U.S. ENVIRONMENTAL PROTECTION AGENCY 

UNDERGROUND INJECTION CONTROL PERMIT 

CLASS VI
TABLE OF CONTENTS 

AUTHORITY ..................................................................................................................................... - 1 -

PERMIT CONDITIONS ........................................................................................................................2

A. EFFECT OF PERMIT ......................................................................................................................2

B. PERMIT ACTIONS..........................................................................................................................2

1. Modification, Revocation and Reissuance, and Termination ............................................................... 2

2. Minor Modifications ............................................................................................................................. 2

3. Transfer of Permits ............................................................................................................................... 2

C. SEVERABILITY ..............................................................................................................................2

D. CONFIDENTIALITY.......................................................................................................................3

E. DEFINITION ....................................................................................................................................3

F. DUTIES AND REQUIREMENTS ...................................................................................................3

1. Duty to Comply..................................................................................................................................... 3

2. Duty to Reapply .................................................................................................................................... 3

3. Penalties for Violations of Permit Conditions ...................................................................................... 3

4. Need to Halt or Reduce Activity Not a Defense ................................................................................... 3

5. Duty to Mitigate .................................................................................................................................... 3

6. Proper Operation and Maintenance ...................................................................................................... 3

7. Duty to Provide Information ................................................................................................................. 4

8. Inspection and Entry ............................................................................................................................. 4

9. Signatory Requirements ........................................................................................................................ 4

G. AREA OF REVIEW AND CORRECTIVE ACTION .....................................................................4

H. FINANCIAL RESPONSIBILITY ....................................................................................................5

1. Financial Responsibility........................................................................................................................ 5

2. Cost Estimate Updates .......................................................................................................................... 5

3. Notification ........................................................................................................................................... 5

4. Establishing Other Coverage ................................................................................................................ 6

I. CONSTRUCTION ............................................................................................................................6

1. Siting ..................................................................................................................................................... 6

2. Casing and Cementing .......................................................................................................................... 6

3. Tubing and Packer Specifications ......................................................................................................... 6

J. PRE-INJECTION TESTING ............................................................................................................7

K. OPERATIONS ..................................................................................................................................8

1. Injection Pressure Limitation ................................................................................................................ 8

2. Stimulation Program ............................................................................................................................. 8

3. Additional Injection Limitation ............................................................................................................ 8

4. Annulus Fluid........................................................................................................................................ 8
5. Annulus/Tubing Pressure Differential .................................................................................................. 8

6. Automatic Alarms and Automatic Shut-off System ............................................................................. 8

7. Precautions to Prevent Well Blowouts ................................................................................................. 9

8. Circumstances Under Which Injection Must Cease ............................................................................. 9

9. Approaches for Ceasing Injection ......................................................................................................... 9

L. MECHANICAL INTEGRITY..........................................................................................................9

1. Standards ............................................................................................................................................... 9

2. Mechanical Integrity Testing .............................................................................................................. 10

3. Prior Notice and Reporting ................................................................................................................. 11

4. Gauge and Meter Calibration .............................................................................................................. 11

5. Loss of Mechanical Integrity .............................................................................................................. 11

6. Mechanical Integrity Testing on Request From Director ................................................................... 12

M. TESTING AND MONITORING ...................................................................................................12

1. Testing and Monitoring Plan .............................................................................................................. 12

2. Carbon Dioxide Stream Analysis........................................................................................................ 13

3. Continuous Monitoring ....................................................................................................................... 13

4. Corrosion Monitoring ......................................................................................................................... 13

5. Ground Water Quality Monitoring ..................................................................................................... 13

6. External Mechanical Integrity Testing................................................................................................ 13

7. Pressure Fall-Off Test ......................................................................................................................... 14

8. Plume and Pressure Front Tracking .................................................................................................... 14

9. Surface Air and/or Soil Gas Monitoring ............................................................................................. 14

10. Additional Monitoring ...................................................................................................................... 14

N. REPORTING AND RECORDKEEPING ......................................................................................14

1. Electronic Reporting ........................................................................................................................... 14

2. Semi-Annual Reports .......................................................................................................................... 14

3. 24-Hour Reporting .............................................................................................................................. 15

4. Reports on Well Tests and Workovers ............................................................................................... 16

5. Advance Notice Reporting .................................................................................................................. 16

6. Additional Reports .............................................................................................................................. 16

7. Records ............................................................................................................................................... 17

O. WELL PLUGGING, POST-INJECTION SITE CARE, AND SITE CLOSURE ..........................18

1. Well Plugging Plan ............................................................................................................................. 18

2. Revision of Well Plugging Plan .......................................................................................................... 18

3. Notice of Plugging and Abandonment ................................................................................................ 18

4. Plugging and Abandonment Approval and Report ............................................................................. 18

5. Temporary Abandonment ................................................................................................................... 19

6. Post-Injection Site Care and Site Closure Plan ................................................................................... 19

P. EMERGENCY AND REMEDIAL RESPONSE ...........................................................................21

Q. COMMENCING INJECTION .......................................................................................................21
ATTACHMENTS .................................................................................................................................23

A. SUMMARY OF REQUIREMENTS 

B. AREA OF REVIEW AND CORRECTIVE ACTION PLAN 

C. TESTING AND MONITORING PLAN 

D. INJECTION WELL PLUGGING PLAN 

E. POST-INJECTION SITE CARE AND SITE CLOSURE PLAN 

F. EMERGENCY AND REMEDIAL RESPONSE PLAN 

G. CONSTRUCTION DETAILS 

H. FINANCIAL ASSURANCE DEMONSTRATION 

I. STIMULATION PROGRAM

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PERMIT CONDITIONS 

A. EFFECT OF PERMIT 

The permittee is allowed to engage in underground injection in accordance with the conditions 

of this permit. Notwithstanding any other provisions of this permit, the permittee authorized by 

this permit shall not construct, operate, maintain, convert, plug, abandon, or conduct any other 

injection activity in a manner that allows the movement of injection, annulus or formation fluids 

into underground sources of drinking water (USDWs) or any unauthorized zones. The objective 

of this permit is to prevent the movement of fluids into or between USDWs or into any 

unauthorized zones consistent with the requirements at 40 CFR 146.86(a). Any underground 

injection activity not specifically authorized in this permit is prohibited. For purposes of 

enforcement, compliance with this permit during its term constitutes compliance with Part C of 

the Safe Drinking Water Act (SDWA). Such compliance does not constitute a defense to any 

action brought under Section 1431 of the SDWA or any other common or statutory law other 

than Part C of the SDWA. Issuance of this permit does not convey property rights of any sort or 

any exclusive privilege; nor does it authorize any injury to persons or property, any invasion of 

other private rights, or any infringement of State or local laws or regulations. Nothing in this 

permit shall be construed to relieve the permittee of any duties under applicable regulations.

