2023 Progress Report

1 1200 New Jersey Avenue SE
Washington DC 20590
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failure to comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of
of Transportation
information displays a current valid OMB Control Number.The OMB Control Number for this information collection is 2137-0584.
Pipeline and Hazardous Public reporting for this collection of information is estimated to be approximately 58.5 hours per response,including the time for
Materials Safety reviewing instructions,gathering the data needed,and completing and reviewing the collection of information.All responses to this
collection of information are mandatory.Send comments regarding this burden estimate or any other aspect of this collection of
Administration information,including suggestions for reducing this burden to:Information Collection Clearance Officer,Pipeline and Hazardous
Materials Safety Administration(PHMSA),PHP-30,1200 New Jersey Ave SE,Washington,D.C.20590
Pipeline Safety
2023 Gas Base Grant Progress Report
for
IDAHO PUBLIC UTILITIES COMMISSION
Please follow the directions listed below :
1. Review the entire document for completeness.
2. Review and have an authorized signatory sign and date page 2.
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FedSTAR Information
Electronic Submission Date: 1/30/2024 4:52:27 PM
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2023 Gas Base Grant Progress Report
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PROGRESS REPORT ATTACHMENTS (GAS)
PHMSA Form No.PHMSA F 999-92
Attachment 1: State Jurisdiction and Agent Status over Facilities.
Attachment 2: State Field Inspection Activity
Attachment 3: Facilities Subject to State Safety Jurisdiction
Attachment 4: Pipeline Incidents
Attachment 5:State Compliance Actions
Attachment 6: State Record Maintenance and Reporting
Attachment 7: State Employees Directly Involved in the Pipeline Safety Program
Attachment 8: State Compliance with Federal Regulations
{there is no attachment 9}
Attachment 10: Performance and Damage Prevention Questions
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Attachment 1 - Stats on Operators
STATE JURISDICTION AND AGENT STATUS OVER GAS FACILITIES AS
OF DECEMBER 31, 2023
State Agency Jurisdiction/ No. of Operators No. of
Operator Type gent Status Operators Inspected Inspection Units Inspected
Units
No' Yes # % # %
Distribution
Private X/60105 3 3 100.0% 11 11 100.0%
Municipal A 0 0 N/A 0 0 N/A
Master Meter X/60105 0 0 N/A 0 0 N/A
LPG X/60105 0 0 N/A 0 0 N/A
Other A 0 0 N/A 0 0 N/A
Transmission
Intrastate X/60105 3 3 100.0% 3 3 100.0%
Interstate F 0 0 N/A 0 0 N/A
LNG
Intrastate X/60105 1 1 100.0% 2 2 100.0%
Interstate A 0 0 N/A 0 0 N/A
Other
Gathering Lines X/60105 1 1 100.0% 1 1 100.0%
Offshore Facilities A 0 0 N/A 0 0 N/A
Total 8 8 100.0% 17 1 17 1100.0%
'Codes: A-None in state and does not have jurisdiction;
B - State does not have jurisdictional authority(Provide current status or action being taken to obtain authority
in notes section below)
F -No, State is currently not an interstate agent.
X/60105P=Yes,I have Section 60105 (Certification)over some of the operator type(meaning: I have 60105
p authority over some,but not all of this operator type and do not have a 60106 agreement with PHMSA to inspect
them). These operators are identified in the notes below.
X/IA-Yes, I have Interstate Agent jurisdiction over this type of operator
Distribution"Other" -ie Co-ops,Public Utility Districts, etc.
States should explain any special circumstances
General Instructions -All above facilities should only include facilities as defined by federal pipeline regulations
and should not include extended jurisdiction by state regulation.
Attachment 1 Notes:
Idaho has 5 operators: 1. Avista(distribution only), 2. Dominion(transmission and distribution), 3. Intermountain Gas
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Company(transmission, distribution and LNG), and 4.Northwest Gas Processing(gathering only). 5.Douglas Pipeline
(transmission only).
