Pipeline Safety Progress Report 2014.pdf

1200 New Jersey Avenue SE
Washington DC 20590
U S Department A thderal agency may not conduct or sponsor,and a person is not required to respond to,nor shall a person be subject to a penalty forfailuretocomplywithacoltectionofinformationsuhecttotherequirementsofthePaperworkReductionActunlessthatcollectionofofTransportationsibrusationdisplaysacurrenta1id0MBControlNumber.The 0MB Control Number tbrthis 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
M t s f t reviewing instructions,gathering the data needed,and completing and reviewing the collection of information.All responses to thisaeriasaeYcollectionofinformationaremandatory.Send comments regarding this burden estimate or any other aspect of this collection ofAdmrnistrationinformation,including suggestions for reducing this burden to.Information Collection Clearance Otlicer,Pipeline and Hazardous
\tatenals Safety Administration PHMSA),PHP-30.1200 New Jersey Ave SE.Washington,DC.20590
Pipeline Safety
2014 Natural Gas Base Grant Progress Report
for
IDAHO PUBLIC UTILITIES COMMISSION
Please follow the directions listed below:
I.Review the entire document for completeness.
2.Review and have an authorized signatory sign and date page 2.
3.Fasten all pages with a paper or binder clip -no staples please as this package will be scanned upon it’s
arrival at PHMSA.
4.Mail the entire document,including this cover page to the following:
ATTN:Gwendolyn M.Hill
U.S.Department of Transportation
Pipeline &Hazardous Materials Safety Administration
Pipeline Safety,PHP-50
1200 New Jersey Avenue,SE Second Floor E22-321
Washington,D.C.20590
FedSTAR Information
Electronic Submission Date:224i2O IS 1:34:03 Pry!
DUNS:02589939 io.si4 \iurai Go 5s Gram Proarass Sopori [D’riSO PUBLiC uriLiTiEs QOiiiSSiON.Pose i
Pipeline and Hazardous Materials Safety Administration
1200 New Jersey Avenue,SE
Washington DC 20590
OFFICE OF PIPELINE SAFETY
2014 Natural Gas Base Grant Progress Report
Omce:IDAHO PUBLIC UTILITIES COMJVIISSION
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PROGRESS REPORT ATTACHMENTS (NATURAL GAS)
PI-IMSA Form No.PHMSA F 999-92
INSTRUCTIONS:
These attachments request information either for the entire calendar year (CY 2014:January 1 through December 31.
2014)or as of (or on)December 31,2014.Please report actual as opposed to estimated numbers on the attachments.Be
careful to provide complete and accurate information since the PI-IMSA 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.Ifthe 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/60 106 in the column designated Yes.[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 2.1
•Attachment 2:Total State Field Inspection Activity.Requires the state to indicate by operator type the number
of inspection person-days spent during CY 2014 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 onsite 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 onsite 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.
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—•Attachment 3:Facility Subject to State Safety Jurisdiction.States should only list the facilities that are
jurisdictional under Parts 192 and 193 (Natural 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 3 1.2014.A iso indicate the operator type (e.g.,intrastate
transmission)consistent with the listing in Attachment I and include the number of inspection units in each
operator’s system.The operator identification number (OPID)assigned by PHMSA must also be included on this
attachment.
—•Attachment 4:Pipeline Incidents.Requires a list ot 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.Please also make an effort to clearly identify 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 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.Please provide a summary of incident
investigations.
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:r14 ‘,iural (s 8as Grant Prortress Rpcri DAHO PF3LIC J fILITTES (OMISSON.‘rae 3
•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 2014.If an employee
has not been in the pipeline safety program the full year of 2014.please note the number of months working on the
program.Indicate a Qualification Category for each of the states 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 ofTraining and Qualifications in Oklahoma City,OK.
Finally,provide in summary form the number of all staff (supervisors,inspectors/investigator,damage preventionl
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 sate (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 of $200,000 per day up to $2,000,000 for a related series of violations please indicate
civil penalty levels in effect in the state as of December 31.2014.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 operato?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 natural 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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DUNS 02589939 dahoSaidNaturalGauBaseGrantProgressRepooIDAHOPUBLICUTTLITESCOMMISSIONPa5e5
Attachment 1 -Stats on Operators
STATE JURISDICTION AND AGENT STATUS OVER NATURAL GAS FACILITIES AS
OF DECEMBER 31,2014
No.of;tate Agency Jurisdiction!No.of Operators Inspection Units InspectedOperatorType\gent Status Operators Inspected Units
Not I Yes
Distribution
Private X1’60105 1 3 3 100.0/o 10 10 100.0%
Municipal A 0 0 N/A 0 0 N/A
Master Meter X/60 105 0 0 N/A 0 0 N’A
LPG X/60 105 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
Interstate F 0 0 N/A 0 0 N/A
Intrastate X/60105 I I 100.0%1 I 100.0%
Other
Gathering Lines X/60 105 0 0 N/A
1
0 0 N/A
Offshore Facilities A 0 0 N/A 0 0 N/A
Total 6 6 lO0.0°/13 13 100.0%,
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
authority over some,but not all of this operator type and do not have a 60106 agreement with PI-IMSA to inspect
them).These operators are identified in the notes below.
