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pdfNotice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
U.S. Department of Transportation
Pipeline and Hazardous Materials
Safety Administration
ANNUAL REPORT FOR CALENDAR YEAR 20___
NATURAL OR OTHER GAS TRANSMISSION and
GATHERING SYSTEMS
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
INITIAL REPORT
SUPPLEMENTAL REPORT
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 2137-0522. Public reporting for this collection
of information is estimated to be approximately 22 hours per response,PIPELINE
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, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.
Important: Please read the separate instructions for completeing this form before you begin.
PART A - OPERATOR INFORMATION
DOT USE ONLY
1. OPERATOR’S 5 DIGIT IDENTIFICATION NUMBER (OPID)
2. NAME OF COMPANY OR ESTABLISHMENT:
/
/
/
/
/
/
IF SUBSIDIARY, NAME OF PARENT:
__________________________________________________
3. INDIVIDUAL WHERE ADDITIONAL INFORMATION MAY BE
OBTAINED:
4. HEADQUARTERS ADDRESS:
Name
Company Name
Title
Street Address
__________________________________________________
Email Address
State: /
/
/ Zip Code: /
/
/__/__/__/-/__/__/__/-/__/__/__/__/
/__/__/__/-/__/__/__/-/__/__/__/__/
Telephone Number
Telephone Number
/
/
/
/ - /
/
/
/
/
5. THIS REPORT PERTAINS TO THE FOLLOWING COMMODITY GROUP: (Select Commodity Group based on the predominant gas carried
and complete the report for that Commodity Group. File a separate report for each Commodity Group included in this OPID.)
Natural Gas
Synthetic Gas
Hydrogen Gas
Propane Gas
Other Gas Name of Other Gas ___________________
6. CHARACTERIZE THE PIPELINES AND/OR PIPELINE FACILITIES COVERED BY THIS OPID AND COMMODITY GROUP WITH
RESPECT TO COMPLIANCE WITH PHMSA’S INTEGRITY MANAGEMENT PROGRAM REGULATIONS (49 CFR 192 Subpart O). (Select
only one)
L and
NO portions of the pipelines and/or pipeline facilities covered by this OPID and Commodity
Group are included in an Integrity Management Program subject to 49 CFR 192. If this box is
checked, leave PARTs B, F, G, and the “HCA” portions of M1 blank, but complete all remaining
PARTs of this form in accordance with PART A, Question 8.
Portions of SOME OR ALL of the pipelines and/or pipeline facilities covered by this OPID and
Commodity Group are included in an Integrity Management Program subject to 49 CFR 192. If
this box is checked, complete all PARTs of this form in accordance with PART A, Question 8.
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 1 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
7. FOR THE DESIGNATED “COMMODITY GROUP”, THE PIPELINES AND/OR PIPELINE FACILITIES INCLUDED WITHIN THIS OPID
ARE: (Select one or both)
INTERstate pipeline List all of the States in which INTERstate pipelines and/or pipeline
facilities included under this OPID exist: __, __, __, __, __, etc.
INTRAstate pipeline List all of the States in which INTRAstate pipelines and/or pipeline
facilities included under this OPID exist: __, __, __, __, __, etc.
8. DOES THIS REPORT REPRESENT A CHANGE FROM LAST YEAR’S FINAL REPORTED NUMBERS FOR ONE OR MORE OF THE
FOLLOWING PARTs: PART B, D, E, H, I, J, K, or L? (For calendar year 2010 reporting or if this is a first-time Report for an operator or
OPID, Commodity Group(s), or pipelines and/or pipeline facilities, select the first box only. For subsequent years’ reporting, select either No or
one or both of the Yes choices.)
This report is FOR CALENDAR YEAR 2010 reporting or is a FIRST-TIME REPORT and,
therefore, the remaining choices in this Question 8 do not apply. Complete all remaining
PARTS of this form as applicable.
NO, there are NO CHANGES from last year’s final reported information for PARTs B, D, E,
H, I, J, K, or L. Complete PARTs A, C, M, and N, along with PARTs F, G, and O when
applicable.
YES, this report represents a CHANGE FROM LAST YEAR’S FINAL REPORTED
INFORMATION for one or more of PARTs B, D, E, H, I, J, K, or L due to corrected
information; however, the pipelines and/or pipeline facilities and operations are the same as
those which were covered under last year’s report. Complete PARTs A, C, M, and N, along
with only those other PARTs which changed (including PARTs B, F, G, and O when applicable).
YES, this report represents a CHANGE FROM LAST YEAR’S FINAL REPORTED
INFORMATION for PARTs B, D, E, H, I, J, K, or L because of one or more of the following
change(s) in pipelines and/or pipeline facilities and/or operations from those which were
covered under last year’s report. Complete PARTs A, C, M, and N, along with only those other
PARTs which changed (including PARTs B, F, G, and O when applicable). (Select all reasons
for these changes from the following list)
Merger of companies and/or operations, acquisition of pipelines and/or
pipeline facilities
Divestiture of pipelines and/or pipeline facilities
New construction or new installation of pipelines and/or pipeline facilities
Conversion to service, change in commodity transported, or change in MAOP
(maximum allowable operating pressure).
Abandonment of existing pipelines and/or pipeline facilities
Change in HCA’s identified, HCA Segments, or other changes to Operator’s
Integrity Management Program
Change in OPID
Other Describe: _____________________________________________
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 2 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
For the designated Commodity Group, complete PARTs B, C, D, and E one time for all pipelines and/or
pipeline facilities – both INTERstate and INTRAstate - included within this OPID.
PART B – TRANSMISSION PIPELINE HCA MILES
Number of HCA Miles
in the IMP Program
Onshore
Offshore
Total Miles
Calc
PART C - VOLUME TRANSPORTED IN TRANSMISSION
PIPELINES (ONLY) IN MILLION SCF PER YEAR
(excludesTransmission lines of Gas Distribution systems)
Check this box and proceed to PART D without completing this
PART C if this report only includes gathering pipelines or transmission
lines of gas distribution systems.
Onshore
Offshore
Natural Gas
Propane Gas
Synthetic Gas
Hydrogen Gas
Other Gas Name: ____________________
PART D - MILES OF STEEL PIPE BY CORROSION PROTECTION
Cathodically protected
Bare
Coated
Cathodically unprotected
Bare
Coated
Transmission
Onshore
Offshore
Subtotal Transmission
Total Miles
Calc
Calc
Calc
Calc
Calc
Calc
Gathering
Onshore Type A
Onshore Type B
Offshore
Calc
Calc
Calc
Calc
Subtotal Gathering
Calc
Calc
Calc
Calc
Calc
Total Miles
Calc
Calc
Calc
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 3 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART E - MILES OF non-STEEL PIPE BY TYPE AND LOCATION
Cast Iron
Pipe
Wrought Iron Pipe
Plastic Pipe
Other Pipe
Total Miles
Transmission
Onshore
Calc
Offshore
Calc
Subtotal Transmission
Calc
Calc
Calc
Calc
Gathering
Onshore Type A
Onshore Type B
Offshore
Calc
Calc
Calc
Calc
Subtotal Gathering
Calc
Calc
Calc
Calc
Calc
Total Miles
Calc
Calc
Calc
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 4 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
For the designated Commodity Group, complete PARTs F and G one time for all INTERstate pipelines
and/or pipeline facilities included within this OPID and multiple times as needed for the designated
Commodity Group for each State in which INTRAstate pipelines and/or pipeline facilities included within
this OPID exist. Each time these sections are completed, designate the State to which the data applies for
INTRAstate pipelines and/or pipeline facilities, or that it applies to all INTERstate pipelines included within
this Commodity Group and OPID.