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Attachment 2 - State Inspection Activity
TOTAL STATE FIELD INSPECTION ACTIVITY AS
OF DECEMBER 31, 2023
Design On-Site Damage
Standard Investigating Integrity Operator Incidents or Compliance
Operator Type Testing and Operator Prevention Total
Comprehensive Construction Training Management Qualification Accidents Activities Follow-up
Distribution
Private 98.000 174.000 0.000 8.000 4.800 0.800 5.000 2.500 293.100
Municipal 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Master Meter 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
LPG 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Other 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Transmission
Intrastate 3.000 0.000 0.000 9.000 0.000 0.000 0.000 0.000 12.000
Interstate 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
LNG
Intrastate 8.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 8.000
Interstate 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Other
Gathering Lines 10.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 10.000
Offshore Facilities 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Total 119.000 174.000 0.000 17.000 4.800 0.800 5.000 2.500 323.100
C
Drug and Alcohol
Total Count of Drug and Alcohol Inspections 1
Attachment 2 Notes
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Attachment 3 - List of Operators
GAS FACILITIES SUBJECT TO STATE SAFETY JURISDICTION AS OF DECEMBER 31, 2023
Distribution TransmissionLNG(Operator type& Other(Operator type
Operator (Operator type&Inspection Units) (Operator type& Inspection Units) &Inspection Units)
Inspection Units)
Business Name Offshore
Operator ID Gathering Facilities
Address Private Municipal
Master Lines Juris- State
LPG Other Intrastate Interstate Intrastate Interstate
Meter dictional Waters
Avista Corporation 5 0 0 0 0 0 0 0 0 0 0
31232
1411 E.Mission, Spokane,WA 99220
Dominion Energy 1 0 0 0 0 1 0 0 0 0 0
12876
1040 W.200 S., Salt Lake City,UT 84145
Douglas Pipeline Co 0 0 0 0 0 1 0 0 0 0 0
31442
_ 3829 Willow Ave Suite 203, Pittsburg,PA 15234
Intermountain Gas Company 5 0 0 0 0 1 0 2 0 0 0
8160
555 South Cole, Boise,ID 83707
Northwest Gas Processing,LLC 0 0 0 0 0 0 0 0 0 1 0
39370
15021 Katy Freeway,Suite 400 Houston,TX 77094
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Distribution Transmission LNG(Operator type& Other(Operator type
(Operator type&Inspection Units) (Operator type& Inspection Units) &Inspection Units)
Inspection Units)
Offshore
Gathering Facilities
Master Lines(Juris- (State
Private Municipal LPG Other Intrastate Interstate Intrastate Interstate
Meter dictional) Waters
Inspection Unit totals by type 11 0 0 0 0 3 0 2 0 1 0
Total Operators 5
Attachment 3 Notes:
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Attachment 4 - Incidents/Accidents
SIGNIFICANT' GAS INCIDENTS/ACCIDENTS JANUARY 1,THROUGH DECEMBER 31,2023
Date of Location- System Injuries FatalitiesProperty Operator State
Incident City/County/etc. Type # # Damage' Cause Cause
$ Code' Code'
Name of Operator:
Operator ID: Report No:
Summary2
'High Level Cause Codes: A-Corrosion failure; B-Natural Force Damage; C-Excavation Damage; D-Other
Outside Force Damage; E-Pipe,Weld or Joint Failure; F-Equipment Failure; G-Incorrect Operation; H-Other
Incident Cause; IP-Investigation Pending;
2Please include a summary or report of the state agency's investigation of each of the above incidents.
'Interstate agents should use the 191.3 Incident definition for listing incidents investigated on interstate facilities.
Attachment 4 Notes
No 191.3 defined incidents were reported for 2023. IPUC maintains state reportable incidents as well but
p nothing was to the extent of 191.3.
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Attachment 5 - Stats on Compliance Actions
STATE COMPLIANCE ACTIONS -- CALENDAR YEAR (CY) 2023
Probable Violation Categories Intrastate Interstate
Number carried over from all previous CY's 1 0
Number Found During CY 11 0
Number submitted for DOT action [60106 Agreement agent 0 0
only]
Number corrected during CY(including carry over from 11 0
previous year(s))
Number to be corrected at end of CY(including carry over) 1 0
Number of Compliance Actions Taken '
(see definition) 11
Civil Penalties
Number assessed during CY 0
Dollars assessed during CY $0.00
Number collected during CY 0
Dollars collected during CY $0.00
'Do not double count for a related series of actions.
Attachment 5 Notes
(1) Compliance action was not closed by end of year. Expected close date of carryover in February 2024.
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Attachment 6 - List of Records Kept
GAS STATE RECORD MAINTENANCE AND REPORTING DURING CY 2023
Records Maintained by the State Agency
Pipeline Safety Program Annual Certification/Progress Report
Operator Annual Reports
Inspection Reports: 2019,2020, 2021,2022, 2023
Compliance Actions
Damage Prevention Program
Inspection Field Days
Annual Inspection Schedule
Operator Incident/Accident
PHMSA Correspondence
PUC Pipeline Safety Program Plan(POP)
PHMSA Program Evaluation
OPS Grants-Base Grant Application
Safety Related Condition Reports
Pipeline Training
T& Q Seminars
NA
NA
Reports Required from Operators
Incident Reports as per IPUC rule
Operators Annual Reports
Attachment 6 Notes
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Attachment 7 - Staffing and TQ Training
STATE EMPLOYEES DIRECTLY INVOLVED IN THE GAS PIPELINE
SAFETY PROGRAM DURING CY 2023
Name/Title % 9 Qual.
Time Months Cat.