XiIA -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:
I)The Idaho State Pipeline safety program is in the process of locating Master Meter Operators for inclussion into the
DUNS:02589939 IJtho
2I4 Natural Gas Base Gram Prnress Report IDAHO PLBLIC UTILITIES COMMISSION.Be
commissions pipeline safe program.2)To date we have not located any LPG distributjo operators in Idaho,however,if
and when any of these LPG operators arise we will have jurisdiction and add them into the program.
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Attachment 4 -Incidents/Accidents
SIGNIFICANT4 NATURAL GAS INCIDENTS/ACCIDENTS JANUARY 1,THROUGH DECEMBER 31,2014
Date of Location -Injuries Fatalities Property Cause
Incident City/County/etc.##Damage3 Codet
$
12/18/2014 LNG Plant Nampa,Idaho 0 0 $100,000.00 S
Name of Operator:Intermountain Gas Company
Cause Reported by Operator (Describe)2
A weld on one of the tubes within the Economizer failed (pulled apart)leaking approximatly 600 psig
methane gas into an enclosed area of the Economizer resulting in damage to the top and side of the
box portion of the Economizer.The methane gas also was leaking into the hot exhaust of the turbine
engine.The Economizer is not salvagable and a new Economizer will arrive at the end of March 2015
and installed.The LNG plant is shut down until then.
‘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
2Please attach a summary or report of the state agency’s investigation of each of the above incidents.
3lnterstate agents should use the 191.3 Incident definition for listing incidents investigated on interstate facilities.
4Significant:Investigated by or reported to the state agency,involving personal injury requiring hospitalization,
fatality,property damage exceeding $50,000 and other incidents otherwise considered significant which involved
jurisdictional facilities.
Attachment 4 Notes
a
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DUNS O2589)39
24 NwraI Gas 3ase Gsa,,,Prossress Report OSHO PUBLIC UTILITIES COMMISSION.Page I
Attachment 5 -Stats on Compliance Actions
STATE COMPLIANCE ACTIONS --CALENDAR YEAR (CY)2014
Probable Violation Categories Intrastate Interstate
Number Carried over from previous CY (including 5 0carryoverandlongterm)
Number Found During CY 6 0
Number submitted for DOT action [60106 Agreement agent 0 0only)
Number corrected during CY (including carry over from 8 0previousyear)
Number to be corrected at end ofCY (including carry over ,0
and long-term)
Number of Compliance Actions Taken’
(see detThition)6
Civil Penalties
umber 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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DUNS:02589939
j4 qwrsi Gas 3as,Grant Progress Report IDAHO PUBLIC UTILITIES COM SSIONPsge 2
Attachment 6 -List of Records Kept
NATURAL GAS STATE RECORD MAINTENANCE AND REPORTING DURING CY
2014
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
One-call Campaign
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 2009,2010.201 1,2012,2013,2014
Reports Required from Operators
Incident Reports as per IPUC rule
Operators Annual Report
Attachment 6 Notes
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i
n
i
t
i
o
n
of
a
Tr
a
n
s
m
i
s
s
i
o
n
Li
n
e
9/
4
/
2
0
0
3
10
/
1
5
/
2
0
0
3
5/
6
/
2
0
0
5
N/
A
95 No
t
e
’
04
/
2
0
0
4
Ad
o
p
t
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d
04
/
2
0
0
5
Ad
o
p
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5/
2
6
,
2
0
0
4
Pi
p
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l
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n
e
in
t
e
g
r
i
t
y
ma
n
a
g
e
m
e
n
t
fo
r
tr
a
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s
m
i
s
s
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o
n
li
n
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s
in
HC
A
s
04
/
2
0
0
5
Ad
o
p
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L)
A
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(
J
PL
H
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li
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ZL
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O
M
M
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S
S
U
J
N
r4
1
96 No
t
e
’
97 No
t
e
’
98 No
t
e
’
99 No
t
e
’
10
0
No
t
e
’
10
1
No
t
e
’
10
2
No
t
e
’
—
10
3
—
No
t
e
—
10
3
a
No
t
e
’
—
72
F
R
’
0
0
5
5
=
No
t
e
10
4
—
No
t
e —
=
10
5
No
t
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’
PI
I
N
I
S
A
F
)9
)
-
5
DU
N
S
:
W2
5
8
9
9
3
9
20
1
4
Na
l
o
r
a
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Ga
s
Ba
s
e
Gr
a
s
s
,
Pr
o
os
s
Ro
p
o
s
,
9/
1
4
/
2
0
0
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7/
2
8
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2
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0
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/
2
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5
Ad
o
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d
04
/
2
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5
Ad
o
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Pr
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s
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m
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d
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g
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a
t
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Pa
s
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of
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9/
9
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0
4
Pe
r
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m
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of
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d
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d
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r
w
a
t
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s
p
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t
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s
6/
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2
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5
AP
I
RP
11
6
2
Pu
b
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m
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7/
1
5
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2
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0
5
PS
I
A
St
a
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a
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Op
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Ad
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7/
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2
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0
6
In
c
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by
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St
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2/
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2
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0
7
Up
d
a
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c
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by
Re
f
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d
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De
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In