PARTs F and G
The data reported in these PARTs F and G applies to: (select only one)
Interstate pipelines/pipeline facilities
Intrastate pipelines/pipeline facilities in the State of /__/__/ (complete for each State)
PART F - INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN BASED ON INSPECTION
1. MILEAGE INSPECTED IN CALENDAR YEAR USING THE FOLLOWING IN-LINE INSPECTION (ILI) TOOLS
a. Corrosion or metal loss tools
b. Dent or deformation tools
c. Crack or long seam defect detection tools
d. Any other internal inspection tools
e. Total tool mileage inspected in calendar year using in-line inspection tools. (Lines a + b + c + d )
Calc
2. ACTIONS TAKEN IN CALENDAR YEAR BASED ON IN-LINE INSPECTIONS
a. Based on ILI data, total number of anomalies excavated in calendar year because they met the operator’s
criteria for excavation.
b. Total number of anomalies repaired in calendar year that were identified by ILI based on the operator’s criteria,
both within an HCA Segment and outside of an HCA Segment.
c. Total number of conditions repaired WITHIN AN HCA SEGMENT meeting the definition of:
Calc
1. “Immediate repair conditions” [192.933(d)(1)]
2. “One-year conditions” [192.933(d)(2)]
3. “Monitored conditions” [192.933(d)(3)]
4. Other “Scheduled conditions” [192.933(c)]
3. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON PRESSURE TESTING
a. Total mileage inspected by pressure testing in calendar year.
b. Total number of pressure test failures (ruptures and leaks) repaired in calendar year, both within an HCA
Segment and outside of an HCA Segment.
c. Total number of pressure test ruptures (complete failure of pipe wall) repaired in calendar year WITHIN AN HCA
SEGMENT.
d. Total number of pressure test leaks (less than complete wall failure but including escape of test medium)
repaired in calendar year WITHIN AN HCA SEGMENT.
(PART F continued)
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 5 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
4. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON DA (Direct Assessment methods)
a. Total mileage inspected by each DA method in calendar year.
Calc
1. ECDA
2. ICDA
3. SCCDA
b. Total number of anomalies identified by each DA method and repaired in calendar year based on the operator’s
criteria, both within an HCA Segment and outside of an HCA Segment.
Calc
1. ECDA
2. ICDA
3. SCCDA
c. Total number of conditions repaired in calendar year WITHIN AN HCA SEGMENT meeting the definition of:
Calc
1. “Immediate repair conditions” [192.933(d)(1)]
2. “One-year conditions” [192.933(d)(2)]
3. “Monitored conditions” [192.933(d)(3)]
4. Other “Scheduled conditions” [192.933(c)]
5. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON OTHER INSPECTION TECHNIQUES
a. Total mileage inspected by inspection techniques other than those listed above in calendar year.
b. Total number of anomalies identified by other inspection techniques and repaired in calendar year based on the
operator’s criteria, both within an HCA Segment and outside of an HCA Segment.
c. Total number of conditions repaired in calendar year WITHIN AN HCA SEGMENT meeting the definition of:
Calc
1. “Immediate repair conditions” [192.933(d)(1)]
2. “One-year conditions” [192.933(d)(2)]
3. “Monitored conditions” [192.933(d)(3)]
4. Other “Scheduled conditions” [192.933(c)]
6. TOTAL MILEAGE INSPECTED (ALL METHODS) AND ACTIONS TAKEN IN CALENDAR YEAR
a. Total mileage inspected in calendar year. (Lines 1.e + 3.a + 4.a.1 + 4.a.2 + 4.a.3 + 5.a)
Calc
b. Total number of anomalies repaired in calendar year both within an HCA Segment and outside of an HCA
Segment. (Lines 2.b + 3.b + 4.b.1 + 4.b.2 + 4.b.3 + 5.b)
Calc
c. Total number of conditions repaired in calendar year WITHIN AN HCA SEGMENT. (Lines 2.c.1 + 2.c.2 + 2.c.3
+ 2.c.4 + 3.c + 3.d + 4.c.1 + 4.c.2 + 4.c.3 + 4.c.4 + 5.c.1 + 5.c.2 + 5.c.3 + 5.c.4)
Calc
PART G– MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED IN CALENDAR YEAR (HCA Segment miles
ONLY)
a. Baseline assessment miles completed during the calendar year.
b. Reassessment miles completed during the calendar year.
c. Total assessment and reassessment miles completed during the calendar year.
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Calc
Pg. 6 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
For the designated Commodity Group, complete PARTs H, I, J, K, L, and M covering INTERstate pipelines
and/or pipeline facilities for each State in which INTERstate systems exist within this OPID and again
covering INTRAstate pipelines and/or pipeline facilities for each State in which INTRAstate systems exist
within this OPID.
PARTs H, I, J, K, L, and M
The data reported in these PARTs H, I, J, K, L, and M applies to: (select only one)
Interstate pipelines/pipeline facilities in the State of /__/__/ (complete for each State)
Intrastate Pipelines/pipeline facilities in the State of /__/__/ (complete for each State)
PART H - MILES OF TRANSMISSION PIPE BY NOMINAL PIPE SIZE (NPS)
NPS 4”
or less
6”
8”
10”
12”
14”
16”
18”
20”
22”
24”
26”
28”
30”
32”
34”
36”
38”
42”
44”
46”
48”
52”
56”
58” and
over
Onshore
Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc
Total Miles of Onshore Pipe - Transmission
NPS 4”
or less
6”
8”
10”
12”
14”
16”
18”
20”
22”
24”
26”
28”
30”
32”
34”
36”
38”
42”
44”
46”
48”
52”
56”
58” and
over
Offshore
Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc
Total Miles of Offshore Pipe - Transmission
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 7 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART I - MILES OF GATHERING PIPE BY NOMINAL PIPE SIZE (NPS)
Onshore
Type A
NPS 4”
or less
6”
8”
10”
12”
14”
16”
18”
20”
22”
24”
26”
28”
30”
32”
34”
36”
38”
42”
44”
46”
48”
52”
56”
58” and
over
Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc
Total Miles of Onshore Type A Pipe - Gathering
NPS 4”
or less
6”
8”
10”
12”
14”
16”
18”
20”
22”
24”
26”
28”
30”
32”
34”
36”
38”
42”
44”
46”
48”
52”
56”
58” and
over
Onshore
Type B
Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc
Total Miles of Onshore Type B Pipe - Gathering
NPS 4”
or less
6”
8”
10”
12”
14”
16”
18”
20”
22”
24”
26”
28”
30”
32”
34”
36”
38”
42”
44”
46”
48”
52”
56”
58” and
over
Offshore
Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc
Total Miles of Offshore Pipe - Gathering
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 8 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART J – MILES OF PIPE BY DECADE INSTALLED
Pre-40 or
Unknown
1940 - 1949
1950 - 1959
1960 - 1969
1970 - 1979
1980 - 1989
Calc
Calc
Calc
Calc
Calc
Calc
Subtotal Gathering
Calc
Calc
Calc
Calc
Calc
Calc
Total Miles
Calc
Calc
Calc
Calc
Calc
Calc
1990 - 1999
2000 - 2009
2010 - 2019
Decade Pipe Installed
Transmission
Onshore
Offshore
Subtotal Transmission
Gathering
Onshore Type A
Onshore Type B
Offshore
Decade Pipe Installed
Total Miles
Transmission
Onshore
Calc
Offshore
Calc
Subtotal Transmission
Calc
Calc
Calc
Calc
Gathering
Onshore Type A
Calc
Onshore Type B
Calc
Offshore
Calc
Subtotal Gathering
Calc
Calc
Calc
Calc
Total Miles
Calc
Calc
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 9 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART K- MILES OF TRANSMISSION PIPE BY SPECIFIED MINIMUM YIELD STRENGTH
CLASS LOCATION
ONSHORE
Total Miles
Class I
Class 2
Class 3
Class 4
Equal to or greater
Less than or equal to
than 20% SMYS...