B. PERMIT ACTIONS 

1. Modification, Revocation and Reissuance, and Termination – The Director of the Water 

Division of Region 5 of the U. S. Environmental Protection Agency (EPA), hereinafter, the 

Director, may, for cause or upon request from any interested person, including the permittee, 

modify, revoke and reissue, or terminate this permit in accordance with 40 CFR 124.5, 

144.12, 146.86(a), 144.39, and 144.40. The permit is also subject to minor modifications for 

cause as specified in 40 CFR 144.41. The filing of a request for a permit modification, 

revocation and reissuance, or termination, or the notification of planned changes, or 

anticipated noncompliance on the part of the permittee does not stay the applicability or 

enforceability of any permit condition. 

2. Minor Modifications – Upon the consent of the permittee, the Director may modify a 

permit to make the corrections or allowances for minor changes in the permitted activity as 

listed in 40 CFR 144.41. Any permit modification not processed as a minor modification 

under 40 CFR 144.41 must be made for cause, and with part 124 draft permit and public 

notice as required in 40 CFR 144.39. 

3. Transfer of Permits – This permit is not transferable to any person except in accordance 

with 40 CFR 144.38(a) and Section N(6)(b) of this permit. 

C. SEVERABILITY 

The provisions of this permit are severable, and if any provision of this permit or the application 

of any provision of this permit to any circumstance is held invalid, the application of such 

provision to other circumstances and the remainder of this permit shall not be affected thereby. 
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D. CONFIDENTIALITY 

In accordance with 40 CFR Part 2 (Public Information) and 40 CFR 144.5, any information 

submitted to EPA pursuant to this permit may be claimed as confidential business information 

by the submitter. Any such claim must be asserted at the time of submission by clearly 

identifying each page with the words "confidential business information" on every page 

containing such information. If no claim is made at the time of submission, EPA may make the 

information available to the public without further notice. If a claim is asserted, the validity of 

the claim will be assessed in accordance with the procedures in 40 CFR Part 2. Claims of 

confidentiality for the following information will be denied: 

1. The name and address of the permittee; and 

2. Information which deals with the existence, absence or level of contaminants in drinking 

water.

E. DEFINITION 

All terms used in this permit shall have the meaning set forth in the SDWA and Underground 

Injection Control regulations specified at 40 CFR parts 124, 144, 146, and 147. Unless 

specifically stated otherwise, all references to “days” in this permit should be interpreted as 

calendar days. 

F. DUTIES AND REQUIREMENTS 

1. Duty to Comply – The permittee shall comply with all conditions of this permit. Any 

permit noncompliance constitutes a violation of the SDWA and is grounds for enforcement 

action, permit termination, revocation and reissuance, modification, or for denial of a permit 

renewal application. 

2. Duty to Reapply – If the permittee wishes to continue an activity regulated by this permit 

after the expiration or termination of this permit, the permittee must apply for and obtain a 

new permit. 

3. Penalties for Violations of Permit Conditions – Any person who violates a permit 

requirement is subject to civil penalties and other enforcement action under the SDWA. Any 

person who willfully violates permit conditions may be subject to criminal prosecution 

under the SDWA and other applicable statutes and regulations. 

4. Need to Halt or Reduce Activity Not a Defense – It shall not be a defense for the permittee 

in an enforcement action to claim that it would have been necessary to halt or reduce the 

permitted activity in order to maintain compliance with the conditions of this permit. 

5. Duty to Mitigate – The permittee shall take all timely and reasonable steps necessary to 

minimize or correct any adverse impact on the environment resulting from noncompliance 

with this permit. 

6. Proper Operation and Maintenance – The permittee shall at all times properly operate and 
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maintain all facilities and systems of treatment and control and related appurtenances which 

are installed or used by the permittee to achieve compliance with the conditions of this 

permit. Proper operation and maintenance includes, among other things, effective 

performance, adequate funding, adequate operator staffing and training, and adequate 

laboratory and process controls, including appropriate quality assurance procedures. This 

provision requires the operation of back-up or auxiliary facilities or similar systems only 

when necessary to achieve compliance with the conditions of this permit. 

7. Duty to Provide Information – The permittee shall furnish to the Director in an electronic 

format, within a time specified, any information which the Director may request to 

determine whether cause exists for modifying, revoking and reissuing, or terminating this 

permit, or to determine compliance with this permit or the UIC regulations. The permittee 

shall also furnish to the Director, upon request within a time specified, electronic copies of 

records required to be kept by this permit. 

8. Inspection and Entry – The permittee shall allow the Director or an authorized 

representative, upon the presentation of credentials and other documents as may be required 

by law, to: 

(a) Enter upon the permittee's premises where a regulated facility or activity is located or 

conducted, or where electronic or non-electronic records are kept under the conditions of 

this permit; 

(b) Have access to and copy, at reasonable times, any electronic or non-electronic records 

that are kept under the conditions of this permit; 

(c) Inspect, at reasonable times, any facilities, equipment (including monitoring and control 

equipment), practices, or operations regulated or required under this permit; and 

(d) Sample or monitor, at reasonable times, for the purposes of assuring permit compliance 

or as otherwise authorized by the SDWA, any substances or parameters at any location, 

including facilities, equipment or operations regulated or required under this permit. 

9. Signatory Requirements – All reports or other information, required to be submitted by 

this permit or requested by the Director shall be signed and certified in accordance with 40 

CFR 144.32. 

G. AREA OF REVIEW AND CORRECTIVE ACTION 

1. The Area of Review (AoR) is the region surrounding the geologic sequestration project 

where USDWs may be endangered by the injection activity. The area of review is delineated 

using computational modeling that accounts for the physical and chemical properties of all 

phases of the injected carbon dioxide stream and is based on available site characterization, 

monitoring, and operational data. The permittee shall maintain and comply with the 

approved Area of Review and Corrective Action Plan (Attachment B of this permit) which 

is an enforceable condition of this permit and shall meet the requirements of 40 CFR 146.84. 
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2. At the fixed frequency specified in the Area of Review and Corrective Action Plan, or more 

frequently when monitoring and operational conditions warrant, the permittee must 

reevaluate the area of review and perform corrective action in the manner specified in 40 

CFR 146.84 and update the Area of Review and Corrective Action Plan or demonstrate to 

the Director that no update is needed. 

3. Following each AoR reevaluation or a demonstration that no evaluation is needed, the 

permittee shall submit the resultant information in an electronic format to the Director for 

review and approval of the AoR results. Once approved by the Director, the revised Area of 

Review and Corrective Action Plan will become an enforceable condition of this permit. 

H. FINANCIAL RESPONSIBILITY 

1. Financial Responsibility – The permittee shall maintain financial responsibility and 

resources to meet the requirements of 40 CFR 146.85 and the conditions of this permit. 