Supervisor
Jeff Brooks
Program Manager 140.0001 12 II
Inspector/Investigator
Jeff Brooks
Inspector 60.0001 12 1 II
Matt Galli
Inspector 100.0001 12 1 IV
Perkins,Bruce
Inspector 100.0001 12 1 11
Summary
Employee Type No. of Staff Person-Years
Supervisor 1 0.400
Damage Prevention/Technical 0 0.000
Inspectors/Investigators 3 2.600
Clerical/Administrative 0 0.000
Total 4 3.000
Attachment 7 Notes
Matt Galli completed the gas path at TQ for inspector, achieved greater than one year of experience and was upgraded to IV.
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Attachment 8 - Compliance with Federal Regulations
STATE COMPLIANCE WITH FEDERAL REQUIREMENTS AS OF DECEMBER 31, 2023
No. Effective Impact Adoption AdoptionStatus
Date Date
Maximum Penalties Substantially same as DOT ( 257,664/ 2,576,627). State
1 must adopt minimum penalties of at least($100,000/$1,000,000).Indicate actual 04/1970 Adopted Other
amount in notes.
Note' $2,000 per each violation per day the violation persists. $200,000 maximum for any related series of violations.
2 Part 192 Amendments
1-115 Pre 2011 [All applicable amendments prior to and including 2010] 12/31/2010Adopted
Note'
116-76 FR 5494 4/4/2011 Mechanical Fitting Failure Reporting Requirements 04/2012 Adopted
Note'
117-76 FR 35130 8/15/2011 Control Room Management/Human Factors 04/2013 Adopted
Note'
Administrative Procedures Updates, and Technical Corrections(Not
118 -78 FR 58897 10/25/2013 04/2016 Adopted
applicable to States)
Note'
119 - 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and 04/2016 Adopted
Miscellaneous Edits
—_ Note'
Miscellaneous Changes to Pipeline Safety Regulations (Part 192.305
120- 80 FR 12779 10/1/2015 DELAYED) 04/2016 Adopted
Note'
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121 - 81 FR 70989 4/14/2017 Expanding the Use of Excess Flow Valves in Gas Distribution 07/2018 Adopted
Systems to Applications Other Than Single-Family Residences
Note'
123 - 82 FR 7972 3/24/2017 Operator Qualification, Cost Recovery,Accident and Incident 07/2018 Adopted
Notification, and Other Pipeline Safety Changes
Note'
124- 83 FR 58694 1/22/2019 Use of Plastic Piping Systems in the Transportation of Natural and 07/2021 Adopted
Other Gas
Note'
Pipeline Safety: Safety of Gas Transmission Pipelines: MAOP
125 - 84 FR 52180 7/l/2020 Reconfirmation,Expansion of Assessment Requirements, and Other 07/2021 Adopted
Related Amendments
Note'
126- 86 FR 2210 3/12/2021 Pipeline Safety: Gas Pipeline Regulatory Reform(Delayed to 3/21) 07/2021 Adopted
(Delayed Compliance date 10/12/2021)
Note'
Pipeline Safety: Safety of Gas Gathering Pipelines: Extension of
127- 87 FR 26296 5/16/2022 Reporting Requirements,Regulation of Large,High-Pressure Lines, 05/2022 Adopted
and Other Related Amendments.
Note'
Pipeline Safety: Amendments to Parts 192 and 195 to Require Valve
128 - 87 FR 20940 10/5/2022 Installation and Minimum Rupture Detection Standards. 10/2022 Adopted
Note'
Pipeline Safety: Safety of Gas Transmission Pipelines: Repair Criteria,
130- 87 FR 52224 5/24/2023 Integrity Management Improvements, Cathodic Protection, 05/2023 Adopted
Management of Change, Other Related Amendments, and Technical
Corrections
Note'
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Pipeline Safety: Safety of Gas Transmission Pipelines: Repair Criteria,
131 - 88 FR 24708 5/24/2023 Integrity Management Improvements, Cathodic Protection, 05/2023 Adopted
Management of Change, and Other Related Amendments: Technical
Corrections
Note'
132- 88 FR 50056 8/l/2023 Pipeline Safety: Requirement to Valve Installation and Minimum 05/2023 Adopted
Rupture Detection Standards: Technical Corrections
Note'
3 Part 193 Amendments(applicable only where state has jurisdiction over LNG)
1-23 Pre 2011 [All applicable amendments prior to and including 2010] 12/2010 Adopted
Note'
24-78 FR 58897 10/25/2013 Administrative Procedures, Updates, and Technical Corrections 04/2016 Adopted
Note'
25 - 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and 04/2016 Adopted
Miscellaneous Edits
Note'
4 Part 199-Drug Testing 03/2001 Adopted
Note'
5 Part 199 Amendments
1-24 Pre 2011 [All applicable amendments prior to and including 2010] 12/2010 Adopted
p Note'
25 -78 FR 58897 10/25/2013 Administrative Procedures, Updates, and Technical Corrections 04/2016 Adopted
C Note'
26- 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and 04/2016 Adopted
Miscellaneous Edits
Note'
Operator Qualification Cost Recovery Accident and Incident
27- 82 FR 7972 3/24/2017 Notification, and Other Pipeline Safety Changes 07/2018 Adopted
Note'
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Conforming Amendments and Technical Corrections to Department
28 - 84 FR 16770 4/23/2019 Rules Implementing the Transportation Industry Drug Testing 07/2021 Adopted
Program
Note'
6 State Adoption of Part 198 State One-Call Damage Prevention Program
a. Mandatory coverage of areas having pipeline facilities 04/1990 Adopted
Note'
b. Qualification for operation of one-call system 04/1990 Adopted
Note'
C. Mandatory excavator notification of one-call center 09/1990 Adopted
Note'
d. State determination whether calls to center are toll free 04/1991 Adopted
Note'
e. Mandatory intrastate pipeline operator participation 04/1990 Adopted
Note'
£ Mandatory operator response to notification 04/1990 Adopted
C Note'
g. Mandatory notification of excavators/public 07/2002 Adopted
Note'
h. Civil penalties/injunctive relief substantially same as DOT 07/2018 Adopted but Different Dollar Amounts
Note' Current law provides for$1,000 penalty for second occurance; $5,000 for any subsequent occurrences.
