# NIAGARA MOHAWK POWER CORP — Notice of Probable Violation

- **operation:** document
- **citation:** CPF 120183005
- **title:** NIAGARA MOHAWK POWER CORP — Notice of Probable Violation
- **source type:** enforcement
- **agency:** Pipeline and Hazardous Materials Safety Administration
- **status:** historical
- **official:** true
- **published on:** 2018-06-12
- **effective on:** Not available
- **summary:** CLOSED notice of probable violation citing 193.2635(d).
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- **source url:** https://primis.phmsa.dot.gov/enforcement-data/case/120183005
**body:**

Notice of Probable Violation involving NIAGARA MOHAWK POWER CORP. PHMSA's enforcement data identifies the cited regulation as 193.2635(d). The case was opened on 2018-06-12 and is reported as closed as of 2020-02-24. Proposed civil penalty: $46,700. Assessed civil penalty: $0. Open the official case record for notices, responses, orders, and the latest status.

Official case documents:

120183005_Final Order_02242020.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Final%20Order_02242020.pdf

120183005_Final Order_02242020_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Final%20Order_02242020_text.pdf

120183005_Hearing_Scheduled_10092018.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Hearing_Scheduled_10092018.pdf

120183005_NOPV PCP PCO_06122018.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_NOPV%20PCP%20PCO_06122018.pdf

120183005_NOPV PCP PCO_06122018_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_NOPV%20PCP%20PCO_06122018_text.pdf

120183005_Operator Post Hearing Submission_01112019.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Operator%20Post%20Hearing%20Submission_01112019.pdf

120183005_Operator Response Notice and Request for Hearing_07102018.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Operator%20Response%20Notice%20and%20Request%20for%20Hearing_07102018.pdf

120183005_Operator Response to Notice and Request for Hearing_07102018.pdf: https://primis.phmsa.dot.gov/enforcement-documents/120183005/120183005_Operator%20Response%20to%20Notice%20and%20Request%20for%20Hearing_07102018.pdf

120183005_Final Order_02242020_text.pdf

February 24, 2020
Mr. John Pettigrew
Chief Executive Officer
National Grid, PLC
1-3 Strand
London WC2N 5EH, United Kingdom
Re: CPF No. 1-2018-3005
Dear Mr. Pettigrew:
Enclosed please find the Final Order issued in the above-referenced case. It withdraws the
allegation in the Notice of Probable Violation issued on June 12, 2018. Accordingly, this case is
now closed. Service of the Final Order by certified mail is effective upon the date of mailing as
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
cc: Mr. Robert Burrough, Director, Eastern Region, Office of Pipeline Safety, PHMSA
Mr. Ross Turrini, Senior Vice President, Gas Process and Engineering, National Grid,
PLC, 40 Sylvan Road, Waltham, Massachusetts 02451
Mr. David C. Lodemore, Esq., Senior Counsel, National Grid, PLC, 40 Sylvan Road,
Waltham, Massachusetts 02451
CERTIFIED MAIL - RETURN 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 )
Niagara Mohawk Power Corporation, ) CPF No. 1-2018-3005
a subsidiary of National Grid, PLC, )
)
)
)
Respondent. )
____________________________________)
FINAL ORDER
From August 29-31, 2017, pursuant to 49 U.S.C. § 60117, a representative of the Pipeline and
Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS),
conducted an on-site pipeline safety inspection of the Providence LNG Plant facilities and
records of Niagara Mohawk Power Corporation (Niagara or Respondent), in Providence, Rhode
Island. Niagara is a subsidiary of National Grid, PLC, which engages in the transmission and
distribution of gas and electricity in several northeastern states including New York,
Massachusetts, and Rhode Island. The Providence LNG Plant is a storage and peak shaving
facility that began service in 1974 with a tank capacity of 600,000 bbl. of LNG.1
As a result of the inspection, the Director, Eastern Region, OPS (Director), issued to Respondent,
by letter dated June 12, 2018, a Notice of Probable Violation, Proposed Civil Penalty, and
Proposed Compliance Order (Notice). In accordance with 49 C.F.R. § 190.207, the Notice
proposed finding that Niagara had violated 49 C.F.R. § 193.2635(d) and proposed assessing a
civil penalty of $46,700 for the alleged violation. The Notice also proposed ordering Respondent
to take certain measures to correct the alleged violation.
Niagara responded to the Notice by letter dated July 10, 2018 (Response). Niagara contested the
allegation and requested a hearing. A hearing was subsequently held on December 12, 2018, in
West Trenton, New Jersey before a Presiding Official from PHMSA’s Office of Chief Counsel.
At the hearing, Respondent was represented by counsel. Respondent provided additional written
materials prior to the hearing on December 3, 2018 (Pre-hearing submission), and following the
hearing on January 11, 2019 (Post-hearing submission). The Director submitted a region
recommendation on April 8, 2019 (Recommendation), and Respondent submitted a reply to the
region recommendation on April 19, 2019 (Reply).
1 Pipeline Safety Violation Report (Violation Report), (June 12, 2018) (on file with PHMSA), at 1.