20% SMYS
Greater than 20% SMYS but
Equal to or greater
less than or equal to
than 30% SMYS...
30% SMYS
Greater than 30% SMYS but
less than or equal to
40% SMYS
Greater than 40% SMYS but
less than or equal to
50% SMYS
Greater than 50% SMYS but
less than or equal to
60% SMYS
Greater than 60% SMYS but
less than or equal to
72% SMYS
Greater than 72% SMYS but
less than or equal to
80% SMYS
Greater than 80% SMYS
Calc
Calc
Calc
Calc
Calc
Calc
Calc
Calc
Unknown percent of SMYS
Calc
All Non-Steel pipe
Calc
Onshore Totals
Calc
OFFSHORE
Class I
Less than or equal to
50% SMYS
Greater than 50% SMYS but
less than or equal to
72% SMYS
Offshore Total
Calc
Total Miles
Calc
Calc
Calc
Calc
Calc
Calc
Calc
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 10 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART L - MILES OF PIPE BY CLASS LOCATION
Class Location
Class I
Class 2
Class 3
Class 4
Transmission
Onshore
Offshore
Subtotal Transmission
Gathering
Onshore Type A
Onshore Type B
Offshore
Total
Class Location
Miles
HCA Miles in
the IMP
Program
Calc
Calc
Calc
Calc
Calc
Calc
Blacked out
these cells.
Calc
Calc
Calc
Calc
Blacked out these cells.
Calc
Subtotal Gathering
Calc
Calc
Calc
Calc
Calc
Total Miles
Calc
Calc
Calc
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Calc
Pg. 11 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
PART M – INCIDENTS, FAILURES, LEAKS, AND REPAIRS
PART M1 – ALL LEAKS ELIMINATED/REPAIRED IN CALENDAR YEAR; INCIDENTS & FAILURES IN HCA SEGMENTS IN
CALENDAR YEAR
Transmission Incidents, Leaks, and Failures
Incidents
in HCA
Segments
Leaks
Onshore Leaks
HCA
Cause
External Corrosion
Internal Corrosion
Stress Corrosion
Cracking
Manufacturing
Construction
Equipment
Incorrect Operations
Third Party Damage/Mechanical Damage
Excavation Damage
Previous Damage (due
to Excavation Activity)
Vandalism (includes all
Intentional Damage)
Weather Related/Other Outside Force
Natural Force Damage
(all)
Other Outside Force
Damage (excluding
Vandalism and all
Intentional Damage)
Other
Total
Calc
Calc
Offshore Leaks
Non-HCA
HCA
Non-HCA
Calc
Calc
Calc
Gathering Leaks
Failures
in HCA
Segments
Calc
Onshore
Leaks
Type
A
Type
B
Calc
Calc
Offshore
Leaks
Calc
PART M2 – KNOWN SYSTEM LEAKS AT END OF YEAR SCHEDULED FOR REPAIR
Transmission
Gathering
PART M3 – LEAKS ON FEDERAL LAND OR OCS REPAIRED OR SCHEDULED FOR
REPAIR
Transmission
Gathering
Onshore Type A
Onshore
Onshore Type B
OCS
OCS
Subtotal Transmission
Calc
Total
Subtotal Gathering
Calc
Calc
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 12 of 13
Reproduction of this form is permitted.
Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation
for each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122.
Form Approved
OMB No. 2137-0522
Expires: xx/xx/xxxx
For the designated Commodity Group, complete PART N one time for all of the pipelines and/or pipeline
facilities included within this OPID, and then also PART O if any portion(s) of the pipelines and/or pipeline
facilities covered under this Commodity Group and OPID are included in an Integrity Management
Program subject to 49 CFR 192.
PART N - PREPARER SIGNATURE (applicable to all PARTs A - M)
/__/__/__/-/__/__/__/-/__/__/__/__/
Telephone Number
Preparer's Name(type or print)
/__/__/__/-/__/__/__/-/__/__/__/__/
Preparer's Title
Facsimile Number
Preparer's E-mail Address
PART O - CERTIFYING SIGNATURE (applicable only to PARTs B, F, G, and M1)
/__/__/__/-/__/__/__/-/__/__/__/__/
Senior Executive Officer’s signature certifying the information in PARTs B, F, G, and M as required by
49 U.S.C. 60109(f)
Telephone Number
Senior Executive Officer’s name certifying the information in PARTs B, F, G, and M as required by
49 U.S.C. 60109(f)
Senior Executive Officer’s title certifying the information in PARTs B, F, G, and M as required by
49 U.S.C. 60109(f)
Senior Executive Officer’s E-mail Address
Form PHMSA F 7100.2-1 (Rev. xx-2010)
Pg. 13 of 13
Reproduction of this form is permitted.
INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
GENERAL INSTRUCTIONS
All section references are to Title 49 of the Code of Federal Regulations (49 CFR). The Natural or
Other Gas Transmission and Gathering Systems Annual Report has been revised as of calendar year
2010 affecting submissions for 2010 and beyond. Please read through the Annual Report and
instructions carefully before beginning to complete the Report. Where common data elements exist
between this Report and an operator’s NPMS submission, the data submitted by the operator on their
Annual Report should be the same as the data submitted through NPMS when possible. (Additionally,
and in order to align an operator’s NPMS submission with their Annual Report data, PHMSA suggests
that operators send their NPMS submission to PHMSA by March 15, representing pipeline assets as of
December 31 of the previous year.)
Annual Reports must be submitted by March 15 for the preceding calendar year. In order to
improve the accuracy of reported data, operators are requested to review prior years’ Reports in order
to validate that their reported numbers are accurate, or to identify and correct inconsistencies or errors
that are either found or that may exist in any previously reported data. Operators should file
Supplemental Reports as necessary, including those supplementing prior years’ Reports.
Each gas transmission system or regulated gathering pipeline operator is required to file an Annual
Report. The terms “operator,” “distribution line,” “gathering line,” “Maximum Allowable Operating
Pressure (MAOP),” “offshore,” “Outer Continental Shelf,” “pipe,” “pipeline,” “pipeline facility,”
“specified minimum yield strength (SMYS),” and “transmission line” are defined in § 192.3. The
terms “assessment,” and “high consequence area (HCA)” are defined in §195.903. § 192.8 describes
how to identify onshore gathering lines and to determine if a gathering line is subject to regulation (i.e.,
is a “regulated gathering line”). If an operator determines that its pipelines fall under the definition for
distribution lines, he or she should submit Form PHMSA F 7100.1-1 rather than this form.
If you need copies of the Form PHMSA F 7100.2-1 and/or instructions, they can be found on the
Pipeline Safety Community main page, http://phmsa.dot.gov/pipeline, by clicking Data and Statistics
and then selecting the Forms hyperlink. If you have questions about this Report or these instructions,
please call the PHMSA Information Resources Manager at (202) 366-8075.
