Form PHMSA FORM F-7000- PHMSA FORM F-7000- Annual Report For Hazardous Liquid or Carbon Dioxide Sys

Notice: This report is required by 49 CFR Part 195. 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___
HAZARDOUS LIQUID OR CARBON DIOXIDE SYSTEMS

Form Approved
OMB No. 2137-0614
Expires: xx/xx/xxxx

INITIAL REPORT
SUPPLEMENTAL REPORT

Important: Please read the separate instructions for completeing this form before you begin.
PART A - *OPERATOR INFORMATION
DOT USE ONLY
1. OPERATOR’S 5 DIGIT IDENTIFICATION NUMBER (OPID)
/

/

/

/

/

2. NAME OF COMPANY OR ESTABLISHMENT

/

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IF SUBSIDIARY, NAME OF PARENT

*The operator is the person (as defined in 49 CFR 195.2) who
exercises substantial control over the operation of the pipeline.
3. LOCATION OF OFFICE WHERE ADDITIONAL INFORMATION
MAY BE OBTAINED

___________________________________________________

4. HEADQUARTERS NAME & ADDRESS, IF DIFFERENT

Number & Street

Number & Street

City & County

City & County

___________________________________________________
State & Zip Code
Telephone

5. OFTENTIMES MORE THAN ONE SET OF ASSETS INVOLVING MORE THAN ONE OPID ARE INCLUDED UNDER AN “UMBRELLA”
INTEGRITY MANAGEMENT PROGRAM. FOR THE PURPOSES OF COMPLIANCE WITH PHMSA’s INTEGRITY MANAGEMENT PROGRAM
REGULATIONS (PART 195.452), ARE THE ASSETS COVERED BY THE ABOVE OPID INCLUDED WITH OTHER ASSETS UNDER OTHER
OPIDs?

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… NO, THE ASSETS COVERED BY THIS OPID DO NOT INCLUDE PIPELINE SEGMENTS THAT
COULD AFFECT HIGH CONSEQUENCE AREAS AND THUS ARE NOT INCLUDED IN AN INTEGRITY
MANAGEMENT PROGRAM. IF THIS BOX IS CHECKED, LEAVE PARTS B, F, G, AND H BLANK.
… NO, THE ASSETS COVERED BY THIS OPID HAVE THEIR OWN INDEPENDENT INTEGRITY
MANAGEMENT PROGRAM.

… YES, THE ASSETS COVERED BY THIS OPID ARE PART OF AN INTEGRITY MANAGEMENT
PROGRAM THAT INCLUDES OTHER OPIDs. PLEASE LIST ANY AND ALL ADDITIONAL OPIDs
INLCUDED IN AN INTEGRITY MANAGEMENT PROGRAM ASSOCIATED WITH THIS OPID:
/__/__/__/__/__/, /__/__/__/__/__/, /__/__/__/__/__/, /__/__/__/__/__/, /__/__/__/__/__/,
/__/__/__/__/__/, /__/__/__/__/__/, /__/__/__/__/__/, etc.

6. THIS REPORT PERTAINS TO THE FOLLOWING SYSTEM TYPE: (Check one and complete the report for that system type. file separate
reports for each System Type included in this OPID)

… Crude Oil

… HVLs

… Petroleum Products / Refined Products

… CO2 or other Æ If “other”, describe __________________________

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 1 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

7. FOR THE DESIGNATED “SYSTEM TYPE”, THE ASSETS INCLUDED WITHIN THIS OPID ARE: (Check one or both)

… INTERstate Æ List all of the States in which INTERstate pipelines and/or pipeline facilities included
under this OPID exist: __, __, __, __, __, etc.
… INTRAstate Æ List all of the States in which INTRAstate pipelines and/or pipeline facilities included
under this OPID exist: __, __, __, __, __, etc.
8. DOES THIS REPORT REPRESENT A CHANGE FROM LAST YEAR’S FINAL REPORTED NUMBERS FOR ONE OR MORE OF THE
FOLLOWING PARTs: PART B, C, D, E, I, J, K, L, M, or N? (Check all that apply)

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… NO, there are no changes from last year’s final reported numbers for
PARTs B, C, D, E, H, I, J, K, L, or M.

