Pipeline Safety: New Reporting Requirements for Hazardous Liquid Pipeline Operators: Hazardous Liquid Annual Report

Instructions (rev 6-2014) for Form PHMSA F 7000-1.1 (rev 6-2014)

ANNUAL REPORT FOR CALENDAR YEAR 20__ HAZARDOUS LIQUID PIPELINE SYSTEMS

GENERAL INSTRUCTIONS

All section references are to Title 49 of the Code of Federal Regulations (49 CFR). The Hazardous Liquid or Carbon Dioxide Pipeline Systems Annual Report has been revised as of calendar year 2010 affecting submissions for 2010 and beyond. This Annual Report is required per §195.49 and must be filed per §195.58. Read through the Annual Report and instructions carefully before beginning to complete the Report. Where common data elements exist between this Report and an operator’s NPMS submission, the data submitted by the operator on their Annual Report should be the same as the data submitted through NPMS when possible. (Additionally, and in order to align an operator’s NPMS submission with their Annual Report data, PHMSA suggests that operators send their NPMS submission to PHMSA by June 15, representing pipeline assets as of December 31 of the previous year.)

Each operator must annually complete and submit DOT Form PHMSA F 7000–1.1 for each type of hazardous liquid pipeline facility operated at the end of the previous year. An operator must submit the annual report by June 15 each year. A separate report is required for crude oil, HVL (including anhydrous ammonia), petroleum products, carbon dioxide pipelines, and fuel grade ethanol pipelines. All pipeline mileage not permanently removed from service should be reported, including pipelines and/or pipeline facilities considered to be idled. Pipelines that have been idled should be reported under the Commodity Group transported just before idling. For each state a pipeline traverses, an operator must separately complete those sections on the form requiring information to be reported for each state. In order to improve the accuracy of reported data, operators are requested to review prior years’ Reports in order to validate that their reported numbers are accurate, or to identify and correct inconsistencies or errors that are either found or that may exist in any previously reported data. Operators should file Supplemental Reports as necessary, including those supplementing prior years’ Reports.

The terms “barrel”, “breakout tank”, “carbon dioxide”, “flammable product”, “gathering line”, “hazardous liquid”, “highly volatile liquid (HVL)”, “intrastate pipeline”, “interstate pipeline”, “low stress pipeline”, “maximum operating pressure”, “offshore”, “operator”, “Outer Continental Shelf (OCS)”, “petroleum”, “petroleum product”, “pipe or line pipe”, “pipeline or pipeline system”, “pipeline facility”, “rural area”, “specified minimum yield strength (SMYS)”, “stress level”, “toxic product”, and “Unusually Sensitive Area (USA)” are defined in §195.2.

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://www.phmsa.dot.gov/pipeline/library/forms. The documents are included in the section titled Accident/Incident/Annual Reporting Forms. If you have questions about this Report or these instructions, please call PHMSA’s Information Resources Manager at 202-366-8075.

ONLINE REPORTING REQUIREMENTS

Annual Reports must be submitted online through the PHMSA Portal at https://portal.phmsa.dot.gov/portal, unless an alternate method is approved (see Alternate Reporting Methods below).

You will not be able to submit reports until you have met all of the Portal registration requirements – see http://opsweb.phmsa.dot.gov/portal_message/PHMSA_Portal_Registration.pdf

Completing these registration requirements could take several weeks. Plan ahead and register well in advance of the report due date.

REPORTING METHOD

Use the following procedure for online reporting:

1. Go to the PHMSA Portal at https://portal.phmsa.dot.gov/portal

2. Enter PHMSA Portal Username and Password ; press enter

3. Select OPID; press “continue” button.

4. Under “Create Reports” on the left side of the screen, under Annual select “Hazardous Liquid” and proceed with entering your data. Only one annual report by commodity for an OPID may be submitted per year.
   

5. To save intermediate work without formally submitting it to PHMSA, click Save. To modify a draft of an annual report that you saved, go to Saved Reports and click on Hazardous Liquid. Locate your saved report by the date, report year, or commodity. Select the record by clicking on it once, and then click Modify above the record.

6. Once all sections of the form have been completed, click on Validate to ensure all required fields have been completed and data meets all other requirements. A list of errors will be generated that must be fixed prior to submitting an Annual Report.

7. Click Submit when you have completed the Report (for either an Initial Report or a Supplemental Report), and are ready to initiate formal submission of your Report to PHMSA.

