2021 Progress Report.pdf

DUNS: 102589939 2021 Gas Base Grant Progress Report Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 1
Pipeline Safety
2021 Gas Base Grant Progress Report

for

IDAHO PUBLIC UTILITIES COMMISSION
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FedSTAR Information

Electronic Submission Date: 3/2/2022 3:47:00 PM
1200 New Jersey Avenue SE
Washington DC 20590
U.S. Department
of Transportation
Pipeline and Hazardous Materials Safety Administration
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 information displays a current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0584. 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 collection of information are mandatory. Send comments regarding this burden estimate or any other aspect of this collection of 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
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Pipeline and Hazardous Materials Safety Administration
1200 New Jersey Avenue, SE
Washington DC 20590
OFFICE OF PIPELINE SAFETY

2021 Gas Base Grant Progress Report
Office:IDAHO PUBLIC UTILITIES COMMISSION
Authorized Signature
Title
Date
Printed Name
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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, 2021
Operator Type State Agency Jurisdiction/
Agent Status
No. of
Operators
Operators
Inspected
No. of Inspection
Units
Units Inspected
No1 Yes #%#%
Distribution
Private X/60105 3 3 100.0%10 10 100.0%
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%1 1 100.0%
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%15 15 100.0%
1Codes: 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 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.New for 2021
Douglas Pipeline added as an operator (transmission only).
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 6
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Attachment 2 - State Inspection Activity

TOTAL STATE FIELD INSPECTION ACTIVITY AS
OF DECEMBER 31, 2021
Operator Type Standard Comprehensive
Design,
Testing and
Construction
On-Site
Operator
Training
Integrity Management Operator Qualification
Investigating
Incidents or
Accidents

Damage
Prevention
Activities
Compliance Follow-up Total
Distribution
Private 131.500 111.000 0.000 9.500 23.000 1.000 2.500 0.000 278.500
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 9.500 0.000 0.000 15.000 2.000 0.000 0.000 0.000 26.500
Interstate 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
LNG
Intrastate 5.500 0.000 0.000 0.000 0.000 2.000 0.000 0.000 7.500
Interstate 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Other
Gathering Lines 12.500 0.000 0.000 0.000 0.500 0.000 0.000 0.000 13.000
Offshore Facilities 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
Total 159.000 111.000 0.000 24.500 25.500 3.000 2.500 0.000 325.500
Drug and Alcohol
Total Count of Drug and Alcohol Inspections 2
Attachment 2 Notes
Per PHMSA guidance the 'training' in our Idaho inspection days tracking was corrected and moved to OQ.

Total count of drug and alcohol were entered for full program I.A. inspections as per PHMSA guidance.
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 7
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Attachment 3 - List of Operators

GAS FACILITIES SUBJECT TO STATE SAFETY JURISDICTION AS OF DECEMBER 31, 2021
Operator Distribution
(Operator type & Inspection Units)
Transmission
(Operator type &
Inspection Units)
LNG(Operator type &
Inspection Units)
Other (Operator type
& Inspection Units)
Business Name Operator ID Address Private Municipal Master Meter LPG Other Intrastate Interstate Intrastate Interstate
Gathering Lines (Juris- dictional)
Offshore Facilities (State Waters)Avista Corporation 5 0 0 0 0 0 0 0 0 0 0
312321411 E. Mission, Spokane, WA 99220
Dominion Energy 1 0 0 0 0 1 0 0 0 0 0
128761040 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 1 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
3937015021 Katy Freeway, Suite 400 Houston, TX 77094
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 8
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Distribution
(Operator type & Inspection Units)
Transmission
(Operator type &
Inspection Units)
LNG(Operator type &
Inspection Units)
Other (Operator type
& Inspection Units)
Private Municipal Master Meter LPG Other Intrastate Interstate Intrastate Interstate
Gathering Lines (Juris- dictional)
Offshore Facilities (State Waters)Inspection Unit totals by type 11 0 0 0 0 3 0 1 0 1 0
Total Operators 5
Attachment 3 Notes:
Avista now has (5) different inspection units which has changed from 4. (2) of them have been and still are often grouped for logistical reasons and proximity.
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Attachment 4 - Incidents/Accidents