9='If Adoption Status is No,Please provide an explanation
State Attendance at 2023 NAPSR Regional Meeting: Attended full time(Lead rep or alternative pipeline staff)
Frequency of General Legislative Session: Annually
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Attachment 8 Notes
Current ECFR Edition of Code of Federal Regulations is utilized per commission order 35344 (issued March 2022).
-
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Attachment 10 - Performance and Damage Prevention Questions
CALENDAR YEAR (CY) 2023
Planned Performance: What are your Planned Annual and Long-term goals for your Pipeline Safety Program?
The IPUC Pipeline Safety Program is committed to improving our safety program. The Commission's annual goals are to ensure
Idaho jurisdictional pipeline operators are providing the safe transportation and delivery of natural gas to its customers and doing this
without affecting the safety of the public. This is accomplished by a comprehensive program of inspections and audits of the
companies'records and field equipment and following-up on each incident and non-compliance found. During the next year,the
Commission expects a new operator into their inspection plan. The Commission's inspection staff will conduct more construction
inspections,conduct follow-up inspections of the high-pressure service sets(HPSS/farm taps)and will attempt to attend the
construction of the renewable natural gas pipelines that are planned in the near future. Another goal is to get our newest inspector
qualified through the TQ IM(gas)path.
Past Performance: What did the Pipeline Safety Program accomplish during the subject year(to this document)to contribute
toward the program's annual and long-term goals?
Five Intrastate operators within the Commission's jurisdiction were inspected for the safe transportation and delivery of natural gas
within the state according to the Commission's approved program of operating procedures. Deficiencies were documented,discussed
with the operators for corrective actions,and follow-up inspections were performed when required. IPUC inspectors completed 9 ILT
T&Q courses in 2023 and performed 323 inspection days.There were 12 resolved compliance actions.
1. Has the state or agency reviewed the Damage Prevention Assistance Program(DPAP)document in the last twelve months?
Yes
2. Has the state or agency developed or is in the process of developing a plan to address the nine elements contained in the PIPES
Act of 2006 for an effective State Damage Prevention Program?
Yes
If yes to question 2,where does the state or agency stand on implementation of the nine elements contained in the PIPES Act of
2006? Please provide a description of how the state or agency has or will meet each element. If not,please provide a brief passage
explaining the reasons why the state or agency has not.
The Commission has continued to participate in the statewide coalition for damage prevention but does not have statutory authority to
9�_ develop a State Damage Prevention Program that would have any enforcement ability. All enforcement authority for damage
prevention is held within Idaho Division of Professional Licensing's Damage Prevention Board. The Commission does hold a seat on
the board but would not have any directive authority over it. The board's objective plan has addressed the nine elements for an
effective State Damage Prevention Program. The Commission supports the program through an alliance with(two)one-call centers,
Operator's public awareness programs,and utility coordinating councils. The goal of the coalition is to improve the underground
damage prevention laws,eliminate as many exemptions as possible,educate the public and establish an effective enforcement
mechanism in accordance with the 9 elements contained in the PIPES Act. During annual audit(s)of each operator,the Commission
continues to review operator's damage prevention program against rules and standards to ensure the programs processes are in place
and effective. Significant process deficiencies result in immediate corrective actions and if needed a compliance action. Procedures
for probable violation process established in the Commission's program operating procedures will be followed.
Attachment 10 Notes
Program manager read the 2008 1 st edition of PHMSA DPAP in January.
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