BUCKEYE PARTNERS, LP — Notice of Probable Violation

party submissionOfficial PDF120095002_ Operator Response to Notice letter_09252009.pdf#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 1Official PDFU.S. Department 820 Bear Tavern Road. Suite 306 of Transportation West Trenton, N.J. 08628 Pipeline and Hazardous Materials Safety Administration NOTICE OF PROBABLE VIOLATION NOTICE OF PROBABLE CIVIL PENALTY AND NOTICE OF PROPOSED COMPLIANCE ORDER CERTIFIED MAIL - RETURN RECEIPT REQUESTED June 26, 2009 Mr. Lawrence Shelton Vice President, Field Operations Buckeye Partners, L.P. 5 TEK Park 9999 Hamilton Blvd Breinigsville, PA 18031 CPF 1-2009-5002 Dear Mr. Shelton: From May to December 2008, representatives of the Pipeline and Hazardous Materials Safety Administration (PHMSA) and the New York Public Service Commission pursuant to Chapter 601 of 49 United States Code inspected Buckeye Partners, L.P. (BPL)’s procedures and records for Operations and Maintenance, Operator Qualification, and Integrity Management at BPL’s Headquarters office, and field inspection of pipeline facilities in the states of Pennsylvania, Ohio, Illinois, Michigan and Colorado. As a result of the inspection, it appears that BPL has committed probable violations of the Pipeline Safety Regulations, Title 49, Code of Federal Regulations. The probable violations are:#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 21. § 195.401 General requirements. (b) Whenever an operator discovers any condition that could adversely affect the safe operation of its pipeline system, it shall correct it within a reasonable time. However, if the condition is of such a nature that it presents an immediate hazard to persons or property, the operator may not operate the affected part of the system until it has corrected the unsafe condition…. The inspection team discovered that 1) a block of wood was being used as support for a control valve in the Greensburg Station; 2) a support device at the tank farm in Toledo, Ohio was installed on the 16-inch manifold where pipe modifications had been made, but no associated concrete foundation was present under the pipe support; 3) at the Malvern Station, the pipeline was found to be in contact with a cutoff section of pipe near a line tank; and 4) at the Greensburg Station, the pipeline was found to be in non-intentional contact with a concrete block at the pig receiver. Buckeye failed to correct these adverse conditions within a reasonable time, as required by the regulation. 2. §195.402 Procedural manual for operations, maintenance, and emergencies. (a) General. Each operator shall prepare and follow for each pipeline system a manual of written procedures for conducting normal operations and maintenance activities and handling abnormal operations and emergencies. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year, and appropriate changes made as necessary to insure that the manual is effective. This manual shall be prepared before initial operations of a pipeline system commence, and appropriate parts shall be kept at locations where operations and maintenance activities are conducted.... At the time of the inspection, BPL could not demonstrate that required reviews of the operations, maintenance, and emergency manuals had been performed once per calendar year at intervals not exceeding 15 months. 3. §195.402 Procedural manual for operations, maintenance, and emergencies. (a) General. Each operator shall prepare and follow for each pipeline system a manual of written procedures for conducting normal operations and maintenance activities and handling abnormal operations and emergencies. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year, and appropriate changes made as necessary to insure that the manual is effective… BPL failed to follow its O&M procedures which require a root cause analysis for accident reports. The PHMSA inspection team identified 25 accident reports that did not include a root cause analysis as required by company procedures. 2#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 34. §195.403 Emergency Response Training. (a) Each operator shall establish and conduct a continuing training program to instruct emergency response personnel… (b) At the intervals not exceeding 15 months, but at least once each calendar year, each operator shall: (1) Review with personnel their performance in meeting the objectives of the emergency response training program set forth in paragraph (a) of this section; and (2) Make appropriate changes to the emergency response training program as necessary to ensure that it is effective…. At the time of the inspection, BPL could not demonstrate that the company had reviewed the performance of personnel during emergencies at the required intervals. 5. §195.412 Inspection of rights-of-way and crossing under navigable waters. (a) Each operator shall, at intervals not exceeding 3 weeks, but at least 26 times each calendar year, inspect the surface conditions on or adjacent to each pipeline right-of-way. Methods of inspection include walking, driving, flying or other appropriate mean of traversing the right-of-way…. BPL uses aerial patrols to inspect surface conditions. However, at the time of the inspection, excessive vegetation and overgrowth was found at 1) the Perryville Station, PA; 2) near stations 814+59, 1290+71 and 128+60 on the Laurel pipeline, in PA; and 3) and near Strawberry Mansion (station 1049+72) in PA. Therefore, detrimental conditions or leaks could not be adequately observed by aerial patrols due to the overgrowth. 