PHMSA F7100.2-1 Annual Report for Gas Transmission and Gas Gathering Pip

Incident and Annual Reports for Gas Pipeline Operators

GTGG_Annual_Report_and_Instructions.clean[1]

Incident and Annual Reports for Gas Pipeline Operators

OMB: 2137-0522

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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.

U.S. Department of Transportation
Pipeline and Hazardous Materials
Safety Administration

ANNUAL REPORT FOR CALENDAR YEAR 20___
NATURAL AND OTHER GAS TRANSMISSION AND
GATHERING PIPELINE SYSTEMS

Form Approved
OMB No. 2137-0522
Expires: 2/28/2014
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 42 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, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.
Important: Please read the separate instructions for completing this form before you begin. They clarify the information requested and provide
specific examples. If you do not have a copy of the instructions, you can obtain one from the PHMSA Pipeline Safety Community Web Page
at http://www.phmsa.dot.gov/pipeline/library/forms.
PART A - OPERATOR INFORMATION

DOT USE ONLY

1. OPERATOR’S 5 DIGIT IDENTIFICATION NUMBER (OPID)

2. NAME OF OPERATOR:

3. RESERVED

4. HEADQUARTERS ADDRESS:
Street Address

State: /

/ Zip Code: /

/ - /

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
 Landfill Gas
 Other Gas  Name of Other Gas ___________________
6. RESERVED

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 and OCS portions 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. RESERVED

Form PHMSA F 7100.2-1 (rev xy-2013)

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For the designated Commodity Group, PARTs B and D will be calculated based on the data entered in
Parts L and P respectively. Complete Part C 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

Onshore

Calc

Offshore

Calc

Total Miles

Calc

PART C - VOLUME TRANSPORTED IN TRANSMISSION
PIPELINES (ONLY) IN MILLION SCF PER YEAR
(Transmission lines of Gas Distribution systems excluded
from 2010 through 2012)



From 2010 through 2012 only - Check this box and do not complete
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
Landfill Gas
Other Gas  Name: ____________________

PART D - MILES OF PIPE BY MATERIAL AND CORROSION PREVENTION STATUS
Steel cathodically
protected

Steel cathodically
unprotected

Bare

Coated

Cast
Iron

Wrought
Iron

Plastic

Composite1

Other

Total
Miles

Transmission
Onshore

Calc

Offshore

Calc

Subtotal Transmission

Calc

Gathering
Onshore Type A

Calc

Onshore Type B

Calc

Offshore

Calc

Subtotal Gathering

Calc

Total Miles

Calc

Use of Composite pipe requires a PHMSA Special Permit or waiver from a State

PART E - RESERVED

Form PHMSA F 7100.2-1 (rev xy-2013)

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For the designated Commodity Group, complete PARTs F and G one time for all INTERstate pipeline
facilities included within this OPID and multiple times as needed for the designated Commodity Group for
each State in which INTRAstate pipeline facilities included within this OPID exist. Part F “WITHIN AN HCA
SEGMENT” data and Part G may be completed only if HCA Miles in Part L is greater than zero.
PARTs F and G
The data reported in these PARTs 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, specify other 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.

Form PHMSA F 7100.2-1 (rev xy-2013)

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(PART F continued)
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. Specify other
inspection technique(s):
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

d. Total number of actionable anomalies eliminated by pipe replacement in calendar year WITHIN AN HCA
SEGMENT:
e. Total number of actionable anomalies eliminated by pipe abandonment in calendar year WITHIN AN HCA
SEGMENT:

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 xy-2013)

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For the designated Commodity Group, complete PARTs H, I, J, K, L, M, P, Q, and R covering INTERstate
pipeline facilities for each State in which INTERstate systems exist within this OPID and again covering
INTRAstate pipeline facilities for each State in which INTRAstate systems exist within this OPID.
PARTs H, I, J, K, L, M, P, Q, and R
The data reported in these PARTs 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

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

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 xy-2013)

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PART I - MILES OF GATHERING PIPE BY NOMINAL PIPE SIZE (NPS)

Onshore
Type A

NPS 4
or less

58 and
over

Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc

Onshore
Type B

Total Miles of Onshore Type A Pipe - Gathering
NPS 4
or less

58 and
over

Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc

Total Miles of Onshore Type B Pipe - Gathering
NPS 4
or less

58 and
over

Offshore

Other Pipe Sizes
Not Listed
Size: __ Miles: ________
Add Sizes as needed
Calc

Total Miles of Offshore - Gathering

Form PHMSA F 7100.2-1 (rev xy-2013)

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PART J – MILES OF PIPE BY DECADE INSTALLED

Decade Pipe Installed

Unknown

Pre-1940

1940 - 1949

1950 - 1959

1960 - 1969

1970 - 1979

1980 - 1989

Calc

Subtotal Gathering

Calc

Total Miles

Calc

1990 - 1999

2000 - 2009

2010 - 2019

Total Miles

Transmission
Onshore
Offshore
Subtotal Transmission

Gathering
Onshore Type A
Onshore Type B
Offshore

Decade Pipe Installed

Transmission
Onshore

Calc

Offshore

Calc

Subtotal Transmission

Calc

Gathering
Onshore Type A

Calc

Onshore Type B

Calc

Offshore

Calc

Subtotal Gathering

Calc

Total Miles

Calc

Form PHMSA F 7100.2-1 (rev xy-2013)