SIGNIFICANT4 GAS INCIDENTS/ACCIDENTS JANUARY 1, THROUGH DECEMBER 31, 2021
Date of
Incident
Location -
City/County/etc.System Type
Injuries
#
Fatalities
#
Property
Damage3
$
Operator
Cause
Code1
State
Cause
Code1
02/17/2021 NO LOCATION LNG 0 0 $3,978,532.00 A1 A1
Name of Operator:INTERMOUNTAIN GAS CO
Operator ID:8160 Report No:20210003
Summary2
On Thursday, February 4, 2021 a Plant Operator was working on the roof of the LNG tank and audibly
and visually discovered a non-hazardous leak. The non-hazardous leak is under a steel backing plate that is welded
to the roof of the
LNG tank. The backing plate is part of the support system for the walking platform. Because the
backing plate is not fully
welded, water accumulated between the backing plate and the LNG tank roof, ultimately leading to a non-hazardous
corrosion leak. An estimated 300 CFH is venting to the atmosphere.
Intermountain Gas Company (IGC) hired an engineering consultant on February 11, 2021 to evaluate
repair options. On
February 17, 2021 at 11:10 a.m. MST, using data provided by the engineering consultant, IGC determined the LNG tank
will be taken out of service to make repairs, which is expected to exceed $50,000, at which time IGC
notified the NRC. As of February 17, 2021, the LNG tank had 3,093,114 gallons of LNG. To allow for
the offload and vaporization of the
LNG, the LNG tank will be taken out of service in June 2021. The estimated volume of commodity released unintentionally (Part A, Question 9) is 201.6 MCF as of
March 4, 2021.
This quantity will be revised for the Final report.
Estimated cost of Operator's property damage & repairs (Part C, Question 1.b.) is $500,000. This cost
will be revised for the Final report.
03/01/2021 GOSHEN GD 0 0 $26,495.00 F1 F1
Name of Operator:INTERMOUNTAIN GAS CO
Operator ID:8160 Report No:20210031
Summary2
Intermountain Gas Company (IGC) was notified of an outside gas odor in Goshen, ID (an
unincorporated community in Bingham
County) at 18:07 on February 27, 2021. After arriving on site at 18:51, a Company first responder
found a 3" relief valve at a district regulator in the full open position at which time additional personnel was dispatched to the
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scene. The regulators at the
location of the relief valve were inspected and found to be operating correctly. Company personnel
then began inspecting the regulators at a regulator station located 3.7 miles west of the blowing relief valve that supplies gas to the same 200 psig MAOP
pipeline. The primary regulator at the second regulator station was shut in at 21:45 at which time the
system pressure dropped to
170 psig; however, the relief valve was still in the open position. The relief valve was isolated at 12:28 on February 28, 2021. It was determined hydrocarbons had accumulated and froze causing the relief valve to stick in the open
position.
The morning of March 1, 2021 Company personnel inspected and repaired the primary regulator at the
second regulator station. A yellow/white powder was found on the seat, diaphragm and pilot components which was the cause of the regulator failure that
resulted in the relief valve opening. The powder was cleaned off all surfaces and the soft components
were replaced.
At 11:52 on March 1, 2021 the engineering department calculated the gas loss for this release at which time it was discovered the 3 million cubic feet reporting threshold was exceeded.
10/28/2021 RATHDRUM GD 0 0 $778,199.00 C3 C1
Name of Operator:AVISTA CORP