CPF No. 1-2018-3005
Page 2
WITHDRAWAL OF ALLEGATION
The Notice alleged that Respondent violated 49 C.F.R. Part 193, as follows:
Item 1: The Notice alleged that Respondent violated 49 C.F.R. § 193.2635(d), which states:
§ 193.2635 Monitoring corrosion control.
Corrosion protection provided as required by this subpart must be
periodically monitored to give early recognition of ineffective corrosion
protection, including the following, as applicable:
(a)…
(d) Each component that is protected from atmospheric corrosion must
be inspected at intervals not exceeding 3 years.
The Notice alleged that Respondent violated 49 C.F.R. § 193.2635(d) by failing to inspect each
component that is protected from atmospheric corrosion at intervals not exceeding three years.
Specifically, the Notice alleged that Niagara failed to inspect insulated piping for the glycol
system and three insulated vaporizers for atmospheric corrosion at its Providence LNG Plant for
the 2014 to 2017 period.
In its Response and at the hearing, Niagara contested the allegation. Niagara argued that while
the facility piping was generally subject to the three-year atmospheric corrosion inspection
requirement, the regulation did not expressly require the piping that was covered by thermal
insulation to be inspected. Niagara pointed out that the atmospheric corrosion inspection
provisions for natural gas pipelines in 49 CFR Part 192 (§ 192.481) and for hazardous liquid
pipelines in 49 CFR Part 195 (§ 195.583) both expressly require inspecting under thermal
insulation, but the cited regulation in Part 193 for LNG facilities does not. Respondent believes
this may have been a purposeful omission. Respondent cited United States v. Approximately
64,695 Pounds of Shark Fins to argue that it was reasonable to presume that PHMSA acted
intentionally when the agency did not include an express requirement to inspect LNG facility
piping under insulation in § 193.2635(d).2
In response to this argument, OPS explained that Niagara’s comparison of the pipeline
regulations in Parts 192 and 195 to the LNG facility regulations in Part 193 failed to observe a
key distinction. Both §§ 192.481 and 195.583 are distinguishable from § 193.2635 because they
concern pipelines that are “exposed to the atmosphere,” whereas § 193.2635 contemplates
inspection of “each component that is protected from atmospheric corrosion.” OPS argued that
this distinction reflects the differences in the types of facilities being regulated. LNG is natural
gas that has been cooled to a liquid state, at or below -260º F. LNG facility piping is almost
always protected with insulation or jacketing to protect the pipe from atmospheric corrosion, to
prevent heat transfer due to the ambient temperature being hundreds of degrees higher, and to
protect the people working in the facility from cryogenic temperatures. In comparison to the
treatment of insulation by the Part 192 and 195 code drafters, the Part 193 code drafters would
2 520 F. 3d 976, 983 (9th Cir. 2008).