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PART K- MILES OF TRANSMISSION PIPE BY SPECIFIED MINIMUM YIELD STRENGTH

CLASS LOCATION
ONSHORE

Total Miles
Class I

Class 2

Class 3

Class 4

Steel pipe Less than
20% SMYS
Steel pipe Greater than or
equal to 20% SMYS but less
than30% SMYS
Steel pipe Greater than or
equal to 30% SMYS but less
than or equal to 40% SMYS
Steel pipe Greater than 40%
SMYS but less than or equal to
50% SMYS
Steel pipe Greater than 50%
SMYS but less than or equal to
60% SMYS
Steel pipe Greater than 60%
SMYS but less than or equal to
72% SMYS
Steel pipe Greater than 72%
SMYS but less than or equal to
80% SMYS
Steel pipe Greater than 80%
SMYS
Steel pipe Unknown percent of
SMYS
All Non-Steel pipe
Onshore Totals
OFFSHORE

Calc

Calc
Calc
Calc
Calc

Calc

Class I

Steel pipe Less than or equal to
50% SMYS
Steel pipe Greater than 50%
SMYS but less than or equal to
72% SMYS
Steel pipe Greater than 72%
SMYS
Steel pipe Unknown percent of
SMYS
All non-steel pipe
Offshore Total

Calc

Total Miles

Calc

Form PHMSA F 7100.2-1 (rev xy-2013)

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PART L - MILES OF PIPE BY CLASS LOCATION
Class Location

Transmission
Onshore
Offshore
Subtotal Transmission

Class I

Class 2

Class 3

Class 4

Total
Class Location
Miles

Calc from Part K

Calc
Calc

Calc from Part K

Calc

HCA Miles

Calc

Gathering
Onshore Type A
Onshore Type B
Offshore

Calc

Calc
Calc
Calc

Subtotal Gathering

Calc

Total Miles

Calc

Form PHMSA F 7100.2-1 (rev xy-2013)

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PART M – FAILURES, LEAKS, AND REPAIRS
PART M1 – ALL LEAKS ELIMINATED/REPAIRED IN CALENDAR YEAR; FAILURES IN HCA SEGMENTS IN CALENDAR YEAR
Transmission Leaks and Failures
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

Offshore Leaks

Non-HCA

HCA

Non-HCA

Calc

Gathering Leaks
Failures
in HCA
Segments

Calc

Onshore
Leaks
Type
A

Type
B

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

Form PHMSA F 7100.2-1 (rev xy-2013)

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Offshore
Leaks

Calc

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PART P - MILES OF PIPE BY MATERIAL AND CORROSION PREVENTION STATUS
Steel cathodically
protected

Steel cathodically
unprotected

Bare

Coated

Cast
Iron

Wrought
Iron

Plastic

Other

Composite1

Total
Miles

Transmission
Onshore

Calc

Offshore

Calc

Subtotal Transmission

Calc

Gathering
Onshore Type A

Calc

Onshore Type B

Calc

Offshore

Calc

1
2

Subtotal Gathering

Calc

Total Miles

Calc

Use of Composite pipe requires a PHMSA Special Permit or waiver from a State
specify Other material(s):

Part Q - Gas Transmission Miles by §192.619 MAOP Determination Method
(a)(1) Total

(a)(1)
(a)(2) Total
(a)(2)
(a)(3) Total
(a)(3)
(a)(4) Total
(a)(4)
Incomplete
Incomplete
Incomplete
Incomplete
Records
Records
Records
Records

(d)
Total

(d)
Incomplete
Records

Other1
Total

Other
Incomplete
Records

Calc

Class 1 (in HCA)
Class 1 (not in HCA)
Class 2 (in HCA)
Class 2 (not in HCA)
Class 3 (in HCA)
Class 3 (not in HCA)
Class 4 (in HCA)
Class 4 (not in HCA)
Total

Calc

Grand Total
Sum of Total row for all “Incomplete Records” columns
1
Specify Other method(s):

Calc

Calc
Calc

Form PHMSA F 7100.2-1 (rev xy-2013)

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Part R – Gas Transmission Miles by Pressure Test (PT) Range and Internal Inspection
PT ≥ 1.25 MAOP

1.25 MAOP > PT ≥ 1.1 MAOP

PT < 1.1 or No PT

Miles Internal
Inspection ABLE

Miles Internal
Inspection
NOT ABLE

Miles Internal
Inspection ABLE

Miles Internal
Inspection
NOT ABLE

Miles Internal
Inspection ABLE

Miles Internal
Inspection
NOT ABLE

Calc

not in HCA subTotal

Calc

Total

Calc

Location

Class 1 in HCA
Class 2 in HCA
Class 3 in HCA
Class 4 in HCA
in HCA subTotal
Class 1 not in HCA
Class 2 not in HCA
Class 3 not in HCA
Class 4 not in HCA

PT ≥ 1.25 MAOP Total

Calc

Total Miles Internal Inspection ABLE

Calc

1.25 MAOP > PT ≥ 1.1

Calc

Total Miles Internal Inspection NOT ABLE

Calc

PT < 1.1 or No PT Total

Calc

Grand Total

Calc

Form PHMSA F 7100.2-1 (rev xy-2013)

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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, and then also PART O if any gas transmission pipeline facilities
included within this OPID have Part L HCA mile value greater than zero.