6. § 195.557 Which pipelines must have coating for external corrosion control? Except bottoms of aboveground breakout tanks, each buried or submerged pipeline must have an external coating for external corrosion control if the pipeline is— (a) Constructed, relocated, replaced, or otherwise changed after the applicable date in §195.401(c), not including the movement of pipe covered by §195.424…. At the time of the inspection, soil-to-air interface on the 301 Line pump discharge pipe and two sample lines at the BPL Toledo Station in Ohio were not coated as required by the regulation. 7. § 195.583 What must I do to monitor atmospheric corrosion control? (a) You must inspect each pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion, as follows: 3#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 4If the pipeline is located: Then the frequency of inspection is: Onshore At least once every 3 calendar years, but with intervals not exceeding 39 months. Offshore At least once each calendar year, but with intervals not exceeding 15 months. BPL records indicated that atmospheric corrosion control inspection for the above ground piping of Mantua Station exceeded the required intervals. Inspections were conducted on 5/4/2004 and 1/29/2008 which exceeded the 39 months interval. 8. § 195.573 What must I do to monitor external corrosion control? (c) Rectifiers and other devices. You must electrically check for proper performance each device in the first column at the frequency stated in the second column. Device Check frequency Rectifier Reverse current switch. Diode. Interference bond whose failure Would jeopardize structural protection. At least six times each calendar year, but with intervals not exceeding 2 1/2 months. Other interference bond At least once each calendar year, but with intervals not exceeding 15 months. BPL failed to check multiple rectifiers at the required frequencies to ensure proper performance. Specifically, a review of the BPL Rectifier Output History Report for 1/1/2006 to 5/1/2008 indicated that inspection intervals for the Harristown Shell system exceeded the 2- 1/2 month maximum interval between May and September 2006) by approximately 1-1/2 months for three rectifiers. A review of the Rectifier Output History Report for 1/1/2006 to 5/1/2008 demonstrates that rectifiers (No.1, No.2, No.3, PM-0.01) in the BPL Trans PA, Malvern Station Tank farm, Paulsboro Deep Well, and Chester Park were not checked at least six times in the 2006 - 2007 calendar period. 4#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 5A review of the Rectifier Output History Report for 1/1/2006 to 5/1/2008 indicated that inspections for the Booth Rectifier LP-07 for Tank #15 exceeded the maximum 2-1/2 month interval between 03/05/2006 to 05/26/2006. A review of the Rectifier Output History Report for 1/1/2006 to 5/1/2008 indicated that BPL did not inspect the rectifier at Booth LP-08 STA40009 BH724SK between 9/5/2006 and 1/12/2007, exceeding the maximum 2 ½ month interval. 9. § 195.571 What criteria must I use to determine the adequacy of cathodic protection? Cathodic protection required by this subpart must comply with one or more of the applicable criteria and other considerations for cathodic protection contained in paragraphs 6.2 and 6.3 of NACE Standard RP 0169 (incorporated by reference, see §195.3). BPL could not demonstrate that the cathodic protection for the facilities at the Philadelphia, PA airport complied with the applicable criteria. According to BPL’s representative, the company does not know if there are adequate levels of cathodic protection for BPL facilities at the Philadelphia, PA Airport apparently due to access limitations. BPL has not taken any pipe-to- soil readings since October 2006. 10. § 195.573 What must I do to monitor external corrosion control? (e) Corrective action. You must correct any identified deficiency in corrosion control as required by §195.401(b). However, if the deficiency involves a pipeline in an integrity management program under §195.452, you must correct the deficiency as required by §195.452(h). BPL did not correct identified corrosion control deficiencies within a reasonable time period, as required by the regulation. A review of Test Point Survey Reports, for 920 NGL, identified inadequate levels of cathodic protection. Specifically, the CP survey at the test point location I-70 XING South, for 920 NGL, indicated inadequate levels of CP in the 2006 and 2007 annual surveys but were not corrected until February 2008. 11. § 195.573 What must I do to monitor external corrosion control? (e) Corrective action. You must correct any identified deficiency in corrosion control as required by §195.401(b). However, if the deficiency involves a pipeline in an integrity management program under §195.452, you must correct the deficiency as required by §195.452(h). The inspection team’s review of the BPL work orders demonstrated that several locations with low CP readings were not corrected by the next inspection cycle. Under §195.401(b), BPL was required to correct the deficiency within a reasonable time. Although BPL had an 5#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 6obligation to correct the deficiency within the time period set in the regulation, the company records reflected that the work at the twelve locations was scheduled to start between years 2005-2007 and yet had not been completed by the time the PHMSA inspection occurred. 