2020 Progress Report

rpe%lb 1200 New Jersey Avenue SE
Washington DC 20590
U.S. Department A federal agency may not conduct or sponsor,and a person is not required to respond to,nor shall a person be subject to a penalty for
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
reviewing instructions,gathering the data needed,and completing and reviewing the collection of information.All responses to this
Materials Safety
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
2020 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.
3. Scan the signed document to your computer and email it to [e-mail].
FedSTAR Information
C
Electronic Submission Date: 3/4/2021 4:55:06 PM
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OF T R4Hsa
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Washington DC 20590
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OFFICE OF PIPELINE SAFETY
2020 Gas Base Grant Progress Report
Office: IDAHO PUBLIC UTILITIES COMMISSION
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PROGRESS REPORT ATTACHMENTS(GAS)
PHMSA Form No.PHMSA F 999-92
INSTRUCTIONS:
These attachments request information either for the entire calendar year(CY 2020: January 1 through December 31,
2020) or as of(or on)December 31,2020. Please report actual as opposed to estimated numbers on the attachments.Be
careful to provide complete and accurate information since the PHMSA State Programs will be validating the attachments
during the state's next annual evaluation.
Attachment 1: State Jurisdiction and Agent Status Over Facilities. Requires the state to indicate those pipeline
•operator types over which the state agency has jurisdiction under existing law. If the state does not have jurisdiction
over an operator type, indicate why not in the column designated No,using the one alpha code(A or B)which best
describes the reason. If the state agency has jurisdiction over an operator type,place an X in the column designated
Yes and provide information on the number of operators,the number and percent of operators inspected,the
number of inspection units, and the number and percent of inspection units inspected. If the jurisdiction over a type
of operator is under a Section 60106 Agreement, indicate X/60106 in the column designated Yes. If an operator has
multiple types of system(i.e. gas distribution and intrastate transmission), each type should be counted in
corresponding category. Total operator count listed in Attachment 3 may not match Attachment 1 totals due to
multiple types of systems per operator. If the same operator/inspection unit is visited more than once during the
year,count only once under number of operators inspected/number of inspection units inspected on Attachment 1.
The multiple visits would,however,be reflected under total inspection person-days in Attachment 2.
• Attachment 2: Total State Field Inspection Activity.Requires the state to indicate by operator type the number
of inspection person-days spent during CY 2020 on inspections; standard comprehensive; design,testing, and
construction;on-site operator training; integrity management; operator qualification; investigating incidents or
accidents;damage prevention activities; and compliance follow-up. Attachment 2 should include drug and alcohol
inspections. Counting "In Office" Inspection Time-An inspector may choose to review pipeline company
procedure manuals or records away from the company facility in order to effectively use on-site inspection time.
The amount of time spent reviewing procedures and records may be counted as part of the inspection process. It is
important that an inspector only record time for activities that normally would be completed as part of an on-site
inspection. For example, an inspector may attribute the three hours he or she spent reviewing a pipeline operator's
procedure manual and records prior to an on-site inspection towards the total inspection time. Each supervisor must
carefully review the reported time to ensure the time attributed is consistent with the activity completed and is
carefully delineated from normal office duties.
• Attachment 3: Facility Subject to State Safety Jurisdiction. States should only list the facilities that are
jurisdictional under Parts 192 and 193 (Gas)and Part 195 (Hazardous Liquid)of which the state has safety
authority over. This attachment requires the business name and address of each person subject to the pipeline
safety jurisdiction of the state agency as of December 31,2020.Also indicate the operator type(e.g., intrastate
transmission)consistent with the listing in Attachment 1 and include the number of inspection units in each
C operator's system. The operator identification number(OPID)assigned by PHMSA must also be included on this
attachment. If an operator has multiple types of system(i.e. gas distribution and intrastate transmission), each type
should be counted in corresponding category. Total operator count listed in Attachment 3 may not match
Attachment 1 totals due to multiple types of systems per operator. Please make comments in notes section to
provide any clarification on operator name changes,mergers,removals and other anomalies.