PART N - PREPARER SIGNATURE

/__/__/__/-/__/__/__/-/__/__/__/__/
Telephone Number

Preparer's Name(type or print)

Preparer's Title

Preparer's E-mail Address

PART O - CERTIFYING SIGNATURE (applicable to PARTs B, F, G, and M1)

/__/__/__/-/__/__/__/-/__/__/__/__/
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 xy-2013)

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Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

GENERAL INSTRUCTIONS
All section references are to Title 49 of the Code of Federal Regulations (49 CFR). The Natural and
Other Gas Transmission and Gathering Pipeline Systems Annual Report has been revised as of calendar
year (CY) 2012 affecting submissions due in 2013 and beyond. This Annual Report is required per
§191.17 and must be filed per §191.7. 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. PHMSA encourages gas transmission
operators to send their NPMS submission to PHMSA by March 15, representing pipeline assets as of
December 31 of the previous year.
Each operator of a transmission or a gathering pipeline system must submit an Annual Report for that
system on DOT Form PHMSA 7100.2-1. This report must be submitted each year, not later than March
15, and provide information about the pipeline system as-of December 31 of the previous year. If an
operator discovers an error in a submitted annual report, a supplemental report should be filed. Changes
made to the pipeline system after the end of the reporting year should not result in a supplemental report.
However, if an operator finds records related to documenting gas transmission MAOP after the end of the
reporting year and these records result in a change in Part Q status from incomplete records to complete
records, the operator may choose to file a supplemental report to change Part Q.
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 §192.903. §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, the operator should submit Form PHMSA F 7100.1-1 rather than this Form PHMSA F
7100.2-1.
If you need copies of the Form PHMSA F 7100.2-1 and/or instructions, they can be found
on http://www.phmsa.dot.gov/pipeline/library/forms. The documents are included in the section titled
Accident/Incident/Annual Reporting Forms.

Page 1 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

ONLINE REPORTING REQUIREMENTS
Annual Reports must be submitted online through the PHMSA Portal at https://portal.phmsa.dot.gov/portal,
unless an alternate method is approved (see Alternate Reporting Methods below).
You will not be able to submit reports until you have met all of the Portal registration requirements –
see http://opsweb.phmsa.dot.gov/portal_message/PHMSA_Portal_Registration.pdf
Completing these registration requirements could take several weeks. Plan ahead and register well in
advance of the report due date.

REPORTING METHOD
Use the following procedure for online reporting:
1. Go to the PHMSA Portal at https://portal.phmsa.dot.gov/portal
2. Enter PHMSA Portal Username and Password ; press enter
3. Select OPID; press “continue” button.
4. Under “Create Reports” on the left side of the screen, under Annual select “Gas
Transmission and Gathering” and proceed with entering your data. Only one annual
report by commodity for an OPID may be submitted per year.
5. To save intermediate work without formally submitting it to PHMSA, click Save. To
modify a draft of an annual report that you saved, go to Saved Reports and click on
Gas Transmission and Gathering. Locate your saved report by the date, report year, or
commodity. Select the record by clicking on it once, and then click Modify above the
record.
6. Once all sections of the form have been completed, click on Validate to ensure all
required fields have been completed and data meets all other requirements. A list of
errors will be generated that must be fixed prior to submitting an Annual Report.
7. 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.
8. A confirmation message will appear that confirms a record has been successfully
submitted. To save or print a copy of your submission, go to Submitted Reports on
the left hand side, and click on Gas Transmission and Gathering. Locate your
submitted report by the date, report year, or Commodity Group, and then click on the
PDF icon to either open the file and print it, or save an electronic copy.

Page 2 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

9. To submit a Supplemental Report, go to Submitted Reports on the left hand side, and
click on Gas Transmission and Gathering. Locate your submitted report by the date,
report year, or Commodity Group. Select the record by clicking on it once, and then
click “Create Supplemental”.
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(d) 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 mileage for the same set of
pipelines is reported in different parts of the form, the online system will require the different parts to be
consistent. Mileage values over 60 miles must be within 0.5% of the baseline and values under 60 miles
must be within 0.3 miles for each of these categories: gas transmission onshore, gas transmission
offshore, gas gathering onshore Type A, gas gathering onshore Type B, and gas gathering offshore. For
example, if you report 60 miles of onshore gas transmission in Part J, the onshore gas transmission
mileage by diameter in Part H must be within 0.3 miles of 60. Use the number of decimal places needed
to satisfy these consistency checks.
Part L will serve as the baseline for gas transmission miles in HCAs. When “in HCA” data is entered in
Parts Q and R, the values must be consistent with HCA miles entered in Part L. HCA mileage values
over 50 must be within 0.2% of the baseline and values under 50 miles must be within 0.1 miles.
Enter the Calendar Year for which the Report is being filed, bearing in mind that the report should reflect
the system as-of the end of that calendar year.
The Initial Report or Supplemental Report box will be populated by the online system.
For a given OPID, a separate Annual Report is required for each Commodity Group within that
OPID. The separate Annual Report is to cover all pipeline facilities – both INTERstate and
INTRAstate – included within that OPID that serve to transport that Commodity Group. As an
example, if an operator uses a single OPID and has one set of pipeline facilities transporting natural
gas and another transporting landfill gas, this operator must file two Annual Reports – one Annual
Report covering natural gas facilities and a second for the landfill gas facilities. When a pipeline
facility transports two or more Commodity Groups, the pipeline facility should be reported only once
under the predominantly transported Commodity Group.