… YES, this report represents a change from last year’s final reported numbers for
PARTs B, C, D, E, H, I, J, K, L, or M due to new or recalculated information; however, the assets
and operations are the same as those which were covered under last year’s report.
List the PARTs which changed: _____________________________

… YES, this report represents a change from last year’s final reported numbers for
PARTs B, C, D, E, H, I, J, K, L, or M because of the following change(s) in assets and/or operations
from those which were covered under last year’s report: (Check all that apply)
… 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
… Modifications to existing pipelines and/or pipeline facilities, change of service, change in
MOP (maximum operating pressure), etc.
… Abandonment of existing pipelines and/or pipeline facilities or placing existing pipelines and/or
pipeline facilities out of service
… Change in OPID
… Other Æ Describe: _______________________________________________

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Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 2 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

For the designated “System Type”, complete PARTs B, C, D, and E one time for all pipelines and/or
pipeline facilities – both INTERstate and INTRAstate - included within this OPID.
PART B - MILES OF PIPE BY
LOCATION
Total Miles That Could Affect HCAs

Onshore
Offshore
Total Miles

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Calc

PART C - VOLUME TRANSPORTED IN BARREL-MILES

Onshore
Offshore
PART D - MILES OF PIPE BY CORROSION PROTECTION
Cathodically protected
Bare

Cathodically unprotected

Coated

Onshore
Offshore

Bare

Calc

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Total Miles

Total Miles

Coated

Calc

Calc

Calc

Calc

Calc

Calc

PART E - MILES OF ELECTRIC RESISTANCE WELD (ERW) PIPE BY WELD TYPE AND DECADE
Decade Pipe Installed

Pre-40 or
Unknown

1940 1949

1950 1959

High Frequency

Low Frequency and DC
Total Miles

Calc

Calc

Calc

1960 1969

1970 1979

1980 1989

1990 1999

2000 –
2009

Total Miles
Calc
Calc

Calc

Calc

Calc

Calc

Calc

Calc

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 3 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

For the designated “System Type”, complete PARTs F znd G one time for all INTERstate pipelines and/or
pipeline facilities included within this OPID and multiple times as needed for the designated System Type
for each State in which INTRAstate pipelines and/or pipeline facilities included within this OPID exist.
Each time these sections are completed, designate the State to which the data applies or that it applies to
INTERstate pipelines.
PART F - INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN BASED ON INSPECTION

The data reported in this part applies to: … Interstate pipelines … Intrastate Pipelines: in State of __ _
1. MILEAGE INSPECTED USING THE FOLLOWING IN-LINE INSPECTIONS (ILI) TOOLS

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a. Corrosion or metal loss tools
b. Dent or deformation tools
c. Crack or long seam defect detection tools
d. Any other internal inspection tools

e. Total mileage inspected in calendar year using in-line inspection tools. (Lines a + b + c + d )
2. ACTIONS TAKEN BASED ON IN-LINE INSPECTIONS

Calc

a. Based on ILI data, how many anomalies were excavated because they met the operator’s criteria for
excavation.

b. Total number of conditions repaired that were identified by ILI in calendar year based on the operator’s criteria,
both within an HCA-affecting Segment and outside of an HCA-affecting Segment.
c. Total Number of Anomalies WITHIN AN HCA-AFFECTING SEGMENT Meeting the Definition of:
1. “Immediate repair condition” [195.452(h)(4)(i)]

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2. “60-day condition” [195.452(h)(4)(ii)]

3. “180-day condition” [195.452(h)(4)(iii)]

3. MILEAGE INSPECTED AND ACTIONS TAKEN BASED ON PRESSURE TESTING
a. Total mileage inspected by pressure testing in calendar year.

b. Total number of hydrostatic test failures (ruptures and leaks) repaired during calendar year, both within an HCAaffecting Segment and outside of an HCA-affecting Segment.
c. Total number of ruptures (complete failure of pipe wall) WITHIN AN HCA-AFFECTING SEGMENT during
hydrostatic testing.

d. Total number of leaks (less than complete wall failure but including escape of test medium) WITHIN AN HCAAFFECTING SEGMENT during hydrostatic testing.