8. A confirmation message will appear that confirms a record has been successfully submitted. To save or print a copy of your submission, go to Submitted Reports on the left hand side, and click on Hazardous Liquid. 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. To submit a Supplemental Report, go to Submitted Reports on the left hand side, and click on Hazardous Liquid. 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 alternate reporting method. Operators must follow the requirements in §195.58(d) to request an alternate 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. All fields are required unless non-applicable. Estimate data only if necessary. Avoid entering any data as UNKNOWN or 0 (zero) except where zero is appropriate to indicate that there were no instances or amounts of the attribute being reported.

Do not report miles of pipe, pipe segments, or pipeline in feet. When mileage for the same set of pipelines is reported in different parts of the form, the online system will require the different parts to be consistent. Mileage values over 60 miles must be within 0.5% of the baseline and values under 60 miles must be within 0.3 miles. Part I, decade of installation, will serve as the mileage baseline for all parts of the form. For example, if you report 60 miles in Part I, the mileage by diameter in Parts H, J, and P must be within 0.3 miles of 60. Use the number of decimal places needed to satisfy these consistency checks.

Enter the Calendar Year for which the Report is being filed, bearing in mind that reporting requirements are for the preceding calendar year (i.e., for the June 15, 2013 deadline, the Report should provide information for assets as they existed at the end of the 2012 calendar year).

The Initial Report or Supplemental Report box will be populated by the online system.

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 195 when reporting mileage and other data.

For a given OPID, a separate Annual Report is to 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 pipelines that transport crude oil and another that transports refined products, this operator is to file two Annual Reports – one Annual Report covering all the facilities and/or pipelines that transport crude oil and another Annual Report covering all the facilities and/or pipelines that transport refined products. If another operator utilizes two OPIDs with both crude oil and refined products facilities and/or pipelines within each OPID, that operator must file four separate Annual Reports.

Parts A and C are 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.

PART A - OPERATOR INFORMATION

Complete all sections of Part A before continuing to the next Part.

1. Operator’s 5 digit Identification Number (OPID)

For online entries, the OPID will automatically populate based on the selection you made when entering the Portal. If you have log-in credentials for multiple OPID, be sure the report is being created for the appropriate OPID. Contact PHMSA’s Information Resources Manager at 202-366-8075 if you need assistance with an OPID.

2. Name of Operator

This is the company name associated with the OPID. If the name that appears is not correct, you need to submit an Operator Name Change (Type A) Notification.

For online entries, Name of Operator is automatically filled in based on the OPID entered in A1. If the name that appears does not coincide with the OPID, contact PHMSA’s Information Resources Manager.

3. Reserved

4. Headquarters address

This is the headquarters address associated with the OPID. For online entries, the address will automatically populate based on the OPID entered in A1. If the address that appears is not correct, you need to change it in the online Contacts module.

5. This Report pertains to the following Commodity Group

Operators submit separate Reports for each Commodity Group within a particular OPID. It should be noted that these Commodity Groups, though similar to the Commodity Groups used when reporting accidents to PHMSA, are not precisely the same when it comes to the reporting of pipelines that transport fuel grade ethanol and ethanol blends. Whereas fuel grade ethanol and ethanol blends are grouped in the same category for accident reporting purposes, pipelines that transport fuel grade ethanol have their own Commodity Group for the purposes of Annual Reporting. Pipelines that transport ethanol in a blended state should be reported as Refined and/or Petroleum Product (non-HVL) in an operator’s Annual Report.

File a separate Annual Report for each of the following Commodity Groups (as further defined in §195.2):

Crude Oil - unrefined oil consisting mainly of hydrocarbons.

Refined and/or Petroleum Product (non-HVL) – 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. Examples include motor gasoline, diesel fuel, fuel oil, aviation gasoline, jet fuel, kerosene, acetone, benzene, MTBE, naphtha, or other non-HVL petroleum products. For the sake of this Report, “petroleum product” is meant to be synonymous with “refined product”.

Highly Volatile Liquids (HVLs) – a hazardous liquid which will form a vapor cloud when released to the atmosphere and which has a vapor pressure exceeding 276 kPa at 37.8º C (100º F). Examples include ethane, ethylene, propane, propylene, butylene, and anhydrous ammonia (NH₃).

Carbon Dioxide (CO₂) – a fluid consisting of more than 90 percent carbon dioxide molecules compressed to a supercritical state.

