
(2) The proximity of the injection
operation to points of withdrawal of
drinking water;
(3) The local geology and hydrology;
(4) The operating pressures and
whether a negative pressure gradient is
being maintained;
(5) The toxicity and volume of the
injected fluid, the formation water, and
the process by-products; and
(6) The injection well density.
§146.33 Operating, monitoring, and
reporting requirements.
(a) Operating Requirements.
Operating requirements prescribed
shall, at a minimum, specify that:
(1) Injection pressure at the wellhead
shall not exceed a maximum which shall
be calculated so as to assure that the
Collapse
No monitoring in
injection stratum
Penetrate USDW
Outside the influence
'opulation
Distance
Gradient
Fluids
Dens ity
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Page
42510 pressure in the injection zone during
injection does not initiate new fractures
or propagate existing fractures in the
injection zone, initiate fractures in the
confining zone or cause the migration of
injection or formation fluids into an
underground source of drinking water;
and
(2) Injection between the outermost
casing protecting underground sources
of drinking water and the well bore is
prohibited.
(b) Monitoring Requirements.
Monitoring requirements shall, at a
minimum, specify:
(1) The analyses of the physical and
chemical characteristics of the injected
fluid with sufficient frequency to yield
representative data on its
characteristics;
(2) Installation and use of continuous
recording devices to monitor the
injection pressure, flow rate and volume;
(3) Demonstration of mechanical
integrity pursuant to § 146.08 at least
once every five years duziag the life of
the well for salt solution mining and
geothermal wells only;
(4) Weekly monitoring of fluid level
and the parameters chosen to measure
water quality in the injection zone; and
(5) Quarterly monitoring of wells
adjacent to the injection site to detect
any migration from the injection zone
into an USDW.
(6) All Class III wells may be
monitored on a field or project basis
rather than an individual well basis by
manifold monitoring. Manifold
monitoring may be used in cases of
facilities consisting of more than one
injection well, operating with a common
manifold. Separate monitoring systems
for each well are not required provided
the owner/operator demonstrates that
Pressure
No fractures
No migration
No injection outside
casing
Sufficient
Continuous recording
Mechanical Integrity
Salt & geothermal only
Weekly
Quarterly
Field or Project
Manifold
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Page
42510 manifold monitoring is comparable to
individual well monitoring.
(c) Reporting Requirements. Reporting
requirements shall, at a minimum,
include:
(1) Quarterly reporting to the Director
on required monitoring;
(2) Results of mechanical integrity and
any other periodic test required by the
Director reported with the first regular
quarterly report after the completion of
the test; and
(3) Monitoring may be reported on a
project or field basis rather than
individual well basis where manifold
monitoring is used.
§146.34 Information to be considered by
the Director.
This section sets forth the information
which must be considered by the
Director in authorizing Class III wells.
Certain maps, cross sections,
tabulations of wells within the area of
review, and other data may be included
in the application by reference provided
they are current, readily available to the
Director (for example, in the permitting
agency's files) and sufficiently identified
to be retrieved. In cases where EPA
issues the permit, all the information in
this section must be submitted to the
Administrator.
(a) Prior to the issuance of a permit for
an existing Class III well or area to
operate or the construction of a new
Class III well the Director shall consider
the following:
(1) Information required in 40 CFR
122.4 and 122.38(c);
(2) A map showing the injection
well(s) for which the permit is sought
and the applicable area of review.
Within the area of review, the map must
show the number, or name, and location
of all producing wells, injection wells,
Quarterly
Mechanical Integrity
Project or Field
Area of Review
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Page
42510 abandoned wells, dry holes, surface
bodies of water, mines (surface and
subsurface), quarries, public water
systems, water wells and other pertinent
surface features including residences
and roads. The map should also show
faults if known or suspected. Only
information of public record is required
to be included on this map;
(3) A tabulation of data on all wells
within the area of review which
penetrate the proposed injection zone.
Such data shall include a description of
each well's type, construction, date
drilled, location, depth, record of
plugging and completion, and any
additional information the Director may
require;
(4) Maps and cross sections indicating
'the vertical and lateral limits of all
underground sources of drinking water
within the area of review, their position
relative to the injection formation, and
the direction of water movement, where
known, in every underground source of
drinking water which may be affected
by the proposed injection;
(5) Maps and cross sections detailing
the geologic structure of the local area;
(6) Generalized map and cross
sections illustrating the regional geologic
setting;
(7) Proposed operating data:
(i) Average and maximum daily rate
and volume of fluid to be injected;
(ii) Average and maximum injection
pressure; and
(iii) Source and an analysis of the
chemical, physical, biological and
radiological characteristics of the
injection fluid.
(8) Proposed formation testing
program to obtain an analysis of the
physical, chemical and radiological
characteristics of the receiving
formation;
Penetrate
USDW - Area of Review
Gradient
Formation Testing
-22-
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Page
42510
42511
(9) Proposed stimulation program;
(10) Proposed injection procedure;
(11) Engineering drawings of the
surface and subsurface construction
details of the system;
(12) Plans (including maps) for
meeting the monitoring requirements of
§ 146.33(b);
(13) Expected changes in pressure,
native fluid displacement, direction of
movement of injection fluid;
(14) Contingency plans to cope with
all shut-ins or well failures so as to
prevent the migration of contaminating
fluids into underground sources of
drinking water;
(15) A certificate that the applicant
has assured, through a performance
bond or other appropriate means, the
resources necessary to close, plug or
abandon the well as required by 40 CFR
122.42(9); and
(16) The corrective action proposed to
be taken under 40 CFR 122.44.