Page 3 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Part A is completed once for each Annual Report.
PART A – OPERATOR INFORMATION
Complete all sections of Part A before continuing to the next Part.
1. Operator’s 5-digit Identification Number (OPID)
For online entries, the OPID will automatically populate based on the selection you made when
entering the Portal. If you have log-in credentials for multiple OPID, be sure the report is being
created for the appropriate OPID. Contact PHMSA’s Information Resources Manager at 202-3668075 if you need assistance with an OPID.
2. Name of Operator
This is the company name associated with the OPID. For online entries, the name will be
automatically populated based on the OPID entered in A1. If the name that appears is not correct, you
need to submit an Operator Name Change (Type A) Notification.
If the company corresponding to the OPID is a subsidiary, enter the name of the parent company.
3. Reserved
4. Headquarters address
This is the headquarters address associated with the OPID. For online entries, the address will
automatically populate based on the OPID entered in A1. If the address that appears is not correct,
you need to change it in the online Contacts module.
5. This Report pertains to the following Commodity Group
It is a PHMSA requirement that operators submit separate Reports for each Commodity Group within
a particular OPID.
File a separate Annual Report for each of the following Commodity Groups:
Natural Gas
Synthetic Gas (such as manufactured gas based on naphtha)
Hydrogen Gas
Propane Gas
Landfill Gas (includes biogas)

Page 4 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Other Gas – If this Commodity Group is selected, report the name of the other gas in the
space provided.
Note: When a pipeline facility transports two or more of the above Commodity Groups, the pipeline
facility should be reported only once under the predominantly transported Commodity Group. For
example, if an operator has a pipeline segment that is used to transport natural gas during the majority of
the year and propane for a couple of weeks, that operator should only file an annual report for the natural
gas. If an operator has two pipeline segments with one pipeline segment used to transport natural gas and
the other pipeline segment transporting hydrogen gas, that operator should file two annual reports - 1
report for natural gas and 1 report for hydrogen gas.
6. Reserved
7. INTERstate and INTRAstate pipeline
For a given OPID, both INTERstate and INTRAstate pipeline facilities for a Commodity Group
can be entered in a single report. Enter each State and portion of the Outer Continental Shelf (OCS) for
both the INTERstate and INTRAstate pipeline facilities. The States and OCS options entered here create
the set of Parts H, I, J, K, L, M, P, Q, and R in the online reporting system. OCS options available for
selection are OCS – Alaska; OCS- Atlantic; OCS-Gulf of Mexico; and OCS – Pacific.
Interstate gas pipeline means a gas pipeline facility or that part of a gas pipeline facility 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.).
Intrastate gas pipeline means a gas pipeline facility or that part of a gas pipeline facility that is used to
transport gas within a state and is not subject to the jurisdiction of FERC under the Natural Gas Act
(15 U.S.C. 717 et seq.).
8. RESERVED

Page 5 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

For the designated Commodity Group, complete Part C one time for all pipeline facilities – both
INTERstate or INTRAstate – included within this OPID. Parts B and D will be populated based on
information entered in Parts L and P respectively.
PART B – TRANSMISSION PIPELINE HCA MILES
In Part L of this report, the number of HCA miles are reported by-State/OCS and by the
INTERstate/INTERstate status of the pipeline. All Part L data will be summed and displayed in Part B.
PART C - VOLUME TRANSPORTED IN TRANSMISSION PIPELINES (ONLY)
IN MILLION SCF PER YEAR
(Transmission lines of Gas Distribution systems excluded from 2010 through 2012)
Report the volume transported in transmission pipelines during the calendar year for this Commodity
Group, in millions of standard cubic feet (60ºF and 14.73 psia). 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 pipeline
facilities should also be reported in Part C within the proper row. For gas transmission pipelines within
storage fields, report the volume moved out of storage. Do not report the volume placed into storage.
Note: This Part does not need to be completed if the reporting OPID includes only gas gathering
pipelines..
PART D – MILES OF PIPE BY MATERIAL AND CORROSION PREVENTION STATUS
In Part P of this report, the miles of pipeline by material type and corrosion prevention status are reported
by-State/OCS and by the INTERstate/INTRAstate status of the pipeline. All Part P data will be summed
and displayed in Part D.
PART E – RESERVED

Page 6 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Parts F and G are reported one time for INTERstate transmission assets and once for each State
with INTRAstate transmission.
PART F includes inspection, assessment, and repair data both within and outside HCAs. In Part L,
the number of HCA miles is collected by-State/OCS portion and by INTERstate/INTRAstate. The
online system will provide Part F for INTERSTATE assets only after an INTERstate Part L with
transmission miles is created. Until HCA miles are entered in an INTERstate Part L, the “within
HCA” portions of Part F will remain locked. For INTRAstate assets, a similar process is followed
but Part F will be created for each State with INTRAstate transmission.
Part G includes assessment data only within an HCA.
applicable Part L, this section will remain locked.

Until HCA miles are entered in the

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. When Part F specifies “WITHIN AN HCA SEGMENT”, report only on
transmission miles within HCA segments. Do not report on transmission pipelines included in an IM
Program as a result of Alternative MAOP under 192.620 or a PHMSA directive such as Corrective Action
Order, Compliance Order, or Special Permit. 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 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.
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, including actions taken as a result of ILI inspections conducted
during prior years. Do not include actions which are anticipated based on review of ILI
results but which did not actually occur during the reporting year.

