Red-line of Gas Transmission Annual Report

30 Day NoticeGT GG Annual Report Form wInstruct09212012.pdf

Incident and Annual Reports for Gas Pipeline Operators

Red-line of Gas Transmission Annual Report

OMB: 2137-0522

⚠️ Notice: This form may be outdated. More recent filings and information on OMB 2137-0522 can be found here:

Document [pdf]

Download: pdf | pdf

26
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: 01/31/2014
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 22 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 completeing 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.
PART A - OPERATOR INFORMATION

DOT USE ONLY

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

2. NAME OF OPERATORCOMPANY OR ESTABLISHMENT:

/
IF SUBSIDIARY, NAME OF PARENT:
__________________________________________________

3. RESERVED
INDIVIDUAL WHERE ADDITIONAL INFORMATION MAY BE
OBTAINED:

4. HEADQUARTERS ADDRESS:

Company Name
Name
Street Address
Title

__________________________________________________

State: /

/ Zip Code: /

Email Address

/__/__/__/-/__/__/__/-/__/__/__/__/

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
 Landfill Gas
 Other Gas  Name of Other Gas ___________________

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 1 of 15
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: 01/31/2014

6. RESERVED
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)

 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 L and 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.
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
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. 06xy-20121)

Pg. 2 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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

Calc

Offshore

Calc

Total Miles

Calc

 Check this box and proceed to PART D without do not completeing

PART C - VOLUME TRANSPORTED IN TRANSMISSION
PIPELINES (ONLY) IN MILLION SCF PER YEAR
(excludesTransmission lines of Gas Distribution systems)

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
Landfill Gas
Other Gas  Name: ____________________

PART D - MILES OF STEEL PIPE BY MATERIAL AND CORROSION PREVENTIONOTECTION 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

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 3 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

PART E - RESERVEDMILES OF non-STEEL PIPE BY TYPE AND LOCATION
Cast Iron
Pipe

Wrought Iron Pipe

Plastic Pipe

Other Pipe

Total Miles

Transmission
Onshore
Offshore

Calc
Calc

Subtotal Transmission

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. 06xy-20121)

Pg. 4 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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. Part F “WITHIN AN HCA SEGMENT” data and Part G may be completed only if HCA Miles
in Part L is greater than zero. 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, 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. 06xy-20121)

Pg. 5 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

(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. 06xy-20121)

Calc

Pg. 6 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

For the designated Commodity Group, complete PARTs H, I, J, K, L, and M, P, Q, and R 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, P, Q, and R
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. 06xy-20121)

Pg. 7 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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

Onshore
Type B

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

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 - Gathering

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 8 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

PART J – MILES OF PIPE BY DECADE INSTALLED

Unknown

Pre-1940 or
Unknown

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

Decade Pipe Installed

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. 06xy-20121)

Pg. 9 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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
than 30% 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

XXXXXXXXXXX

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. 06xy-20121)

Pg. 10 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

PART L - MILES OF PIPE BY CLASS LOCATION
Class Location
Class 4

Total
Class Location
Miles

Calc from Part K

Calc

XXXXXXXXXX

Calc

Class I

Class 2

Class 3

Calc from Part K

XXXXXXXXX

Calc

HCA Miles in
the IMP
Program

Transmission
Onshore
Offshore
Subtotal Transmission

Calc

Gathering
Onshore Type A
Onshore Type B
Offshore

Calc
Calc
Calc

Subtotal Gathering

Calc

Total Miles

Calc

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Calc

Pg. 11 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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
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

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

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 12 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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

Steel cathodically
unprotected

Bare

Coated

Cast
Iron

Wrought
Iron

Plastic

Composite

Other2

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)
w/out
Recds

(a)(2)
Total

(a)(2)
w/out
Recds

(a)(3)
Total

(a)(3)
w/out
Recds

(a)(4)
Total

(a)(4)
w/out
Recds

(d)
Total

(d)
w/out
Recds

Other1
Total

Other
w/out
Recds

Class 1 (in HCA)
Class 1 (not in HCA)

XXXXXX

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

Sum of Total row for all “Total” columns
Sum of Total row for all “w/out Recds” columns
1
Specify Other method(s):

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 13 of 15
Reproduction of this form is permitted.