Financial responsibility shall be maintained through all phases of the project. The approved 

financial assurance mechanisms are found in Attachment H and in the administrative record 

of this permit. 

The financial instrument(s) must be sufficient to cover the cost of: 

(a) Corrective action (that meets the requirements of 40 CFR 146.84); 

(b) Injection well plugging (that meets the requirements of 40 CFR 146.92); 

(c) Post injection site care and site closure (that meets the requirements of 40 CFR 146.93); 

(d) Emergency and remedial response (that meets the requirements of 40 CFR 146.94). 

2. Cost Estimate Updates – During the active life of the geologic sequestration project, the 

permittee must adjust the cost estimate for inflation within 60 days prior to the anniversary 

date of the establishment of the financial instrument(s) and provide this adjustment to the 

Director in an electronic format. The permittee must also provide to the Director written 

updates in an electronic format of adjustments to the cost estimate within 60 days of any 

amendments to the Project Plans included as Attachments B – F of this permit, which 

address items (a) through (d) in Section H(1) of this permit. 

3. Notification –

(a) Whenever the current cost estimate increases to an amount greater than the face amount 

of a financial instrument currently in use, the permittee, within 60 days after the 

increase, must either cause the face amount to be increased to an amount at least equal to 

the current cost estimate and submit evidence of such increase to the Director, or obtain 

other financial responsibility instruments to cover the increase. Whenever the current 

cost estimate decreases, the face amount of the financial assurance instrument may be 

reduced to the amount of the current cost estimate only after the permittee has received 

written approval from the Director. 
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(b) The permittee must notify the Director by certified mail and in an electronic format of 

adverse financial conditions such as bankruptcy that may affect the ability to carry out 

injection well plugging, post-injection site care and site closure, and any applicable 

ongoing actions under Corrective Action and/or Emergency and Remedial Response. 

(i) In the event that the permittee or the third party provider of a financial 

responsibility instrument is going through a bankruptcy, the permittee must notify 

the Director by certified mail and in an electronic format of the commencement of 

a voluntary or involuntary proceeding under Title 11 (Bankruptcy), U.S. Code, 

naming the permittee as debtor, within 10 days after commencement of the 

proceeding. 

(ii) A guarantor of a corporate guarantee must make such a notification if he or she is 

named as debtor, as required under the terms of the guarantee. 

(iii) A permittee who fulfills the requirements of paragraph (a) of this section by 

obtaining a trust fund, surety bond, letter of credit, escrow account, or insurance 

policy will be deemed to be without the required financial assurance in the event of 

bankruptcy of the trustee or issuing institution, or a suspension or revocation of the 

authority of the trustee institution to act as trustee of the institution issuing the trust 

fund, surety bond, letter of credit, escrow account, or insurance policy. 

4. Establishing Other Coverage – The permittee must establish other financial assurance or 

liability coverage acceptable to the Director, within 60 days of the occurrence of the events 

in Section H(2) or H(3) of this permit. 

I. CONSTRUCTION 

1. Siting – The permittee has demonstrated to the satisfaction of the Director that the well is in

an area with suitable geology in accordance with the requirements at 40 CFR 146.83. 

2. Casing and Cementing – Casing and cement or other materials used in the construction of 

the well must have sufficient structural strength for the life of the geologic sequestration 

project. All well materials must be compatible with all fluids with which the materials may 

be expected to come into contact and must meet or exceed standards developed for such 

materials by the American Petroleum Institute, ASTM International, or comparable 

standards acceptable to the Director. The casing and cementing program must prevent the 

movement of fluids into or between USDWs for the expected life of the well in accordance 

with 40 CFR 146.86. The casing and cement used in the construction of this well are shown 

in Attachment G of this permit and in the administrative record for this permit. Any change 

must be submitted in an electronic format for approval by the Director before installation. 

3. Tubing and Packer Specifications – Tubing and packer materials used in the construction 

of the well must be compatible with fluids with which the materials may be expected to 

come into contact and must meet or exceed standards developed for such materials by the 

American Petroleum Institute, ASTM International, or comparable standards acceptable to 

the Director. The permittee shall inject only through tubing with a packer set within the long 

string casing at a point within or below the confining zone immediately above the injection 
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zone. The tubing and packer used in the well are represented in engineering drawings 

contained in Attachment G of this permit. Any change must be submitted in an electronic 

format for approval by the Director before installation. 

J. PRE-INJECTION TESTING 

1. Prior to the Director authorizing injection, the permittee shall perform all pre-injection 

logging, sampling, and testing specified at 40 CFR 146.87. This testing shall include: 

(a) Logs, surveys and tests to determine or verify the depth, thickness, porosity, 

permeability, lithology, and formation fluid salinity in all relevant geologic formations. 

These tests shall include: 

(i) Deviation checks that meet the requirements of 40 CFR 146.87(a)(1); 

(ii) Logs and tests before and upon installation of the surface casing that meet the 

requirements of 40 CFR 146.87(a)(2); 

(iii) Logs and tests before and upon installation of the long-string casing that meet the 

requirements of 40 CFR 146.87(a)(3);

(iv) Tests to demonstrate internal and external mechanical integrity that meet the 

requirements of 40 CFR 146.87(a)(4); and 

(v) Any alternative methods that are required by and/or approved by the Director 

pursuant to 40 CFR 146.87(a)(5). 

(b) Whole cores or sidewall cores of the injection zone and confining system and formation 

fluid samples from the injection zone that meet the requirements of 40 CFR 146.87(b); 

(c) Records of the fluid temperature, pH, conductivity, reservoir pressure, and static fluid 

level of the injection zone that meet the requirements of 40 CFR 146.87(c); 

(d) Tests as necessary to provide information about the injection and confining zones to 

allow determination or calculation of the fracture pressure and the physical and chemical 

characteristics of the injection and confining zones and the formation fluids in the 

injection zone that meet the requirements of 40 CFR 146.87(d); and 

(e) Tests to verify hydrogeologic characteristics of the injection zone that meet the 

requirements of 40 CFR 146.87(e), including: 

(i) A pressure fall-off test and 

(ii) A pumping test or injectivity tests. 

2. The permittee shall submit to the Director for approval in an electronic format a schedule for 

logging and testing activities 30 days prior to conducting the first test and submit any 

changes to the schedule 30 days prior to the next scheduled test. The permittee must provide 
- 8 - IL-137-6A-0004

the Director or their representative with the opportunity to witness all logging, sampling, and 

testing required under this Section. 