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Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
Anomalies not excavated and eliminated by pipe replacement are reported in Parts F6d and
F6e.
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, such as recoating, were taken.
Report in c. only the anomalies in HCA pipeline segments that were repaired and were
considered conditions under the repair criteria in the IM regulations. Scheduled
conditions, as used in c.4, 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 repaired conditions reported in item c. may not exceed the total number of repaired
anomalies 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.
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,
including actions taken as a result of DA inspections conducted during prior years. Do not
include actions which are anticipated based on DA inspection results but which did not
actually occur during the reporting year.

Page 8 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Report in b. the total number of anomalies excavated and repaired, not those for which
other mitigative actions, such as recoating, were taken, 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.
Report in c. only the anomalies in HCA pipeline segments that were repaired and were
considered conditions under the repair criteria in the IM regulations. Scheduled
conditions, as used in c.4, 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 repaired conditions reported in item c. may not exceed the total number of repaired
anomalies reported in item b.
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. Describe the other
technique(s) in the “specify” field.
Include all actions taken during the calendar year that resulted from information obtained
during an inspection using an other technique including, actions taken as a result of
inspections conducted during prior years. Do not include actions which are anticipated
based on inspection results but which did not actually occur during the reporting year.
Report in b. only those anomalies actually repaired, not those for which other mitigative
actions, such as recoating, were undertaken.
Report in c. only the anomalies in HCA pipeline segments that were repaired and were
considered conditions under the repair criteria in the IM regulations. Scheduled
conditions, as used in c.4, 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 repaired conditions reported in item c. may not exceed the total number of repaired
anomalies reported in item b.
Section 6 - Total Mileage Inspected (all Methods) and Actions Taken.
Items a. through c. will be calculated automatically based on data entered in sections 1-5.
Items d and e require information about actionable anomalies eliminated from HCAs by
pipe replacement and abandonment. An anomaly is considered actionable if it may exceed
acceptable limits, based on the operator’s anomaly and pipeline data analysis. Any
anomaly excavated and repaired should be reported in section 2, 4, or 5. Do not report

Page 9 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

these anomalies again in items d and e. If pipeline facilities in an HCA were abandoned
and the operator replaced the transportation functionality with new pipeline facilities, enter
the anomalies in item d, replacement. If the transportation functionality of the abandoned
facility was NOT replaced by the operator, enter the anomalies in item e, abandonment.
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 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 are not in an HCA but which are included in an IM Program as a
result of Alternative MAOP under 192.620 or a PHMSA directive such as Corrective Action Order,
Compliance Order, or Special Permit.
Report only assessments that were completed during the calendar year. An assessment is considered
complete on 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 validate the total completed and scheduled
assessment mileage in their Assessment Plans with the mileage reported here. The comparison of these
two 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.

While the regulations do not recognize an intermediate state between operational and abandoned , PHMSA has acknowledged
that operators sometimes maintain some of their pipe in an idle status in which conducting IM assessments is impractical.

Page 10 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

For the designated Commodity Group, complete PARTs H, I, J, K, L, M, P, Q, and R covering
INTERstate pipeline facilities for each State and each Outer Continental Shelf (OCS) option in
which INTERstate systems exist within this OPID. Report offshore pipelines in state waters in the
State portion. Separately report offshore pipelines on the OCS under one of the four OCS options;
Alaska, Atlantic, Gulf of Mexico, and Pacific. Complete all of these Parts again for INTRAstate
pipeline facilities in each State in which INTRAstate systems exist within this OPID.
For example: Consider a gas pipeline system that includes INTERstate pipeline facilities in six
states and the Gulf of Mexico OCS and INTRAstate pipeline facilities in three states. These Parts
will be completed ten times; – seven times for INTERstate assets (once for each state and once for
OCS) and once for the INTRAstate assets in three states.
Each time these Parts are completed, the online reporting
INTERstate/INTRAstate and State/OCS portion for the data.

system

will

show

the

When mileage for the same set of pipelines is reported in different parts of the form, the online
system will require the different parts to be consistent for each of these categories: gas transmission
onshore, gas transmission offshore, gas gathering onshore Type A, gas gathering onshore Type B,
and gas gathering offshore. Mileage values over 60 miles must be within 0.5% of the baseline and
values under 60 miles must be within 0.3 miles. For example, if you report 60 miles of offshore gas
gathering by decade of installation in Part J, the offshore gas gathering mileage by diameter in Part I must
be within 0.3 miles of 60.
Part K will serve as the baseline for gas transmission miles by class location. When class location miles
are entered in Parts Q and R, the values must be consistent with those entered in Part K.
Part L will serve as the baseline for gas transmission miles in HCAs. When “in HCA” data is entered in
Parts Q and R, the values must be consistent with HCA miles entered in Part L. HCA mileage values
over 50 must be within 0.2% of the baseline and values under 50 miles must be within 0.1 miles.
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. Enter the appropriate mileage in the corresponding nominal size blocks. Only integers are used
for NPS. For example, report 6.625” diameter pipe in the NPS 6 category.
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.
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. Report onshore Type A and Type B gathering lines (§192.8) separately. Enter the appropriate
mileage in the corresponding nominal size blocks. Only integers are used for NPS. For example, report
6.625” diameter pipe in the NPS 6 category.