Rev. xx-20xx
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
REPORTING METHOD
Annual Reports must be submitted online unless an alternate method is approved (see Alternate
Reporting Methods below). Use the following procedure:
1. Navigate
to
the
Pipeline
Safety
Community
main
page,
http://www.phmsa.dot.gov/pipeline, click the ONLINE DATA ENTRY link listed.
2. Click on the Annual Gas Transmission & Gathering System Report link
3. Enter Operator Identification Number (OPID) and PIN. [If an operator does not
have an OPID or a PIN, the ONLINE DATA ENTRY page includes directions on
how to obtain one.]
4. Click Add to begin data entry for a new calendar year’s Report. [For Supplemental
Reports, click on the Report ID and select Modify to make corrections or add new
information.]
5. To save intermediate work without formally submitting it to PHMSA, click Save.
6. Click Submit when you have completed the Report (for either an Initial Report or a
Supplemental Report) and are ready to initiate formal submission of your Report to
PHMSA.
7. A confirmation page will appear for you to print and save for your records.
Alternate Reporting Methods
Operators for whom electronic reporting imposes an undue burden and hardship may submit a written
request for an alternative reporting method. Operators must follow the requirements in §191.7(c) to
request an alternative reporting method and must comply with any conditions imposed as part of
PHMSA’s approval of an alternate reporting method.
SPECIFIC INSTRUCTIONS
Make an entry in each block for which data is available. Estimate data only if necessary. Avoid
entering any data as UNKNOWN or 0 (zero) except where zero is appropriate to indicate that there
were no instances or amounts of the attribute being reported.
Do not report miles of pipe, pipe segments, or pipeline in feet. When reporting mileages that are less
than 1 mile or when reporting portions of a mile, convert feet into a decimal notation (e.g. 2,640 feet =
.5 miles) and report mileage using decimals rounded to the nearest tenth of a mile. Operators may
round all mileages that are greater than 1 mile to the nearest mile. Do not use fractions.
Enter the Calendar Year for which the Report is being filed, bearing in mind that reporting
requirements are for the preceding calendar year (i.e., for the March 15, 2011 deadline, the Report
should provide information for assets as they existed at the end of the 2010 calendar year).
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
Check Initial Report if this is the original filing for the calendar year. Check Supplemental Report
if this is a follow-up to a previously filed Report to amend or correct information for that calendar
year. On Supplemental Reports, enter all information requested in Parts A and N, and only the new or
revised information for the other Parts of the Report, completing Part O as required.
Report miles of pipe, pipe segments, or pipeline in the system at the end of the reporting year,
including any additions or deletions to the system occurring during that year. Report other data for the
duration of the calendar year as appropriate. Adhere to definitions in 49 CFR 192 when reporting
mileage and other data.
PART A – OPERATOR INFORMATION
Complete all 8 sections of Part A before continuing to the next Part.
1. Operator’s 5-digit Identification Number (OPID)
All operators that meet the definition of an “operator” under § 192.3 must have a PHMSA-assigned
Operator Identification Number (also known as an OPID). If the person completing the Report
does not know the OPID for the system being reported, this information may be requested from the
PHMSA Information Resources Manager at (202) 366-8075. (See instructions on the ONLINE
DATA ENTRY page as described above.)
2. Name of Company or Establishment
This is the company name used when registering for an OPID and PIN in the Online Data Entry
System. When completing the Report online, the Name of Operator is automatically filled in based
on the OPID entered in Part A, Question 1. If the name that appears does not coincide with the
OPID, contact the PHMSA Information Resources Manager.
If the company corresponding to the OPID is a subsidiary, enter the name of the parent company.
3. Individual where additional information may be obtained
Enter the name, title, email address and telephone number of the individual who should be
contacted if additional information regarding this Report submission is needed.
4. Headquarters address
Enter the address and phone number of the operator’s corporate headquarters.
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
5. This Report pertains to the following Commodity Group
It is a PHMSA requirement that operators submit individual Reports by Commodity Group.
File a separate Report for each of the following Commodity Groups:
Natural Gas
Synthetic Gas (Examples include landfill gas, biogas, and manufactured gas based on
naphtha)
Hydrogen Gas
Propane Gas
Other Gas – If this Commodity Group is selected, report the name of the other gas in the
space provided.
Note: When a single pipeline serves as two or more of the above Commodity Groups, that pipeline
should be reported only once, reporting within the Commodity Group for the commodity that is
transported most predominantly.
6. Integrity Management Program
Indicate here whether any portion(s) of the pipelines and/or pipeline facilities for this Commodity
Group covered under this OPID are subject to the integrity management (IM) requirements of 49
CFR 192, Subpart O.
Pipelines and/or pipeline facilities that include high consequence areas (HCAs) are required to be
in an IM Program in accordance with Subpart O. For the purposes of this question and, more
generally, this Report, do not consider pipelines or portions of pipelines that could otherwise not
affect an HCA but which are included in an IM Program as a result of other PHMSA directives
(such as Corrective Action Orders, Compliance Orders, Special Permits, etc.). Check the box
indicating that portions of SOME or ALL of the pipelines and/or pipeline facilities covered under
this OPID are included in an IM Program as required by Subpart O, and complete other Parts of
this Report in accordance with Part A, Question 8.
If NO PORTIONS of the pipelines and/or pipeline facilities covered under this OPID are included
in an IM Program as required by Subpart O, check the box indicating such. In this case, Parts B, F,
G, the “HCA” portions of M1, and O need not be completed.
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
7. Interstate and/or Intrastate pipeline
Pipeline assets included within a particular Commodity Group under a single OPID may be either
interstate, intrastate, or both. Check the appropriate box or boxes to indicate whether the pipelines
and/or pipeline facilities for the OPID and Commodity Group are interstate or intrastate or both.
List the two-letter state abbreviation for each state in which reported interstate and intrastate assets
are located.
Interstate pipeline means a pipeline or that part of a pipeline that is used to transport gas and is
subject to the jurisdiction of the Federal Energy Regulatory Commission (FERC) under the Natural
Gas Act (15 U.S.C. 717 et seq.).
Interstate pipeline means a pipeline or that part of a pipeline that is used to transport gas and is
subject to the jurisdiction of the Federal Energy Regulatory Commission (FERC) under the Natural
Gas Act (15 U.S.C. 717 et seq.).
8. Does this Report represent a change from last year’s final reported information for one or
more of the following Parts?
Check “This Report is for calendar year 2010 reporting or is a first-time Report…” only for the
reporting of calendar year 2010 information, including any supplements to that information, or if
this is a first-time Report. Because this revision of the Annual Report will be used for the first time
to report information for calendar year 2010, some of the “Parts” of this Report referred to in this
question are new and, therefore, no comparable information will have been reported for the prior
year. For calendar year 2010 only, respond to this question by selecting the box “This Report is for
calendar year 2010 reporting or is a first-time Report…”, and then complete all remaining Parts of
the Report as applicable. Similarly, if no Annual Report has been previously filed for this operator,
OPID, Commodity Group, or pipelines and/or pipeline facilities, or for other reasons, select the box
“This Report is for calendar year 2010 reporting or is a first-time Report…”, and then complete all
remaining Parts of the Report as applicable.
For calendar year submissions beyond 2010, an option has been created to allow the operator to
provide information for relevant Parts when certain portions of the information have not changed.
Check “No” if there are no changes in the information reported for the current reporting year
compared against the prior calendar year for Parts B, D, E, H, I, J, K, or L for the Commodity
Group reported.
