# COLONIAL PIPELINE CO — Safety Order

- **operation:** document
- **citation:** CPF 22021005NOPSO
- **title:** COLONIAL PIPELINE CO — Safety Order
- **source type:** enforcement
- **agency:** Pipeline and Hazardous Materials Safety Administration
- **status:** historical
- **official:** true
- **published on:** 2021-03-29
- **effective on:** Not available
- **summary:** CLOSED safety order.
- **machine formats:** - **json:** https://regulus.evalyn.ai/document/phmsa-enforcement-22021005nopso.json
- **markdown:** https://regulus.evalyn.ai/document/phmsa-enforcement-22021005nopso.md
- **app url:** https://regulus.evalyn.ai/document/phmsa-enforcement-22021005nopso
- **source url:** https://primis.phmsa.dot.gov/enforcement-data/case/22021005NOPSO
**body:**

Safety Order involving COLONIAL PIPELINE CO. The dataset does not identify a cited regulation for this case. The case was opened on 2021-03-29 and is reported as closed as of 2025-08-25. Open the official case record for notices, responses, orders, and the latest status.

Official case documents:

22021005NOPSO_Closure Letter_08252025_(20-188854).pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Closure%20Letter_08252025_(20-188854).pdf

22021005NOPSO_Closure Letter_08252025_(20-188854)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Closure%20Letter_08252025_(20-188854)_text.pdf

22021005NOPSO_Consent Agreement and Order_06152021_(20-188854).pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Consent%20Agreement%20and%20Order_06152021_(20-188854).pdf

22021005NOPSO_Consent Agreement and Order_06152021_(20-188854)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Consent%20Agreement%20and%20Order_06152021_(20-188854)_text.pdf

22021005NOPSO_Notice of Proposed Safety Order_03292021_(20-188854).pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Notice%20of%20Proposed%20Safety%20Order_03292021_(20-188854).pdf

22021005NOPSO_Notice of Proposed Safety Order_03292021_(20-188854)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/22021005NOPSO/22021005NOPSO_Notice%20of%20Proposed%20Safety%20Order_03292021_(20-188854)_text.pdf

22021005NOPSO_Consent Agreement and Order_06152021_(20-188854)_text.pdf

June 15, 2021
Mr. Joseph Blount
President and Chief Executive Officer
Colonial Pipeline Company
1185 Sanctuary Parkway
Suite 100
Alpharetta, Georgia 30009
CPF No. 2-2021-005-NOPSO
Dear Mr. Blount:
Enclosed please find a Consent Order incorporating the terms of the Consent Agreement between
the Pipeline and Hazardous Materials Safety Administration (PHMSA) and Colonial Pipeline
Company which was executed on June 4, 2021. Service of the Consent Order and Consent
Agreement by electronic mail is deemed effective upon the date of transmission, or as otherwise
provided under 49 C.F.R. § 190.5.
Thank you for your cooperation in this matter.
Sincerely,
Alan K. Mayberry
Associate Administrator
for Pipeline Safety
Enclosure: Order and Consent Agreement
cc: Mr. James Urisko, Director, Southern Region, Office of Pipeline Safety, PHMSA
Mr. Mark Piazza, Manager, Pipeline Compliance and R&D, Colonial Pipeline Company
Ms. Catherine Little, Troutman Pepper, Counsel for Colonial Pipeline Company
CONFIRMATION OF RECEIPT REQUESTED



U.S. DEPARTMENT OF TRANSPORTATION
PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION
OFFICE OF PIPELINE SAFETY
WASHINGTON, D.C. 20590
____________________________________
In the Matter of
Colonial Pipeline Company,
)
)
)
)
)
Respondent.
)
____________________________________)
CPF No. 2-2021-005-NOPSO
CONSENT ORDER
By letter dated March 29, 2021, the Pipeline and Hazardous Materials Safety Administration,
Office of Pipeline Safety, issued a Notice of Proposed Safety Order (Notice) to Colonial Pipeline
Company (Colonial or Respondent).
In accordance with 49 C.F.R. § 190.239, the Notice alleged that conditions existed on
Respondent’s pipeline system that posed a pipeline integrity risk to public safety, property, or the
environment and that the conditions potentially exist throughout the Colonial Pipeline System.
The Notice proposed that Respondent take certain corrective measures to remedy the alleged
conditions and ensure that the public, property, and the environment are protected from the
potential risk.
On April 9, 2021, pursuant to 49 C.F.R. § 190.239(b)(2), Colonial responded to the Notice by
submitting a request for an informal consultation, whereupon the parties engaged in good-faith
discussions that resulted in the Consent Agreement attached to this Order that settles all of the
allegations in the Notice.
Accordingly, the Consent Agreement is hereby approved and incorporated by reference into this
Order. Colonial is hereby ordered to comply with the terms of the Consent Agreement, effective
immediately.
Pursuant to 49 U.S.C. 60101, et seq., failure to comply with this Consent Order may result in the
assessment of civil penalties as set forth in 49 C.F.R. § 190.223.
The terms and conditions of this Consent Order are effective upon service in accordance with 49
C.F.R. § 190.5.
June 15, 2021
___________________________________ __________________________
Alan K. Mayberry Date Issued
Associate Administrator
for Pipeline Safety