Operator ID:31232 Report No:20210098
Summary2
At approximately 10:00 a.m. PDT on October 28, 2021, PG Contractors, a third-party contractor, was
installing
telecommunications infrastructure using a horizontal directional drill when they severed a 2" polyethylene (PE) main at the intersection of Christine Street and Beechwood Street in front of 6997 W Christine St., Rathdrum,
Idaho. The PE pipe operated at
a pressure of approximately 55 psig with an MAOP of 60 psig, was at a depth of 36 inches, and locate
marks were present and accurate. Avista was notified at 10:13 a.m. PDT and was on site at 10:20 a.m. PDT. The Northern Lakes Fire District responded
and evacuated 3 nearby residences at 6971, 6997 and 7025 W Christine Street. The location of the
damage required squeezing
the 2" main in three locations as it was close to a tee. The squeezes were complete at 11:43 a.m. PDT to control the flow of gas. The fire department left once the scene was secure. Underground barhole readings were taken in front
of the three evacuated
houses and showed 0 percent LEL. Inside gas readings were taken at 6997 W Christine Street at
approximately 12:10 p.m. PDT and showed readings between 10% and 70% LEL. The Gas Serviceman exited the house and left the doors open to air out the
house.
At approximately 12:30 p.m. PDT the homeowners at 7025 W Christine Street came home and
requested to enter their house. A Gas Serviceman checked each room of the house with a combustible gas indicator and found readings of 0% LEL, so the Gas
Serviceman cleared the house for the homeowners to reenter.
Shortly thereafter, the homeowners at 6997 W Christine Street requested to get back into their house.
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The Gas Serviceman
checked each room with a combustible gas indicator, which now read 0% LEL and he allowed the
homeowners back in their house. At this time, the gas and electricity were still shut off to the house and the electric meter had to be re-installed. After
turning the electricity back on the homeowner reported popping noises coming from the furnace. The
Gas Serviceman checked
near the furnace and found 0% LEL and decided to turn the furnace off at the thermostat. While entering the house from the Form PHMSA F 7100.1 (rev 4-2019) Page 12 of
12
Reproduction of this form is permitted
garage, the Gas Serviceman saw a red glow above his head which was an ignition of gas at approximately 12:46 p.m. PDT. The Gas Serviceman exited through the open garage door and the male homeowner exited through the rear
garage access door.
Individuals on scene then helped to get the female homeowner out of the upstairs of the house through
a window. Shortly thereafter the building was consumed by flames. Operator personnel on scene called 911 immediately after the gas ignited and
the Northern Lakes Fire District was on scene at approximately 12:57 p.m. PDT. The female
homeowner was assessed by EMTs
on site and the male homeowner went to the hospital to be treated for second degree burns on his forearm but was not admitted. Preliminary investigation suggests that there was a pocket of gas inside the house in a location that
could not be detected by the
Gas Serviceman's instrument. It was that pocket of gas that ignited causing the fire. The building was
deemed a total loss with a value exceeding $122,000 resulting in this incident being reportable. Avista denies liability for damages and injuries associated
with this incident.
1High 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.