12. § 195.438 Smoking or open flames. Each operator shall prohibit smoking and open flames in each pump station area and each breakout tank area where there is a possibility of the leakage of a flammable hazardous liquid or of the presence of flammable vapors. BPL did not prohibit smoking and open flames in the designated areas. Buckeye could have posted signs identifying potential hazards and prohibiting smoking and open flames. During the field inspection, it was noted that the National Fire Protection Association (NFPA) hazardous diamond placards, indicating that the tanks contain flammable liquid and vapors, were not posted on tanks at the Chelsea or the Booth facilities in PA. It was also noted that “No Smoking” signs were not posted at the entrance to tank dikes at Booth Station. Although some of the Booth area tanks were marked as a “No Smoking” area, others were not appropriately marked. 13. §195.402 Procedural manual for operations, maintenance, and emergencies. (a) General. Each operator shall prepare and follow for each pipeline system a manual of written procedures for conducting normal operations and maintenance activities and handling abnormal operations and emergencies. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year, and appropriate changes made as necessary to insure that the manual is effective. This manual shall be prepared before initial operations of a pipeline system commence, and appropriate parts shall be kept at locations where operations and maintenance activities are conducted…. On March 22, 2005, on BPL’s 209 Line in Wayne, Michigan, personnel failed to follow Buckeye’s repair procedures for dents. Per Buckeye’s procedure MA E-08 and associated Exhibit H, all “sharp” dents shall be repaired using a sleeve. However, the dent at Sta. 913+96 was not repaired using a sleeve. On June 1, 2005, BPL’s personnel failed to repair a wrinkle bend in conformance with Buckeye’s repair procedures. At the listed MOP of 1233 psig, the wrinkle bend would require repair per Procedure MA E-08, MA E-08 Exhibit I. Instead, Buckeye’s management decided that since the line does not normally operate above 900 psig, no repair was necessary. However, Buckeye did not re-establish the MOP of the line to the lower 900 psig. BPL did not initiate an engineering evaluation of the wrinkle bend until 2008, after the issue was brought to BPL’s attention during the PHMSA inspection. 14. §195.452 (j) What is a continual process of evaluation and assessment to maintain a pipeline's integrity? 6#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 7(2) Evaluation. An operator must conduct a periodic evaluation as frequently as needed to assure pipeline integrity. An operator must base the frequency of evaluation on risk factors specific to its pipeline, including the factors specified in paragraph (e) of this section. The evaluation must consider the results of the baseline and periodic integrity assessments, information analysis (paragraph (g) of this section), and decisions about remediation, and preventive and mitigative actions (paragraphs (h) and (i) of this section). At the time of inspection, BPL could not demonstrate that periodic evaluations of the pipeline integrity program were performed as required by the integrity management regulations. The BPL Integrity Management Plan manages approximately 3,558 miles of HCA piping. 15. §195.452(b) What program and practices must operators use to manage pipeline integrity? Each operator of a pipeline covered by this section must: (2) Include in the program an identification of each pipeline or pipeline segment in the first column of the following table not later than the date in the second column: ------------------------------------------------------------------------ Pipeline Date ------------------------------------------------------------------------ Category 1................................ December 31, 2001. Category 2................................ November 18, 2002. Category 3................................ Date the pipeline begins operation. ------------------------------------------------------------------------ At the time of inspection, BPL failed to identify in its Baseline Assessment Plan idle pipelines intersecting with HCAs. BPL’s identification of facilities that could affect HCAs was to be completed by Dec. 31, 2001, per the regulation. Identification of idle pipelines is necessary to consider risks which could affect an HCA. 16. §195.452(b) What program and practices must operators use to manage pipeline integrity? Each operator of a pipeline covered by this section must: (2) Include in the program an identification of each pipeline or pipeline segment in the first column of the following table not later than the date in the second column: ------------------------------------------------------------------------ Pipeline Date 7#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 8------------------------------------------------------------------------ Category 1................................ December 31, 2001. Category 2................................ November 18, 2002. Category 3................................ Date the pipeline begins operation. ------------------------------------------------------------------------ Buckeye did not identify all facilities affecting HCAs. Buckeye did not consider the contribution of tank volumes from tank farms to overland spread, nor was an overland spread analysis performed at facilities greater than ¼ mile from HCAs. After identification of this issue by the PHMSA inspection team in 2008, Buckeye subsequently identified 6 additional facilities with the potential to affect HCAs using overland spread analysis. 