K. OPERATIONS 

1. Injection Pressure Limitation – Except during stimulation, the permittee must ensure that 

injection pressure does not exceed 90 percent of the fracture pressure of the injection zone(s) 

so as to ensure that the injection does not initiate new fractures or propagate existing 

fractures in the injection zone(s). In no case shall injection pressure initiate fractures or 

propagate existing fractures in the confining zone or cause the movement of injection or 

formation fluids into a USDW. The maximum injection pressure limit is listed in 

Attachment A.

2. Stimulation Program – Pursuant to requirements at 40 CFR 146.82(a)(9), all stimulation 

programs proposed by the permittee must be approved by the Director as a permit 

modification and incorporated into Attachment I of this permit.

3. Additional Injection Limitation – No injectate other than that identified on page 1 of this 

permit shall be injected except fluids used for stimulation, rework, and well tests as 

approved by the Director.

4. Annulus Fluid – The permittee must fill the annulus between the tubing and the long string 

casing with a non-corrosive fluid approved by the Director. 

5. Annulus/Tubing Pressure Differential – Except during workovers or times of annulus 

maintenance, the permittee must maintain on the annulus a pressure that exceeds the 

operating injection pressure as specified in Attachment A of this permit, unless the Director 

determines that such requirement might harm the integrity of the well or endanger USDWs.

6. Automatic Alarms and Automatic Shut-off System – 

(a) The permittee must: 

(i) Install, continuously operate, and maintain an automatic alarm and an 

automatic shut-off system or, at the discretion of the Director, down-hole shutoff systems, or other mechanical devices that provide equivalent protection; 

and

(ii) Successfully demonstrate the functionality of the alarm system and shut-off 

system prior to the Director authorizing injection, and at a minimum of once 

every twelfth month after the last approved demonstration. 

(b) Testing under this Section must involve subjecting the system to simulated failure 

conditions and must be witnessed by the Director or his or her representative unless 

the Director authorizes an unwitnessed test in advance. The permittee must provide 

notice in an electronic format 30 days prior to running the test and must provide the 

Director or their representative the opportunity to attend. The test must be 

documented using either a mechanical or digital device which records the value of 
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the parameter of interest, or by a service company job record. A final report 

including any additional interpretation necessary for evaluation of the testing must be 

submitted in an electronic format within the time period specified in Section N(4) of 

this permit. 

7. Precautions to Prevent Well Blowouts – At all times, the permittee shall maintain on the 

well a pressure which will prevent the return of the injection fluid to the surface. The well 

bore must be filled with a high specific gravity fluid during workovers to maintain a positive 

(downward) gradient and/or a plug shall be installed which can resist the pressure 

differential. A blowout preventer must be installed and kept in proper operational condition 

whenever the wellhead is removed to work on the well. The permittee shall follow 

procedures such as those below to assure that a backflow or blowout does not occur: 

(a) Limit the temperature and/or corrosivity of the injectate; and 

(b) Develop procedures necessary to assure that pressure imbalances do not occur. 

8. Circumstances Under Which Injection Must Cease –

Injection shall cease when any of the following circumstances arises:

(a) Failure of the well to pass a mechanical integrity test; 

(b) A loss of mechanical integrity during operation; 

(c) The automatic alarm or automatic shut-off system is triggered; 

(d) A significant unexpected change in the annulus or injection pressure; 

(e) The Director determines that the well lacks mechanical integrity; or 

(f) The permittee is unable to maintain compliance with any permit condition or regulatory 

requirement and the Director determines that injection should cease. 

9. Approaches for Ceasing Injection –

(a) The permittee must shut-in the well by gradual reduction in the injection pressure as 

outlined in Attachment A of this permit; or 

(b) The permittee must immediately cease injection and shut-in the well as outlined in the 

Emergency and Remedial Response Plan (Attachment F of this permit). 

L. MECHANICAL INTEGRITY 

1. Standards – Other than during periods of well workover (maintenance) approved by the 

Director in which the sealed tubing-casing annulus is disassembled for maintenance or 

corrective procedures, the injection well must have and maintain mechanical integrity 

consistent with 40 CFR 146.89. To meet these requirements, mechanical integrity 
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tests/demonstrations must be witnessed by the Director or an authorized representative of 

the Director unless prior approval has been granted by the Director to run an un-witnessed 

test. In order to conduct testing without an EPA representative, the following procedures 

must be followed. 

(a) The permittee must submit prior notification in an electronic format within the time 

period specified in Section L(3) of this permit, including the information that no EPA 

representative is available, and receive permission from the Director to proceed; 

(b) The test must be performed in accordance with the Testing and Monitoring Plan 

(Attachment C of this permit) and documented using either a mechanical or digital 

device that records the value of the parameter of interest; 

(c) A final report including any additional interpretation necessary for evaluation of the 

testing must be submitted in an electronic format within the time period specified in 

Section N(4) of this permit. 

2. Mechanical Integrity Testing – The permittee shall conduct a casing inspection log and 

mechanical integrity testing as follows: 

(a) Prior to receiving authorization to inject, the permittee shall perform the following 

testing to demonstrate internal mechanical integrity pursuant to 40 CFR 146.87(a)(4): 

(i) A pressure test with liquid or gas; and 

(ii) A casing inspection log; or 

(iii) An alternative approved by the Director that has been approved by the 

Administrator pursuant to requirements at 40 CFR 146.89(e). 

(b) Prior to receiving authorization to inject, the permittee shall perform the following 

testing to demonstrate external mechanical integrity pursuant to 40 CFR 146.87(a)(4): 

(i) A tracer survey such as an oxygen activation log; or 

(ii) A temperature or noise log; or 

(iii) An alternative approved by the Director that has been approved by the 

Administrator pursuant to requirements at 40 CFR 146.89(e). 

(c) Other than during periods of well workover (maintenance) approved by the Director in 

which the sealed tubing-casing annulus is disassembled for maintenance or corrective 

procedures, the permittee must continuously monitor injection pressure, injection rate, 

injection volumes; pressure on the annulus between tubing and long string casing; and 

annulus fluid volume as specified in 40 CFR 146.88(e), and 146.89(b). 

(d) At least once per year, the permittee must perform the following testing to demonstrate 

external mechanical integrity pursuant to 40 CFR 146.89(c): 
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(i) An Administrator-approved tracer survey such as an oxygen-activation log; or 

(ii) A temperature or noise log. The Director may require such tests whenever the well 

is worked over; or 

(iii) An alternative approved by the Director that has been approved by the 

Administrator pursuant to requirements at 40 CFR 146.89(e). 

(e) After any workover that may compromise the internal mechanical integrity of the well, 

the well shall be tested by means of a pressure test approved by the Director and the well 

must pass the test to demonstrate mechanical integrity. 

(f) Prior to plugging the well, the permittee shall demonstrate external mechanical integrity 

as described in the Injection Well Plugging Plan and that meets the requirements of 40 

CFR 146.92(a). 