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12
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8
Ad
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Id
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1
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PU
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16
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10
7
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FR
62
1
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7
No
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10
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79
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10
9
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FR
28
8
9
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11
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17
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11
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FR
62
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11
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63
3
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=
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—
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No
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11
5
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75
FR
72
6
7
8
—
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11
6
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6
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4
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N
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,
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d
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(7
3
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16
5
6
2
)
St
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)
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-
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(7
3
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79
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Up
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Up
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:
A
m
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Up
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12
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11
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4/
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9
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17
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6
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35
1
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1
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04
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1
3
Ad
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d
No
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’
1
18
-
78
FR
58
8
9
7
9/
2
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2
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l
3
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Up
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No
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Di
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th
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20
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6
4
Pa
r
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19
3
Am
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p
p
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7
Pr
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20
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20
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Ad
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d
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8
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9
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4
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st
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04
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5
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19
7/
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2
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6
In
c
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s
04
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2
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8
Ad
o
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e
d
No
t
e
’
20
-
7
3
FR
16
5
6
2
3/
2
8
/
2
0
0
8
Ad
m
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s
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s
(7
3
04
/
2
0
10
Ad
o
p
t
e
d
No
t
e
’
21
-
7
4
FR
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Attachment 10 -Performance and Damage Prevention Questions
CALENDAR YEAR (CY)2014
Planned Performance:What are your Planned Annual and Iong-term goals for your Pipeline Safety Program?
The commissions Pipeline Safety Program long term goals for 2015 and beyond are to further grow the program by bring in Master
Meter operators into the pipeline safety program.Identified Master Meter operators will be educated on the requirements of Part 192
and tracked for inclussion into the commissions inspection program later in the year.Another area of focus for 2015 is operator (High
Pressure Service Sets)farm taps.We have scheduled several weeks in 2015 to inspect these farm taps for general condition,corrosion
and damage.Here at the commission we feel that due to the large number of these Irm taps (7.000±)in our system they could
possibly be lacking the required attention need to keep them safe with the required inspection intervals being several years apart.Our
short term goal is to continue inspecting/auditing our three interstate operators annually and follow-up on each non-compliance noted.
During the 2014 cycle we were able to hire a FTE for pipeline safety and once qualified we will be able to assign this employee
specific areas of pipeline safety to be the commissions expert.
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?
The commissions Pipeline Safety section was able to inspect all three intrastate operators records and field units during the 2014
inspection cycle.Control Room management inspection/audits were performed on all Idaho intrastate operators with one inspection
being ajoint inspection with Oregon and Washington.Our new ETE hired in 2014 has completed his PL 1250 course in Oklahoma
City and in 2014 attended most inspections with a commission qualified inspector.We have been able to use this new FTE as our
Master meter point-of-contact and we will continue to have him focus on locating master meter operators and conducting initial
education of these operators to bring them into the commissions safety program.
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 maintained membership in a local damage prevention coalition through out 2014.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.This new legislation is being
introduced and presented during the 2015 legislative session as House Bill 118.
Attachment 10 Notes
DUNS:02589939 Idaha
,I-4 issa Gas 5as Gsanl Progress Rporl DHO P1BLIQ UGLIGES (Q4MI5SIQN Pase:24