3Interstate agents should use the 191.3 Incident definition for listing incidents investigated on interstate facilities.

Attachment 4 NotesThe LNG incident is considered to be located in Nampa, ID.
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Attachment 5 - Stats on Compliance Actions

STATE COMPLIANCE ACTIONS -- CALENDAR YEAR (CY) 2021
Probable Violation Categories Intrastate Interstate
Number carried over from all previous CY's 0 0
Number Found During CY 12 0
Number submitted for DOT action [60106 Agreement agent
only]0 0
Number corrected during CY (including carry over from previous year(s))12 0
Number to be corrected at end of CY (including carry over)0 0
Number of Compliance Actions Taken 1
(see definition)12
Civil Penalties
Number assessed during CY 0
Dollars assessed during CY $0.00
Number collected during CY 0
Dollars collected during CY $0.00
1Do not double count for a related series of actions.
Attachment 5 Notes
(12) separate compliance notices and letters during the CY.
IPUC also recieved a whistleblower complaint regarding OQ compliance. IPUC conducted an investigation of
these claims. The case is continuing into the next year. Civil penalties are expected pending commission
approval.
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Attachment 6 - List of Records Kept

GAS STATE RECORD MAINTENANCE AND REPORTING DURING CY 2021
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: 2017, 2018, 2019, 2020, 2021
Reports Required from Operators
Incident Reports as per IPUC rule
Operators Annual Reports
Attachment 6 Notes
NAPSR Surveys are conducted online. A receipt is not always given from the Survey Monkey website for
Idaho retention.
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 14
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Attachment 7 - Staffing and TQ Training

STATE EMPLOYEES DIRECTLY INVOLVED IN THE GAS PIPELINE
SAFETY PROGRAM DURING CY 2021
Name/Title %#Qual.Time MonthsCat.
Supervisor
Jeff Brooks
Program Manager 50.000 0.5 NA
Ulmer, Darrin
Program Manager 40.000 8 NA
Inspector/Investigator
Jeff Brooks
Inspector 98.000 12 III
Perkins, Bruce
Inspector 100.000 12 II
Ulmer, Darrin
Inspector 60.000 8 II
Summary
Employee Type No. of Staff Person-Years
Supervisor 2 0.290
Damage Prevention/Technical 0 0.000
Inspectors/Investigators 3 2.380
Clerical/Administrative 0 0.000
Total 5 2.670
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 15
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Attachment 7 Notes
Kyle Russo was not with the program in 2021 - he left prior to 2021. Darrin Ulmer left the program in September. Jeff Brooks was the new
program manager as of the middle of December 2021.
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 16
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Attachment 8 - Compliance with Federal Regulations