U.S. DEPARTMENT OF TRANSPORTATION
PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION
OFFICE OF PIPELINE SAFETY
WASHINGTON, D.C. 20590
____________________________________
In the Matter of )
Colonial Pipeline Company, )
)
)
)
Respondent. )
____________________________________)
CPF No. 2-2021-005-NOPSO
CONSENT AGREEMENT
On March 29, 2021, pursuant to 49 C.F.R. § 190.239, the Pipeline and Hazardous Materials
Safety Administration (PHMSA), Office of Pipeline Safety (OPS or Agency), issued a Notice of
Proposed Safety Order (Notice) to Colonial Pipeline Company (Colonial or Respondent). The
Notice alleged that conditions existed on Respondent’s pipeline system that posed a pipeline
integrity risk that could potentially affect public safety, property, or the environment and that the
conditions potentially exist throughout the Colonial Pipeline System.
Specifically, the Notice alleged that on August 14, 2020, a Colonial employee was notified by a
local resident of a possible leak in Colonial’s right-of-way (ROW), approximately 100 feet north
(downstream) of Huntersville-Concord Road in Huntersville, North Carolina. Upon inspection, a
Colonial employee confirmed a product release visible at the ground surface that was believed to
be gasoline (the Failure). The Colonial Control Center initiated a shutdown of its pipeline
facilities in the area (Lines 1 and 2). Colonial notified the National Response Center (NRC) of
the release (NRC Report No. 1284598) on August 14, 2020, reporting an estimated release
volume of 75 barrels of gasoline. On August 15, 2020, Colonial identified the leak source to be
Line 1 (gasoline service) and restarted Line 2 the same day.
Colonial determined the leak originated from under a Type A sleeve repair installed in 2004,
originally intended to reinforce and protect a shallow dent identified by an integrity assessment.
The pipeline was initially repaired on August 19, 2020, by installing a Type B pressure
containing sleeve over the prior Type A sleeve repair. Colonial restarted Line 1 on August 19,
2020, after initial repairs were completed. On September 13, 2020, Colonial submitted an initial
accident report (PHMSA Form 7000.1) to PHMSA that updated the estimated release volume to
6,490 barrels of gasoline. On November 10, 2020, Colonial cut out the Type B sleeve which
contained the failed section of pipe and additional sections of Line 1 on either side of the Type B
sleeve repair. The cut-out section of pipe was sent to an independent laboratory for metallurgical
analysis. The cut-out and welding of the replacement pipeline tie-in was witnessed by PHMSA.



Upon identification and confirmation of the release and potential soil contamination, Colonial
initiated monitoring and remediation efforts, which included installation of 167 wells (81
monitoring wells, 50 recovery wells, 11 hydraulic control wells, and 25 air sparge system wells)
between August 27, 2020 and January 16, 2021. The released gasoline penetrated the soil and
affected the ground water in the area.1
On February 1, 2021, Colonial submitted a supplemental report to PHMSA updating the
estimated release volume to 28,571 barrels (1.2 million gallons) of gasoline. Colonial’s
metallurgical analysis was received by PHMSA on March 19, 2021. The analysis identifies the
primary crack growth mechanism as corrosion fatigue. At this time, Colonial has not provided
any other supplemental 7000.1 reports to PHMSA regarding the estimated release volume due to
the Failure.
Colonial has experienced several other accidents that were not detected by its leak detection
system or by Colonial personnel. For example, on September 21, 2015, a reportable accident
occurred on Colonial's Line 4 hazardous liquid pipeline in Centreville, Virginia, resulting in the
release of approximately 95 barrels (4,000 gallons) of gasoline. Colonial was notified by the
Fairfax County Fire Marshall of a sheen on a retention pond in close proximity to Colonial’s
Line 4 ROW. The cause of the leak was determined to be a crack that formed in a shallow dent
on the bottom side of the pipe. In February 2016, Colonial experienced a failure in Gwinnett
County, Georgia, that was discovered by a second-party contractor. According to Colonial
documentation and reporting, the failure mode was fatigue cracks within an area where a dent
was present with significant corrosion (up to 35%) under a Type A sleeve with shrink sleeves on
the end that was installed in 2005. The final volume of release was reported to be approximately
14 barrels (588 gallons) of gasoline. On September 9, 2016, Colonial experienced a failure
outside of Pelham, Alabama. Colonial was made aware of the suspected release by local
governmental personnel. According to the final accident report dated May 6, 2019, Colonial
reported an estimated volume released of 7,370 barrels (309,540 gallons) of gasoline. The
failure mechanism was determined to be a crack in a buckle that formed due to inadequate
compaction following a prior maintenance project.
On April 9, 2021, Colonial responded to the Notice by timely submitting a request for an
informal consultation pursuant to 49 C.F.R. § 190.239(b)(2). An informal consultation was held
virtually on April 30, 2021.
As a result of the informal consultation, PHMSA and Colonial (collectively, the Parties) agreed
that settlement of this proceeding will avoid further administrative proceedings or litigation and
will serve the public interest by promoting safety and protection of the environment. Pursuant to
49 C.F.R. Part 190, and upon consent and agreement of Colonial and PHMSA, the Parties hereby
agree as follows:
1 See https://sr2448.colonialresponse.com/.