Calc

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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

1.25 MAOP > PT ≥ 1.1 MAOP Total

Calc

PT < 1.1 or No PT Total

Calc
Grand Total

Calc

Form PHMSA F 7100.2-1 (Rev. 06xy-20121)

Pg. 14 of 15
Reproduction of this form is permitted.

Form Approved
OMB No. 2137-0522
Expires: 01/31/2014

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 portion(s) of the
pipelines and/or pipeline facilities included within this covered under this Commodity Group and OPID
have Part L HCA mile value greater than zero.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. 06xy-20121)

Pg. 15 of 15
Reproduction of this form is permitted.

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
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 20120 affecting submissions for 20120 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. (Additionally, and in order to align an operator’s NPMS
submission with their Annual Report data, PHMSA encourages suggests that 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 system as-of December 31 of the previous year. for the preceding
calendar year, except that for the 2010 reporting year the report must be submitted by June 15, 2011. 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. If an operator discovers an
error in a submitted annual report, a supplemental report should be filed. However, the Annual Report
reflects the system at the end of a calendar year. Supplemental reports should not be filed for changes
made to the system after the end of the reporting calendar year.Operators should file Supplemental
Reports as necessary, including those supplementing prior years’ Reports.
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 operatorr she 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 the Pipeline
Safety Community main page, http://phmsa.dot.gov/pipeline, then select by clicking Data, Reports &
Library, and Statistics and then selecting the Forms under the “Mini-Menu” on the right side of the
pagehyperlink. The forms are included in the section titled Accident/Incident/Annual Reporting Forms.If
you have questions about this Report or these instructions, call PHMSA’s Information Resources
Manager at 202-366-8075.

Page 1 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
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/pipeline, 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.
The following two separate PIN/password requirements must be fulfilled prior to submitting data online:
1. You must have an Office of Pipeline Safety (OPS) provided Operator Identification
Number (OPID) and Personal Identification Number (PIN). If you do not have one,
complete and submit the form located on the OPS Online Data Entry and Operator
Registration
System
New
Operator
Registration
web
site
at
http://opsweb.phmsa.dot.gov/cfdocs/opsapps/pipes/new_operator.cfm to obtain one.
2. You must ALSO have a Username and Password obtained by registering through the
PHMSA Portal. If you have an OPS OPID and PIN, you may obtain a Username and
Password through the PHMSA Portal. If you do not have a Username and Password for
the PHMSA Portal, go to https://portal.phmsa.dot.gov/pipeline and click on Create
Account and complete the form as required.
Important: Each operator without an OPID is to plan accordingly and allow for several weeks prior to the
due date of the Report to obtain their OPID from PHMSA.

REPORTING METHOD
Use the following procedure for online reportings to complete an Annual Report:
1. Go to to the PHMSA Portal at https://portal.phmsa.dot.gov/pipeline
2. Enter PHMSA Portal Username and Password ; press enter
3. Select OPID ; press “continue” button.
4. On the left side menu under “Incident/accident” select “ODES 2.0”
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 “Year 2010 and later” hyperlink under the Gas Transmission and Gathering
Pipeline Systems subtitle. This takes you to the PHMSA Portal login screen.

Page 2 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

3. Enter your “Username” and “Password and click on “Login”.
4.5.Under “Create Reports” on the left side of the screen, under Annual select “Gas
Transmission and Gathering” and proceed with entering your data. Note: Data fields
marked with a single asterisk are considered required fields that must be completed
before the system will accept your initial submission. Also, only one annual report by
commodity for an OPID may be submitted per year.
5.6.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
belowabove the record.
6.7.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.
7.8.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.
8.9.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.
9.10.
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

Page 3 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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. Part J, decade of installation, will serve as the mileage baseline for gas
transmission onshore, gas transmission offshore, gas gathering onshore, 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. 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 the report should reflect
the system as-of the end of the calendar year for which the report is being filed.ing 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).
The Select Initial Report or if this is the original filing for the calendar year. Select Supplemental
Report box will be populated by the online systemif 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.