17. §195.452(f) What are the elements of an integrity management program? An integrity management program begins with the initial framework. An operator must continually change the program to reflect operating experience, conclusions drawn from results of the integrity assessments, and other maintenance and surveillance data, and evaluation of consequences of a failure on the high consequence area. An operator must include, at minimum, each of the following elements in its written integrity management program: (6) Identification of preventive and mitigative measures to protect the high consequence area (see paragraph (i) of this section); Buckeye failed to include a process to identify potential preventive and mitigative actions in its written integrity management program. Buckeye operates 5,576 miles of pipe of which 3,558 miles could affect an HCA. Therefore, it is particularly important for Buckeye to consider and identify preventive and mitigative measures to provide further protection to these areas. 18. §195.452(i) What preventive and mitigative measures must an operator take to protect the high consequence area? (2) Risk analysis criteria. In identifying the need for additional preventive and mitigative measures, an operator must evaluate the likelihood of a pipeline release occurring and how a release could affect the high consequence area. This determination must consider all relevant risk factors, including, but not limited to: (i) Terrain surrounding the pipeline segment, including drainage systems such as small streams and other smaller waterways that could act as a conduit to the high consequence area; (ii) Elevation profile; (iii) Characteristics of the product transported; (iv) Amount of product that could be released; (v) Possibility of a spillage in a farm field following the drain tile into a waterway; (vi) Ditches along side a roadway the pipeline crosses; (vii) Physical support of the pipeline segment such as by a cable suspension bridge; 8#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 9(viii) Exposure of the pipeline to operating pressure exceeding established maximum operating pressure…. Buckeye failed to evaluate the likelihood of a pipeline release occurring and how such an event could affect the HCAs in order to determine the need for additional preventive and mitigative measures. This determination must consider all relevant risk factors including but not limited to the criteria listed in §195.452(i)(2)(i)-(viii). Buckeye failed to assess these risk factors. 19. §195.452(i) What preventive and mitigative measures must an operator take to protect the high consequence area? (4) Emergency Flow Restricting Devices (EFRD). If an operator determines that an EFRD is needed on a pipeline segment to protect a high consequence area in the event of a hazardous liquid pipeline release, an operator must install the EFRD. In making this determination, an operator must, at least, consider the following factors–the swiftness of leak detection and pipeline shutdown capabilities, the type of commodity carried, the rate of potential leakage, the volume that can be released, topography or pipeline profile, the potential for ignition, proximity to power sources, location of nearest response personnel, specific terrain between the pipeline segment and the high consequence area, and benefits expected by reducing the spill size. At the time of inspection, Buckeye had not performed EFRD evaluations since 2005. BPL’s Integrity Management Plan, Section 15, issued 12/2005, requires annual review of pipelines scheduled for integrity assessment during that year to determine whether impact to an HCA can be mitigated by adding an EFRD. Buckeye also did not have a technical justification explaining why the EFRDs recommended in 2002 had not been installed. 20. §195.452 (f) What are the elements of an integrity management program? An integrity management program begins with the initial framework. An operator must continually change the program to reflect operating experience, conclusions drawn from results of the integrity assessments, and other maintenance and surveillance data, and evaluation of consequences of a failure on the high consequence area. An operator must include, at minimum, each of the following elements in its written integrity management program: (3) An analysis that integrates all available information about the integrity of the entire pipeline and the consequences of a failure (see paragraph (g) of this section) Buckeye did not change its integrity management program to reflect relevant operating experience. In May 2005, Buckeye’s Risk Management Team determined that the risk analysis program did not provide the necessary insight for the risks associated with the analyzed pipeline segments. However, actions to improve the risk analysis model were not initiated until 2008. 21. § 195.561 When must I inspect pipe coating used for external corrosion control? 9#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 10(a) You must inspect all external pipe coating required by § 195.557 just prior to lowering the pipe into the ditch or submerging the pipe. (b) You must repair any coating damage discovered. Buckeye did not properly repair coating damage when inspecting pipe coating. During the NORCO pipe replacement project in 2008, PHMSA staff observed that Buckeye's contractor personnel were improperly applying patchstick repairs to fusion bonded epoxy coating. In lieu of having BPL procedures in place, personnel were not properly following the manufacturer's instructions. 