(g) The Director may require the use of any other tests to demonstrate mechanical integrity 

other than those listed above with the written approval of the Administrator pursuant to 

requirements at 40 CFR 146.89(e). 

3. Prior Notice and Reporting –

(a) The permittee shall notify the Director in an electronic format of his or her intent to 

demonstrate mechanical integrity in an electronic format at least 30 days prior to such 

demonstration. At the discretion of the Director a shorter time period may be allowed. 

(b) Reports of mechanical integrity demonstrations which include logs must include an 

interpretation of results by a knowledgeable log analyst. The permittee shall report in an 

electronic format the results of a mechanical integrity demonstration within the time 

period specified in Section N(4) of this permit. 

4. Gauge and Meter Calibration – The permittee shall calibrate all gauges used in 

mechanical integrity demonstrations and other required monitoring to an accuracy of not 

less than 0.5 percent of full scale, within one year prior to each required test. The date of the 

most recent calibration shall be noted on or near the gauge or meter. A copy of the 

calibration certificate shall be submitted to the Director in an electronic format with the 

report of the test. Pressure gauge resolution shall be no greater than five psi. Certain 

mechanical integrity and other testing may require greater accuracy and shall be identified in 

the procedure submitted to the Director prior to the test. 

5. Loss of Mechanical Integrity –

(a) If the permittee or the Director finds that the well fails to demonstrate mechanical 

integrity during a test, or fails to maintain mechanical integrity during operation, or that 

a loss of mechanical integrity as defined by 40 CFR 146.89(a)(1) or (2) is suspected 

during operation (such as a significant unexpected change in the annulus or injection 

pressure), the permittee must: 
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(i) Cease injection in accordance with Sections K(8) and K(9)(a) or (b), and 

Attachments C or F of this permit; 

(ii) Take all steps reasonably necessary to determine whether there may have been a 

release of the injected carbon dioxide stream or formation fluids into any 

unauthorized zone. If there is evidence of USDW endangerment, implement the 

Emergency and Remedial Response Plan (Attachment F of this permit); 

(iii) Follow the reporting requirements as directed in Section N of this permit; 

(iv) Restore and demonstrate mechanical integrity to the satisfaction of the Director 

and receive written approval from the Director prior to resuming injection; and 

(v) Notify the Director in an electronic format when injection can be expected to 

resume.

(b) If a shutdown (i.e., down-hole or at the surface) is triggered, the permittee must 

immediately investigate and identify as expeditiously as possible the cause of the 

shutdown. If, upon such investigation, the well appears to be lacking mechanical 

integrity, or if monitoring required indicates that the well may be lacking mechanical 

integrity, the permittee must take the actions listed above in Section L(5)(a)(i) through 

(v).

(c) If the well loses mechanical integrity prior to the next scheduled test date, then the well 

must either be plugged or repaired and retested within 30 days of losing mechanical 

integrity. The permittee shall not resume injection until mechanical integrity is 

demonstrated and the Director gives written approval to recommence injection in cases 

where the well has lost mechanical integrity. 

6. Mechanical Integrity Testing on Request From Director – The permittee shall 

demonstrate mechanical integrity at any time upon written notice from the Director. 

M. TESTING AND MONITORING 

1. Testing and Monitoring Plan – 

(a) The permittee shall maintain and comply with the approved Testing and Monitoring Plan 

(Attachment C of this permit) and with the requirements at 40 CFR 144.51(j), 146.88(e),

and 146.90. The Testing and Monitoring Plan is an enforceable condition of this permit. 

Samples and measurements taken for the purpose of monitoring shall be representative 

of the monitored activity. Procedures for all testing and monitoring under this permit 

must be submitted to the Director in an electronic format for approval at least 30 days 

prior to the test. In performing all testing and monitoring under this permit, the permittee 

must follow the procedures approved by the Director. If the permittee is unable to follow 

the EPA approved procedures, then, the permittee must contact the Director at least 30 

days prior to testing to discuss options, if any are feasible. When the test report is 

submitted, a full explanation must be provided as to why any approved procedures were 
- 13 - IL-137-6A-0004

not followed. If the approved procedures were not followed, EPA may take an 

appropriate action, including but not limited to, requiring the permittee to re-run the test. 

(b) The permittee must update the Testing and Monitoring Plan as required at 40 CFR 

146.90 (j) to incorporate monitoring and operational data and in response to AoR 

reevaluations required under Section G.2. of this permit or demonstrate to the Director 

that no update is needed. The amended Testing and Monitoring Plan or demonstration 

shall be submitted to the Director in an electronic format within one year of an AoR 

reevaluation; following any significant changes to the facility such as addition of 

monitoring wells or newly permitted injection wells within the AoR; or when required 

by the Director. 

(c) Following each update of the Testing and Monitoring Plan or a demonstration that no 

update is needed, the permittee shall submit the resultant information in an electronic 

format to the Director for review and approval of the results. Once approved by the 

Director, the revised Testing and Monitoring Plan will become an enforceable condition 

of this permit. 

2. Carbon Dioxide Stream Analysis – The permittee shall analyze the carbon dioxide stream 

with sufficient frequency to yield data representative of its chemical and physical 

characteristics, as described in the Testing and Monitoring Plan and to meet the 

requirements of 40 CFR 146.90(a). 

3. Continuous Monitoring – The permittee shall maintain continuous monitoring devices and 

use them to monitor injection pressure, flow rate, volume, the pressure on the annulus 

between the tubing and the long string of casing, annulus fluid level, and temperature. This 

monitoring shall be performed as described in the Testing and Monitoring Plan to meet the 

requirements of 40 CFR 146.90(b). The permittee shall maintain for EPA's inspection at the 

facility an appropriately scaled, continuous record of these monitoring results as well as 

original files of any digitally recorded information pertaining to these operations. 

4. Corrosion Monitoring – The permittee shall perform corrosion monitoring of the well 

materials for loss of mass, thickness, cracking, pitting, and other signs of corrosion on a 

quarterly basis using the procedures described in the Testing and Monitoring Plan and in 

accordance with 40 CFR 146.90(c) to ensure that the well components meet the minimum 

standards for material strength and performance set forth in 40 CFR 146.86(b). 

5. Ground Water Quality Monitoring– The permittee shall monitor ground water quality and 

geochemical changes above the confining zone(s) that may be a result of carbon dioxide 

movement through the confining zone(s) or additional identified zones. This monitoring 

shall be performed for the parameters identified in the Testing and Monitoring Plan at the 

locations and depths, and at frequencies described in the Testing and Monitoring Plan to 

meet the requirements of 40 CFR 146.90(d). 