CPF No. 1-2018-3005
Page 3
have been well aware that LNG facility piping was generally insulated requiring removal for
visual inspection of the protected piping.3 OPS is correct that it follows from the Part 193
language that the material to be inspected is the protected material, even if it is underneath
insulation or jacketing. Moreover, there is no rationale for the proposition that insulated LNG
piping should receive lesser inspections than aboveground natural gas and hazardous liquid pipes
that are insulated.
Niagara further argued that it had not received “fair notice” of PHMSA’s application of
§ 193.2635(d).4 Niagara noted that in contrast to PHMSA’s approach under Parts 192 and 195, it
made no compliance guidance on atmospheric corrosion inspections under Part 193 available to
operators.5 In response, OPS noted that the DC Circuit stated in General Electric Company v.
US EPA that where a party argues that an agency is providing notice of interpretation through an
enforcement action, the relevant question is, “whether the regulated party received, or should
have received notice of the agency’s interpretation in the most obvious way of all: by reading the
regulations.”6
Having considered these arguments, I find that PHMSA did provide such notice to LNG
operators. The regulation states:
(d) Each component that is protected from atmospheric corrosion must
be inspected at intervals not exceeding 3 years.
Component is defined by § 193.2007, to include:
“any part, or system of parts functioning as a unit, including, but not limited
to, piping, processing equipment, containers, control devices, impounding
systems, lighting, security devices, fire control equipment, and
communication equipment, whose integrity or reliability is necessary to
maintain safety in controlling, processing, or containing a hazardous fluid.”
Thus, the regulation itself provides fair notice that operators must inspect each component that is
protected from atmospheric corrosion at intervals not exceeding three years. Niagara
acknowledged that its asbestos insulation and aluminum jacketing served as thermal insulation
and protection against atmospheric corrosion.7 Insulation is not a component protected from
atmospheric corrosion. Rather, insulation protects the component in question from atmospheric
corrosion. To comply with § 193.2635(d), an operator must “inspect” the component being
3 OPS also pointed out that in Shark Fins, the court analyzed subsections within the same regulation, specifically 50
CFR § 600.1204(b) and (c). Conversely, the LNG regulation § 193.2635 is in a completely different Part of title 49
from the parts dealing with natural gas and hazardous liquid pipelines, Parts 192 and 195.
4 Post-hearing submission, at 3.
5 Post-hearing submission, at 6.
6 53 F. 3d 1324, 1329 (D.C. Cir. 1995).
7 Pre-hearing submission, at 3.



CPF No. 1-2018-3005
Page 4
protected. While non-destructive examination methods can be utilized, if visual inspection is the
method of inspecting the exterior surface of a component for atmospheric corrosion, the
requirement to inspect these components requires operators to actually look at the condition of
the component being protected from atmospheric corrosion which by definition would involve
visual inspection of enough of the pipe surface under the insulation to confirm the absence of
atmospheric corrosion. In this case, Niagara was required to visually inspect enough of the
glycol system piping and the vaporizers that were protected by asbestos insulation and aluminum
jacketing to confirm the absence of atmospheric corrosion.8
Niagara then argued in the alternative that even if § 193.2635(d) does require the operator of an
LNG facility to inspect under thermal insulation, certain activities that it conducted at the
Providence LNG Plant during the relevant period should be considered to have satisfied any such
requirement.9 Niagara explained that the facility had an ongoing program of replacing the
asbestos insulation with polycarbonate insulation whenever the asbestos insulation was found to
be in a deleterious condition. Niagara stated that atmospheric corrosion inspections were
performed on the pipe surface exposed by the removal of the old asbestos insulation during this
insulation replacement program. During the hearing, Niagara provided photos of portions of the
glycol system and vaporizers with insulation removed demonstrating that the pipe surface was
inspected. Niagara further explained that these visual atmospheric corrosion inspections were
supplemented with ultrasonic readings of the 8-inch glycol pipe and other sections of piping.10
OPS conceded that it may be possible to “conduct atmospheric corrosion inspections and achieve
compliance with § 193.2635(d) during the performance of other field activities.”11 However,
OPS maintained that although deteriorated insulation could be a factor to consider for
prioritizing locations for atmospheric corrosion inspection, none of the 2014, 2015, 2016, or
2017 asbestos insulation removal locations were identified in Niagara’s records as locations that
corresponded to a risk-based assessment of the portions of the glycol lines or vaporizers with the
greatest risk of atmospheric corrosion.
The issue to be determined in this case is whether the regulation at issue allowed Niagara to
conduct its atmospheric corrosions in the manner described. Under § 193.2635(d), an LNG
facility operator has wide latitude in developing the procedures by which its atmospheric
corrosion inspections will be conducted. The regulations permit an operator to determine the
appropriate manner of inspection for its particular facility so long as the procedures account for
the presence of piping that is not visually accessible such as insulated piping. For example,
operators that utilize visual inspection as the primary method can establish procedures for
8 In a highly similar case from 2012, for example, PHMSA alleged that Transco, an LNG operator, failed to inspect
any pipe under the thermal insulation on its steel piping during atmospheric corrosion surveys. The operator was
found to have violated § 193.2635(d), ordered to pay a civil penalty of $48,400, and ordered to comply with
compliance terms. In the Matter of Transcontinental Gas Pipe Line Company, LLC, CPF No. 1-2012-3002, Final
Order, 2012 WL 6892766 (D.O.T., Oct. 26, 2012).
9 Post-hearing submission, at 8-12.
10 Reply, at 2.
11 Region recommendation, at 6.



