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pdf1200 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 Expires: mm/dd/yyyy
Pipeline Safety
20xx Gas Base Grant Progress Report
for
{state agency name}
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 [email protected].
FedSTAR Information
Electronic Submission Date:
DUNS:
Gas Base Grant Progress Report
Page: 1
Pipeline and Hazardous Materials Safety Administration
1200 New Jersey Avenue, SE
Washington DC 20590
OFFICE OF PIPELINE SAFETY
20xx Gas Base Grant Progress Report
Office:
{state agency name}
Authorized Signature
Printed Name
Title
Date
DUNS:
Gas Base Grant Progress Report
Page: 2
PROGRESS REPORT ATTACHMENTS (GAS )
PHMSA Form No. PHMSA F 999-92
INSTRUCTIONS:
These attachments request information either for the entire calendar year (CY 20xx: January 1 through December 31,
20xx) or as of (or on) December 31, 20xx. 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 20xx 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.
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DUNS:
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, 20xx. 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
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.
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.
Gas Base Grant Progress Report
Page: 3
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DUNS:
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 20xx. If an employee
has not been in the pipeline safety program the full year of 20xx, 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.
Gas Base Grant Progress Report
Page: 4
DEFINITIONS
.
.
.
.
DUNS:
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 jobsite 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.
Gas Base Grant Progress Report
Page: 5
Attachment 1 - Stats on Operators
STATE JURISDICTION AND AGENT STATUS OVER GAS FACILITIES
AS OF DECEMBER 31, 20xx
Operator Type
State Agency Jurisdiction/
Agent Status
No1
No. of
Operators
Yes
Operators
Inspected
#
%
No. of
Inspection
Units
Units Inspected
#
%
Distribution
Private
Municipal
Master Meter
LPG
Other
Transmission
Intrastate
Interstate
LNG
Intrastate
Interstate
Other
Gathering Lines
Offshore Facilities
Total
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)
1
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:
DUNS
Gas Base Grant Progress Report
Page: 6
Attachment 2 - State Inspection Activity
TOTAL STATE FIELD INSPECTION ACTIVITY
AS OF DECEMBER 31, 20xx
Operator Type
Design,
Standard
Testing and
Comprehensive
Construction
On-Site
Operator
Training
Investigating Damage
Integrity
Operator
Compliance
Incidents or Prevention
Management Qualification
Follow-up
Accidents
Activities
Total
Distribution
Private
Municipal
Master Meter
LPG
Other
Transmission
Intrastate
Interstate
LNG
Intrastate
Interstate
Other
Gathering Lines
Offshore Facilities
Total
Drug and Alcohol
Total Count of Drug and Alcohol Inspections
Attachment 2 Notes
DUNS:
Gas Base Grant Progress Report
Page: 7
Attachment 3 - List of Operators
GAS FACILITIES SUBJECT TO STATE SAFETY JURISDICTION AS OF DECEMBER 31, 20xx
Operator
Business Name
Operator ID
Address
DUNS:
Gas Base Grant Progress Report
Distribution
(Operator type & Inspection Units)
Transmission
(Operator type &
Inspection Units)
LNG(Operator type & Other (Operator type
Inspection Units)
& Inspection Units)
Offshore
Gathering Facilities
Private Municipal Master LPG Other Intrastate Interstate Intrastate Interstate Lines (Juris- (State
Meter
dictional) Waters)
Page: 8
Distribution
(Operator type & Inspection Units)
Inspection Unit totals by type
Transmission
(Operator type &
Inspection Units)
LNG(Operator type & Other (Operator type
Inspection Units)
& Inspection Units)
Offshore
Gathering Facilities
Private Municipal Master LPG Other Intrastate Interstate Intrastate Interstate Lines (Juris- (State
dictional) Waters)
Meter
Total Operators
Attachment 3 Notes:
DUNS: 8
Gas Base Grant Progress Report
Page: 15
Attachment 4 - Incidents/Accidents
SIGNIFICANT4 GAS INCIDENTS/ACCIDENTS JANUARY 1, THROUGH DECEMBER 31, 20xx
Date of
Incident
Location City/County/etc.
System Injuries FatalitiesProperty
#
#
Damage3
Type
$
Cause
Code1
State
Cause
Code1
Name of Operator:
Operator ID:
Report No:
Summary
2
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;
1
Please provide a brief summary of the incident.
2
Interstate agents should use the 191.3 Incident definition for listing incidents investigated on interstate facilities.
3
Significant: 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.