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Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
PART J – MILES OF PIPE BY DECADE INSTALLED
Report the miles of pipe by decade installed. When the decade of construction is unknown, enter
estimates of the totals of such mileage in the “Unknown” section of Part J.
PART K – MILES OF TRANSMISSION PIPE BY SPECIFIED MINIMUM YIELD STRENGTH
Class locations are defined in §192.5. Report the total miles of gas transmission pipe by hoop stress (as
percent of SMYS) for pipe onshore and offshore by stress range and Class Location. Report pipe for
which hoop stress is unknown and all non-steel pipe, regardless of operating pressure, in the rows
indicated.
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.
Miles by class locations from this part must be consistent with class location miles entered in Parts Q and
R.
PART L – MILES OF PIPE BY CLASS LOCATION

Gas transmission miles will be populated based on data entered in Part K. Report the number of Onshore
and Offshore miles of gas gathering pipe in each Class Location available on the form.
Report the number of HCA miles for both Onshore and Offshore transmission pipe. Do not include
pipelines or portions of pipelines that are not in an HCA but which are included in an IM Program as a
result of Alternative MAOP under 192.620 or a PHMSA directive such as Corrective Action Order,
Compliance Order, or Special Permit.
HCA Mile data entered in this Part will be summarized in Part B and affects the ability to enter data in
Parts F and G. HCA miles entered here must be consistent with HCA miles entered in Parts Q and R.

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Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

PART M – FAILURES, LEAKS, AND REPAIRS
For the designated Commodity Group, this Part includes reporting for both pipeline facilities covered by
this OPID which are in HCAs as well as pipeline facilities that are not. Additional instructions are
provided below.
PART M1 – ALL LEAKS ELIMINATED/REPAIRED IN CALENDAR YEAR; 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 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 should also report the number of failures in HCAs, as required by
§192.945 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, Type B, and offshore
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 they have available.
For sections replaced and 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 and are reported on Form PHMSA F 7100.2.
For the purposes of this Part M1, Leaks and Failures are to be classified as one of the following:
EXTERNAL CORROSION: includes releases or failures in the pipe or other component due to
galvanic, bacterial, chemical, stray current, or other corrosive action initiating on the outside surface of
the pipe. This includes the “External Corrosion” sub-cause on the PHMSA Gas Transmission/Gathering
Incident Report form.

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Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

INTERNAL CORROSION: includes releases or failures in the pipe or other component due to
galvanic, bacterial, chemical, stray current, or other corrosive action initiating on the inside surface of the
pipe. This includes the “Internal Corrosion” sub-cause on the PHMSA Gas Transmission/Gathering
Incident Report form.
STRESS CORROSION CRACKING: includes releases or failures 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. This includes the
“Environmental Cracking-related” sub-cause on the PHMSA Gas Transmission/Gathering Incident
Report form.
MANUFACTURING: includes releases or failures caused by a defect or anomaly introduced during the
process of manufacturing the pipe, including seam defects and defects in the pipe body or pipe girth weld.
This includes the “Original Manufacturing Defect-related” sub-cause on the PHMSA Gas
Transmission/Gathering Incident Report form.
CONSTRUCTION: includes releases or failures caused by a dent, gouge, excessive stress, or some
other defect or anomaly introduced during the process of constructing, installing, or fabricating pipe (or
welds which are an integral part of pipe), including welding or other activities performed at the facility.
This includes the “Construction-, Installation-, or Fabrication-related” sub-cause on the PHMSA Gas
Transmission/Gathering Incident Report form.
EQUIPMENT: includes releases from or failures of items other than pipe or welds, and includes
releases or failures resulting from: malfunction of control/relief equipment including valves, regulators,
or other instrumentation; compressors or compressor-related equipment; various types of connectors,
connections, and appurtenances; the body of equipment, vessel plate, or other material (including those
caused by: construction-, installation-, or fabrication-related and original manufacturing-related defects or
anomalies; and low temperature embrittlement); and, all other equipment-related releases or failures. This
includes all of the sub-causes under G6, Equipment Failure, on the PHMSA Gas Transmission/Gathering
Incident Report form.
INCORRECT OPERATIONS: includes releases or failures resulting from operating, maintenance,
repair, or other errors by operator or operator contractor personnel, including, but not limited to improper
valve selection or operation, inadvertent overpressurization, or improper selection or installation of
equipment. This includes all of the sub-causes under G7, Incorrect Operations, on the PHMSA Gas
Transmission/Gathering Incident Report form. Also includes releases or failures 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).
THIRD PARTY DAMAGE/MECHANICAL DAMAGE: includes releases or failures 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:

Page 14 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

•

Third Party Excavation Damage - includes releases or failures resulting directly from
excavation damage by people or contractors not associated with the operator (oftentimes
referred to as “third party” excavation damage).

•

Previous Damage (due to Excavation Activity) - includes releases or failures that are
determined to have resulted from previous damage due to excavation activity. This
includes only the Previous Damage due to Excavation Activity sub-cause on the PHMSA
Gas Transmission/Gathering Incident Report form.

•

Vandalism (includes all Intentional Damage) – includes releases or failures due to
willful or malicious destruction of the operator’s pipeline facility or equipment. This
includes only the “Intentional Damage” sub-cause on the PHMSA Gas
Transmission/Gathering Incident Report form.