6. External Mechanical Integrity Testing – The permittee shall demonstrate external 

mechanical integrity as described in the Testing and Monitoring Plan and Section L of this 

permit to meet the requirements of 40 CFR 146.90(e). 
- 14 - IL-137-6A-0004

7. Pressure Fall-Off Test – The permittee shall conduct a pressure fall-off test at least once 

every five years unless more frequent testing is required by the Director based on sitespecific information. The test shall be performed as described in the Testing and Monitoring 

Plan to meet the requirements of 40 CFR 146.90(f). 

8. Plume and Pressure Front Tracking –The permittee shall track the extent of the carbon 

dioxide plume and the presence or absence of elevated pressure (e.g., the pressure front) as 

described in the Testing and Monitoring Plan. 

(a) The permittee shall use direct methods to track the position of the carbon dioxide 

plume and the pressure front in the injection zone as described in the Testing and 

Monitoring Plan and to meet the requirements of 40 CFR 146.90(g)(1). 

(b) The permittee shall use indirect methods to track the position of the carbon dioxide 

plume and pressure front as described in the Testing and Monitoring Plan and to 

meet the requirements of 40 CFR 146.90(g)(2). 

9. Surface Air and/or Soil Gas Monitoring – The permittee shall conduct any surface air 

monitoring and/or soil gas monitoring required by the Director to detect movement of 

carbon dioxide that could endanger a USDW at the frequency and locations described in the 

Testing and Monitoring Plan to meet the requirements of 40 CFR 146.90(h). 

10. Additional Monitoring – If required by the Director as provided in 40 CFR 146.90(i), the 

permittee shall perform any additional monitoring determined to be necessary to support, 

upgrade, and improve computational modeling of the AoR evaluation required under 40 

CFR 146.84(c) and to determine compliance with standards under 40 CFR 144.12 or 40 

CFR 146.86(a). This monitoring shall be performed as described in a modification to the 

Testing and Monitoring Plan. 

N. REPORTING AND RECORDKEEPING 

1. Electronic Reporting – Electronic reports, submittals, notifications and records made and 

maintained by the permittee under this permit must be in an electronic format approved by 

EPA. The permittee shall electronically submit all required reports to the Director at: 

https://epa.velo.pnnl.gov/operators

2. Semi-Annual Reports – The permittee shall submit semi-annual reports containing: 

(a) Any changes to the physical, chemical, and other relevant characteristics of the carbon 

dioxide stream from the proposed operating data; 

(b) Monthly average, maximum, and minimum values for injection pressure, flow rate and 

daily volume, temperature, and annular pressure; 

(c) A description of any event that exceeds operating parameters for annulus pressure or 

injection pressure specified in the permit; 
- 15 - IL-137-6A-0004

(d) A description of any event which triggers the shut-off systems required in Section(K)(6) 

of this permit pursuant to 40 CFR 146.88(e), and the response taken; 

(e) The monthly volume and/or mass of the carbon dioxide stream injected over the 

reporting period and the volume and/or mass injected cumulatively over the life of the 

project; 

(f) Monthly annulus fluid volume added or produced; and

(g) Results of the continuous monitoring required in Section M(3) including: 

(i) A tabulation of: (1) daily maximum injection pressure, (2) daily minimum annulus 

pressure, (3) daily minimum value of the difference between simultaneous 

measurements of annulus and injection pressure, (4) daily volume, (5) daily 

maximum flow rate, and (6) average annulus tank fluid level; and 

(ii) Graph(s) of the continuous monitoring as required in Section M(3) of this permit, 

or of daily average values of these parameters. The injection pressure, injection 

volume and flow rate, annulus fluid level, annulus pressure, and temperature shall 

be submitted on one or more graphs, using contrasting symbols or colors, or in 

another manner approved by the Director; and 

(h) Results of any additional monitoring identified in the Testing and Monitoring Plan and 

described in Section M of this permit. 

3. 24-Hour Reporting – 

(a) The permittee shall report to the Director any permit noncompliance which may 

endanger human health or the environment and/or any events that require 

implementation of actions in the Emergency and Remedial Response Plan (Attachment F 

of this permit). Any information shall be provided orally within 24 hours from the time 

the permittee becomes aware of the circumstances. Such verbal reports shall include, but 

not be limited to the following information: 

(i) Any evidence that the injected carbon dioxide stream or associated pressure front 

may cause an endangerment to a USDW, or any monitoring or other information 

which indicates that any contaminant may cause endangerment to a USDW; 

(ii) Any noncompliance with a permit condition, or malfunction of the injection 

system, which may cause fluid migration into or between USDWs; 

(iii) Any triggering of the shut-off system required in Section (K)(6) of this permit (i.e., 

down-hole or at the surface); 

(iv) Any failure to maintain mechanical integrity; 

(v) Pursuant to compliance with the requirement at 40 CFR 146.90(h) for surface 
- 16 - IL-137-6A-0004

air/soil gas monitoring or other monitoring technologies, if required by the 

Director, any release of carbon dioxide to the atmosphere or biosphere; and 

(vi) Actions taken to implement appropriate protocols outlined in the Emergency and 

Remedial Response Plan (Attachment F of this permit). 

(b) A written submission shall be provided to the Director in an electronic format within 

five days of the time the permittee becomes aware of the circumstances described in 

Section(N)(3)(a) of this permit. The submission shall contain a description of the 

noncompliance and its cause; the period of noncompliance, including exact dates and 

times, and, if the noncompliance has not been corrected, the anticipated time it is 

expected to continue as well as actions taken to implement appropriate protocols 

outlined in the Emergency and Remedial Response Plan (Attachment F of this permit); 

and steps taken or planned to reduce, eliminate and prevent recurrence of the 

noncompliance. 

4. Reports on Well Tests and Workovers – Report, within 30 days, the results of: 

(a) Periodic tests of mechanical integrity; 

(b) Any well workover, including stimulation; 

(c) Any other test of the injection well conducted by the permittee if required by the 

Director; and 

(d) Any test of any monitoring well required by this permit. 

5. Advance Notice Reporting –

(a) Well Tests – The permittee shall give at least 30 days advance written notice to the 

Director in an electronic format of any planned workover, stimulation, or other well test. 

(b) Planned Changes – The permittee shall give written notice to the Director in an 

electronic format, as soon as possible, of any planned physical alterations or additions to 

the permitted injection facility other than minor repair/replacement or maintenance 

activities. An analysis of any new injection fluid shall be submitted to the Director for 

review and written approval at least 30 days prior to injection; this approval may result 

in a permit modification. 

(c) Anticipated Noncompliance – The permittee shall give at least 14 days advance written 

notice to the Director in an electronic format of any planned changes in the permitted 

facility or activity which may result in noncompliance with permit requirements. 

6. Additional Reports – 

(a) Compliance Schedules – Reports of compliance or noncompliance with, or any 

progress reports on, interim and final requirements contained in any compliance 

schedule of this permit shall be submitted in an electronic format by the permittee no 
- 17 - IL-137-6A-0004

later than 30 days following each schedule date. 