CPF No. 1-2018-3005
Page 5
removing select portions of the insulation or clamps or developing a program whereby visual
inspections occur in predetermined critical inspection locations by creating inspection ports.
They can also supplement visual inspections with non-destructive methods such as ultrasonic or
radiographic testing.
OPS is correct that Respondent did not utilize a rigorous risk-based approach for planning and
conducting its atmospheric corrosion inspections on the insulated piping and that its written
procedures in this area were not ideal. Respondent correctly pointed out, however, that the
regulation does not require a risk-based atmospheric corrosion inspection program. Niagara
reasoned that the areas it did visually inspect where the insulation had deteriorated would tend to
correspond to the higher risk areas for atmospheric corrosion.12 Moreover, in this case the sheer
extent of Niagara’s insulation replacement program resulted in hundreds of linear feet of the
insulation on piping being replaced and hundreds of square feet of insulation on the vaporizers
being replaced during the 2014 to 2017 period. As a result, Respondent may well have inspected
a greater amount of the pipe surface under the insulation at its facility than an operator that has
pre-designated its inspection locations typically inspects. While Niagara would be well advised
to clarify and enhance its atmospheric corrosion inspection procedures, in this case OPS did not
establish that the inspections under the insulation that Respondent did conduct were so
inadequate that they constituted non-compliance with the minimum requirements in the
regulation.
Based upon the foregoing, I hereby order that this allegation be withdrawn.
COMPLIANCE ORDER
The Notice proposed a compliance order with respect to the alleged violation of 49 C.F.R. §
193.2635(d). Because the allegation has been withdrawn, the compliance terms are also
withdrawn.
The terms and conditions of this Final Order are effective upon service in accordance with 49
C.F.R. § 190.5.
February 24, 2020
___________________________________ __________________________
Alan K. Mayberry Date Issued
Associate Administrator
for Pipeline Safety
12 Reply, at 4.

120183005_NOPV PCP PCO_06122018_text.pdf

NOTICE OF PROBABLE VIOLATION
PROPOSED CIVIL PENALTY
and
PROPOSED COMPLIANCE ORDER
OVERNIGHT EXPRESS DELIVERY
June 12, 2018
Mr. Ross Turrini
SVP, Gas Process and Engineering
Niagara Mohawk Power Corp.
25 Hub Drive
Melville, NY 11747
CPF 1-2018-3005
Dear Mr. Turrini:
From August 29-31, 2017, a representative of the Pipeline and Hazardous Materials Safety
Administration (PHMSA), Office of Pipeline Safety, pursuant to Chapter 601 of 49 United States
Code (U.S.C.), inspected Niagara Mohawk Power Corporation (Niagara)’s LNG Plant in
Providence, Rhode Island. Niagara is a subsidiary of National Grid plc.
As a result of the inspection, it is alleged that you have committed a probable violation of the
Pipeline Safety Regulations, Title 49, Code of Federal Regulations (CFR). The items inspected
and the probable violation is:
1. § 193.2635 Monitoring corrosion control.
(d) Each component that is protected from atmospheric corrosion must be inspected
at intervals not exceeding 3 years.
Niagara failed to inspect each component that is protected from atmospheric corrosion (AC) at
intervals not exceeding 3 years. Specifically, Niagara failed to conduct effective AC inspections
for the insulated glycol system and three insulated vaporizers at its Providence LNG Plant during
the timeframe of 2014 to 2017.