4
Attachment 4 Notes
DUNS:
Gas Base Grant Progress Report
Page: 16
Attachment 5 - Stats on Compliance Actions
STATE COMPLIANCE ACTIONS -- CALENDAR YEAR (CY) 20xx
Probable Violation Categories
Intrastate
Interstate
Number carried over from all previous CY's
Number Found During CY
Number submitted for DOT action [60106 Agreement agent
only]
Number corrected during CY (including carry over from
previous year(s))
Number to be corrected at end of CY (including carry over)
Number of Compliance Actions Taken 1
(see definition)
Civil Penalties
Number assessed during CY
Dollars assessed during CY
Number collected during CY
Dollars collected during CY
Do not double count for a related series of actions.
1
Attachment 5 Notes
DUNS:
Gas Base Grant Progress Report
Page: 17
Attachment 6 - List of Records Kept
GAS STATE RECORD MAINTENANCE AND REPORTING DURING CY 20xx
Records Maintained by the State Agency
Reports Required from Operators
Attachment 6 Notes
DUNS:
Gas Base Grant Progress Report
Page: 18
Attachment 7 - Staffing and TQ Training
STATE EMPLOYEES DIRECTLY INVOLVED IN THE GAS
PIPELINE SAFETY PROGRAM DURING CY 20xx
Name/Title
%
Time
#
Qual.
Months Cat.
Supervisor
Inspector/Investigator
Damage Prevention/Technical
Clerical/Administrative
DUNS:
Gas Base Grant Progress Report
Page: 19
Summary
Employee Type
No. of Staff
Supervisor
Inspectors/Investigators
Damage Prevention/Technical
Clerical/Administrative
Total
Last Name
First Name
Person-Years
Course
Completion
Date
Attachment 7 Notes
DUNS:
Gas Base Grant Progress Report
Page: 21
Attachment 8 - Compliance with Federal Regulations
STATE COMPLIANCE WITH FEDERAL REQUIREMENTS AS OF DECEMBER 31, 20xx
Effective
Date
No.
Impact
Adoption
AdoptionStatus
Date
Maximum Penalties Substantially same as DOT ($213,268/@2,132,268). State
must adopt minimum penalties of at least ($100,000/$1,000,000). Indicate actual 08/2008
1
Note1
191.23 and 191.25 Safety-Related Conditions(through current amendment
191-14)
2
Note1
3
Part 192 Amendments
01-90
Pre 2002
Note
N
91
4/23/2004
Definition of high consequnce areas for gas transmission lines
9/4/2003
Procedures for Producer-operated outer continental shelf natural
pipelines that cross directly into state waters
10/15/2003
various changes to gas pipeline safety standards from NAPSR
recommendations
1
[All applicable amendments prior to and including 2002]
Note
1
92
Note1
93
Note1
DUNS:
Gas Base Grant Progress Report
Page: 22
94
5/6/2005
Modification to the definition of a Transmission Line
5/26/2004
Pipeline integrity management for transmission lines in HCAs
9/14/2004
Pressure limiting and regulating stations
7/28/2004
Passage of internal inspection devices on new and retrofitted
transmission pipelines
9/9/2004
Performance of periodic underwater inspections
6/20/2005
API RP 1162 Public awareness campaign
7/15/2005
PSIA Statuory changes to Operator Qualification Program
11/25/2005
Adoption of NACE Standard as a direct assesment standard
4/14/2006
Definition of a Gathering Line
7/10/2006
Incorporate by Reference various Standards
2/1/2007
Update Incorporated by Reference and Corrrection
4/23/2007
Design and Construction Standards to Reduce Internal Corrosion in
Gas Transmission Pipelines
Note
1
95
Note1
96
Note1
97
Note1
98
Note
1
99
Note
1
100
Note1
101
Note1
102
Note1
103
Note1
103a
Note
1
72 FR 20055
Note1
DUNS:
Gas Base Grant Progress Report
Page: 23
104
5/23/2007
Integrity Management Program Modifications and Clarifications
12/13/2007
Applicability of Public Awareness Regulations to Certain Gas
Distribution Operators
3/28/2008
Administrative Procedures, Updates and Technical Amendments (73
FR 16562)
10/17/2008
Standards for Increasing the Maximum Allowable Operating Pressure
for Gas Transmission Pipelines (73 FR 62147)
12/24/2008
PA-11 Design Pressures (73 FR 79005)
1/16/2009
Administrative Procedures, Address Updates , and Technical
Amendments
4/14/2009
Incorporation by Reference Update:American Petroleum Institute
(API) Standards 5L and 1104
11/30/2009
Editorial Amendments to Pipeline Safety Regulations
12/3/2009
Control Room Management/Human Factors
12/4/2009
Integrity Management Program for Gas Distribution Pipelines
Note
1
105
Note1
106-73 FR 16562
Note1
107-73 FR 62147
Note1
108-73 FR 79002
Note
1
109-74 FR 2889
Note1
110-74 FR 17099
Note1
111-74 FR 62503
Note1
112-74 FR 63310
Note
1
113-74 FR 63906
Note
1
114 - 75 FR 48593 8/11/2010
Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits
Note1
DUNS:
Gas Base Grant Progress Report
Page: 24
115 - 75 FR 72878 11/26/2010
Updates to Pipeline and Liquefied Gas Reporting Requirements
Note
1
116 - 76 FR 5494
4/4/2011
Note1
.