(b) Transfer of Permits – This permit is not transferable to any person except after notice is 

sent to the Director in an electronic format at least 30 days prior to transfer and the 

requirements of 40 CFR 144.38(a) have been met. Pursuant to requirements at 40 CFR 

144.38(a), the Director will require modification or revocation and reissuance of the 

permit to change the name of the permittee and incorporate such other requirements as 

may be necessary under the SDWA. 

(c) Other Noncompliance – The permittee shall report in an electronic format all other 

instances of noncompliance not otherwise reported with the next monitoring report. The 

reports shall contain the information listed in Section N(3)(b) of this permit. 

(d) Other Information – When the permittee becomes aware of failure to submit any 

relevant facts in the permit application or that incorrect information was submitted in a 

permit application or in any report to the Director, the permittee shall submit such facts 

or corrected information in an electronic format within 10 days in accordance with 40 

CFR 144.51(l)(8). 

(e) Report on Permit Review – Within 30 days of receipt of this permit, the permittee shall 

certify to the Director in an electronic format that he or she has read and is personally 

familiar with all terms and conditions of this permit. 

7. Records –

(a) The permittee shall retain records and all monitoring information, including all 

calibration and maintenance records and all original chart recordings for continuous 

monitoring instrumentation and copies of all reports required by this permit (including 

records from pre-injection, active injection, and post-injection phases) for a period of at 

least 10 years from collection. 

(b) The permittee shall maintain records of all data required to complete the permit 

application form for this permit and any supplemental information (e.g. modeling inputs 

for AoR delineations and reevaluations, plan modifications) submitted under 40 CFR 

144.27, 144.31, 144.39, and 144.41 for a period of at least 10 years after site closure. 

(c) The permittee shall retain records concerning the nature and composition of all injected 

fluids until 10 years after site closure. 

(d) The retention periods specified in Section N(7)(a) through (c) of this permit may be 

extended by request of the Director at any time. The permittee shall continue to retain 

records after the retention period specified in Section N(7)(a) through (c) of this permit 

or any requested extension thereof expires unless the permittee delivers the records to 

the Director or obtains written approval from the Director to discard the records. 

(e) Records of monitoring information shall include: 

(i) The date, exact place, and time of sampling or measurements; 
- 18 - IL-137-6A-0004

(ii) The name(s) of the individual(s) who performed the sampling or measurements; 

(iii) A precise description of both sampling methodology and the handling of samples; 

(iv) The date(s) analyses were performed; 

(v) The name(s) of the individual(s) who performed the analyses; 

(vi) The analytical techniques or methods used; and 

(vii) The results of such analyses. 

O. WELL PLUGGING, POST-INJECTION SITE CARE, AND SITE CLOSURE 

1. Well Plugging Plan – The permittee shall maintain and comply with the approved Well 

Plugging Plan (Attachment D of this permit) which is an enforceable condition of this 

permit and shall meet the requirements of 40 CFR 146.92. 

2. Revision of Well Plugging Plan – If the permittee finds it necessary to change the Well 

Plugging Plan (Attachment D of this permit), a revised plan shall be submitted in an 

electronic format to the Director for written approval. Any amendments to the Well 

Plugging Plan must be approved by the Director and must be incorporated into the permit, 

and are subject to the permit modification requirements at 40 CFR 144.39 or 144.41. 

3. Notice of Plugging and Abandonment – The permittee must notify the Director in writing 

in an electronic format pursuant to 40 CFR 146.92(c), at least 60 days before plugging, 

conversion or abandonment of a well. At the discretion of the Director, a shorter notice 

period may be allowed. 

4. Plugging and Abandonment Approval and Report –

(a) The permittee must receive written approval of the Director before plugging the well and 

shall plug and abandon the well in accordance with 40 CFR 146.92, as provided in the 

Well Plugging Plan (Attachment D of this permit). 

(b) Within 60 days after plugging, the permittee must submit in an electronic format a 

plugging report to the Director. The report must be certified as accurate by the permittee 

and by the person who performed the plugging operation (if other than the permittee.) 

The permittee shall retain the well plugging report in an electronic format for 10 years 

following site closure. The report must include: 

(i) A statement that the well was plugged in accordance with the Well Plugging Plan 

previously approved by the Director (Attachment D of this permit); or 

(ii) If the actual plugging differed from the approved plan, a statement describing the 

actual plugging and an updated plan specifying the differences from the plan 

previously submitted and explaining why the Director should approve such 
- 19 - IL-137-6A-0004

deviation. If the Director determines that a deviation from the plan incorporated in 

this permit may endanger underground sources of drinking water, the permittee 

shall replug the well as required by the Director. 

5. Temporary Abandonment – If the permittee ceases injection into the well for more than 24 

consecutive months, the well is considered to be in a temporarily abandoned status, and the 

permittee shall plug and abandon the well in accordance with the approved Well Plugging 

Plan, 40 CFR 144.52 (a)(6), and 40 CFR 146.92, or make a demonstration of nonendangerment of this well while it is in temporary abandonment status. During any periods 

of temporary abandonment or disuse, the well will be tested to ensure that it maintains 

mechanical integrity, according to the requirements and frequency specified in Section L(2) 

of this permit. The permittee shall continue to comply with the conditions of this permit, 

including all monitoring and reporting requirements according to the frequencies outlined in 

the permit. 

6. Post-Injection Site Care and Site Closure Plan – 

(a) The permittee shall maintain and comply with the Post-Injection Site Care and Site 

Closure Plan, found as Attachment E of this permit, which meets the requirements of 40 

CFR 146.93 and is an enforceable condition of this permit. The permittee shall: 

(i) Upon cessation of injection, either submit in an electronic format for the Director’s 

approval an amended Post-Injection Site Care and Site Closure Plan or 

demonstrate through monitoring data and modeling results that no amendment to 

the plan is needed. 

(ii) At any time during the life of the project, the permittee may modify and resubmit 

in an electronic format the Post-Injection Site Care and Site Closure Plan for the 

Director’s approval. The permittee may, as part of such modifications to the Plan, 

request a modification to the post-injection site care timeframe that includes 

documentation of the information at 40 CFR 146.93(c)(1). 

(b) The permittee shall monitor the site following the cessation of injection to show the 

position of the carbon dioxide plume and pressure front and demonstrate that USDWs 

are not being endangered, as specified in the Post-Injection Site Care and Site Closure 

Plan and in 40 CFR 146.90, and 40 CFR 146.93, including: 

(i) Ground water quality monitoring; 

(ii) Tracking the position of the carbon dioxide plume and pressure front including 

direct pressure monitoring and geochemical plume monitoring and the use of 

indirect methods; 

(iii) Any other required monitoring, e.g., soil gas and/or surface air monitoring 

described in the Post-Injection Site Care and Site Closure Plan; 
- 20 - IL-137-6A-0004

(iv) The permittee shall submit in an electronic format the results of all monitoring 

performed according to the schedule identified in the Post-Injection Site Care and 

Site Closure Plan; and 

(v) The permittee shall continue to conduct post-injection site monitoring for at least 

50 years or for the duration of any alternative timeframe approved pursuant to 40 

CFR 146.93(c) and the Post-Injection Site Care and Site Closure Plan. 