(b) Prior to granting approval for the
operation of a Class III well the Director
shall consider the following information:
(1) All available logging and tebdr.g
data on the well;
(2) A satisfactory demonstration of
mechanical integrity for all new wells
and for all existing salt solution and
geothermal wells pursuant So § 140.08.
(3) The actual operating data;
(4) The results of the formation testing
program;
(oj The actual injection procedures;
and
(6) The status ot corrective action on
defective wells in the area of review.
(c) Prior to granting approval for the
plugging and abandonment of a Class 111
well the Director shall consider the
following information:
Stimulation
Monitoring
Changes
Corrective action
Mechanical integrity
Corrective action
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Page
42511
[i] The type and number of plugs to be1
used;
(2) The placement of each plug
including the elevation of the top and
bottom;
(3) The type, grade and quantity of
cement to be used;
(4) The method of placement of the
plugs, and
(5) The procedure to be used to meet
the requirements of § 146.10(c).
§146.35 Mid-course evaluation
requirements.
In compliance with 40 CFR
122.18(c)(4)(C)(ii] the data to be
submitted on each Class III permit at six
month intervals during the first two
years of operation of the State program
shall at a minimum include the
following:
[a) The data required in § 146.14(a)(i);
(b) The data required in § 146.34(a)(3)
including, under location, the distance
and direction from the injection well;
(c) The depth to the top and bottom of
any USDW;
(d) The distance to the nearest down-
gradient water supply well;
(e) A description of the geology and
hydrology of the area;
(f) The construction characteristics of
the well;
(g) The type and results of all
mechanical integrity tests reported to
the Director during the first two years of
the program; and
(h) Any reporting to the Director
under § 122.41(d).
pe rmi t
c, .
o 1 X KtontnS
TWO
Subpart E—Criteria and Standards
Applicable to Class !V Injection Wells
L Reserved]
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33438
Subpart F—Criteria and Standards
Applicable to Class V Injection Wells
§ 146.51 Applicability.
This subpart sets forth Criteria and
Standards for underground injection
control programs to regulate all injection
not regulated in Subparts B, C, D, and E.
(a) Generally, wells covered by this
Subpart inject non-hazardous fluids into
or above formations that contain
underground sources of drinking water.
It includes all wells listed in § 146.05(e)
but is not limited to those types of
injection wells.
(b) It also includes wells not covered
in Class IV that inject radioactive
materials listed in 10 CFR Part 20,
Appendix B, Table II, Column 2, and
injection wells used to store
hydrocarbons which are gases at
standard temperature and pressure.
§ 146.52 Inventory and Assessment.
(a) The owner or operator of any
Class V well shall, within one year of
the effective date of an underground
injection control program, notify the
Director of the existence of any well
meeting the definitions of Class V under
his control, and submit the inventory
information required in 40 CFR
(d) Inventory requirements. All
injection wells covered by rule shdil
submit inven^ry information to the
Director. Any rule under this section
shall provide for the automatic
termination of authorization for any well
which fails to comply within the time
specified in paragraph (c)(3) of this
section.
Note: Natural gas
storage may be excluded
by amendments
One year
Inventory
122.37(0)(1
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Page
33438
(1) Contents, The Director shall
require at least the information listed in
§ 146.52 as part of the inventory.
425H (b) Within three (3] years of approval
of the State program the Director shall
complete and submit to EPA a report
containing:
(1) The information on the
construction features of Class V wells,
and the nature and volume of the
injected fluids;
(2) An assessment of the
contamination potential of the Class V
wells using hydrogeological data
available to the State;
[3) An assessment of the available
corrective alternatives where
appropriate and their environmental and
economic consequences; and
(4) Recommendations both for the
most appropriate regulatory approaches
and for remedial actions where
appropriate.
Three years
Contamination potential
Alternatives
Recomnendations
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NEARBY WELLS
-27-
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Scoring Guide
CFR 146 -Subpairts C,D,E,F,
Note: These questions and the answers
given are not official guidance or policy
146 C
1. True.
2. True.
3. True.
4. False.
5. True.
6. False.
7. True.
8. True.
9. True.
10. True.
11. False.
12. True.
13. True.
[146.22(a)]
[146.22(b)]
[146.22(e)] Needs an appropriate
plan upon submission.
Only those involving a pilot hole
[146.23(3)(1)]
Weekly, monthly, daily.
[146.23(b)(2)]
[146.23(b)(3)]
[146.23(c)]
[146.24(a)(2)]
[146.25(3)1
[146.25(b)j Existing and new
conversions only
[146.25(c)]
Tests of non-existing wells
are suspect.
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146 D
14. True.
15. True.
16. True.
17. True.
18. False.
19. True
146.33
20, True.
21. False.
22, False.
23. True.
24. True.
25. True.
146.34
26. True.
27. True.
146.35
28. True.
146.357
29. True.
[146.32(a)]
(Just to keep you awake)
[146.32(c)J
[146o32(e) & (f)]
[146.32(g)]
114 6 „ 3 2 (h ) ]
[146.33(b)(2)]
"salt solution mining and
geotherraal wells only"
[146.33(b)(3)]
"Weekly monitoring ..."
[146.33(b) (4)]
[146.33(b)(6)]
[146.33(c) (1)]
[146.33(c)(2)]
[146.34(b)(2)]
[146.34(a) (16)] and (b) (6)
[146.35]
[146.51(a)]
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146 F
30. True. [146.51(b)]
31. True. [146.52(b)J
32. True. [146.52(b)(2)]
33. True. .(Just wanted to see if you're
still awake)
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