For a given OPID, a separate Annual Report is requiredto be completed for each Commodity
Group within that OPID. The separate Annual Report is to cover all pipelines and/or 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
facilities and/or pipeline facilities that transporting natural gas and another that transportings
landfillsynthetic gas, this operator must is to file two Annual Reports – one Annual Report covering
all the facilities and/or pipelines that transport natural gas facilities and a second for the and
another Annual Report covering all the facilities and/or pipelines that transport landfillsynthetic
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.If another
operator utilizes two OPIDs with both natural gas and synthetic gas facilities and/or pipelines
within each OPID, that operator must file four separate Annual Reports.

Page 4 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Parts A – E isare to be completed once for each Annual Report., namely once for each Commodity
Group within an OPID, covering ALL of the pipelines and/or facilities (both Interstate and
Intrastate) and combining all states in which those assets exist. Separate reporting by state is not
required for these Parts. Parts F – M, however, are to be reported separately for Interstate and for
Intrastate facilities, or by state, or both depending on the instructions pertaining to each Part.

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)
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.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 Contact PHMSA’s Information Resources Manager at -202--366-8075 if you
need assistance with an OPID. (See instructions on the ONLINE DATA ENTRY page as described
above.)
2. Name of OperatorCompany or Establishment
This is the company name associated with theused when registering for an OPID and PIN in the
Online Data Entry System. When completing the Report For online entries, the nameName of
Operator is will be automatically populatedfilled in based on the OPID entered in Part A, Question 1.
If the name that appears is not correctdoes not coincide with the OPID, you need to submit an
Operator Name Change (Type A) Notification.contact PHMSA’s Information Resources Manager.
If the company corresponding to the OPID is a subsidiary, enter the name of the parent company.
3. ReservedIndividual 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
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.Enter the address and phone number of the
operator’s corporate headquarters.
5. This Report pertains to the following Commodity Group

Page 5 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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 Examples include landfill gas, biogas, and manufactured gas based on
naphtha)
Hydrogen Gas
Propane Gas
Landfill Gas (includes biogas)
Other Gas – If this Commodity Group is selected, report the name of the other gas in the
space provided.
Note: When a single pipeline or facility serves to transports two or more of the above Commodity
Groups, theat pipeline or facility should be reported only once under the predominantly transported ,
reporting within the Commodity Group for the commodity that is transported most predominantly during
the year being reported. 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 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.). Select the box indicating that portions of SOME or
ALL of the pipelines and/or pipeline facilities for this Commodity Group 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.

Page 6 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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, select the box indicating such. In this case, Parts B, F, G, the
“HCA” portions of M1, and O need not be completed.
7. INTERnterstate and/or INTRAntrastate pipeline
For a given OPID, both INTERstate and INTRAstate Ppipeline facilitiesassets for a included
within a particular Commodity Group can be entered in under a single reportOPID may be either
interstate, intrastate, or both. Enter each State and portion of the Outer Continental Shelf (OCS) for both
the INTERstate and INTRAstate pipeline facilities.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. 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 facility 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
Does this Report represent a change from last year’s final reported information for one or more of
the following Parts?
Select “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 filing of an Annual Report for these facilities. 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.
Select “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

Page 7 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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 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 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.
Select 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), select 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).
•

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 191/192, such as a
propane gas line.)

Page 8 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

•

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 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. Parts B
and D will be populated based on information entered in Parts L and P respectivelySeparate
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
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.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.

Page 9 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE 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 14.73 psia). Include the annual total volume
transported for all Sstates 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. 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 pipeline system corresponding to thereporting 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 select the box to so indicate.

PART D – MILES OF STEEL PIPE BY MATERIAL AND CORROSION PREVENOTECTION
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.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 – RESERVEDMILES 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.

For the designated Commodity Group, complete Parts F and G are reported one time for
INTERstate transmission assets and once for each State with INTRAstate transmission.

Page 10 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

PARTs 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 and G includes assessment data only within an HCA. Until HCA miles are entered in the
applicable Part L, this section will remain locked.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 twoletter 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. When Part F specifies “WITHIN AN HCA SEGMENT”, report only on
transmission miles within HCA segments. Do not report on transmission pipelines 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 Alternative MAOP under 192.620 orf other a PHMSA directives ( such as
Corrective Action Orders, Compliance Orders, or 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

Page 11 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
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 including
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) 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).
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, (not repair) were undertaken.
Report in c. only the anomalies in HCA pipeline segments that were repaired and were
considered conditions under were repaired because they met one of the repair criteria in the
IM regulations. “Scheduled conditions”, as used in c.4this 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 repaired conditions repairs reported in
item c. mayshould not exceed the total number of repaired anomalies repairs reported in
item b.)
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.