4. MILEAGE INSPECTED AND ACTIONS TAKEN BASED ON ECDA (EXTERNAL COROSION DIRECT ASSESSMENT)
a. Total mileage inspected by ECDA in calendar year.

b. Total number of conditions identified by ECDA and repaired in calendar year based on the operator’s criteria,
both within an HCA-affecting Segment and outside of an HCA-affecting Segment.
c. Total Number of Anomalies WITHIN AN HCA-AFFECTING SEGMENT Meeting the Definition of:
1. “Immediate repair condition” [195.452(h)(4)(i)]
2. “60-day condition” [195.452(h)(4)(ii)]

3. “180-day condition” [195.452(h)(4)(iii)]

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 4 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

5. MILEAGE INSPECTED AND ACTIONS TAKEN BASED ON OTHER INSPECTION TECHNIQUES
a. Total mileage inspected by inspection techniques other than those listed above in calendar year.
b. Total number of conditions identified by other inspection techniques and repaired in calendar year based on the
operator’s criteria, both within an HCA-affecting Segment and outside of an HCA-affecting Segment.
c. Total Number of Anomalies WITHIN AN HCA-AFFECTING SEGMENT Meeting the Definition of:
1. “Immediate repair condition” [195.452(h)(4)(i)]
2. “60-day condition” [195.452(h)(4)(ii)]
3. “180-day condition” [195.452(h)(4)(iii)]

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6. TOTAL MILEAGE INSPECTED (ALL METHODS) AND ACTIONS TAKEN
a. Total mileage inspected. (Lines 1.e + 3.a + 4.a + 5.a)

Calc

b. Total number of conditions repaired. (Lines 2.b + 3.b + 4.b + 5.b)

Calc

c. Total number of conditions repaired WITHIN AN HCA-AFFECTING SEGMENT. (Lines 2.c.1 + 2.c.2 + 2.c.3 + 3.c
+ 3.d + 4.c.1 + 4.c.2 + 4.c.3 + 5.c.1 + 5.c.2 + 5.c.3)

Calc

PART G – MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED (HCA-AFFECTING SEGMENT MILES ONLY)

The data reported in this Part applies to: … Interstate pipelines … Intrastate pipelines: In State of _
_
a. Baseline assessment miles completed during the calendar year.
st

b. 1 -time Reassessment miles completed during the calendar year.
nd

c. 2 -time Reassessment miles completed during the calendar year.

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d. 3 -time Reassessment miles completed during the calendar year.
th

e. 4 -time Reassessment miles completed during the calendar year.
Add as needed

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 5 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

For the designated “System Type”, complete PARTs H, I, J, K, L, and M covering INTERstate pipelines
and/or pipeline facilities for each State in which INTERstate systems exist within this OPID and again
covering INTRAstate pipelines and/or pipeline facilities for each State in which INTRAstate systems exist
within this OPID.

Data reported in Parts H, I, J, K, L, and M immediately following apply to …  INTERstate or …  INTRAstate 
(select one) pipelines in the following state: __ 

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PART H - MILES OF PIPE BY NOMINAL PIPE SIZE (NPS)
NPS 4”
or less

6”

8”

10”

22”

24”

26”

28”

Onshore

Calc

Total Miles of Onshore Pipe
NPS 4”
or less

6”

8”

10”

22”

24”

26”

28”

Offshore

Calc

Total Miles of Offshore Pipe

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PART I - MILES OF PIPE BY DECADE INSTALLED
Pre-20 or
Unknown

1920 1929

1930 1939

1940 1949

1950 –
1959

1960 –
1969

12”

14”

16”

18”

20”

30”

32”

34”

36”

over 36”

12”

14”

16”

18”

20”

30”

32”

34”

36”

over 36”

1970 –
1979

1980 –
1989

1990 1999

2000 2009

Total Miles
Calc

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 6 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

PART J - MILES OF PIPE BY SPECIFIED MINIMUM YIELD STRENGTH
Onshore

Offshore

Steel Pipelines
- Operating at Greater than 20% SMYS

Calc
Populated
Onshore Areas

Steel Pipelines
- Operating at an
Unknown Stress Level
Non-Steel Pipelines
- Operating at Greater than 125 psi

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Total Miles

Rural Onshore
Areas

Offshore

Total Miles

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Steel Pipelines
- Operating at Less than
or Equal to 20% SMYS

Non-Steel Pipelines
- Operating at Less than
or Equal to 125 psi

Total Miles

Calc

Calc

Calc

Calc

Calc

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 7 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