117-76 FR 35130
8/15/2011
Mechanical Fitting Failure Reporting Requirements
Control Room Management/Human Factors
Note1
118 - 78 FR 58897 9/28/2013
Administrative Procedures, Updates, and Technical Corrections (Not
applicable to States)
Note1
119 - 80 FR 168
3/6/2015
Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits
Note1
120 - 80 FR 12779 10/1/2015
Miscellaneous Changes to Pipeline Safety Regulations (Part 192.305
DELAYED)
Note1
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
Note1
122 - 82 FR 7972
3/24/2017
Operator Qualification, Cost Recovery, Accident and Incident
Notification, and Other Pipeline Safety Changes
Note1
4
Part 193 Amendments (applicable only where state has jurisdiction over LNG)
01-17
Pre 2002
[All applicable amendments prior to and including 2002]
18
4/9/2004
Updated LNG standards by section
Note1
.
19
7/10/2006
Note
1
Incorporate by Reference various Standards
Note1
DUNS:
Gas Base Grant Progress Report
Page: 25
20-73 FR 16562
3/28/2008
Administrative Procedures, Updates and Technical Amendments (73
FR 16562)
1/16/2009
Administrative Procedures , Address Updates and Technical
Amendments
8/11/2010
Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits
11/26/2010
Updates to Pipeline and Liquefied Gas Reporting Requirements
9/28/2013
Administrative Procedures, Updates, and Technical Corrections
3/6/2015
Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits
Note1
21-74 FR 2889
Note1
22 - 75 FR 48593
Note1
23 - 75 FR 72878
Note
1
24 - 78 FR 58897
Note
1
25 - 80 FR 168
Note1
5
Part 199 - Drug Testing
Note
1
6
Part 199 Amendments
01-19
Pre 2002
[All applicable amendments prior to and including 2002]
3/12/2003
Definition of Administrator
12/31/2003
Instructions for Single Use Form for MIS
7/14/2004
New address for reporting
Note1
20
Note1
21
Note
1
22
Note
1
DUNS:
Gas Base Grant Progress Report
Page: 26
23
3/8/2005
Administration name change
3/28/2008
Administrative Procedures, Updates and Technical Amendments (73
FR 16562)
9/28/2013
Administrative Procedures, Updates, and Technical Corrections
3/6/2015
Periodic Updates of Regulatory References to Technical Standards and
Miscellaneous Edits
3/24/2017
Operator Qualification, Cost Recovery, Accident and Incident
Notification, and Other Pipeline Safety Changes
Note
1
24-73 FR 16562
Note1
25 - 78 FR58897
Note
1
26 - 80 FR 168
Note1
27 - 82 FR 7972
Note1
7
State Adoption of Part 198 State One-Call Damage Prevention Program
a.
Mandatory coverage of areas having pipeline facilities
Note
1
b.
Qualification for operation of one-call system
Note
1
c.
Mandatory excavator notification of one-call center
Note
1
d.
State determination whether calls to center are toll free
Note
1
e.
Mandatory intrastate pipeline operator participation
Note
1
f.
Mandatory operator response to notification
Note1
DUNS:
Gas Base Grant Progress Report
Page: 27
g.
Mandatory notification of excavators/public
Note
1
h.
Civil penalties/injunctive relief substantially same as DOT
Note1
If Adoption Status is No, Please provide an explanation
State Attendance at 2018 NAPSR Regional Meeting:
Frequency of General Legislative Session: Annually
1
Attachment 8 Notes
DUNS:
Gas Base Grant Progress Report
Page: 28
Attachment 10 - Performance and Damage Prevention Questions
CALENDAR YEAR (CY) 20xx
Planned Performance: What are your Planned Annual and Long-term goals for your Pipeline Safety Program?
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?
1. Has the state or agency reviewed the Damage Prevention Assistance Program (DPAP) document in the last twelve months?
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?
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.
Attachment 10 Notes
DUNS:
Gas Base Grant Progress Report
Page: 29
| File Type | application/pdf |
| File Modified | 2019-02-05 |
| File Created | 2018-12-03 |