22. § 195.406 Maximum operating pressure. (b) No operator may permit the pressure in a pipeline during surges or other variations from normal operations to exceed 110 percent of the operating pressure limit established under paragraph (a) of this section. Each operator must provide adequate controls and protective equipment to control the pressure within this limit. According to BPL's Abnormal Operating Condition (AOC) forms, BPL exceeded 110 percent of the operating pressure limit established in §195.406(a) on three separate occasions. The AOC forms dated May 11, 2006, November 5, 2007, and June 3, 2007 document the three events. Proposed Civil Penalty Under 49 United States Code, § 60122, you are subject to a civil penalty not to exceed $100,000 for each violation for each day the violation persists up to a maximum of $1,000,000 for any related series of violations. The Compliance Officer has reviewed the circumstances and supporting documentation involved in the above probable violation(s) and has recommended that you be preliminarily assessed a civil penalty of $645,200 as follows: Item number PENALTY #3 $ 41,500 #4 $ 29,000 #7 $ #8 14,000 $ 14,000 #9 $ 35,300 #11 $ 29,000 #13 $ 41,500 #14 $ 120,300 #17 $ 200,300 #19 $ 120,300 10#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 11Warning Items With respect to item #1, #2, #5, #6, #10, #12, #15, #16, #18, #20, #21, and #22 we have reviewed the circumstances and supporting documents involved in this case and have decided not to conduct additional enforcement action or penalty assessment proceedings at this time. We advise you to promptly correct these items. Be advised that failure to do so may result in Buckeye Partners, L.P. being subject to additional enforcement action. Proposed Compliance Order With respect to items #3, #9, #17, #19, pursuant to 49 United States Code § 60118, the Pipeline and Hazardous Materials Safety Administration proposes to issue a Compliance Order to Buckeye Partners, L.P. Please refer to the Proposed Compliance Order, which is enclosed and made a part of this Notice. Response to this Notice Enclosed as part of this Notice is a document entitled Response Options for Pipeline Operators in Compliance Proceedings. Please refer to this document and note the response options. Be advised that all material you submit in response to this enforcement action is subject to being made publicly available. If you believe that any portion of your responsive material qualifies for confidential treatment under 5 U.S.C. 552(b), along with the complete original document you must provide a second copy of the document with the portions you believe qualify for confidential treatment redacted and an explanation of why you believe the redacted information qualifies for confidential treatment under 5 U.S.C. 552(b). If you do not respond within 30 days of receipt of this Notice, this constitutes a waiver of your right to contest the allegations in this Notice and authorizes the Associate Administrator for Pipeline Safety to find facts as alleged in this Notice without further notice to you and to issue a Final Order. In your correspondence on this matter, please refer to CPF 1-2009-5002 and for each document you submit, please provide a copy in electronic format whenever possible. Sincerely, Byron E. Coy, P.E. Director, Eastern Region Pipeline and Hazardous Materials Safety Administration Enclosures: Proposed Compliance Order Response Options for Pipeline Operators in Compliance Proceedings 11#

120095002_NOPV-PCP-PCO_06262009_text.pdf, page 12PROPOSED COMPLIANCE ORDER Pursuant to 49 United States Code § 60118, the Pipeline and Hazardous Materials Safety Administration (PHMSA) proposes to issue to Buckeye Partners, L.P. a Compliance Order incorporating the following remedial requirements to ensure the compliance of Buckeye Partners, L.P.(BPL) with the pipeline safety regulations: 1. In regard to Item Number 3 of the Notice pertaining to the numerous accident reports that did not include documentation of the required root cause analysis (from BPL’s Operations and Maintenance (O&M) Manual). BPL shall develop a plan to ensure that a root cause analysis is conducted and documented for all accidents that occur as required by BPL’s O&M Manual, and that recommended corrective action(s) from the root cause analysis is implemented. 2. In regard to Item Number 9 of the Notice, BPL must establish and implement a plan to correct access problems to BPL cathodic protection test point facilities at the Philadelphia, PA airport area. Any outstanding remedial problems with those test points must also be included in the plan. 3. In regard to Item Number 17 of the Notice, BPL must establish and implement processes to evaluate their pipeline segments for additional preventive and mitigative actions. Upon completion of the evaluation of pipeline segments, a schedule for implementing additional preventive and mitigative measures must be submitted. 4. In regard to Item Number 19 of the Notice, BPL must establish an improved process to evaluate the need for additional EFRDs. Upon establishment of the improved process, BPL must perform EFRD evaluations on its pipeline segments and develop a schedule for installing EFRDs where necessary and document the logic where EFRDs are not necessary for all locations BPL considered. 5. BPL shall submit a plan and schedule for completing the Proposed Compliance Order Items above to PHMSA for review and approval within 60 days after receipt of the Final Order. Upon receiving approval of the plan and schedule, BPL shall submit evidence of completion for the Proposed Compliance Order Items above to PHMSA within 180 days after receipt of the Final Order. Submit all correspondence for review and approval to Mr. Byron Coy Director, Eastern Region, Office of Pipeline Safety, Pipeline and Hazardous Materials Safety Administration, 409 3rd Street, S.W., Washington, DC 20024. 6. BPL shall maintain documentation of the safety improvement costs associated with fulfilling this Compliance Order and submit the total to Mr. Byron Coy, Director, Eastern, Pipeline and Hazardous Materials Safety Administration. Costs shall be reported in two categories: 1) total cost associated with preparation/revision of plans, procedures, studies and analyses, and 2) total cost associated with replacements, additions and other changes to pipeline infrastructure. 12#