PART K - MILES OF REGULATED GATHERING LINES
Populated Onshore
Areas

Rural Onshore
Areas

Offshore

Total Miles

Steel Pipelines
- Operating at
Less than 20% SMYS
Calc

Steel Pipelines
- Operating at
Greater than 20% SMYS

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Calc

Non-steel Pipelines
- Operating at Greater than 125 psi
Total Miles

Calc

Calc

Calc

Calc

PART L – HCA-AFFECTING SEGMENT MILES OF PIPE BY TYPE OF HCA
POPULATION AREAS
High Population

Other Population

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Onshore
Offshore

PART M - BREAKOUT TANKS

Commodity

Add as needed

Total Number of
Tanks Less than or
equal to 50,000 Bbls

Total Number of
Tanks 50,001
to 100,000 Bbls

USAs

Drinking Water

Ecological
Resource

Total Number of
Tanks 100,001 to
150,000 Bbls

Total Number of
Tanks Over 150,000
Bbls

COMMERCIALLY
NAVIGABLE
WATERWAYS

Total Number of
Tanks
Calc
Calc
Calc
Calc

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 8 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

Notice: This report is required by 49 CFR Part 195. 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. 2137-0614
Expires: xx/xx/xxxx

For the designated “System Type”, complete PARTs O and P one time for all of the pipelines and/or
pipeline facilities included within this OPID.

PART N - PREPARER SIGNATURE
Area Code and Telephone Number
Preparer's Name and Title (type or print)

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Area Code and Facsimile Number

Preparer's E-mail Address

Preparer's E-mail Address

PART O - CERTIFYING SIGNATURE

Senior Executive Officer’s signature certifying the information in PARTs H and I as required by
49 U.S.C. 60109(f)

Area Code and Telephone Number

Senior Executive Officer’s name and title certifying the information in PARTs H and I as required by
49 U.S.C. 60109(f)

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Senior Executive Officer’s E-mail Address

Form PHMSA F 7000-1.1 (Rev. xx-200x)
Pg. 9 of 9
This is a Proposed Draft of the Hazardous Liquid Annual Report. Distribution of this draft is limited to gather comments only. Please send comments to
[email protected] or [email protected]; Reproduction of this form is permitted.

INSTRUCTIONS FOR FORM PHMSA F 7000-1.1 (Rev. xx-20xx)
ANNUAL REPORT FOR CALENDAR YEAR 20__
HAZARDOUS LIQUID OR CARBON DIOXIDE SYSTEMS
GENERAL INSTRUCTIONS

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All section references are to Title 49 of the Code of Federal Regulations. The Hazardous Liquid and
Carbon Dioxide Systems Annual Report has been revised for calendar year 20__. Please read the form
and instructions carefully before beginning to complete the report.

Annual reports must be submitted by June 15 for the preceding calendar year. In order to
improve the accuracy of reported data, operators are requested to review prior years’ reports in order to
validate that their reported numbers are accurate, or to identify and correct inconsistencies or errors
that are either found or that may exist in any previously reported data. Operators should file
supplemental reports as necessary.
Each hazardous liquid pipeline operator is required to file an annual report. The terms “barrel”,
“breakout tank”, “carbon dioxide”, “gathering line”, “intrastate”, “interstate”, “hazardous liquid”,
“highly volatile liquid (HVL)”, “offshore”, “outer continental shelf (OCS)”, “pipeline facility”, “rural
area”, “specified minimum yield strength (SMYS)”, etc., are defined in §195.2. The term “operator” is
defined in §195.2 as a person who owns or operates pipeline facilities. For purposes of this report, the
operator is further defined as the person (“person” is defined in §195.2) who exercises substantial
control over the operation of the pipeline.

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If you need copies of the Form PHMSA F 7000-1.1 and/or instructions they can be found on the
Pipeline Safety Community main page, http://phmsa.dot.gov/pipeline, by clicking the Forms hyperlink
or the Library hyperlink and then the OPS FORMS section of the ONLINE LIBRARY. If you have
questions about this report or these instructions, please call (202) 366-8075.