Fuel Grade Ethanol – a clear, colorless, flammable oxygenated hydrocarbon. Ethanol is typically produced chemically from ethylene, or biologically from fermentation of various sugars from carbohydrates found in agricultural crops and cellulosic residues from crops or wood. This Commodity Group is to be selected only if the pipeline and/or pipeline facility is used predominantly to transport ethanol which has NOT been blended with petroleum products. This commodity is sometimes also known as “neat” ethanol. Pipelines that transport ethanol in a blended state should be reported as Refined and/or Petroleum Product (non-HVL).

Note: When a single pipeline or facility serves to transport two or more of the above Commodity Groups, that pipeline or facility should be reported only once, reporting within the Commodity Group for the commodity that is transported most predominantly during the year being reported.

6. Reserved

7. Interstate and/or Intrastate pipeline

Pipeline assets included within a particular Commodity Group under a single OPID may be either interstate, intrastate, or both. Select 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/or intrastate assets are located.

The terms INTERstate and INTRAstate pipeline are defined in §195.2. Appendix A to 49 CFR 195 contains PHMSA’s Statement of Policy and Interpretation on the delineation between interstate and intrastate pipelines, and provides additional guidance.

8. Reserved

PART B - MILES OF PIPE BY LOCATION

In Part L of this report, the number of HCA miles are reported by-State/OCS and by the INTERstate/INTRAstate status of the pipeline. All Part L data will be summed and displayed in Part B.

PART C – VOLUME TRANSPORTED IN BARREL-MILES

Barrel-miles means the total of the number of barrels transported multiplied by the distance in miles the specific barrels were moved. Report the volume of all commodities transported during the calendar year for this Commodity Group. Include the annual total volume transported in barrel-miles for all states and for all pipelines and/or pipeline facilities – both INTERstate and 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. Example: If 2,000,000 barrels of crude oil were moved in one 35-mile onshore pipeline from end to end and 80,000,000 barrels of crude oil were moved in a second 1,000-mile onshore pipeline from end to end, both occurring in a given reporting year, then the total volume transported in barrel-miles for the Crude Oil Commodity Group for Onshore is equal to (2,000,000 x 35) + (80,000,000 x 1,000) = 70,000,000 + 80,000,000,000 = 80,070,000,000 Onshore Crude Oil Barrel-Miles. If, additionally, 500,000 barrels of an HVL were moved in the same 35-mile onshore pipeline from end to end, then 17,500,000 barrel-miles (500,000 x 35) should also be included in Part C for the Crude Oil Commodity Group under the “HVL” row and “Onshore” column in the table.

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

In Part P of this report, the miles of pipeline by material type and corrosion prevention status are reported by-State/OCS and by the INTERstate/INTRAstate status of the pipeline. All Part P data will be summed and displayed in Part D.

PART E – MILES OF ELECTRIC RESISTANCE WELDED (ERW) PIPE BY WELD TYPE AND DECADE

In Part Q of this report, the miles of electric resistance welded pipe by weld type and decade are reported by-State/OCS and by the INTERstate/INTRAstate status of the pipeline. All Part Q data will be summed and displayed in Part E.

For the designated Commodity Group, complete Parts F and G one time for all INTERstate pipelines and/or pipeline facilities included within this OPID and multiple times as needed for the designated Commodity Group for each State in which INTRAstate pipelines and/or pipeline facilities included within this OPID exist.

For example: Consider a set of crude oil 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 crude oil 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).

PART F includes inspection, assessment, and repair data for both pipeline segments that could affect HCAs and those that2 could not. In Part L, the number of miles that could affect an HCA 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 is created. Until “could affect HCA” miles are entered in an INTERstate Part L, the “could affect 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 mileage.

Part G includes assessment data only for pipeline segments that could affect an HCA. Until “could affect HCA” miles are entered in the applicable Part L, this section will remain locked.

PART F - INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN

BASED ON INSPECTION

Report all integrity assessments (inspections) required by PHMSA’s IM regulations which were conducted and actions which were taken during the calendar year based on inspection results. Include all inspections conducted in the reporting period calendar year including baseline assessments and re-assessments. Do not consider pipelines or portions of pipelines that could otherwise not affect an HCA but which are included in an IM Program as a result of other PHMSA directives (such as Corrective Action Orders, Compliance Orders, Special Permits, etc.). Part F is subdivided into six (6) sections.

Section 1 - Mileage inspected in calendar year using the following In-Line Inspection (ILI) tools.

Report the mileage inspected using each of the listed tool types. Include total miles inspected, not just the mileage 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. 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.

Text entry in the “specify” field is required if data is entered in Part F1d “Any other internal inspection tools, specify other tools”.

Section 2 - Actions taken in calendar year based on In-Line Inspections.

