Uniied States

                Environmental Protection

                Agency
                Office of Drinking

                Water (WH 550)

                Washington, D.C. 20460
               NOVEMBER 1980
     c/EPA
UNDERGROUND
INJECTION
CONTROL PROGRAM
INSTRUCTIONAL MODULE
f—> "x-V-'A °f%'—° -~ ^ ° ^-s^^-* 
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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
                         -2-

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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
                          -3-

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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
                         -4-

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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
                                        -5-

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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
                                      -6-

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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
                                           -7-

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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
                                      -9-
                                                 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
                                       -10-

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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
                                        -11-

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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
                                       -12-

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Page
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;
                                       -13-

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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
                         -15-

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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
                         16

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Page
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
                                        -17-

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Page
         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
                                            -18-

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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
                                       -19-

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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
                                     -20-

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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]
                                          -24-

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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
                                         -25-

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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.
                         -28-

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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)]
                        -29-

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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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