I. General Provisions
1. Respondent acknowledges that as the operator of the Colonial Pipeline System in
Texas, Louisiana, Mississippi, Alabama, Georgia, Tennessee, South Carolina, North Carolina,
Virginia, Maryland, Delaware, Pennsylvania, New Jersey, and New York, Respondent and its
Colonial Pipeline System are subject to the jurisdiction of the federal pipeline safety laws, 49
U.S.C. § 60101, et seq., and the regulations and administrative orders issued thereunder. For
purposes of this Consent Agreement (“Agreement”), Respondent acknowledges that it received
proper notice of PHMSA's action in this proceeding and that the Notice states claims upon which
relief may be granted pursuant to 49 U.S.C. § 60101, et seq., and the regulations and orders
issued thereunder.
2. After Colonial returns this signed Agreement to PHMSA, the Agency’s
representative will present it to the Associate Administrator for Pipeline Safety, recommending
that the Associate Administrator adopt the terms of this Agreement by issuing an administrative
order (Consent Order or Order) incorporating the terms of this Agreement. The terms of this
Agreement constitute an offer of settlement until accepted by the Associate Administrator. Once
accepted, the Associate Administrator will issue a Consent Order incorporating the terms of this
Agreement.
3. Respondent consents to the issuance of the Consent Order, and hereby waives any
further procedural requirements with respect to its issuance. Respondent waives all rights to
contest the adequacy of notice, or the validity of the Consent Order or this Agreement, including
all rights to administrative or judicial hearings or appeals, except as set forth herein.
4. This Agreement shall apply to and be binding upon PHMSA and Colonial, its
officers, directors, and employees, and its successors, assigns, or other entities or persons
otherwise bound by law. Respondent agrees to provide a copy of this Agreement and any
incorporated work plans and schedules to all of Colonial’s officers, employees, and agents whose
duties might reasonably include compliance with this Agreement.
5. This Agreement constitutes the final, complete, and exclusive agreement and
understanding between the Parties with respect to the settlement embodied in this Agreement.
The Parties acknowledge that there are no representations, agreements, or understandings relating
to settlement other than those expressly contained in this Agreement, except that the terms of this
Agreement may be construed by reference to the Notice.
6. Nothing in this Agreement affects or relieves Respondent of its responsibility to
comply with all applicable requirements of the federal pipeline safety laws, 49 U.S.C. § 60101, et
seq., and the regulations and orders issued thereunder. Nothing in this Agreement alters
PHMSA's right of access, entry, inspection, and information gathering or PHMSA's authority to
bring enforcement actions against Colonial pursuant to the federal pipeline safety laws, the
regulations and orders issued thereunder, or any other provision of federal or state law.
7. For all transfers of ownership or operating responsibility of Colonial’s pipeline
system which occur while this Agreement is in effect, Colonial will provide a copy of this
Agreement to the prospective transferee at least 30 days prior to such transfer. Colonial will