Page 12 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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 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,
including. 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, 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) 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. only the number of anomalies identified in HCA pipeline segments that were
repaired and were considered conditions under because when excavated and examined they
met one of 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.

Page 13 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
As for the other techniques, iInclude all actions taken during the calendar year that resulted
from information obtained during an inspection using an other technique including. 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 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 in b. only those anomalies actually repaired, not those for which other mitigative
actions, such as recoating, (not repair) 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.
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.
Items a. through c. These entries 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
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.
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.

Page 14 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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 are could otherwise not inaffect an HCA
but which are included in an IM Program as a result of Alternative MAOP under 192.620 or a other
PHMSA directives ( such as Corrective Action Orders, Compliance Orders, or Special Permit.s, etc.).
Report only assessments that were completed during the calendar year. An assessment is considered
complete on the 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 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, P, Q, and R covering
INTERstate pipelines and/or 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 and
again forcovering INTRAstate pipelines and/or pipeline facilities in 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 sixeven states and the Gulf of Mexico OCS and INTRAstate pipeline facilities in three
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).

Page 15 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

states. These Parts H, I, J, K, L, and M shouldwill be completed ten times; for this set of natural
gas pipeline systems – seven times for INTERstate assets (once for each state and once for OCS 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 these remaining Parts are completed, the online reporting system will show the indicate
whether the data reported is for INTERstate/ or INTRAstate and State/OCS portion for the
data.pipelines and/or pipeline facilities, and enter in the space provided the two-letter postal
abbreviation for the state.
Part J, by-decade installed, will serve as the mileage baseline gas transmission onshore, gas
transmission offshore, gas gathering onshore, and gas gathering offshore. 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 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 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 oOnshore and
oOffshore locations. 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.
Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any blocks
blank.

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. 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.

Page 16 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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
Class locations are defined in §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
(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, welldefined 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 steelgas 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-

Page 17 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
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.
In addition, rReport the number of HCA miles in the IMP program 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.
Note: Operators should cross check their numbers for the various Parts, when applicable.

PART M – INCIDENTS, FAILURES, LEAKS, AND REPAIRS
For the designated Commodity Group, this Part includes reporting for both pipelines and/or pipeline
facilities covered by this OPID which are in HCAs subject to the integrity management (IM) requirements
of 49 CFR 192, Subpart O as well as pipelines and/or pipeline facilities that are notcovered 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

Page 18 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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 §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, gathering lines and Type
B, and gathering lines for offnshore 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 andbut 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, and Incidents are to be classified as one of
the followingeither:
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. For PHMSA’s Gas Transmission/Gathering Incident Reporting form, Tthis includes the
“External Corrosion” sub-cause under G1 – Corrosion Failureon the PHMSA Gas
Transmission/Gathering Incident Report form.
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. From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the
purposes of this Part M1, Tthis includes the “Internal Corrosion” sub-cause on the PHMSA Gas
Transmission/Gathering Incident Report form.under G1 – Corrosion Failure.
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. From PHMSA’s Gas
Transmission/Gathering Incident Reporting form, and specifically for the purposes of this Part M1, tThis
includes the “Environmental Cracking-related” sub-cause on the PHMSA Gas Transmission/Gathering
Incident Report form under G5 – Material Failure of Pipe or Weld, which includes Stress Corrosion
Cracking as well as Sulfide Stress Cracking and Hydrogen Stress Cracking.

Page 19 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the purposes
of this Part M1, tThis includes the “Original Manufacturing Defect-related” sub-cause on the PHMSA
Gas Transmission/Gathering Incident Report formunder G5 – Material Failure of Pipe or Weld.
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.
From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the purposes
of this Part M1, tThis includes the “Construction-, Installation-, or Fabrication-related” sub-cause on the
PHMSA Gas Transmission/Gathering Incident Report formunder G5 – Material Failure of Pipe or Weld.
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.
From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the purposes
of this Part M1, tThis 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. From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for
the purposes of this Part M1, tThis includes all of the sub-causes under G7, – Incorrect Operations, on the
PHMSA Gas Transmission/Gathering Incident Report form.
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:
•