REPORTING METHODS

Annual reports must be submitted online. Use the following procedure:
1. Navigate to the OPS Home Page , http://www.phmsa.dot.gov/pipeline, click the ONLINE
DATA ENTRY link listed in the second column of hyperlinks on the Pipeline Safety
Community main page
2. Click on the Annual Hazardous Liquid or Carbon Dioxide Systems Report link
3. Enter Operator ID and PIN [If an operator does not have an Operator ID or a PIN, the website
(http://opsweb.rspa.dot.gov/cfdocs/opsapps/pipes/main.cfm) includes directions on how to
obtain one.]
4. Click add to begin

Hazardous Liquid Annual Report_proposed instructions.doc

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5. Click submit when finished. NOTE: For supplemental reports use steps 1a and 1b then click
on the report ID to make corrections. Click save when finished.
6. A confirmation page will appear for you to print and save for your records

SPECIAL INSTRUCTIONS
Make an entry in each block for which data is available. Estimate data if necessary. Please avoid
entering any data as UNKNOWN or 0 (zero) in the columns except where zero is appropriate to
indicate that there were no instances of the attribute being reported.

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Please do not report miles of pipeline in feet. If necessary, please convert feet into a decimal notation
(e.g. 1,320 feet = .25 miles).

SPECIFIC INSTRUCTIONS

Enter the Calendar Year for which the report is being filed in the header of the form near the form title,
bearing in mind that reporting requirements are for the preceding calendar year (i.e., for the June 15,
2010 deadline, reporting would be for calendar year 2009).

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Check Initial Report if this is the original filing for the calendar year. Check Supplemental Report
if this is a follow-up to a previously filed report to amend or correct information for the calendar year.
On Supplemental Reports, enter all information requested in Parts A and N, and only the new or
revised information for the remainder of the form.
Report miles of pipeline in the system at the end of the reporting year, including additions to the
system during that year. Please adhere to definitions in Title 49 Part 195 of the Code of Federal
Regulations when reporting pipeline mileage.

Report mileage using decimals. Please round all mileage to the nearest thousandth of a mile. DO
NOT USE FRACTIONS. Please convert fractions to the nearest decimal number, (e.g., 3/8 to 0.375,
3/4 to 0.75 or ½ to 0.5). Note: Length/amount of pipe is to be reported in miles of pipeline, not
feet.

PART A - OPERATOR INFORMATION

Complete all 8 sections of Part A before continuing to Part B.
1. Operator 5 digit Identification number (OPID)
All operators that meet the definition of a “person” under 49 CFR 195.2 must have an
identification number. If the person completing the report does not have the operator
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identification number, this information may be requested from the Information Resources
Manager.
2. Name of Company
This is the company name used when registering for an Operator ID and PIN in the Online
Data Entry System. When completing the form online, the Name of Operator should be
automatically filled in based on the Operator Identification Number entered in question 1.
If the name that appears does not coincide with the Operator ID, contact PHMSA at (202)
366-4566.

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If the company corresponding to the Operator ID is a subsidiary, enter the name of the
parent company.
3. Location of the Office where additional information may be obtained

Enter the address of the operator’s business office to which any correspondence related to
the report should be sent.
4. Headquarters address if different

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Enter the address of the operator’s corporate headquarters if different from the address
reported in question 3.

5. Umbrella Integrity Management Program

Some of the data required on this form relates to activities conducted under the operator’s
integrity management (IM) program.

Some pipeline systems do not include pipeline segments that could affect high consequence
areas (HCA) and thus are not required to have an IM program. Indicate here if that is the
case for the pipeline system included within the Operator ID reported in question 1. If the
pipeline system is not covered by an IM program, Parts B, F, G, and H need not be
completed.
Some IM activities are conducted as part of a common program with other operators (e.g.,
other subsidiaries of a common parent). Report here whether the IM program for the
operator ID reported in question 1 is an independent program or is a common program. If
common, list the other operator identification numbers that are included in the common
program.

6. This report pertains to the following System type
For System Type, it is the Pipeline Safety Program’s intent to collect individual reports for
mileage by system type in order to alleviate any confusion in reporting mileage on multiple
systems.

Hazardous Liquid Annual Report_proposed instructions.doc

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File a separate report for each of the following system types:
Crude Oil - a dark oil consisting mainly of hydrocarbons.
Highly Volatile Liquids (HVLs) - flammable or toxic fluids, which are gases at
ambient conditions, including anhydrous ammonia (NH3) and propane.
Petroleum and Refined Products – gasoline, diesel, fuel, or other petroleum products,
which are liquid at ambient conditions. Petroleum products means flammable, toxic, or
corrosive products obtained from distilling and processing of crude oil, unfinished oils,
natural gas liquids, blend stocks, and other miscellaneous hydrocarbon compounds. For the
sake of this report, “petroleum products” is meant to be synonymous with “refined
products”.