provide written notice of the transfer to the PHMSA Southern Region Director no later than 60
days after the transfer occurs.
8. This Agreement does not waive or modify any federal, state, or local laws or
regulations that are applicable to Respondent’s pipeline systems. This Agreement is not a permit,
or a modification of any permit, under any federal, state, or local laws or regulations. Colonial
remains responsible for achieving and maintaining compliance with all applicable federal, state,
and local laws, regulations, and permits. Respondent agrees that the activities to be performed
pursuant to the Work Plan may go beyond the minimum federal pipeline safety regulations.
9. This Agreement does not create rights in, or grant any cause of action to, any third
party not party to this Agreement. The U.S. Department of Transportation is not liable for any
injuries or damages to persons or property arising from acts or omissions of Respondent or its
officers, employees, or agents carrying out the work required by this Agreement. Colonial agrees
to hold harmless the U.S. Department of Transportation, its officers, employees, agents, and
representatives from any and all causes of action arising from any acts or omissions of
Respondent or its contractors in carrying out any work required by this Agreement.
10. This Agreement does not constitute a finding of violation of any federal law or
regulation and may not be used in any civil proceeding of any kind as evidence or proof of any
fact, fault or liability, or as evidence of a violation of any law, rule, regulation, or requirement,
except in a proceeding to enforce the provisions of this Agreement or in future PHMSA
enforcement actions. Respondent neither admits nor denies any allegation or conclusion in the
Notice or this Agreement and Order, but agrees, for purposes of this Agreement and Order, to
address the alleged risk condition by completing the terms of this Agreement.
11. Upon issuance of the Consent Order, the Parties agree to all terms in this
Agreement and its appendices, which are incorporated herein.
II. Definitions
12. The “Director” means the Director, Pipeline and Hazardous Materials Safety
Administration, Office of Pipeline Safety, Southern Region. The Director’s address is
230 Peachtree Street NW, Suite 2100, Atlanta, Georgia, 30303.
13. The “Failure” means the release of gasoline that occurred on Colonial’s Line 1 in
Huntersville, North Carolina, which Colonial reported to the NRC on August 14, 2020.
III. Corrective Measures
Colonial agrees to take the following corrective measures to address the alleged risk conditions
on the Colonial Pipeline System set forth in the Preliminary Findings of the Notice, as follows:
14. Remedial Work Plan. Within 120 days after the Consent Order is issued, develop
and submit to the Director for approval, a written remedial work plan (Work Plan or Plan) that
includes corrective measures. The Plan must include provisions to:



i. Evaluate the effectiveness and capability of Colonial’s leak detection
system on the entirety of the Colonial Pipeline System, including main lines, stub lines,
and delivery lines. At a minimum, Colonial’s evaluation must consider the following
factors—length and size of the pipeline, type of product carried, the swiftness of leak
detection, limitations on detectable quantities, location of nearest response personnel, and
leak history. This evaluation must also consider maximum operating pressure (MOP),
normal operating pressures, flow rates (or throughput), and impacts from any pressure
cycles or operational changes. For mainline segments that could affect high consequence
areas (HCAs), Colonial’s evaluation must consider the pipeline’s proximity to the HCA
and risk assessment results.
ii. Based on the findings of the evaluation pursuant to paragraph i of this
Item, determine corrective measures to improve the effectiveness of Colonial’s leak
detection system. The corrective measures must result in improving the capability of the
leak detection system to detect leaks that could potentially affect public safety, property,
or the environment, similar to (but not limited to) leaks with characteristics common to
those referenced above.
iii. Evaluate Colonial’s written plans and procedures for inspection and
maintenance that address leak detection, ROW inspection and repairs and determine the
extent to which the written plans contribute to the elimination of hazardous leaks. Based
on the findings, determine appropriate amendments to improve the extent to which the
plans contribute to the elimination of hazardous leaks.
iv. Evaluate the effectiveness of Colonial’s ROW inspection program as it
pertains to leak detection. This evaluation must consider any geographic regions or
features (i.e., HCAs and other sensitive areas) that may require specific or additional
means of patrol. Based on the findings, determine corrective measures to improve the
effectiveness of Colonial’s ROW inspection program relative to leak detection.
v. Provide to the Director an inventory of all Type A sleeve repairs made on
the Colonial Pipeline System. For each identified Type A sleeve, the inventory must
include the most accurate information regarding, at a minimum, the installation date, a
summary of the basis for the original application (i.e., remediated condition), and
identification of any scheduled follow-up actions.
vi. Establish a program and requirements for classifying all future repairs as
temporary or permanent. The Plan must establish timeframes for the removal of any
repair identified as “temporary,” or the permanent remediation of the condition requiring
repair. If such designations and timeframes have been incorporated in to its programs,
Colonial must submit documentation confirming the temporal disposition for repair
methods deemed acceptable for all line pipe.
15. Third-party facilitator. Paragraphs i through iv of the Work Plan must be
facilitated by an independent third-party approved by the Director. Documentation from the
third-party facilitator must be included in each required submission to the Director.