It should be noted that PHMSA expects that the data describing volume transported (Part C) and
integrity management activity (Parts F and G) will change each year. Therefore, Part C, describing
volume transported, must be completed by every operator every year. Additionally, those Parts of
this Report related to integrity management activity (Parts F, G and O) must be completed every
year by every operator with portions of pipelines and/or pipeline facilities subject to PHMSA’s IM
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
regulations as indicated in Part A, Question 6.
When there are changes in the information reported for the current reporting year compared against
the prior calendar year, these changes can occur for one of the two following reasons:
1) New information or new calculations may have changed the understanding of
pipeline and/or pipeline facility data, leading to differences in some data elements
reported on the Annual Report in the previous year’s Report, even though the physical
pipeline(s) and/or pipeline facility(ies) themselves have not changed; or
2) The pipeline(s) and/or pipeline facility(ies) may have changed – either physically or
operationally.
Check one or both of the two “Yes” boxes if reported system information has changed.
If the change is due to a change in the pipelines and/or pipeline facilities and/or
operations (number 2 above), check the appropriate box or boxes to indicate the nature
of the change(s). If “Other” is selected, provide a brief description of the change.
•
Merger/acquisition involves a change in ownership or operating responsibility that
would likely result in increases or other changes in the reported miles of pipeline in
most Parts of the Report.
•
Divestiture involves a change in ownership or operating responsibility that would
likely result in decreases or other changes in the reported miles of pipeline.
•
New construction or new installation that would likely result in increases or other
changes in the reported miles of pipeline, including rerouting of pipelines.
•
Conversion of service, change in commodity transported, or change in MOP
(maximum operating pressure).
Rev. xx-20xx
•
Conversion to service means conversion to transportation of natural or
other gas under § 192.14 that would likely result in increases or other
changes in the reported miles of pipeline. (This is selected if a
pipeline that was previously used to transport a commodity or
material that was not covered under 49 CFR 191/192, such as water,
is being converted to move a commodity that is covered under 49
CFR 191/2 such as a propane gas line.)
•
Change in commodity transported means a change in the commodity
predominately transported and thus in the “Commodity Group”
reported in Part A, Question 6. (This is selected if the previous
commodity moved in a pipeline covered under 49 CFR 191/192 is
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
changed to a different commodity moved under 49 CFR 191/192, for
example a natural gas line being changed to a synthetic gas line.)
•
Change in MAOP (maximum allowable operating pressure) could
result in changes to the mileage of pipeline operating in different
categories of hoop stress (i.e., percent SMYS (Specified Minimum
Yield Strength)) as reported in Part K.
•
“Abandoned,” as defined in § 192.3, means permanently removed from service.
All pipeline mileage not permanently removed from service should be reported,
including pipelines and/or pipeline facilities considered to be idled.
•
Change in various aspects of an operator’s IM Program may result in changes to
information reported in Parts B, F, and/or G.
•
Change in an operator’s OPID number – or changes in pipelines and/or pipeline
facilities covered by a particular OPID number - may result in changes throughout
the Annual Report.
For the designated Commodity Group, complete Parts B, C, D, and E one time for all pipelines
and/or pipeline facilities – both INTERstate or INTRAstate – included within this OPID.
Separate reporting by state is not required for these Parts. Data reported should represent the
system in total, including all states in which system assets are located.
PART B – TRANSMISSION PIPELINE HCA MILES
Report in Part B the total miles of Onshore and Offshore pipe that are high consequence areas (HCAs).
Do not include miles of pipeline that are not HCAs but which are included in the IM Program as a
result of other PHMSA directives (such as Corrective Action Orders, Compliance Orders, Special
Permits, etc.). This Part should be left blank if no portions of the pipelines and/or pipeline facilities
covered by this OPID are in an IM Program, as indicated in Part A, Question 6.
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
PART C - VOLUME TRANSPORTED IN TRANSMISSION PIPELINES (ONLY) IN
MILLION SCF PER YEAR (excludes Transmission lines of Gas Distribution systems)
Report the volume transported in transmission pipelines during the calendar year for this Commodity
Group, in millions of standard cubic feet (60ºF and 14.73psia). Include the annual total volume
transported for all states and for all pipelines and/or pipeline facilities – both INTERstate or
INTRAstate – included within this OPID and for this Commodity Group. Volumes of any Commodity
Group transported in addition to the Commodity Group predominately transported through these
pipelines and/or pipeline facilities should also be reported in Part C within the proper row.
Note: This Part does not need to be completed if the pipeline system corresponding to the OPID
reported in Part A, Question 1, includes only gathering pipelines or if the transmission line is operated
by a gas distribution company as an integral part of its distribution pipeline system. Operators whose
pipelines are limited to these types should check the box to so indicate.
PART D – MILES OF STEEL PIPE BY CORROSION PROTECTION
For steel pipe only, report the total miles of Onshore and Offshore Transmission and Gathering pipe
that is cathodically protected and cathodically unprotected subdivided, in each case, into the amount
that is bare and the amount that is coated pipe. COATED means pipe coated with an effective hot or
cold applied dielectric coating or wrapper. Enter zero (0) in any cell for which the pipeline system
includes no mileage. Do not leave any cells blank.
PART E – MILES OF non-STEEL PIPE BY TYPE AND LOCATION
For non-steel pipe only, report the total miles of Onshore and Offshore pipe that is of a material other
than steel. Enter zero (0) in any cell for which the pipeline system includes no mileage. Do not leave
any cells blank.
OTHER PIPE means a pipe made of a non-steel material not specifically designated on the form,
such as copper, aluminum, etc.
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
For the designated Commodity Group, complete PARTs F and G one time for all INTERstate
pipelines and/or pipeline facilities included within this OPID and multiple times as needed for
the designated Commodity Group for each State in which INTRAstate pipelines and/or pipeline
facilities included within this OPID exist.
For example: Consider a set of natural gas pipeline systems that includes INTERstate pipeline
facilities in seven states and INTRAstate pipeline facilities in three states. Parts F and G should
be completed four times for this set of natural gas pipeline systems – once for all INTERstate
assets (combined) and once for the INTRAstate assets in each of the three states in which
INTRAstate assets are located (separately).
Each time Parts F and G are completed, indicate whether the data reported is for INTERstate or
INTRAstate pipelines and/or pipeline facilities. If INTRAstate, enter in the space provided the
two-letter postal abbreviation for the state.
PART F – INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN
BASED ON INSPECTION
This Part incorporates transmission pipeline integrity management performance measure reporting
required by § 192.945 and ASME/ANSI B31.8S, Section 9.4(b) (incorporated into the regulations by
reference), items 1-3. Report all integrity assessments (inspections) required by PHMSA’s IM
regulations which were conducted and actions which were taken during the calendar year based on
inspection results. Include all inspections conducted in the reporting period calendar year including
baseline assessments and re-assessments. Do not consider pipelines or portions of pipelines that could
otherwise not affect an HCA but which are included in an IM Program as a result of other PHMSA
directives (such as Corrective Action Orders, Compliance Orders, Special Permits, etc.). Part F is
subdivided into six (6) sections.
Section 1 - Mileage inspected in calendar year using the following In-Line Inspection (ILI)
tools.
Report the mileage inspected using each of the listed tool types. Include total miles
inspected, not just the mileage in high consequence areas (HCA). Where multiple ILI
tools are used (e.g., a metal loss tool and a deformation tool), report the mileage in both
categories. Where a combination tool is used (i.e., a single tool with multiple
capabilities), report the mileage separately in each category included as part of the
combination. Thus, the total mileage inspected during the calendar year (the sum of the
mileage reported for individual tools) may be greater than the actual number of physical
pipeline miles on which ILI inspections were run.