STATE COMPLIANCE WITH FEDERAL REQUIREMENTS AS OF DECEMBER 31, 2021
No.Effective
Date Impact Adoption
Date AdoptionStatus
1
Maximum Penalties Substantially same as DOT ($225,134/$2,251,334). State
must adopt minimum penalties of at least ($100,000/$1,000,000). Indicate actual
amount in notes.
04/1970 Adopted Other
Note1 $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
Note1
116 - 76 FR 5494 4/4/2011 Mechanical Fitting Failure Reporting Requirements 04/2012 Adopted
Note1
117-76 FR 35130 8/15/2011 Control Room Management/Human Factors 04/2013 Adopted
Note1
118 - 78 FR 58897 10/25/2013 Administrative Procedures, Updates, and Technical Corrections (Not applicable to States)04/2016 Adopted
Note1
119 - 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits 04/2016 Adopted
Note1
120 - 80 FR 12779 10/1/2015 Miscellaneous Changes to Pipeline Safety Regulations (Part 192.305
DELAYED)04/2016 Adopted
Note1
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121 - 81 FR 70989 4/14/2017 Expanding the Use of Excess Flow Valves in Gas Distribution
Systems to Applications Other Than Single-Family Residences 07/2018 Adopted
Note1
123 - 82 FR 7972 3/24/2017 Operator Qualification, Cost Recovery, Accident and Incident Notification, and Other Pipeline Safety Changes 07/2018 Adopted
Note1
124 - 83 FR 58694 1/22/2019 Use of Plastic Piping Systems in the Transportation of Natural and
Other Gas 07/2021 Adopted
Note1 Adopted through CFR and Commission Safety Regulations Order 35095 (Rule 201). Code of Federal Regulations have been updated to the most current annual editions.
125 - 84 FR 52180 7/1/2020
Pipeline Safety: Safety of Gas Transmission Pipelines: MAOP
Reconfirmation, Expansion of Assessment Requirements, and Other
Related Amendments
07/2021 Adopted
Note1 Adopted through CFR and Commission Safety Regulations Order 35095 (Rule 201). Code of Federal Regulations have been updated to the
most current annual editions.
126 - 86 FR 2210 3/12/2021 Pipeline Safety: Gas Pipeline Regulatory Reform (Delayed to 3/21) (Delayed Compliance date 10/12/2021)07/2021 Adopted
Note1 Adopted through CFR and Commission Safety Regulations Order 35095 (Rule 201). Code of Federal Regulations have been updated to the
most current annual editions.
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
Note1
24 - 78 FR 58897 10/25/2013 Administrative Procedures, Updates, and Technical Corrections 04/2016 Adopted
Note1
25 - 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits 04/2016 Adopted
Note1
4 Part 199 - Drug Testing 03/2001 Adopted
Note1
5 Part 199 Amendments
Idaho IDAHO PUBLIC UTILITIES COMMISSION, Page: 18
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1-24 Pre 2011 [All applicable amendments prior to and including 2010]12/2010 Adopted
Note1
25 - 78 FR 58897 10/25/2013 Administrative Procedures, Updates, and Technical Corrections 04/2016 Adopted
Note1
26 - 80 FR 168 3/6/2015 Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits 04/2016 Adopted
Note1
27 - 82 FR 7972 3/24/2017 Operator Qualification, Cost Recovery, Accident and Incident Notification, and Other Pipeline Safety Changes 07/2018 Adopted
Note1
28 - 84 FR 16770 4/23/2019
Conforming Amendments and Technical Corrections to Department
Rules Implementing the Transportation Industry Drug Testing
Program
07/2021 Adopted
Note1 Commission Safety Regulations Order 35095 is expected to be amended within the year 2022 to incorporate by reference the pipeline safety
Code of Federal Regulations to the most current eCFR editions.
6 State Adoption of Part 198 State One-Call Damage Prevention Program
a. Mandatory coverage of areas having pipeline facilities 04/1990 Adopted
Note1
b. Qualification for operation of one-call system 04/1990 Adopted
Note1
c. Mandatory excavator notification of one-call center 09/1990 Adopted
Note1
d. State determination whether calls to center are toll free 04/1991 Adopted
Note1
e. Mandatory intrastate pipeline operator participation 04/1990 Adopted
Note1
f. Mandatory operator response to notification 04/1990 Adopted
Note1
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g. Mandatory notification of excavators/public 07/2002 Adopted
Note1
h. Civil penalties/injunctive relief substantially same as DOT 07/2018 Adopted but Different Dollar Amounts
Note1 Current law provides for $1,000 penalty for second occurance; $5,000 for any subsequent occurrences.
1If Adoption Status is No, Please provide an explanation
State Attendance at 2021 NAPSR Regional Meeting:Attended full time (Lead rep or alternative pipeline staff)
Frequency of General Legislative Session:Annually
Attachment 8 NotesCommission Safety Regulations Order 35095 (July, 2021) is expected to be amended within the year 2022 to incorporate by reference the Title 49 pipeline safety Code
of Federal Regulations to the most current eCFR editions.
Commission Safety Regulations Order 35095 is expected to be amended within the year 2022 to incorporate by reference the pipeline safety Code of Federal
Regulations to the most current eCFR editions.

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 11 person board but does not have any directive authority over it.
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Attachment 10 - Performance and Damage Prevention Questions

CALENDAR YEAR (CY) 2021
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. The Commission has added a
new operator into their inspection plan. The Commission's inspection staff will continue conducting construction inspections, follow-
up inspections of the high-pressure service sets (HPSS/farm taps) and will continue to attend the construction of the renewable natural
gas pipelines. The Commission's goal is to get a new inspector hired to begin the TQ learning path and be able to lead basic
inspections with the long term goal of maintaining a full inspection staff.
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. Any deficiencies found were documented and discussed with the operators for corrective action(s). Follow-up inspections were performed as required. IPUC inspectors completed 13 T&Q courses in 2021. The PUC's program manager vacated the position but was replaced with one of the existing PUC inspectors. The PUC is attempting to hire a third inspector 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 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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