16. Schedule. The Plan must include a proposed timeline for completion of
implementation of the corrective measures identified by Item 14.i – 14.vi of the Agreement.
17. Submissions of procedures. Submit to the Director all written procedures, new or
amended, that will be used to complete the requirements of the Work Plan.
18. Quarterly reports. Submit quarterly reports to the Director that: (1) include
available data and evaluations conducted pursuant to the Work Plan; and (2) describe the
progress of the remedial measures being undertaken. The first quarterly report shall be due 90
days from the date of the approval of the Work Plan, and thereafter on the 15th day of the last
month of the calendar quarter.
19. Consent Agreement Documentation Report (CADR). When Colonial has
completed all the items in this Agreement, it will submit a final CADR to the Director. This will
allow the Director to conduct a thorough review of all measures identified by Colonial with
regards to this Agreement prior to approving the closure of this Agreement. The intent is for the
CADR to summarize all activities and documentation associated with this Agreement in one
document. The CADR must include, but is not limited to:
i. Table of contents;
ii. Summary of the Failure, its root cause, and response activities;
iii. Summary of all inspections, assessments, evaluations, and analysis
required by this Agreement, including those conducted by the third-party
facilitator;
iv. Summary of all metallurgical testing and/or metallurgical analysis related
to the Failure;
v. Documentation of all corrective measures taken by Colonial to implement
the Work Plan, and the results of those corrective measures;
vi. Documentation of any revisions to the Work Plan; and
vii. Lessons learned while completing the Work Plan.
20. Documentation of costs. It is requested that Colonial maintain documentation of
the safety improvement costs associated with fulfilling this Agreement and submit the total to the
Director, Southern Region, Pipeline and Hazardous Materials Safety Administration. It is
requested that these costs be reported in two categories: 1) total cost associated with
preparation/revision of plans, procedures, studies, and analyses; and 2) total cost associated with
replacements, additions and other changes to pipeline infrastructure.



IV. Implementation, Review, and Approval Process:
21. Respondent agrees to complete the Work Plan in accordance with the schedules
set forth therein as it is approved by the Director, including revisions to the Plan. Results of
measures taken in accordance with the approved Plan must be available for review by PHMSA
or its representative.
22. With respect to any submission by the Respondent under the Work Plan that
requires the approval of the Director, the Director may: (1) approve the submission, in whole or
in part; (2) disapprove the submission on specified conditions; (3) disapprove the submission, in
whole or in part; or (4) undertake any combination of the foregoing. In the event of approval in
whole, in part, or upon conditions, Colonial will proceed to take all actions required by the
submission as modified by the Director. In the event the Director does not approve all or any
portion of a submission, the Director will provide Colonial with a written notice of the
deficiencies. Respondent will correct all deficiencies within the time specified by the Director
and resubmit it for approval.
23. All submittals required by the Work Plan that include decisions and
determinations must also describe the options and factors considered by Colonial.
24. Respondent agrees to revise the Work Plan as necessary to incorporate new
information obtained during the activities performed under the Work Plan. Respondent shall
submit any such plan revisions to the Director for prior approval.
25. The Director may grant an extension of time for completion of any of the work to
be performed under the Agreement or the Work Plan upon Respondent’s timely, written request
that demonstrates both good cause for an extension and provides sufficient detail to enable the
Director to evaluate Respondent’s request. The Director shall respond in writing to any such
request.
26. After receiving and analyzing additional data in the course of this proceeding and
implementation of the Work Plan, PHMSA may identify other safety measures that need to be
taken. In that event, Respondent will be notified in writing of any proposed additional measures
and, if necessary, amendments to the Work Plan.
V. Enforcement
27. This Agreement, including all elements of the incorporated Work Plan, is subject
to all enforcement authorities available to PHMSA under 49 U.S.C. § 60101, et seq., and
49 C.F.R. Part 190, including administrative civil penalties under 49 U.S.C. § 60122, of up to
$200,000 (as adjusted) per violation for each day the violation continues and referral of the case
to the Attorney General for judicial enforcement, if PHMSA determines that Respondent is not
complying with the terms of this Agreement in accordance with determinations made by the
Director, or if appealed, in accordance with decisions of the Associate Administrator. The
maximum civil penalty amounts are adjusted annually for inflation. See 49 C.F.R. § 190.233.