Enter zero (0) for any tool which was not used for IM assessments during the year.
Leave no rows blank.
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
Section 2 - Actions taken in calendar year based on In-Line Inspections.
Include all actions taken during the calendar year that resulted from information
obtained during an ILI inspection. This should include actions taken as a result of
information developed during ILI inspections conducted during the calendar year PLUS
actions taken as a result of ILI inspections conducted during prior years and for which
all required actions were not completed during the year of the inspection. Do not
include actions which are anticipated based on review of ILI results but which did not
actually occur during the reporting year.
Report in items a. and b. the total number of anomalies excavated and repaired based on
the operator’s repair criteria even if those criteria are different from (i.e., require repair
of damage more or less significant) than the repair criteria in IM regulations applicable
to anomalies in HCA pipeline segments. (The operator’s criteria for anomalies in HCA
pipeline segments must be at least as conservative as those required by the regulations).
Report in a. the total number of anomalies excavated, recognizing that multiple
anomalies may be exposed in a single excavation.
Report in b. only those anomalies actually repaired, not those for which other mitigative
actions (not repair) were undertaken.
Report in c. only the anomalies in HCA pipeline segments that were repaired because
they met one of the repair criteria in the IM regulations. “Scheduled conditions” as
used in this section refers to anomalies that are required to be repaired in accordance
with the schedule in ASME/ANSI B31.8S, section 7, Figure 4 (see § 193.933(c)). (The
total of repairs reported in item c. should not exceed the total number of repairs reported
in item b.)
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.
Section 3 – Mileage inspected and actions taken in calendar year based on Pressure
Testing.
Report in a. total miles inspected by pressure testing, including both HCA mileage and
mileage outside HCA.
Report in b. the total number of test failures (ruptures and leaks) on all mileage tested
during the year.
Report in c. the ruptures and in d. the leaks repaired ONLY in HCA segments.
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank. Enter
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
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NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
zero (0) in all rows of section 3 if no IM assessments were conducted by pressure test
during the year.
Section 4 – Mileage inspected and actions taken in calendar year based on DA (Direct
Assessment).
Include all actions taken during the calendar year that resulted from information
obtained through external corrosion direct assessment, internal corrosion direct
assessment, and stress corrosion cracking direct assessment inspections. Include all
actions taken during the calendar year that resulted from information obtained during a
DA inspection. This should include actions taken as a result of information developed
during DA inspections conducted during the calendar year PLUS actions taken as a
result of DA inspections conducted during prior years and for which all required actions
were not completed during the year of the inspection. Do not include actions which are
anticipated based on DA inspection results but which did not actually occur during the
reporting year.
Report in b. the total number of anomalies excavated and repaired within an HCA
segment and outside an HCA segment based on the operator’s repair criteria even if
those criteria are different from (i.e., require repair of damage more or less significant)
than the repair criteria in IM regulations applicable to anomalies in HCA pipeline
segments. (The operator’s criteria for anomalies in HCA pipeline segments must be at
least as conservative as those required by the regulations).
Report in c. the number of anomalies identified in HCA pipeline segments that were
repaired because when excavated and examined they met one of the repair criteria in the
IM regulations.
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.
Section 5 - Mileage inspected and actions taken in calendar year based on Other
Inspection Techniques.
IM regulations allow operators to use other assessment techniques provided that they
notify PHMSA (or states exercising regulatory jurisdiction) in advance. Report here the
mileage inspected and actions taken as a result of inspections conducted using any
technique other than those covered in Sections 1-4 of Part F.
As for the other techniques, include all actions taken during the calendar year that
resulted from information obtained during an inspection using another technique. This
should include actions taken as a result of information developed as part of inspections
conducted during the calendar year PLUS actions taken as a result of inspections
conducted during prior years and for which all required actions were not completed
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
during the year of the inspection. Do not include actions which are anticipated based on
inspection results but which did not actually occur during the reporting year.
Report only those anomalies actually repaired, not those for which other mitigative
actions (not repair) were undertaken.
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.
Section 6 - Total Mileage Inspected (all Methods) and Actions Taken.
These entries will be calculated automatically based on data entered in sections 1-5.
For operators completing a paper form as a result of PHMSA approval to use alternate
reporting measures (see above), report here the total mileage inspected and actions
taken as the sum of the indicated elements from other sections.
PART G – MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED
IN CALENDAR YEAR (HCA Segment miles ONLY)
Report the number of miles of pipeline in HCA (as reported in part B) that were assessed during the
calendar year pursuant to §§ 192.921 or 192.937. Report separately the number of miles inspected for
baseline assessments (e.g., initial baseline assessments and new baseline assessments, including those
which occur due to new pipelines or facilities, new HCA, etc.) and miles for which a reassessment was
conducted. Do not include pipelines or portions of pipelines that could otherwise not affect an HCA
but which are included in an IM Program as a result of other PHMSA directives (such as Corrective
Action Orders, Compliance Orders, Special Permits, etc.).
Report only assessments that were completed during the calendar year. These “completed
assessments” are defined consistently with FAQ 34 http://primis.phmsa.dot.gov/gasimp/faqlist.gim.
The date on which an assessment is considered complete will be the date on which final field
activities related to that assessment are performed, not including repair activities. That is when a
hydrostatic test is completed, when the last in-line inspection tool run of a scheduled series of tool runs
is performed, when the last direct examination associated with direct assessment is made, or the date
on which "other technology" for which an operator has provided timely notification is conducted.
Operators should report in Part G the total number of miles actually assessed. This differs from Part F
where operators report the number of miles inspected by individual inspection methods and where
some mileage may be reported multiple times. Operators should note that the mileages reported as
completed Assessments in Part G should be a subset of the total miles of onshore/offshore pipe in
HCA reported in Part B. Operators should validate the total completed and scheduled assessment
mileage in their Assessment Plans with the mileage reported here. The comparison of these two
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
numbers will highlight any discrepancies resulting from new HCA segments being added or deleted,
acquired or sold, or idled 1 or converted, and which need to be properly reflected in this Report.
For the designated Commodity Group, complete PARTs H, I, J, K, L, and M covering
INTERstate pipelines and/or pipeline facilities for each State in which INTERstate systems exist
within this OPID and again covering INTRAstate pipelines and/or pipeline facilities separately
for each State in which INTRAstate systems exist within this OPID.
For example: Consider a set of natural gas pipeline systems that includes INTERstate pipeline
facilities in seven states and INTRAstate pipeline facilities in three states. Parts H, I, J, K, L, and
M should be completed ten times for this set of natural gas pipeline systems – seven times for
INTERstate assets (once for each state in which INTERstate assets are located) and once for the
INTRAstate assets in each of the three states in which INTRAstate assets are located.
Each time the remaining parts are completed, indicate whether the data reported is for
INTERstate or INTRAstate pipelines and/or pipeline facilities, and enter in the space provided
the two-letter postal abbreviation for the state.
PART H – MILES OF TRANSMISSION PIPE BY NOMINAL PIPE SIZE (NPS)
Report the miles of transmission pipe by Nominal Pipe Size (NPS) and location for both onshore and
offshore locations. Enter the appropriate mileage in the corresponding nominal size blocks.
Pipe size which does not correspond to NPS measurements should be included in the “Other Pipe Sizes
Not Listed” columns. Include both the pipe size and the corresponding mileage.
Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.
1
While the regulations do not recognize an intermediate state between operational and abandoned (see instructions for Part
A, Question 8 above), PHMSA has acknowledged that operators sometimes maintain some of their pipe in an idle status in
which conducting IM assessments is impractical. This consideration of “idle” pipe is discussed in FAQ 7 on the PHMSA
Gas IM website (http://primis.phmsa.dot.gov/gasimp/faqlist.gim).
Rev. xx-20xx
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INSTRUCTIONS FOR FORM PHMSA F 7100.2-1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL OR OTHER GAS TRANSMISSION AND GATHERING SYSTEMS
PART I – MILES OF GATHERING PIPE BY NOMINAL PIPE SIZE (NPS)
Report the miles of gathering pipe by Nominal Pipe Size (NPS) and location for both Onshore and
Offshore locations. Report onshore Type A and Type B gathering lines (§ 192.8) separately, as shown.
Enter the appropriate mileage in the corresponding nominal size blocks.
Pipe size which does not correspond to NPS measurements should be included in the “Other Pipe Sizes
Not Listed” columns. Include both the pipe size and the corresponding mileage.
Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.
PART J – MILES OF PIPE BY DECADE INSTALLED
Report the miles of pipe by decade installed. Make an entry in each block including zero (0) when
appropriate. Some companies may have pipe for which installation records may not exist. When the
decade of construction is unknown, enter estimates of the totals of such mileage in the “Pre-40 or
Unknown” section of Part J.
PART K – MILES OF TRANSMISSION PIPE BY SPECIFIED MINIMUM YIELD
STRENGTH
Section 192.5 defines class locations as:
§ 192.5 Class locations.
(a) This section classifies pipeline locations for purposes of this part. The following criteria apply
to classifications under this section.
(1) A ''class location unit'' is an onshore area that extends 220 yards (200 meters) on
either side of the centerline of any continuous 1-mile (1.6 kilometers) length of pipeline.
(2) Each separate dwelling unit in a multiple dwelling unit building is counted as a
separate building intended for human occupancy.
(b) Except as provided in paragraph (c) of this section, pipeline locations are classified as follows:
(1) A Class 1 location is:
(i) An offshore area; or
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(ii) Any class location unit that has 10 or fewer buildings intended for human
occupancy.
(2) A Class 2 location is any class location unit that has more than 10 but fewer than 46
buildings intended for human occupancy.
(3) A Class 3 location is:
(i) Any class location unit that has 46 or more buildings intended for human
occupancy; or
(ii) An area where the pipeline lies within 100 yards (91 meters) of either a
building or a small, well-defined outside area (such as a playground, recreation
area, outdoor theater, or other place of public assembly) that is occupied by 20 or
more persons on at least 5 days a week for 10 weeks in any 12-month period. (The
days and weeks need not be consecutive.)
(4) A Class 4 location is any class location unit where buildings with four or more stories
above ground are prevalent.
(c) The length of Class locations 2, 3, and 4 may be adjusted as follows:
(1) A Class 4 location ends 220 yards (200 meters) from the nearest building with four or
more stories above ground.
(2) When a cluster of buildings intended for human occupancy requires a Class 2 or 3
location, the class location ends 220 yards (200 meters) from the nearest building in the
cluster.
Report the total miles of steel transmission pipe by hoop stress (as percent of SMYS) for pipe onshore
and offshore by stress range and Class Location. Enter zero (0) in any cell for which the pipeline
system includes no mileage. Report pipe for which hoop stress (i.e., percent of SMYS) is unknown
and all non-steel pipe, regardless of operating pressure, in the rows indicated. Do not leave any cells
blank.
Pay close attention to the classification of each pipeline. Short segments of pipeline operated by
distribution systems at less than or equal to 20 percent SMYS have sometimes been inaccurately
reported as transmission lines. Unless such pipelines meet the definition of transmission lines in §
192.3, they should be reported as distribution pipelines (Form PHMSA F 7100.1-1). If pipelines
operating at less than or equal to 20 percent SMYS meet the definition of transmission lines, they
should be reported here.
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PART L – MILES OF PIPE BY CLASS LOCATION
Report the number of Onshore and Offshore miles of pipe in each Class Location. In addition, report
the number of HCA miles in the IMP program for both Onshore and Offshore transmission pipe.
Note: Operators should cross check their numbers for the various Parts, when applicable.
PART M – INCIDENTS, FAILURES, LEAKS, AND REPAIRS
This Part includes reporting for both pipelines and/or pipeline facilities covered by this OPID which
are subject to the integrity management (IM) requirements of 49 CFR 192, Subpart O as well as
pipelines and/or pipeline facilities covered by this OPID which are not subject to the integrity
management (IM) requirements of 49 CFR 192, Subpart O. Additional instructions are provided
below.
PART M1 – ALL LEAKS ELIMINATED/REPAIRED IN CALENDAR YEAR; INCIDENTS &
FAILURES IN HCA IN CALENDAR YEAR
This Part incorporates transmission pipeline integrity management performance measure reporting
required by § 192.945 and ASME/ANSI B31.8S, Section 9.4(b)(4) (incorporated into the regulations
by reference), along with reporting of all leaks that has historically been part of the Annual Report.
Include all leaks repaired or eliminated including by replaced pipe or other component during the
calendar year. Operators with pipe segments in HCA and subject to IM requirements (as reported in
Part A, Question 5) should report separately the number of leaks repaired or eliminated in HCA in the
appropriate columns. All operators should report leaks for non-HCA pipe segments, including all
leaks on pipelines that contain no HCAs and all leaks in non-HCA locations on pipelines in which
HCAs exist. Do not include test failures.
Operators with pipe segments in HCA (as reported in Part A, Question 5) should also report the
number of failures and incidents in HCAs, as required by § 195.945 and ASME/ANSI B31.8S, Section
9.4(b)(4).
Integrity management performance measures are not required for gathering pipelines. For gathering
pipelines, report only leaks. Report separately the number of leaks in Type A gathering lines and Type
B gathering lines for onshore gathering pipelines.
Leaks are unintentional escapes of gas from the pipeline that are not reportable as Incidents
under § 191.3. A non-hazardous release that can be eliminated by lubrication, adjustment, or
tightening is not a leak. Operators should report the number of leaks repaired based on the best data
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they have available. For sections replaced but retired in place, operators should consider leak survey
information to determine, to the extent practical, the number of leaks in the replaced section.
Failure is defined in ASME/ANSI B31.8S as a general term used to imply that a part in service: has
become completely inoperable, is still operable but is incapable of satisfactorily performing its
intended function; or has deteriorated seriously, to the point that it has become unreliable or unsafe for
continued use. Failures that result in an unintentional release of gas should be reported as leaks.
Incidents are defined in § 191.3.
For the purposes of this Part M1, Leaks, Failures, and Incidents are to be classified as either:
EXTERNAL CORROSION: release resulting from a hole in the pipe or other component that
galvanic, bacterial, chemical, stray current, or other corrosive action causes initiating on the outside
surface of the pipe. For PHMSA’s Gas Transmission/Gathering Incident Reporting form, this includes
the “External Corrosion” sub-cause under G1 – Corrosion Failure.
INTERNAL CORROSION: release resulting from a hole in the pipe or other component that
galvanic, bacterial, chemical, stray current, or other corrosive action causes initiating on the inside
surface of the pipe. From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and
specifically for the purposes of this Part M1, this includes the “Internal Corrosion” sub-cause under G1
– Corrosion Failure.