WEATHER RELATED/OTHER OUTSIDE FORCE DAMAGE: includes releases or failures
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
industrial, man-made, or other fire or explosion; damage by vehicles, boats, fishing or maritime vessels or
equipment; and, electrical arcing. Report separately, as indicated:
•

Natural Force Damage (all) - This includes all of the sub-causes under G2, Natural Force
Damage, on the PHMSA Gas Transmission/Gathering Incident Report form.

•

Other Outside Force Damage (excluding Vandalism and all Intentional Damage) This includes all of the sub-causes under G4 – Other Outside Force Damage except
Intentional Damage, on the PHMSA Gas Transmission/Gathering Incident Report form.

OTHER: includes releases or failures resulting from any other cause not listed above, including those of
a miscellaneous or unknown or unknowable nature. This includes both of the two sub-causes under G8,
Other Incident Cause, on the PHMSA Gas Transmission/Gathering Incident Report form.
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.

Page 15 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
PART P – MILES OF PIPE BY MATERIAL AND CORROSION PREVENTION STATUS
For steel pipe, 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. For non-steel pipe, report the total miles of onshore and offshore pipe for
each type listed.
Composite means pipe consists of two or more dissimilar materials layered together to be stronger than
the individual materials. Use of composite pipe requires a PHMSA Special Permit or waiver from a State.
Examples include, but are not limited to, fiber reinforced thermoplastic composite pipe, fiber reinforced
thermosetting plastic pipe, steel reinforced thermoplastic pipe, and metallic composite pipe. If a
dissimilar material has been inserted into older pipe, report the pipe as the material that contains the
pressure.
Other means a pipe made of a material not specifically designated on the form, such as copper,
aluminum, etc. Describe the other material(s) in the “specify” field.

Page 16 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

PART Q – Gas Transmission Miles by § 192.619 MAOP Determination Method
In the “Total” columns, operators report transmission pipeline miles by the MAOP determination method
and by each combination of class location and HCA status.
A short explanation of each MAOP determination method is:
§ 192.619

Method Description

(paragraph)

(a)(1)
(a)(2)
(a)(3)
(a)(4)
(c)
(d)
Other

Design Pressure
Post-Construction Pressure Test
Highest Actual Operating Pressure during 5 years preceding July 1, 1970 – this
is NOT the Grandfather Clause
History of Pipe (primarily corrosion and actual operating pressure)
Grandfather Clause - Highest Actual Operating Pressure during 5 years preceding
1970, even if this MAOP is higher than pressures determined by other (a) methods
Alternative MAOP under § 192.620(a) and Alternative MAOP Special Permits
Use this category if you did not base your MAOP on any of the paragraphs within
§ 192.619

A short explanation of each Class Location and HCA is:
Location
Class 1
Class 2
Class 3
Class 4
High
Consequence
Area (HCA)

Short Description (full detail in § 192.5)
≤10 buildings intended for human occupants.
<46 and >10 buildings intended for human occupants.
≥46 buildings or an area within 100 yards of building/well defined area
occupied by at least 20 persons at designated intervals.
Any location where buildings with four or more stories above ground are
prevalent.
A location which is specifically defined in § 192.903. In general, a HCA is
an area where a pipeline release could have greater consequence to human
health and safety or the environment.

Transmission miles may only be entered under one of the seven MAOP determination methods. For each
combination of class location and HCA shown on the form, report the miles for each MAOP
determination method. The sum of all “Total” columns for 192.619 subsections and Other for each class
location must be consistent with the class location data reported in Parts K and R. The sum of all “Total”
columns in HCA must be consistent with HCA miles entered in Part L. The sum of all “Total” columns
in HCA for each class location must be consistent with HCA miles for each class location entered in Part
R. If miles are entered in any row of the Other column, enter text describing the Other method(s) used to
establish MAOP.
For each combination of class location and HCA, except Classes 1 and 2 outside HCAs, report the
transmission miles for which the operator lacks complete records to verify the MAOP determination