120095002_Closure Letter_06172013_text.pdf, page 1Official PDFU.S. Department Of Transportation Pipeline and 609.989.2171 Hazardous Materials Safety Administration 820 Bear Tavern Road, Suite 103 West Trenton, NJ 08628 OVERNIGHT EXPRESS MAIL June 17, 2013 Mr. Thomas S. Collier, VP Performance Assurance & Asset Integrity Buckeye Partners, L.P. Five TEK Park 9999 Hamilton Boulevard Breinigsville, PA 18031 CPF 1-2009-5002 Dear Mr. Collier: On May 30, 2012, the Pipeline and Hazardous Materials Safety Administration (PHMSA) issued to Buckeye Partners, L.P. a Final Order in the above-referenced case. This Order included a Compliance Order and Civil Penalty assessment. Based on our review of the documentation you provided, and confirmation of payment of the civil penalty, it has been determined that you have complied with the terms of this Order. Accordingly, this case is now closed and no further action is contemplated with respect to the matters involved in this case. Thank you for your cooperation in this matter. Sincerely, Byron Coy, PE Director, Eastern Region Pipeline and Hazardous Materials Safety Administration#

120095002_Final Order _05302012.pdf, page 1Official PDFU.S. Department 1200 New Jersey Avenue SE of Transportation Washington. DC 20590 Materials Safety Pipeline and Hazardous Administration MAY 3 0 2012 Mr. Clark Smith President and CEO Buckeye Partners, LP One Greenway Plaza, Suite 600 Houston, TX 77046 Re: CPF No. 1-2009-5002 Dear Mr. Smith: Enclosed please find the Final Order issued in the above-referenced case. It withdraws one of the allegations of violation, makes other findings of violation, assesses a civil penalty of $524,900, and specifies actions that need to be taken by Buckeye Partners, LP, to comply with the pipeline safety regulations. The penalty payment terms are set forth in the Final Order. When the civil penalty has been paid and the terms of the compliance order completed, as determined by the Director, Eastern Region, this enforcement action will be closed. Service of the Final Order by certified mail is deemed effective upon the date of mailing, or as otherwise provided under 49 C.F.R. § 190.5. Thank you for your cooperation in this matter. Sincerely, / Jeffrey D. Wiese Associate Administrator for Pipeline Safety Enclosure Cc: Mr. Byron Coy, PE, Director, Eastern Region, OPS Mr. Alan Mayberry, Deputy Associate Administrator for Field Operations, OPS Ir. Scott Collier, Vice President, Buckeye Partners, LI TEK Park, 9999 Hamilton Boulevard. Breiniasville PA 1803 CERTIFIED MAIL - RETURN RECEIPT REQUESTED#

120095002_Final Order _05302012.pdf, page 2U.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION OFFICE OF PIPELINE SAFETY WASHINGTON, D.C. 20590 In the Matter of Buckeye Partners, LP, CPF No. 1-2009-5002 Respondent. FINAL ORDER During the period from May to December, 2008, pursuant to 49 U.S.C. § 60117, representatives of the Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), and the New York Public Service Commission conducted on-site pipeline safety inspections of the facilities and records of Buckeye Partners, LP (BPL or Respondent), in several states, including Pennsylvania, Ohio and Michigan. BPL owns and operates approximately 6,000 miles of pipelines transporting refined petroleum products and highly volatile liquids, principally in the Northeastern and upper Midwestern states.' Approximately 3,558 of those pipeline miles are in or could affect High Consequence Areas (HCAs) and are covered by BPL's integrity management program. As a result of the inspection, the Director, Eastern Region, PHMSA (Director), issued to Respondent, by letter dated June 26, 2009, a Notice of Probable Violation, Proposed Civil Penalty, and Proposed Compliance Order (Notice). In accordance with 49 C.F.R. § 190.207, the Notice proposed finding that BPL had committed various violations of 49 C.F.R. Part 195, assessing a civil penalty of $645,200 for the alleged violations, and ordering Respondent to take certain measures to correct the alleged violations. The Notice also proposed finding that Respondent had committed other probable violations of 49 C.F.R. Part 195 and warning the company to take appropriate corrective action or be subject to future enforcement action. BPL responded to the Notice by letters dated September 25, 2009 (Response), and January 6, 2010 (Supplemental Response). The company contested some of the allegations of violation and requested reduction or elimination of the associated penalties. BPL did not contest other allegations and provided information concerning the corrective actions it had taken. Respondent did not request a hearing and therefore has waived its right to one. 'http://www.buckeye.com/BusinessOperations/tabid/56/Default.aspx and http://www.buckeye.com/AboutUs/tabid/54/Default.aspx (last accessed on March 22, 2012). = 49 C.F.R. $ 195.450. * 19 C.F.R. $ 195.452.#