STRESS CORROSION CRACKING: release resulting from a form of environmental attack of the
pipe metal involving an interaction of a local corrosive environment and tensile stresses in the metal
resulting in formation and growth of cracks. From PHMSA’s Gas Transmission/Gathering Incident
Reporting form, and specifically for the purposes of this Part M1, this includes the “Environmental
Cracking-related” sub-cause under G5 – Material Failure of Pipe or Weld, which includes Stress
Corrosion Cracking as well as Sulfide Stress Cracking and Hydrogen Stress Cracking.
MANUFACTURING: release resulting from a hole in the pipe or other component caused by a
defect introduced during the process of manufacturing the pipe, including seam defects and defects in
the pipe body or pipe girth weld. From PHMSA’s Gas Transmission/Gathering Incident Reporting
form, and specifically for the purposes of this Part M1, this includes the “Original Manufacturing
Defect-related” sub-cause under G5 – Material Failure of Pipe or Weld.
CONSTRUCTION: release resulting from a hole in the pipe or other component caused by a defect
introduced during the process of constructing the pipeline or installing the pipe. From PHMSA’s Gas
Transmission/Gathering Incident Reporting form, and specifically for the purposes of this Part M1, this
includes the “Construction-, Installation-, or Fabrication-related” sub-cause under G5 – Material
Failure of Pipe or Weld.
EQUIPMENT: release resulting from: malfunction of control/relief equipment including valves,
regulators, or other instrumentation; stripped threads or broken pipe couplings on nipples, valves, or
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mechanical couplings; or seal failures of gaskets, O-rings, seal/pump packing, or similar leaks. From
PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the purposes of
this Part M1, this includes all of the sub-causes under G6 – Equipment Failure.
INCORRECT OPERATIONS: release resulting from inadequate procedures or safety practices, or
failure to follow correct procedures, or other operator error.
From PHMSA’s Gas
Transmission/Gathering Incident Reporting form, and specifically for the purposes of this Part M1, this
includes all of the sub-causes under G7 – Incorrect Operation.
THIRD PARTY DAMAGE/MECHANICAL DAMAGE: release resulting from damage caused by
earth moving or other equipment, tools, or vehicles which occurs as a result of excavation activities or
a release caused by vandalism or other similar intentional damage. Report separately, as indicated:
•
Excavation Damage - leaks resulting directly from excavation damage by operator's
personnel (oftentimes referred to as “first party” excavation damage) or by the
operator’s contractor (oftentimes referred to as “second party” excavation damage) or
by people or contractors not associated with the operator (oftentimes referred to as
“third party” excavation damage) From PHMSA’s Gas Transmission/Gathering
Incident Reporting form, and specifically for the purposes of this Part M1, this includes
the Excavation Damage by Operator (First Party), Excavation Damage by Operator’s
Contractor (Second Party), and Excavation Damage by Third Party sub-causes under
G3 – Excavation Damage;
•
Previous Damage (due to Excavation Activity) - leaks that are determined to have
resulted from previous damage due to excavation activity From PHMSA’s Gas
Transmission/Gathering Incident Reporting form, and specifically for the purposes of
this Part M1, this includes only the Previous Damage due to Excavation Activity subcause under G3 – Excavation Damage; and,
•
Vandalism (includes all Intentional Damage) - deliberate or willful acts, such as
vandalism. From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and
specifically for the purposes of this Part M1, this includes only the “Intentional
Damage” sub-cause under G4 – Other Outside Force Damage. (For proper treatment of
the other sub-causes under G4 – Other Outside Force Damage, see the next category.)
WEATHER RELATED/OTHER OUTSIDE FORCE DAMAGE: release resulting from earth
movement, earthquakes, landslides, subsidence, lightning, heavy rains/floods, washouts, flotation,
mudslide, scouring, temperature, frost heave, frozen components, high winds, or similar natural causes,
or a release from other, non-excavation-related outside forces, such as nearby fires or explosions;
contact with vehicles, boats, fishing or maritime vessels or equipment; and, electrical arcing. Report
separately, as indicated:
•
Natural Force Damage (all) - From PHMSA’s Gas Transmission/Gathering Incident
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Reporting form, and specifically for the purposes of this Part M1, this includes all of the
sub-causes under G2 – Natural Force Damage
•
Other Outside Force Damage (excluding Vandalism and all Intentional Damage) From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically
for the purposes of this Part M1, this includes all of the sub-causes under G4 – Other
Outside Force Damage except Intentional Damage.
OTHER: release resulting from any other cause, such as exceeding the service life, not attributable to
the above causes. From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and
specifically for the purposes of this Part M1, this includes both of the two sub-causes under G8 – Other
Incident Cause.
PART M2 –KNOWN SYSTEM LEAKS AT END OF YEAR SCHEDULED FOR REPAIR
Include all known leaks scheduled for elimination by repairing or by replacing pipe or some other
component, indicating separately for transmission lines and gathering lines.
Enter zero (0) in any cell for which the pipeline system includes no mileage or there are no known
leaks scheduled for repair. Do not leave any cells blank.
PART M3 –LEAKS ON FEDERAL LAND OR OCS REPAIRED OR SCHEDULED FOR
REPAIR
FEDERAL LANDS means all lands owned by the United States except lands in the National Park
System, lands held in trust for an Indian or Indian tribe, and lands on the Outer Continental Shelf
(OCS), as defined in 30 USC 185.
Enter all leaks repaired, eliminated, or scheduled for repair during the reporting year, excluding those
reported as incidents on Form PHMSA F 7100.2.
Enter zero (0) in any cell for which the pipeline system includes no mileage or there are no known
leaks scheduled for repair. Do not leave any cells blank.
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For the designated Commodity Group, complete Part N one time for all of the pipelines and/or
pipeline facilities included within this OPID. Complete Part O one time for all the pipelines
and/or pipeline facilities covered under this Commodity Group and OPID if any portion(s) of the
pipelines and/or pipeline facilities are included in an IM Program subject to Subpart O as
indicated in Part A, Question 6.
PART N – PREPARER SIGNATURE
The Preparer is the person who compiled the information and prepared the responses to the Report.
Enter the Preparer’s name and title, and e-mail address if the Preparer has one, and the phone and fax
numbers used by the Preparer.
PART O – CERTIFYING SIGNATURE
CERTIFYING SIGNATURE must be a senior executive officer of the operator. The Pipeline
Inspection, Protection, Enforcement and Safety Act (signed in December 2006) requires pipeline
operators to have a senior executive officer of the company sign and certify annual pipeline Integrity
Management Program (IMP) performance reports (Parts B, F, G, and M1 – HCA data only - of this
Report). By this signature, the senior executive officer is certifying that he or she has (1) reviewed the
Report and (2) to the best of his or her knowledge, believes the Report is true and complete.
Senior Executive Officer is the person who is certifying the information on Parts B, F, G, and M1 as
required by 49 U.S.C. 60109(f).
The name and title of the senior executive officer certifying the Report should be entered in the
appropriate blanks on this section of the Report. The name of the senior executive officer certifying
the Report should also be entered in the signature block on the Report. Operators should keep in mind
that entering the senior executive officer’s name onto the electronic Report is equivalent to a paper
submission and has the same legal authenticity and requirements.
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| File Type | application/pdf |
| File Title | ANNUAL REPORT |
| Subject | GAS TRANSMISSION/GATHERING SYS |
| File Modified | 2011-05-20 |
| File Created | 2010-10-06 |