Page 17 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

method in the “Incomplete Records” column. The value in the “Incomplete Records” column must be
less than or equal to the value in the “Total” column for each combination of class location and HCA. For
the purpose of this part, “verification records” can include traceable, verifiable, and complete records
demonstrating that the criteria of the MAOP determination have been met. For 619(a)(1), the
“verification records” can include pipe mill tests (mechanical and chemical properties), as-built drawings,
alignment sheets, specifications, and design, construction, inspection, and maintenance documents. For
619(a)(2), the “verification records” are pressure test records. For miles of transmission pipeline for
which the operator has not completed the records review, include these miles in the “Incomplete Records”
column. See PHMSA Advisory Bulletin (ADB) 2012-06 for additional
details: http://www.phmsa.dot.gov/staticfiles/PHMSA/DownloadableFiles/Pipeline/Regulations/Advisory
Bulletins/AD-12-06.pdf
When reporting transmission miles for which 192.619(d) was used to establish MAOP, include miles of
pipeline installed pursuant to a PHMSA Alternative MAOP Special Permit allowing operation up to 80%
SMYS in Class 1 areas. From 2006 through 2010, PHMSA issued fifteen of these special permits with
conditions equivalent to pipeline installed under 192.619(d). Alternative MAOP pipelines with MAOP
determined by the limitations in 192.611(a)(1)(ii) or (a)(3)(iii) are to be reported as 619(d).
For pipeline systems placed in operation after July 1, 1970, selecting the MAOP determination method is
fairly simple. Neither 619(a)(3) nor 619(c) are viable options. When the pressures calculated under (a)(1)
and (a)(2) are identical, report the miles under (a)(2).
The MAOP for certain gas transmission pipelines placed in operation after July 1, 1970 may have been
affected by a class location study under 192.609. The relevant limitations on MAOP after these studies
are in Part 192.611. Any gas transmission pipeline with MAOP reduced pursuant to Part 192.611 should
be reported under the appropriate 619(a) section. For segments of gas transmission pipeline where the
reductions in 192.611 were not implemented due to a waiver/special permit from PHMSA or a
predecessor agency, report the miles under the MAOP determination method used prior to the
waiver/special permit.
For pipeline systems placed in operation before July 1, 1970, the situation is more complicated.
Operators could either implement 619(c) or determine a pressure under each of the 619(a) options and
choose the lowest value as MAOP. For segments of pipe operating at more than 72% SMYS in class one
locations, 192.619(c) is the only viable option. 192.619(c) is referred to as the Grandfather Clause and
can be the MAOP determination method for pipe operated before July 1, 1970 regardless of the ability to
determine pressure values under 192.619(a)(1) and (a)(2).
After the original effective date of Part 192, gas pipeline operators established MAOP under the 192.619
options in the original regulations. Some of these 619 options are no longer in Part 192 or have a
different section designation. The table on the next page provides instruction for proper reporting of these
original code sections:

Page 18 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Original Part
192 Section
619(a)(4)
619(a)(5)

619(a)(6)

Original 619 Text
For furnace butt welded steel pipe, a pressure equal to 60 percent of the
mill test pressure to which the pipe was subjected.
For steel pipe other than furnace butt welded pipe, a pressure equal to 85
percent of the highest test pressure to which the pipe has been subjected,
whether by mill test or by the post installation test.
The pressure determined by the operator to be the maximum safe pressure
after considering the history of the segment, particularly known corrosion
and the actual operating pressure.

Report in
Part Q
619(a)(1)
619(a)(2)

619(a)(4)

The original Part 192 also required class location studies under 192.607 for certain pipelines in service
before July 1, 1970. When a class location study, under either 192.607 or 192.609, finds that MAOP
needs to be reduced, Part 192.611 provides guidance for determining the MAOP. Proper reporting of the
MAOP determination method depends on whether the pipe was replaced with new pipe or the MAOP was
reduced for existing pipe. Report any portion of new pipe under the appropriate 619(a) section, but (a)(3)
is no longer a viable option. No change in MAOP determination method occurs for pipe within the class
location study area whose MAOP was not reduced. When MAOP is reduced on existing pipe, report the
miles under the appropriate 619(a) section, but (a)(3) is no longer a viable option.

PART R - Gas Transmission Miles by Pressure Test (PT) Range and Internal Inspection
For Part R, enter miles of gas transmission pipe in each of the three pressure test ranges with each range
divided into miles able to be internally inspected and miles unable to be internally inspected. All gas
transmission miles must be reported in this part. The miles entered for each class location must be
consistent with the class location data entered in Parts K and Q. The sum of HCA miles must be
consistent with HCA miles entered in Part L. The HCA miles in each class location must be consistent
with HCA miles for each class location entered in Part Q.
If an operator is uncertain whether a gas transmission pipeline has been subjected to a post-construction
pressure test, report the miles in the “PT < 1.1 or No PT” section. Operators must consider elevation
changes when deciding on the appropriate pressure test range and report the miles in the appropriate
pressure range. During a hydrostatic pressure test, the recorded test pressure is the lowest pressure during
the test calculated at the highest elevation point. This test pressure may put the bulk of the mileage in the
1.1 to 1.25 times MAOP range. Some pipeline at lower elevations could have experienced test pressures
higher than 1.25 times MAOP and could be reported in the PT > 1.25 MAOP range.
“Miles Internal Inspection ABLE” means a length of pipeline through which commercially available
devices can travel, inspect the entire circumference and wall thickness of the pipe, and record or transmit
inspection data in sufficient detail for further evaluation of anomalies. If an operator is uncertain whether
a gas transmission pipeline is able to be internally inspected, report the miles in the “Miles Internal
Inspection NOT ABLE” column.

Page 19 of 20

Instructions (rev xy-2013) for Form PHMSA F 7100.2-1 (rev xy-2013)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

For the designated Commodity Group, complete Part N one time for all of the pipeline facilities
included within this OPID. Complete Part O one time for all the pipeline facilities included within
this OPID if any Part L HCA mile value is greater than zero.
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, title, e-mail address, phone number. PHMSA will contact the Preparer if data
quality checks raise questions about the report.
PART O – CERTIFYING SIGNATURE
CERTIFYING SIGNATURE must be a senior executive officer of the operator. The Pipeline
Inspection, Protection, Enforcement and Safety Act (49 U.S.C. 60109(f)) requires pipeline operators to
have a senior executive officer of the company sign and certify annual pipeline Integrity Management
Program (IMP) performance reports - portions of Parts M1, F, G, and L. 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. 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.

Page 20 of 20

File Type	application/pdf
Subject	GAS TRANSMISSION/GATHERING SYS
Author	Roger Little
File Modified	2014-09-18
File Created	2013-11-25