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Carbon Dioxide (CO2) - other non-flammable, non-toxic fluids (gases at ambient
temperature). If the commodity is other than CO2, then describe the commodity in the
space provided.

Note: When a single pipeline serves as two or more of the above system types, that
pipeline should only be reported only once, reporting as system type the commodity that is
transported most predominantly.

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7. Interstate and/or Intrastate

The terms interstate and intrastate are defined in section 195.2. Pipeline assets included
within a particular system type under a single operator identification number may be either
interstate, intrastate, or both. Check the appropriate box to indicate whether pipeline assets
for the OPID and system type that is the subject of this report are interstate or intrastate
(both boxes may be checked). List the two-letter state abbreviation for each state in which
reported interstate and intrastate assets are located.

8. Does this report represent a change from last year’s final reported numbers for one or
more of the following parts?
Data that is reported on the annual report can change from year to year for one of two
reasons:

New information or new calculations may have changed the understanding of system data,
leading to differences in some data elements reported on the form, or
The pipeline system may have changed.
Check “No” if there are no changes in the data reported on this form, for the pipeline
system that is the subject of this report, from the data reported for the prior year.
Check one of the two “Yes” boxes if reported data has changed. If the change is due to a
change in the pipeline system, check the appropriate box to describe the change. If “other”
is selected, provide a brief description of the system change.
4

(Note: This revision of the annual report form will be used for the first time to report data
for calendar year 20xx. Some of the “parts” of this form referred to in this question are new
and no comparable data will have been reported for the prior year. For calendar year 20xx
only, respond to this question by indicating whether data reported for the prior year has
changed and, if so, why, regardless of the fact that some data will be reported for the first
time for this calendar year or may have been reported in a different designated “part” for
the prior year.)

T
F
A

For the designated “System Type”, complete PARTs B, C, D, and E one time for all pipelines
and/or pipeline facilities – both INTERstate or INTRAstate – included within this OPID.
Separate reporting by state is not required for these Parts. Data reported should represent the
system in total, including all states in which system assets are located.

PART B - MILES OF PIPE BY LOCATION

Report in Part B the total miles of Onshore and Offshore pipe that could affect High Consequence
Areas (HCAs) and are thus in the integrity management program.

R
D

PART C – VOLUME TRANSPORTED IN BARREL-MILES

Report volume transported during the calendar year. Include annual volume transported totals in
barrel-miles regardless of state. Mixed system operators should report all mileage under the
predominant system type for mixed commodity category systems.
Barrel-miles means one barrel transported one mile. The volume transported should be consistent
with the system type in order to have clear data for analysis.

PART D - MILES OF PIPE BY CORROSION PROTECTION

Report the total miles of Onshore and Offshore 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.

Hazardous Liquid Annual Report_proposed instructions.doc

5

Report here only pipe that was manufactured using an electronic resistance weld (ERW) process.
Report separately the miles of installed pipe manufactured using a high-frequency ERW process and
that manufactured with a low-frequency or DC ERW process, in each case by decade installed.

T
F
A

“High Frequency” means the ERW pipe was manufactured using a high frequency ERW process.
High frequency ERW pipe is pipe that was manufactured using a high frequency electrical current,
usually about 450 thousand Hertz (kHz) to provide heat for fusion of the weld seam. Most pipe using
this process has been manufactured since the late 1960s.
“Low Frequency” means the ERW pipe was manufactured using a low frequency ERW process. Low
frequency ERW pipe is pipe that was manufactured using a 250 Hertz (Hz) alternating electrical
current to provide heat for fusion of the weld seam. Most pipe using this process was manufactured
prior to 1970.
“DC” means direct current.

R
D

If you need additional information, please check the PHMSA website at http://ops.dot.gov for
documents further explaining ERW.

Make an entry in each block. We recognize that some companies may have very old pipe for which
installation records may not exist. Enter estimates of the totals of such mileage in the “Pre-20 or
UNKNOWN” section of Part E. Enter zero (0) in any block for which the pipeline system includes no
mileage. Do not leave any blocks blank.

For the designated “System Type”, complete PART 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 System Type for each State in which INTRAstate pipelines and/or pipeline
facilities are located.