CPF 1-2018-3005
During the inspection, the PHMSA inspector reviewed Niagara’s LNG Plant, Plant Atmospheric
Corrosion Inspection, 17.PR-M5 Rev 9 (Procedure), and its 2014-2017 records of AC inspections.
The PHMSA inspector performed a field review of the LNG Plant and identified insulation barriers
that prevented access to the majority of the glycol system and three vaporizers. The glycol system
consisted of 1,650 feet of 8-inch pipe. Inspecting these carbon steel components required
specialized preparation or expanded effort to access and evaluate them for evidence of AC.
Niagara’s Procedure failed to provide a pathway for the inspection of carbon steel components
under thermal insulation. Further review of the Procedure revealed lack of similar pathways to
access and inspect other components with visual barriers, such as, pipe at supports and areas under
disbonded coating.
The records reviewed demonstrated that Niagara conducted annual AC inspections of its facility.
The 2017 records indicated that Niagara did not perform the AC inspections under most of the 8-
inch glycol system piping and the three vaporizers due to the insulation barriers. The 2014-2016
Niagara AC inspection records showed inspection results for components under insulation, but
there were no records to attest that the insulation had been removed to access and evaluate the
carbon steel components. Niagara stated that it had not removed insulation during the AC
inspections. Niagara’s actions and its procedures present no alternate method to perform the AC
inspections.
Therefore, Niagara failed to inspect, at intervals not exceeding 3 years, each component that is
protected from atmospheric corrosion, by failing to conduct effective AC inspections of above-
ground components under insulation at its Providence LNG Plant from 2014 to 2017.
Proposed Civil Penalty
Under 49 U.S.C. § 60122 and 49 CFR § 190.223, you are subject to a civil penalty not to exceed
$209,002 per violation per day the violation persists, up to a maximum of $2,090,022 for a related
series of violations. For violations occurring prior to November 2, 2015, the maximum penalty
may not exceed $200,000 per violation per day, with a maximum penalty not to exceed $2,000,000
for a related series of violations. Also, for LNG facilities, an additional penalty of not more than
$76,352 for each violation may be imposed. The Compliance Officer has reviewed the
circumstances and supporting documentation involved in the above probable violation and has
recommended that you be preliminarily assessed a civil penalty of $46,700 as follows:
Item number PENALTY
1 $46,700
Proposed Compliance Order
With respect to item number 1, pursuant to 49 U.S.C. § 60118, the Pipeline and Hazardous
Materials Safety Administration proposes to issue a Compliance Order to Niagara Mohawk Power
Corp. Please refer to the Proposed Compliance Order, which is enclosed and made a part of this
Notice.
Response to this Notice
Enclosed as part of this Notice is a document entitled Response Options for Pipeline Operators in
Compliance Proceedings. Please refer to this document and note the response options. All material
120183005_NOPV PCP PCO_06122018_text Page 2 of 4



CPF 1-2018-3005
you submit in response to this enforcement action may be made publicly available. If you believe
that any portion of your responsive material qualifies for confidential treatment under 5 U.S.C.
552(b), along with the complete original document, you must provide a second copy of the
document with the portions you believe qualify for confidential treatment redacted and an
explanation of why you believe the redacted information qualifies for confidential treatment under
5 U.S.C. 552(b).
Following the receipt of this Notice, you have 30 days to submit written comments, or request a
hearing under 49 CFR § 190.211. If you do not respond within 30 days of receipt of this Notice,
this constitutes a waiver of your right to contest the allegation in this Notice and authorizes the
Associate Administrator for Pipeline Safety to find facts as alleged in this Notice without further
notice to you and to issue a Final Order. If you are responding to this Notice, we propose that you
submit your correspondence to my office within 30 days from receipt of this Notice. This period
may be extended by written request for good cause.
Please submit all correspondence in this matter to Robert Burrough, Director, PHMSA Eastern
Region, 820 Bear Tavern Road, Suite 103, West Trenton, New Jersey 08628. Please refer to
CPF 1-2018-3005 on each document you submit, and whenever possible provide a signed PDF
copy in electronic format. Smaller files may be emailed to robert.burrough@dot.gov. Larger files
should be sent on a CD accompanied by the original paper copy to the Eastern Region Office.
Additionally, if you choose to respond to this (or any other case), please ensure that any response
letter pertains solely to one CPF case number.
Sincerely,
Robert Burrough
Director, Eastern Region
Pipeline and Hazardous Materials Safety Administration
Enclosures: Proposed Compliance Order
Response Options for Pipeline Operators in Compliance Proceedings
120183005_NOPV PCP PCO_06122018_text Page 3 of 4



CPF 1-2018-3005
PROPOSED COMPLIANCE ORDER
Pursuant to 49 United States Code § 60118, the Pipeline and Hazardous Materials Safety
Administration (PHMSA) proposes to issue to Niagara Mohawk Power Corp. a Compliance Order
incorporating the following remedial requirements to ensure the compliance of Niagara Mohawk
Power Corp. with the pipeline safety regulations:
1. 2. 3. 4. In regard to Item Number 1 of the Notice pertaining to § 193.2635, Niagara shall
revise its procedure for atmospheric corrosion inspection to address insulated
components, pipe at supports and pipe under disbonded coating. Niagara shall
provide PHMSA the revised procedure for review within 90 days of receipt of the
Final Order.
Within 365 days of PHMSA’s acceptance of the procedure in Number 1 above,
Niagara must then apply those procedures to conduct effective atmospheric
corrosion inspections for all insulated components at Niagara’s Providence LNG
Plant.
Upon request, Niagara shall provide records indicating the completion of the
atmospheric corrosion inspections in Number 2 above.
It is requested (not mandated) that Niagara Mohawk Power Corp. maintain
documentation of the safety improvement costs associated with fulfilling this
Compliance Order and submit the total to Robert Burrough, Director, Eastern
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.
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