Excavation Damage - 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) 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, tThis includes
the Excavation Damage by Operator (First Party), Excavation Damage by Operator’s
Contractor (Second Party), and Excavation Damage by Third Party sub-causes on the
PHMSA Gas Transmission/Gathering Incident Report formunder G3 – Excavation

Page 20 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

Damage; .
•

Previous Damage (due to Excavation Activity) - includes releases or failures 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, tThis includes only the Previous Damage due to Excavation
Activity sub-cause on the PHMSA Gas Transmission/Gathering Incident Report
form.under G3 – Excavation Damage; and,

•

Vandalism (includes all Intentional Damage) – includes releases or failures due to
willful or malicious destruction of the operator’s pipeline facility or equipment. From
PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for the
purposes of this Part M1, tThis includes only the “Intentional Damage” sub-cause on the
PHMSA Gas Transmission/Gathering Incident Report form.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: 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) - From PHMSA’s Gas Transmission/Gathering Incident
Reporting form, and specifically for the purposes of this Part M1, tThis 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) From PHMSA’s Gas Transmission/Gathering Incident Reporting form, and specifically for
the purposes of this Part M1, tThis 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. From PHMSA’s Gas Transmission/Gathering
Incident Reporting form, and specifically for the purposes of this Part M1, tThis 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 21 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

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.
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.
PART Q – Gas Transmission Miles by § 192.619 MAOP Determination Method
In the “Total” columns, operators report transmission pipeline miles by the subsection of § 192.619
serving as the limiting factor for establishing MAOP and by each combination of class location and HCA.
A short explanation of each § 192.619 subsection for MAOP determination methodology is:
§ 192.619

Methodology Description

Page 22 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS
(paragraph)

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

Introduction: Except as specified in (c) and (d), use the lowest MAOP determined
by (a)(1), (a)(2), (a)(3), (a)(4).
Design Pressure
Post-Construction Pressure Test
High Actual Operation Pressure (5 years preceding 1970)
History of Pipe (primarily corrosion and actual operating pressure)
Allows the use of (a)(3) even if MAOP is higher than MAOPs determined by other
methodologies in (a)
Alternative MAOP (§ 192.620)
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 a single subsection of § 192.619. In some scenarios,
192.619(a)(1) through (4) may all have been considered when establishing MAOP, but PHMSA expects
that one value is lower than the others and was used to establish MAOP. In other scenarios, 192.619(c)
could be used to set MAOP, regardless of the values in 192.619(a)(1) through (4). For each combination
of class location and HCA shown on the form, report the miles in each MAOP category. 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 Part K. If miles are entered in 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 in the “w/out
Recds” column. The value in the “w/out Recds” 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” are records that can be used to validate the MAOP for the subject pipelines such as:
as-built drawings, alignment sheets, specifications, and all design, construction, inspection, testing,
maintenance, manufacturer, or other related documents. These records should be traceable, verifiable,
and complete. For miles of transmission pipeline for which the operator has not completed the records
review, include these miles in the “w/out Recds” column. See PHMSA Advisory Bulletin (ADB) 2012-

Page 23 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

06 for additional details:
http://www.phmsa.dot.gov/staticfiles/PHMSA/DownloadableFiles/Pipeline/Regulations/AdvisoryBulletin
s/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 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).

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 Part K.
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.
“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.
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 Groupincluded within this and OPID if any Part L
HCA mile value is greater than zeroany 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. 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)signed in December 2006)
requires pipeline operators to have a senior executive officer of the company sign and certify annual

Page 24 of 241

Instructions (rev xy-2012) for Form PHMSA F 7100.2-1 (rev xy06-20121)
ANNUAL REPORT FOR CALENDAR YEAR 20__
NATURAL AND OTHER GAS TRANSMISSION AND GATHERING PIPELINE SYSTEMS

pipeline Integrity Management Program (IMP) performance reports - (portions of Parts M1, F, G, and
LParts B, F, G, and M1O1 – 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 M1O1 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
eEntering 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 25 of 241

File Type	application/pdf
Subject	GAS TRANSMISSION/GATHERING SYS
Author	Roger Little
File Modified	2012-09-20
File Created	2012-09-20