VI. Dispute Resolution
28. The Director and Colonial will informally attempt to resolve any disputes arising
under this Agreement, including, but not limited to, any decision of the Director. If Colonial and
the Director are unable to informally resolve the dispute within 15 calendar days after the dispute
is first raised in writing, Colonial may submit a written request for a determination resolving the
dispute from the Associate Administrator for Pipeline Safety. The written request for a
determination must be provided to the Director, counsel for the Southern Region, and to the
Associate Administrator no later than 10 calendar days after the 15-day deadline for informal
resolution referenced in this paragraph. Along with its request, Colonial must provide the
Associate Administrator with all information Colonial believes is relevant to the dispute.
Determinations of the Associate Administrator under this paragraph constitute final Agency
action. The existence of a dispute and PHMSA’s consideration of matters placed in dispute, will
not excuse, toll, or suspend any term or timeframe for completion of any work to be performed
under this Agreement during the pendency of the dispute resolution process, except as agreed
upon by the Director or Associate Administrator in writing.
VII. Recordkeeping and Information Disclosure
29. Unless otherwise required in this Agreement, Respondent agrees to maintain
records demonstrating compliance with all requirements of this Agreement for a period of at
least 5 years following completion of all work to be performed. For any reports, plans, or other
deliverables required to be submitted to PHMSA pursuant to this Agreement, Respondent may
assert a claim of business confidentiality or other protections applicable to the release of
information by PHMSA, covering part or all of the information required to be submitted to
PHMSA pursuant to this Agreement in accordance with 49 C.F.R. Part 7. Respondent must
mark the claim of confidentiality in writing on each page, and include a statement specifying the
grounds for each claim of confidentially. PHMSA will determine the release of any information
submitted pursuant to this Agreement in accordance with 49 C.F.R. Part 7, the Freedom of
Information Act, 5 U.S.C. § 552, DOT and PHMSA policies, and other applicable regulations
and Executive Orders.
VIII. Effective Date
30. The term “Effective Date,” as used herein, is the date on which the Consent Order
is issued by the Associate Administrator, PHMSA, incorporating the terms of this Agreement.
IX. Modification
31. The terms of this Agreement may be modified by mutual agreement of the Parties.
Such modifications must be in writing and signed by both parties.



X. Termination
32. This Agreement will terminate upon submission, approval where specified, and
completion of the deliverables set forth in the Work Plan.
XI. Ratification
33. The Parties’ undersigned representatives certify that they are fully authorized to
enter into the terms and conditions of this Agreement and to execute and legally bind such party
to this document.
34. The Parties hereby agree to all conditions and terms of this Agreement.
For Colonial Pipeline Company:
________________________
Wes Dunbar
Vice President of Operations
________________________
Date
For PHMSA:
_________________________
James Urisko
Director, Southern Region
Date

22021005NOPSO_Closure Letter_08252025_(20-188854)_text.pdf

VIA ELECTRONIC MAIL TO: mlittle@colpipe.com; qfrazier@colpipe.com;
dlangley@colpipe.com
August 25, 2025
Ms. Melanie Little
President, Chief Executive Officer
Colonial Pipeline Company
1000 Lake Street
Alpharetta, GA 30009
RE: CPF 2-2021-005-NOPSO
Dear Ms. Little:
On March 29, 2021, the Pipeline and Hazardous Materials Safety Administration (PHMSA)
issued to Colonial Pipeline Company (Colonial), a Notice of Proposed Safety Order. On
June 4, 2021, PHMSA and Colonial entered into a Consent Agreement and Order. This Order
included a requirement for Colonial to implement system-wide corrective actions, with regular
submittals for review and approval. Based on PHMSA’s review of the documentation provided it
has been determined that Colonial has complied with the terms of the Order.
Accordingly, this case is now closed, and no further action is anticipated with respect to the
matters involved in this case. Thank you for your cooperation in this matter.
Sincerely,
James A. Urisko
Regional Director, Southern Region, Office of Pipeline Safety
Pipeline and Hazardous Materials Safety Administration