120095002_Final Order _05302012.pdf, page 32 FINDINGS OF VIOLATION The Notice alleged that Respondent violated 49 C.F.R. Part 195, as follows: Operations and Maintenance Items: Item 3: The Notice alleged that Respondent violated 49 C.F.R. § 195.402(a), which states in relevant part: $ 195.402 Procedural manual for operations, maintenance, and (a) General. Each operator shall prepare and follow for each pipeline emergencies. system a manual of written procedures for conducting normal operations and maintenance activities and handling abnormal operations anc emergencies. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year, and appropriate changes made as necessary to insure that the manual is effective.... The Notice alleged that BPL violated 49 C.F.R. § 195.402(a) by failing to follow its manual of written procedures for conducting normal operations and maintenance (O&M) activities and handling abnormal operations and emergencies. Specifically, it alleged that BPL had failed to conduct root-cause analyses in 25 accident reports, as required by its own O&M procedures. The BPL Safety Manual, Section A-04, required that a root cause analysis be conducted for each product release that required regulatory reporting. In its Response, BPL did not contest the allegation of violation but contended that in August positions was to conduct root cause analyses for accidents. BPL also stated that the 25 accident 2006, it had created six new positions within the company and that one of the duties of these new positions.® BPL stated that it had "recognized that there was a need to ensure that root cause reports which lacked a root cause analysis had all been performed before the creation of the new that the penalty associated with this Item be "rescinded."" Since this argument relates to a analyses were conducted... almost two years prior to the integrated inspection" and requested potential reduction in the amount of the penalty, it is discussed in the "Assessment of Penalty" section below. Accordingly, based upon a review of all of the evidence, I find that Respondent violated 49 C.F.R. $ 195.402(a) by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Item 4: The Notice alleged that Respondent violated 49 C.F.R. § 195.403(b), which states: * Pipeline Safety Violation Report (Violation Report), Exhibit A (on file with PHMSA). " Response at 2. " Id. 1 Id.#

120095002_Final Order _05302012.pdf, page 43 $ 195.403 Emergency response training. (a) Each operator shall establish and conduct a continuing training program to instruct emergency response personnel... (b) At the intervals not exceeding 15 months, but at least once each calendar year, each operator shall: (1) Review with personnel their performance in meeting the objectives of the emergency response training program set forth in paragraph (a) of this section; and (2) Make appropriate changes to the emergency response training program as necessary to ensure that it is effective. The Notice alleged that BPL violated 49 C.F.R. § 195.403(b) by failing to review with company personnel their performance in meeting the objectives of the company's emergency response training program, at intervals not exceeding 15 months but at least once each calendar year. In its Response, BPL did not explicitly contest the allegation but argued that it had reviewed the performance of its employees in responding to emergencies through the use of a form which had been "approved by the government" and which had documented personnel "responses and follow up actions to emergencies."* The company further explained that its Training Manual called for a critique of employee responses after all emergencies and response drills but acknowledged that it did not "specifically document the review of the performance of its employees on the form." Notwithstanding these existing procedures, BPL indicated that it had revised the form to include a check box to document specifically that the performance of company personnel had been reviewed. The company provided OPS with a blank copy of the revised form.? While BPL indicated that the form had been approved by the government, there is no indication that the form had ever been approved by PHMSA for purposes of satisfying this regulatory requirement. In addition, BPL did not provide any completed forms to demonstrate that the required reviews had actually been conducted. Therefore, it is impossible to tell whether the reviews were properly completed in a timely manner. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. $ 195.403(b) by failing to review with company personnel, at the required intervals. their performance in meeting the objectives of BPL's emergency response training program. Item 13: The Notice alleged that Respondent violated 49 C.F.R. § 195.402(a), as quoted above, by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Specifically, it alleged that BPL failed to follow its Maintenance Manual, Procedure E-08, Damaged or Defective Non-Leaking Pipe, on two occasions. On March 22, 2005, the company allegedly failed to repair a sharp dent at Sta. 913+96 on its 209 Line in Wayne, Michigan, using a sleeve required by its own written procedures. Similarly, the Notice alleged that on June 1, 2005, the company allegedly failed to repair a wrinkle bend in accordance with BPL's own written procedures. 8 Response at 3. • Id. 10 Violation Report, Exhibit B.#