(c ) The post-injection monitoring must continue until the project no longer poses an 

endangerment to USDWs and the demonstration pursuant to 40 CFR 146.93(b)(2) and as 

described in Section O(6)(d) of this permit is approved by the Director. 

(d) Prior to authorization for site closure, the permittee shall submit to the Director for 

review and approval, in an electronic format, a demonstration, based on information 

collected pursuant to Section O(6)(b) of this permit, that the carbon dioxide plume and 

the associated pressure front do not pose an endangerment to USDWs and that no 

additional monitoring is needed to ensure that the project does not pose an endangerment 

to USDWs, as required under 40 CFR 146.93(b)(3). The Director reserves the right to 

amend the post-injection site monitoring requirements (including extend the monitoring 

period) if there is a concern that USDWs are being endangered. 

(e) The permittee shall notify the Director in an electronic format at least 120 days before 

site closure. At this time, if any changes to the approved Post-Injection Site Care and 

Site Closure Plan in Attachment E of this permit are proposed, the permittee shall submit 

a revised plan. 

(f) After the Director has authorized site closure, the permittee shall plug all monitoring 

wells as specified in Attachment E of this permit – the Post-Injection Site Care and Site 

Closure Plan – in a manner which will not allow movement of injection or formation 

fluids that endangers a USDW. The permittee shall also restore the site to its preinjection condition. 

(g) The permittee shall submit a site closure report in an electronic format to the Director 

within 90 days of site closure. The report must include the information specified at 40 

CFR 146.93(f). 

(h) The permittee shall record a notation on the deed to the facility property or any other 

document that is normally examined during a title search that will in perpetuity provide 

any potential purchaser of the property the information listed at 40 CFR 146.93(g). 

(i) The permittee shall retain for 10 years following site closure an electronic copy of the 

site closure report , records collected during the post-injection site care period, and any 

other records required under 40 CFR 146.91(f)(4). The permittee shall deliver the 

records in an electronic format to the Director at the conclusion of the retention period. 
- 21 - IL-137-6A-0004

P. EMERGENCY AND REMEDIAL RESPONSE 

1. The Emergency and Remedial Response Plan describes actions the permittee must take to 

address movement of the injection or formation fluids that may cause an endangerment to a 

USDW during construction, operation, and post-injection site care periods. The permittee 

shall maintain and comply with the approved Emergency and Remedial Response Plan 

(Attachment F of this permit), which is an enforceable condition of this permit, and with 40 

CFR 146.94. 

2. If the permittee obtains evidence that the injected carbon dioxide and/or associated pressure 

front may cause endangerment to a USDW, the permittee must: 

(a) Cease injection in accordance with Sections K(8) and K(9)(a) or (b), and Attachments 

C or F of this permit; 

(b) Take all steps reasonably necessary to identify and characterize any release; 

(c) Notify the Director within 24 hours; and 

(d) Implement the Emergency and Remedial Response Plan (Attachment F of this permit) 

approved by the Director. 

3. At the frequency specified in the Area of Review and Corrective Action Plan, or more 

frequently when monitoring and operational conditions warrant, the permittee shall review 

and update the Emergency and Remedial Response Plan as required at 40 CFR 146.94(d) or 

demonstrate to the Director that no update is needed. The permittee shall also incorporate 

monitoring and operational data and in response to AoR reevaluations required under 

Section G.2. of this permit or demonstrate to the Director that no update is needed. The 

amended Emergency and Remedial Response Plan or demonstration shall be submitted to 

the Director in an electronic format within one year of an AoR reevaluation; following any 

significant changes to the facility such as addition of injection wells; or when required by 

the Director. 

4. Following each update of the Emergency and Remedial Response Plan or a demonstration 

that no update is needed, the permittee shall submit the resultant information in an electronic 

format to the Director for review and confirmation of the results. Once approved by the 

Director, the revised Emergency and Remedial Response Plan will become an enforceable 

condition of this permit. 

Q. COMMENCING INJECTION 

The permittee may not commence injection until: 

1. Results of the formation testing and logging program as specified in Section J of this permit 

and in 40 CFR 146.87 are submitted to the Director in an electronic format and subsequently 

reviewed and approved by the Director; 
- 22 - IL-137-6A-0004

2. Mechanical integrity of the well has been demonstrated in accordance with 40 CFR 

146.89(a)(1) and (2), and in accordance with Section L(1) through (3) of this permit; 

3. The completion of corrective action required by the Area of Review and Corrective Action 

Plan found in Attachment B of this permit in accordance with 40 CFR 146.84; 

4. All requirements at 40 CFR 146.82(c) have been met, including but not limited to reviewing 

and updating of the Area of Review and Corrective Action, Testing and Monitoring, Well 

Plugging, Post-Injection Site Care and Site Closure, and Emergency and Remedial Response 

plans to incorporate final site characterization information, final delineation of the AoR, and 

the results of pre-injection testing, and information has been submitted in an electronic 

format, reviewed and approved by the Director; 

5. Construction is complete and the permittee has submitted to the Director in an electronic 

format a notice that completed construction is in compliance with 40 CFR 146.86 and 

Section I of this permit; 

6. The Director has inspected or otherwise reviewed the injection well and all submitted 

information and finds it is in compliance with the conditions of the permit; 

7. The Director has approved demonstration of the alarm system and shut-off system under 

Section K.6 of this permit; and. 

8. The Director has given written authorization to commence injection. 
- 23 - IL-137-6A-0004

ATTACHMENTS 

These attachments include, but are not limited to, permit conditions and plans concerning operating 

procedures, monitoring and reporting, as required by 40 CFR Parts 144 and 146. The permittee 

shall comply with these conditions and adhere to these plans as approved by the Director, as 

follows: 

A. SUMMARY OF OPERATING REQUIREMENTS 

B. AREA OF REVIEW AND CORRECTIVE ACTION PLAN 

C. TESTING AND MONITORING PLAN 

D. WELL PLUGGING PLAN 

E. POST-INJECTION SITE CARE AND SITE CLOSURE PLAN 

F. EMERGENCY AND REMEDIAL RESPONSE PLAN 

G. CONSTRUCTION DETAILS 

H. FINANCIAL ASSURANCE DEMONSTRATION 

I. STIMULATION PROGRAM