22021005NOPSO_Notice of Proposed Safety Order_03292021_(20-188854)_text.pdf

VIA ELECTRONIC MAIL TO: jblount@colpipe.com; mpiazza@colpipe.com
March 29, 2021
Mr. Joseph Blount
President, Chief Executive Officer
Colonial Pipeline Company
1185 Sanctuary Parkway
Suite 100
Alpharetta, GA 30009-4765
CPF No. 2-2021-005-NOPSO
Dear Mr. Blount:
Enclosed is a Notice of Proposed Safety Order (Notice) issued in the above-referenced case.
The Notice proposes that Colonial Pipeline Company take certain measures with respect to the
Colonial Pipeline System to ensure pipeline safety. Your options for responding are set forth in
the Notice. Service of this Notice by electronic mail is deemed effective upon the date of
transmission, or as otherwise provided under 49 C.F.R. § 190.5.
We look forward to a successful resolution to ensure pipeline safety. Please direct any
questions on this matter to me at (404) 832-1150.
Sincerely,
James Urisko
Director, Southern Region
Pipeline and Hazardous Materials Safety Administration
Enclosure: Notice of Proposed Safety Order
Copy of 49 C.F.R. § 190.239
Cc: Ms. Linda Daugherty, Deputy Associate Administrator for Field Operations, OPS
Mr. Mark Piazza, Manager, Pipeline Compliance and R&D, Colonial Pipeline Company



DEPARTMENT OF TRANSPORTATION
PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION
OFFICE OF PIPELINE SAFETY
SOUTHERN REGION
ATLANTA, GEORGIA
____________________________________
In the Matter of
Colonial Pipeline Company,
Respondent
)
)
)
)
)
____________________________________)
CPF No. 2-2021-005-NOPSO
NOTICE OF PROPOSED SAFETY ORDER
Introduction and Purpose
This Notice of Proposed Safety Order (NOPSO or Notice) is being issued by the Pipeline and
Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), under
the authority of 49 U.S.C. § 60117. Pursuant to § 60117, PHMSA initiated an investigation of
the safety of Colonial Pipeline Company’s (Colonial or the company) Pipeline System following
a gasoline release in Huntersville, North Carolina on August 14, 2020 (Failure).1
PHMSA’s ongoing investigation indicates that conditions may exist on the Colonial Pipeline
System that pose a pipeline integrity risk to public safety, property or the environment. The
conditions that led to the Failure potentially exist throughout the Colonial Pipeline System.
Further, Colonial’s inability to effectively detect and respond to this release, as well as other past
releases, has potentially exacerbated the impacts of this and numerous other failures over the
operational history of Colonial’s entire system. After evaluating the preliminary findings of fact
described below and considering the characteristics of the Colonial Pipeline System, as well as
the failure history of that system, it appears that the continued operation of the Colonial Pipeline
System without corrective measures would pose a pipeline integrity risk to public safety,
property, or the environment.
This NOPSO notifies Colonial of the preliminary findings of the investigation, and proposes that
Colonial take measures to ensure that the public, property, and the environment are protected
from the potential risk.
1 Colonial became aware of the release on August 14, 2020, however, the first day of the release is unknown.



2
Background
On August 14, 2020 at 18:20 ET, a Colonial employee was notified by a local resident of a
possible leak in Colonial’s right-of-way (ROW), approximately 100 feet north (downstream) of
Huntersville-Concord Road in Huntersville, North Carolina. Upon inspection, a Colonial
employee confirmed a product release visible at the ground surface at 18:42 ET near
Mile Marker 980 that was believed to be gasoline. The Colonial Control Center initiated a
shutdown of its pipeline facilities in the area (Lines 1 and 2) at 18:43 ET. The lines were
blocked by closing valves upstream of the release location at Colonial's Charlotte Delivery
Facility and downstream of the release location at the Kannapolis Station.
At 19:42 ET, Colonial notified the National Response Center (NRC) of the release (NRC Report
No. 1284598). Colonial reported the estimated release amount was 75 barrels. Colonial also
notified the Charlotte-Mecklenburg Emergency Management Office, the U.S. Environmental
Protection Agency, the North Carolina Department of Environmental Quality, and PHMSA.
Colonial identified the leak source to be Line 1 on August 15, 2020 at approximately 12:00 ET.
Following confirmation of the leak source, Colonial restarted Line 2 at 12:05 ET the same day.
Colonial determined the leak originated from a Type A sleeve repair installed in 2004, originally
intended to reinforce and protect a shallow dent identified by an integrity assessment. The leak
was repaired on August 19, 2020, by installing a Type B pressure containing sleeve over the
prior Type A sleeve repair. Colonial restarted Line 1 on August 19, 2020 at approximately
21:00 ET after repairs were completed.
On September 13, 2020, Colonial submitted an initial accident report (PHMSA Form 7000.1) to
PHMSA that updated the estimated release volume to 6,490 barrels of gasoline. On November
10, 2020, Colonial cut out the Type B sleeve and the failed section of pipe and sent them to an
independent laboratory for metallurgical analysis. The cut-out and welding of the replacement
pipeline tie-in was witnessed by PHMSA. On February 1, 2021, Colonial submitted a
supplemental report to PHMSA updating the estimated release volume to 28,571 barrels (1.2
million gallons) of gasoline. Colonial has not provided any other reports to PHMSA regarding
the estimated release volume due to the Failure.
Upon identification and confirmation of the release and potential soil contamination, Colonial
initiated monitoring and remediation efforts which are ongoing as of the issuance of this Notice.
The preliminary findings of the PHMSA’s ongoing investigation are as follows:
Preliminary Findings:
• The Colonial Pipeline System consists of approximately 5,500 miles of hazardous liquid
transmission pipeline within the United States, including lateral and spur lines, and fixed
facilities (tanks, pump stations, etc.). The system traverses the states of Texas, Louisiana,
Mississippi, Alabama, Georgia, North Carolina, South Carolina, Virginia, Maryland,
Pennsylvania, New Jersey, and New York. Branches from the main lines also extend