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

Report in items a. and b. the total number of anomalies excavated and repaired based on the operator’s repair criteria even if those criteria are different from (i.e., require repair of damage more or less significant) than the repair criteria in IM regulations applicable to anomalies in pipeline segments that could affect HCA. (The operator’s criteria for anomalies in segments that could affect an HCA 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, were taken.

Report in c. only the anomalies in pipeline segments that could affect an HCA that were repaired because they met one of 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 in calendar year based on Pressure Testing.

Report in a. the total miles inspected by pressure testing, including both mileage that could affect an HCA and mileage that could not affect an HCA.

Report in b. the total number of test failures (ruptures and leaks) repaired 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.

Section 4 - Mileage inspected and actions taken in calendar year 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.

Report in b. the total number of anomalies excavated and repaired based on the operator’s repair criteria even if those criteria are different from (i.e., require repair of damage more or less significant) than the repair criteria in IM regulations applicable to anomalies in pipeline segments that could affect an HCA. (The operator’s criteria for anomalies in segments that could affect an HCA must be at least as conservative as those required by the regulations). Report in b. only those anomalies actually repaired, not those for which other mitigative actions, such as recoating, were undertaken.

Report in c. the number of anomalies in pipeline segments that could affect an HCA that were repaired because when excavated and examined they met one of the three repair criteria in the IM regulations. Anomalies not excavated and eliminated by pipe replacement are reported in Parts F6d and F6e.

Enter a value in each row, using zero (0) as appropriate. Leave no rows blank.

Section 5 – Mileage inspected and actions taken in calendar year based on Other Inspection Techniques

IM regulations allow operators to use other assessment techniques provided that they notify PHMSA (or states exercising regulatory jurisdiction) in advance. Report here the mileage inspected and actions taken as a result of inspections conducted using any technique other than those covered in Sections 1-4 of Part F.

As for the other techniques, include all actions taken during the calendar year that resulted from information obtained during an inspection using another technique. This should include actions taken as a result of information developed as part of inspections conducted during the calendar year PLUS actions taken as a result of inspections conducted during prior years and for which all required actions were not completed 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, such as recoating, were taken. Anomalies not excavated and eliminated by pipe replacement are reported in Parts F6d and F6e.

Text entry in the “specify” field is required if data is entered in Part F5a “Total mileage inspected by inspection techniques other than those listed above in calendar year. Specify other inspection technique(s)”.

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. 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.

PART G – MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED IN CALENDAR YEAR (segment miles that could affect HCAs ONLY)

Report the number of miles of pipeline that could affect an HCA (as reported in Part B) that were assessed during the calendar year pursuant to §195.452. 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 or newly identified HCAs, new spill flow paths, new spill volume calculations, low-stress pipe for which the baseline assessment deadline has not yet passed, etc.) and miles for which a reassessment was conducted. Do not include pipelines or portions of pipelines that could otherwise not affect an HCA but which are included in an IM Program as a result of other PHMSA directives (such as Corrective Action Orders, Compliance Orders, Special Permits, etc.).

Report only assessments that were completed during the calendar year. These “completed assessments” are defined consistently with FAQ 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.

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 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 that could affect High Consequence Areas reported in Part(s) 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 resulting from new HCA segments being added or deleted, acquired or sold, or idled¹ or converted, and which need to be properly reflected in this Report.

For the designated Commodity Group, complete Parts H, I, J, K, L, M, P, and Q covering INTERstate pipelines and/or pipeline facilities separately for each State in which INTERstate systems exist within this OPID and again covering INTRAstate pipelines and/or pipeline facilities separately for each State in which INTRAstate systems exist within this OPID.

For example: Consider a set of crude oil pipeline systems that includes INTERstate pipeline facilities in seven states and INTRAstate pipeline facilities in three states. Parts H, I, J, K, L, and M, P and Q should be completed ten times for this set of crude oil pipeline systems – seven times for INTERstate assets (once for each of the seven states in which INTERstate assets are located) and once for the INTRAstate assets in each of the three states in which INTRAstate assets are located.

Each time the remaining Parts are completed, indicate whether the data reported is for INTERstate or INTRAstate pipelines and/or pipeline facilities, and enter in the space provided the two-letter postal abbreviation for the state.

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

Report the miles of pipe by Nominal Pipe Size (NPS) and location for both onshore and offshore locations. Enter the appropriate mileage in the corresponding nominal size blocks.

Pipe sizes which do 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 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 “Unknown” section of Part I.