For example: Consider a pipeline system that includes INTERstate pipeline in seven states and
INTRAstate pipelines in three states. Parts F and G should be completed four times for this
pipeline system – 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)

PART F - INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN
BASED ON INSPECTION

Each time Part F is completed, indicate whether the data reported is for INTERstate or INTRAstaet
pipelines. If INTRAstate, enter in the space provided the two-letter postal abbreviation for the state.
6

Report the integrity assessments (inspections) conducted and actions taken during the calendar year
based on inspection results. Include all inspections conducted in the reporting period calendar year
(including Baseline, non-Baseline, and new construction). Part F is subdivided into six (6) sections.
Section 1 - Mileage inspected 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 that could affect a high consequence area. Where
multiple ILI tools are used (e.g., a metal loss tool and a deformation tool), report the
mileage in both categories. 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.

T
F
A

Enter zero (0) for any tool which was not used for IM assessments during the year.
Leave no rows blank.
Section 2 - Actions taken based on ILI inspections.

Include all actions taken during the calendar year that resulted from information
obtained during an ILI inspection. This should include actions taken as a result of
information developed during ILI inspections conducted during the calendar year PLUS
actions taken as a result of ILI inspections conducted during prior years and for which
all required actions were not completed during the year of the inspection. Do not
include actions which are anticipated based on review of ILI results but which did not
actually occur during the reporting year.

R
D

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 more conservative (i.e., require
repair of damage less significant) than the repair criteria in IM regulations applicable to
anomalies in pipeline segments that could affect HCA. Report only those anomalies
actually repaired, not those for which other mitigative actions (not repair) were
undertaken.
Report in item c only the anomalies in pipeline segments that could affect HCA that
were repaired because they exceeded the three repair criteria in the IM regulations.
(The total of repairs reported in item c. should not exceed the total number of repairs
reported in item b.)
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.

Section 3 – Mileage inspected and actions taken based on Pressure Testing.
Report in a. total miles inspected by pressure testing, including both mileage that could
affect an HCA and mileage that could not affect.

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7

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 segments that could
affect an HCA.
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.

T
F
A

Section 4 - Mileage inspected and actions taken based on ECDA (External Corrosion Direct
Assessment)

Include all actions taken during the calendar year that resulted from information
obtained during an ECDA inspection. This should include actions taken as a result of
information developed during ECDA inspections conducted during the calendar year
PLUS actions taken as a result of ECDA 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 ECDA inspection results but which
did not actually occur during the reporting year.

R
D

Report in item b. the total number of anomalies excavated and repaired based on the
operator’s repair criteria even if those criteria are more conservative (i.e., require repair
of damage less significant) than the repair criteria in IM regulations applicable to
anomalies in pipeline segments that could affect HCA.

Report in item c. the number of anomalies in pipeline segments that could affect an
HCA that were repaired because when excavated and examined they exceeded the three
repair criteria in the IM regulations.
Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.

Section 5 - 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
method other than those covered in sections 1-4.

As for the other methods, include all actions taken during the calendar year that resulted
from information obtained during an inspection using another method. 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 only those anomalies actually repaired, not those for which other mitigative
actions (not repair) were undertaken.
8

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.
Report here the total mileage inspected and actions taken as the sum of the indicated
elements from other sections.

T
F
A

PART G – MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED
(HCA-AFFECTING SEGMENT MILES ONLY)

Each time Part G is completed, indicate whether the data reported is for INTERstate or INTRAstate
pipelines. If INTRAstate, enter in the space provided the two-letter postal abbreviation for the state.
Report the number of miles of pipeline that could affect high consequence areas (as reported in part B)
that were assessed during the calendar year pursuant to section 195.452. Report separately the number
of miles inspected for baseline assessments (e.g., new pipelines, new HCA) and miles for which a
reassessment was conducted. Report only assessments that were completed during the calendar year.
These
“completed
assessments”
are
defined
consistently
with
FAQ
4.13
http://primis.phmsa.dot.gov/iim/faqs.htm. 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
external corrosion direct assessment is made, or the date on which "other technology" for which an
operator has provided timely notification is conducted.

R
D

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 that could affect High Consequence Areas reported in
Parts B and L. 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 that might result from new HCA segments being added or deleted,
acquired or sold, or idled or converted. Any corrections to previously reported data should be
submitted in a supplemental report.