3
into Tennessee. The system delivers an average of approximately 100 million gallons of
liquid petroleum products throughout the southern and eastern United States per day.
• Colonial’s Line 1 Pipeline is an interstate pipeline, traversing eight states, beginning in
Texas and ending in Virginia. The Line 1 portion of PHMSA inspection Unit NC-1
(Charlotte) is approximately 80 miles long, with three pump stations and as many as 25
breakout tanks. In North Carolina, Line 1 traverses five counties: Cabarrus, Cleveland,
Gaston, Rowan, and Mecklenburg.
• The Line 1 Pipeline is 40-inches in diameter with a 0.312-inch wall thickness, is API 5L
X-60 grade, has a coal tar coating, a DSAW seam, and was manufactured in 1978 by
Bethlehem Steel. It has an impressed current cathodic protection system. It transports
refined products, including gasoline. The MOP is 673 psig. At the estimated time of
failure, the operating pressure was 183 psig.
• The Failure occurred on Line 1 in the Oehler Nature Preserve, near the intersection of
Huntersville-Concord Road and Asbury Chapel Road, east of the Town of Huntersville,
in Mecklenburg County, North Carolina. The Failure and resulting release was identified
by local residents with access to Colonial’s ROW.
• Colonial initially submitted an NRC Report (Incident Report 1284598,
dated August 14, 2020) and reported an estimate of 75 barrels due to “equipment failure.”
• Following confirmation of the release on August 14, 2020, Colonial submitted an initial
accident report (PHMSA Form 7000.1) dated September 13, 2020, and reported an
estimated release volume of 6,490 barrels. Colonial submitted a supplemental report on
September 14, 2020, updating the total cost estimates with no change to estimated release
volume. A second supplemental report was submitted on February 1, 2021, updating the
estimated release volume to 28,571 barrels. Colonial has not provided any other reports
to PHMSA regarding the estimated release volume due to the Failure.
• The released gasoline penetrated the soil and affected the ground water in the area.2
Colonial installed 167 wells (81 monitoring wells, 50 recovery wells, 11 hydraulic
control, and 25 air sparge system wells) between August 27, 2020 and
December 23, 2020.
• Preliminary findings confirmed the presence of the above-referenced Type A sleeve, the
original anomaly (shallow dent), a through-wall crack that developed in the anomaly, and
an electrolyte (water). Colonial’s metallurgical analysis was received by PHMSA on
March 19, 2021. The analysis identifies the primary crack growth mechanism as
corrosion fatigue.
• PHMSA is aware that Colonial has made other repairs using Type A sleeves across the
Colonial Pipeline System, and has implemented an ongoing Type A sleeve remediation
2 See https://sr2448.colonialresponse.com/.



4
program intended to remove or replace existing Type A sleeves via an alternate repair
method (i.e., Type B sleeve or pipe replacement).
• The leak detection system used on the Colonial Pipeline System consists of a line-balance
approach to track volumes transported, with regular reporting between field stations and
Colonial’s control room in Alpharetta, Georgia. The process is predominantly manual,
with a defined tolerance for any potential imbalance (i.e., discrepancy between stations).
Colonial employs computational pipeline monitoring (CPM) on portions of the system,
but not on Line 1.
• On September 21, 2015, a reportable accident occurred on Colonial's Line 4 hazardous
liquid pipeline in Centreville, Virginia, resulting in the release of approximately
95 barrels (4,000 gallons) of gasoline. Colonial was notified by the Fairfax County Fire
Marshall of a sheen on a retention pond along Colonial’s Line 4 ROW. Line 4 is a
continuation of Colonial’s Line 1. The accident occurred on a 288-mile section of Line 4
that runs between the company's Greensboro Tank Farm in Greensboro, North Carolina,
and th
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