PART J – MILES OF PIPE BY SPECIFIED MINIMUM YIELD STRENGTH

Report the total miles of steel pipe by hoop stress (as percent of SMYS) and pipe material type (steel or non-steel) for pipe onshore (in non-rural and rural areas where indicated) and offshore.

Report the total miles of non-steel pipe operating above 125 psig and at or below 125 psig, differentiated for location as for steel pipe.

Report data only for pipelines regulated by PHMSA (and their certified State agencies) and not those which are regulated by other federal or state authorities, including those rural, low stress pipeline segments subject only to Subpart B of 49 CFR 195.

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

PART K – MILES OF REGULATED GATHERING LINES

This Part only applies to Commodity Groups “crude oil” and “highly volatile liquids” and to those portions of gathering lines that are regulated by PHMSA. Report the total mileage of these lines only.

Gathering lines are defined in §195.2 as “A pipeline 219.1mm (8-5/8 inch) or less nominal outside diameter that transports petroleum from a production facility.”

Regulated rural gathering lines are defined in §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 – TOTAL SEGMENT MILES THAT COULD AFFECT HCAs

By Type of HCA. Report the miles of pipeline that the operator has determined could affect an HCA of each designated type. Operators should note that a single segment of pipeline may be able to affect HCAs of multiple types (e.g., an Other Population Area as well as a Drinking Water USA). Accordingly, the total of the miles reported in these columns may add to more than the total mileage that could affect an HCA.

Not By Type. Report the total miles of pipeline that the operator has determined could affect an HCA. For this number, Operators should NOT double-count mileage for a single segment of pipeline that may be able to affect HCAs of multiple types (e.g., an Other Population Area as well as a Drinking Water USA).

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 Group, including any Commodity Groups which are not the predominantly transported Commodity Group within this Report. The Commodity Groups listed here in Part M should match those listed in Part C. Operators are required to submit all breakout tank information in their Annual Report. The operator can also submit their breakout tank information to NPMS, but breakout tanks must always be reported in their Annual Report.

PART P – MILES OF PIPE BY MATERIAL AND CORROSION PREVENTION STATUS

For steel pipe, 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. For plastic and “other” pipe, report the total miles of onshore and offshore pipe. For any mileage reported in the “other” column, describe the material in the “Other (specify)” field.

PART Q – MILES OF ELECTRIC RESISTANCE WELDED (ERW) PIPE
BY WELD TYPE AND DECADE

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

“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 manufactured 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 low frequency, usually about 250 Hertz (Hz) alternating electrical current to provide heat for fusion of the weld seam. Most pipe manufactured using this process was manufactured prior to 1970.

Flash welded pipe (EFW) is NOT a type of ERW pipe and should NOT be included in the reported numbers for this Part E.

“DC” means direct current.

Make an entry in each block. PHMSA recognizes that some companies may have pipe for which installation records may not exist. If records do not exist, enter estimates of the totals of such mileage in the “Pre-40 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 Commodity Group, complete Part N one time for all of the pipelines and/or pipeline facilities included within this OPID. Complete Part O one time for all the pipelines and/or pipeline facilities covered under this Commodity Group and OPID if any portion(s) of the pipelines and/or pipeline facilities are included in an IM Program subject to §195.452 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, as well as the phone and fax numbers used by the Preparer.

PART O – CERTIFYING SIGNATURE

CERTIFYING SIGNATURE must be a senior executive officer of the operator. The Pipeline Inspection, Protection, Enforcement and Safety Act (signed in December 2006) requires pipeline operators to have a senior executive officer of the company sign and certify annual pipeline Integrity Management Program (IMP) performance reports (Parts B, F, G, and L 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 L as required by 49 U.S.C. 60109(f).

The name and title of the senior executive officer certifying the Report should be entered in the appropriate blanks on this section of the Report. The name of the senior executive officer certifying the Report should also be entered in the signature block on the Report. Operators should keep in mind that entering the senior executive officer’s name onto the electronic Report is equivalent to a paper submission and has the same legal authenticity and requirements. The online system will provide Part O access for entry only after HCA mileage is entered in Part L.

1 While the regulations do not recognize an intermediate state between operational and abandoned , PHMSA has acknowledged that operators sometimes maintain some of their pipe in an idle status in which conducting IM assessments is impractical. This consideration of “idle” pipe is discussed in FAQ 2.3 on the PHMSA IM website (http://primis.phmsa.dot.gov/iim/faqs.htm).

OMB No. 2137-0614 Expires: 12/31/2015 Page 16 of 16