For the designated “System Type”, complete PARTs H, I, J, K, L, and M covering INTERstate
pipelines and/or pipeline facilities for each State in which INTERstate systems exist within this
OPID and again covering INTRAstate pipelines and/or pipeline facilities for each State in which
INTRAstate systems exist within this OPID.
For example: Consider a pipeline system that includes INTERstate pipeline in seven states and
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9

INTRAstate pipelines in three states. Parts H, I, J, K, L, and M should be completed ten times
for this pipeline system – seven times for INTERstate assets (once for each state in which
INTERstate assets are located) and once for the INTRAstate assets in each of the three states in
which INTRAstate assets are located (separately).
Each time the remaining parts are completed, indicate whether the data reported is for
INTERstate or INTRAstate pipelines and enter in the space provided the two-letter postal
abbreviation for the state.

T
F
A

PART H – MILES OF PIPE BY NOMINAL PIPE SIZE (NPS)

Report the miles of steel pipe by Nominal Pipe Size (NPS) (outside diameter) and location for both
onshore and offshore locations. Enter the appropriate mileage in the corresponding nominal size
blocks.
Pipe size which does not correspond to NPS measurements should be rounded up to the next larger
category. For example, 7 inch pipe would fall in the NPS 8” block. Operators should use the closest
approximation for diameter.

R
D

Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.

PART I – 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. We recognize that some companies may have very old pipe for which installation records
may not exist. Enter estimates of the totals of such mileage in the “Pre-20 or UNKNOWN” section of
Part I.
The sum total of pipeline mileage should match Part D, H, and J by miles and type.

PART J – MILES OF PIPE BY SPECIFIED MINIMUM YIELD STRENGTH

Report the total miles of pipe by specified minimum yield strength for pipe onshore (in populated and
rural areas where indicated) and offshore by percentage SMYS. Report data only for pipelines
regulated by the Pipeline Safety Program and not those which are regulated by other federal or state
authorities.
Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.
10

PART K – MILES OF REGULATED GATHERING LINES

Complete this part only for system type “crude oil.” Include all petroleum gathering line mileage
under crude oil systems. Report the total mileage of PHMSA regulated gathering lines only.
Gathering lines are defined in 49 CFR §195.2 as, “A pipeline 219.1mm (8
outside diameter that transports petroleum from a production facility.”

5/8

inch) or less nominal

T
F
A

Regulated rural gathering lines are defined in section 195.11(a) and should be reported in this part.

Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.

PART L – HCA AFFECTING SEGMENT MILES OF PIPE BY TYPE OF HCA

Report the miles of pipeline that the operator has determined could affect HCAs of the designated type.
Operators should note that a segment of pipeline may be able to affect HCAs of multiple type (e.g.,
other population area and drinking water USA). Accordingly, the total of the miles reported in the
various blocks in this part may add to more than the total mileage that could affect HCAs reported in
part B.

R
D

Enter zero (0) in any block for which the pipeline system includes no mileage. Do not leave any
blocks blank.

PART M – BREAKOUT TANKS

List the number of tanks by capacity and by commodity.

For the designated “System Type”, complete PARTs N and O one time for all of the pipelines
and/or pipeline facilities included within this OPID.
PART N – PREPARER SIGNATURE

The Preparer is the person who compiled the data and prepared the responses to the report and who is
to be contacted for more information (preferably the person most knowledgeable about the information
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11

in the report or who knows how to contact the person most knowledgeable). Please enter the
Preparer’s e-mail address if the Preparer has one, and the phone and fax numbers used by the Preparer.
PART O – CERTIFYING SIGNATURE

CERTIFYING SIGNATURE must be a senior executive officer of the operator. The Pipeline
Inspection, Protection, Enforcement and Safety Act (signed in December 2006) requires pipeline
operators to have a senior executive officer of the company sign and certify annual pipeline integrity
management program (IMP) performance reports (Part F and G of this form). By his or her 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.

T
F
A

Senior Executive Officer is the person who is certifying the information on Part F and G 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 form. The name of the senior executive officer certifying the
report should also be entered in the signature block on the form. Operators should keep in mind that
entering the senior executive officer’s name onto the electronic form is equivalent to a paper
submission and has the same legal authenticity and requirements of a paper document.

R
D

12