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• Attachment 4: Pipeline Incidents.Requires a list of incidents investigated by or reported to the state agency that
involved personal injury requiring hospitalization, a fatality,property damage exceeding$50,000, and others
deemed significant by the operator. Clearly identify the operator's reported cause AND the state's determination
of the cause of the incident using the one most appropriate alpha code footnoted in the attachment. We summarize
this information for Congress by classifying the cause into one of eight top-level categories: (A)corrosion failure;
(B)natural force damage; (C)excavation damage; (D) other outside force damage; (E)material failure of pipe or
weld; (F)equipment failure; (G) incorrect operation; (H)other accident cause. Within each top-level cause you will
find multiple sub-causes, select the appropriate cause code. You can also choose(IP) Investigation Pending for
those incidents remaining under investigation as of December 31. Then provide a summary of incident
investigations.
• Attachment 5: State Compliance Actions.This requires a summary of state pipeline inspection and compliance
actions. [In the Number of Compliance Actions Taken column,keep in mind one compliance action can cover
multiple probable violations.]
•Attachment 6: State Record Maintenance and Reporting.Requires a list of records and reports maintained and
required by the state agency.
• Attachment 7: State Employees Directly Involved in the Pipeline Safety Program.This attachment requires a
list by name and title of each employee directly involved in the pipeline safety program. Be sure to include the
percentage of time each employee has been involved in the pipeline safety program during 2020. If an employee
has not been in the pipeline safety program the full year of 2020,please note the number of months working on the
program. Indicate a Qualification Category for each of the state's inspectors (see Attachment 7a). The categories are
shown in descending order of education and experience. Please enter the number of the highest description
applicable to each inspector. For each inspector and supervisor, indicate the month and year he/she successfully
completed the training courses at the Pipeline Safety Office of Training and Qualifications in Oklahoma City,OK.
Finally,provide in summary form the number of all staff(supervisors, inspectors/investigator, damage prevention/
technical and clerical/administrative)working on the pipeline safety program and the person-years devoted to
pipeline safety. Person-years should be reported in hundreds (e.g., 3.25).
• Attachment 8: State Compliance with Federal Requirements. This requires the state to indicate whether it is in
compliance with applicable federal requirements. If a particular requirement is not applicable to the state(e.g.
offshore inspections),indicate NA in the column designated Y/N/NA and indicate in the notes section why the
regulation is not applicable. If a regulation has been adopted, indicate the date adopted(e.g., 05/01/04)in the
appropriate column. If the regulation is applicable but has not been adopted indicate N in the Y/N/NA column and
explain why not in the appropriate column(e.g.,requires legislative action). If the state has not adopted the
maximum penalty amounts for a related series of violations please indicate civil penalty levels in effect in the state
as of December 31. For State Adoption of Part 198 State One Call Damage Prevention Program if a state has any
penalty amount for its damage prevention law please mark item 7.h as"Adopted but Different Dollar Amounts"
and list the penalty amount in the Note section.Note at the end of Attachment 8 we are requesting each state to
indicate the frequency its legislature meets in general session. This information will be taken into account when
determining if applicable federal regulations have been adopted within 24 months of the effective date or two
general sessions of the state legislature.
• Attachment 10: Performance and Damage Prevention Questions. This attachment requires a narrative of each
states goals and accomplishments. In addition it requires a narrative on each states progress toward meeting the
nine elements of an effective damage prevention program as described in the PIPES Act of 2006.
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DEFINITIONS
• Inspection Unit. An inspection unit is all or part of an operator's pipeline facilities that are under the control of an
administrative unit that provides sufficient communication and controls to ensure uniform design,construction,
operation, and maintenance procedures for the facilities. (See Glossary of Terms in Guidelines for States Participating
in the Pipeline Safety Program for application of the inspection unit concept to transmission and hazardous liquid
pipeline systems, distribution systems, liquefied gas systems,municipality,master meter system,regulated gathering
pipeline systems, and propane-air systems/petroleum gas systems.)
• Inspection Person-Day.An inspection person-day is all or part of a day spent by a state agency representative
including travel in an on-site examination or evaluation of an operator or his system to determine if the operator is in
compliance with federal or state pipeline safety regulations, in an on-site investigation of a pipeline incident,or in job-
site training of an operator. Time expended on such activities should be reported as one inspection person-day for each
day devoted to safety issues,regardless of the number of operators visited during that day.
• Probable Violation.A probable violation is a non-compliance with any section or,where a section is divided into
subsections(a), (b),(c), etc., any subsection of federal or state pipeline regulations. Each numbered section should be
counted separately. Multiple non-compliances of a numbered section discovered on the same inspection should be
counted as one probable violation with multiple pieces of evidence.
• Compliance Action.A compliance action is an action or series of sequential actions taken to enforce federal or state
pipeline regulations. One compliance action can cover multiple probable violations. A compliance action may take the
form of a letter warning of future penalties for continued violation,an administratively imposed monetary sanction or
order directing compliance with the regulations,an order directing corrective action under hazardous conditions,a
show-cause order, a criminal sanction, a court injunction,or a similar formal action.
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Attachment 1 - Stats on Operators
STATE JURISDICTION AND AGENT STATUS OVER GAS FACILITIES AS
OF DECEMBER 31, 2020
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% 10 7 70.0%
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 2 2 100.0% 2 2 100.0%
Interstate F 0 0 N/A 0 0 N/A
LNG
Intrastate X/60105 1 1 100.0% 1 1 100.0%
Interstate A 0 0 N/A 0 0 N/A
Other
Gathering Lines I X/60105 1 1 1100.0%1 1 1 1 1100.0%
Offshore Facilities A 0 0 N/A 1 0 1 0 1 N/A
Total 7 7 100.00/ 14 1 11 178.6%
'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
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 actually only has 4 operators: 1. Avista(distribution only),2. Dominion(transmission and distribution), 3.
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Intermountain Gas Company(transmission,distribution and LNG),and 4.Northwest Gas Processing(gathering only).
Due to travel restrictions and COVID-19 Pandemic some of the Inspection units were postponed from 2020 to 2021.New
for 2021 Douglas Pipeline will be added as an operator(transmission only).
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Attachment 4 - Incidents/Accidents
SIGNIFICANT GAS INCIDENTS/ACCIDENTS JANUARY 1,THROUGH DECEMBER 31, 2020
Date of Location - System Injuries FatalitiesProperty Operator State
Incident City/County/etc. Type # # Damage' Cause Cause
$ Code' Code'
01/16/2020 IDAHO FALLS GD 0 0 $61,756.00 C4 G5
Name of Operator: INTERMOUNTAIN GAS CO
Operator ID: 8160 Report No: 20200025
Summary'
Leak was identified via a failed pressure test, corrosion happened due to improper application of field
wrap that replaced a piece of vintage coal tar wrap that had been knocked off years ago.
'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;
'Please 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
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Attachment 5 - Stats on Compliance Actions
STATE COMPLIANCE ACTIONS -- CALENDAR YEAR (CY) 2020
Probable Violation Categories Intrastate Interstate
Number carried over from all previous CY's 0 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) 0 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
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Attachment 6 - List of Records Kept
GAS STATE RECORD MAINTENANCE AND REPORTING DURING CY 2020
Records Maintained by the State Agency
Pipeline Safety Program Annual Certification/Progress Report
Operator Annual Reports
Common Ground Alliance
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
NAPSR Surveys
Inspection Reports: 2016, 2017, 2018, 2019, 2020
Reports Required from Operators
Incident Reports as per IPUC rule
Operators Annual Report
Attachment 6 Notes
NAPSR Surveys are conducted on-line using Survey Monkey.
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Attachment 10 - Performance and Damage Prevention Questions
CALENDAR YEAR (CY) 2020
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 has added 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. The Commission's goal is to their new
inspector qualified to lead basic inspections.
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?
Four 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. Any deficiencies noted were documented,
discussed with the operators for corrective actions,and follow-up inspections were performed when required. IPUC inspectors
completed 5 T&Q courses and the scheduled inspections that could be completed due to the travel restrictions from Covid-19. With
limited overnight travel the inspectors increased local construction inspections.The PUC's third inspector departed the Commission,
but a replacement has been hired to fill the vacancy.
1. Has the state or agency reviewed the Damage Prevention Assistance Program (DPAP)document in the last twelve months?
No
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
develop a State Damage Prevention Program that would have any enforcement ability. All enforcement authority for damage
prevention is held within Idaho Division of Building Safety'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
C 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 law,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.
Noted deficiency(s)are documented on the IPUC Form 1 and the appropriate section of the PHMSA checklist. 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
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The State of Idaho does not have a formal Damage Prevention Assistance Program document. There is not any provision in
statute for a specific state agency to develop and enforce such a document.
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