120095002_Final Order _05302012.pdf, page 54 According to the Notice, BPL's procedures stated that at the pipeline's listed Maximum Operating Pressure (MOP) of 1233 psig, the wrinkle bend had to be repaired in accordance with the company's Procedure MA E-08, Exhibit I. The company allegedly decided, however, that no repair was needed for the wrinkle bend because the line did not normally operate at over 900 psig. However, BPL did not subsequently lower the MOP on the line to 900 psig. BPL did not contest the alleged violations. The company acknowledged that in August 2009, it had excavated and re-evaluated the sharp dent in the 209 line and had installed a repair sleeve." As for the wrinkle bend, the company stated that it was in the process of conducting an engineering evaluation to determine the appropriate MOP for this line segment.' Accordingly, based upon a review of all of the evidence, I find that Respondent violated 49 C.F.R. § 195.402(a) by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Corrosion Control Items Item 7: The Notice alleged that Respondent violated 49 C.F.R. § 195.583(a), which states: § 195.583 What must I do to monitor atmospheric corrosion control? (a) You must inspect each pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion, as follows: If the pipeline is located: Then the frequency of inspection is: Onshore.. At least once every 3 calendar years, but with intervals not exceeding 39 months. Offshore... At least once each calendar year, but with intervals not exceeding 15 months. The Notice alleged that BPL violated 49 C.F.R. § 195.583(a) by failing to inspect the above- ground pipeline facilities at the company's Mantua Station for atmospheric corrosion at least once every three calendar years, but at intervals not exceeding 39 months. Specifically, it alleged that BPL's own records showed inspections had been conducted on May 4, 2004, and January 29, 2008, an interval that exceeded 39 months. BPL did not contest this allegation. Accordingly, after considering all of the evidence, I find that ipeline exposed to the atmosphere for atmospheric corrosion. It is noted that BPL represent respondent violated 49 C.F.K. § 195.583(a) by failing to inspect, at the required intervals, eac that it has improved its process for conducting such inspections. " Response at 6. 12 Id.#

120095002_Final Order _05302012.pdf, page 65 Item 8: The Notice alleged that Respondent violated 49 C.F.R. § 195.573(c), which states: § 195.573 What must I do to monitor external corrosion control? (c) Rectifiers and other devices. You must electrically check for proper performance each device in the first column at the frequency stated in the second column. Device Check frequency Rectifier.......... At least six times each calendar year, but with intervals not exceeding 2½ Reverse current switch. months. Diode. Interference bond whose failure would jeopardize structural protection. Other interference bond...... At least once each calendar year, but with intervals not exceeding 15 months. The Notice alleged that BPL violated 49 C.F.R. § 195.573(c) by failing to electrically check several rectifiers for proper performance at the required frequency. Specifically, it alleged the following failures: 1. Three rectifiers in the Harristown Shell system were not inspected at the required intervals twice during 2006, each time exceeding the 2½-month maximum by 1½ months; 2. The rectifiers in the BPL Trans PA, Malvern Station Tank Farm, Paulsboro Deep Well, and Chester Park systems were not checked at least six times each year during 2006- 2007; 3. The Booth rectifier LP-07 for Tank #15 was not inspected between March 5, 2006, and May 26, 2006, an interval that exceeded 2½ months; and 4. The Booth rectifier LP-08 STA40009 BH724SK was not inspected between September 5, 2006, and January 12, 2007, an interval that exceeded 2½ months. In its Response, BPL only contested the portion of the allegation relating to the rectifiers on the Harristown Shell system. The company asserted that during the March and July inspections, the Harristown rectifiers were out of service due to tank projects and were noted as "locked#

120095002_Final Order _05302012.pdf, page 76 out/tagged out" on the company's inspection records." BPL's rectifier output-history documents included comments for the Harristown rectifiers for the March and July inspections. In March, the rectifiers were noted as "Locked out - Due to cleaning tank" and in July they were listed as "Down - Due to construction." Based on these records and BPL's explanation for them, it is plausible that the rectifiers were out of service during these inspections. To remain in compliance with the regulation, however, BPL was obliged to check the rectifiers before they were put back into service. The company failed to inspect them until the next scheduled inspection two months later, resulting in a four-month interval between inspections. BPL stated that it had subsequently revised its procedures to require that rectifiers be checked both prior to and after being locked out and that the company had added a field in its work order system to show when an inspection would be out of compliance with § 195.573(c). '4 Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.573(c) by failing to check several rectifiers for proper performance within the required intervals. Item 9: The Notice alleged that Respondent violated 49 C.F.R. § 195.571, which states: § 195.571 What criteria must I use to determine the adequacy of cathodic protection? Cathodic protection required by [Subpart H] must comply with one or more of the applicable criteria and other considerations for cathodic protection contained in paragraphs 6.2 and 6.3 of NACE SP 0169 (incorporated by reference, see § 195.3). The Notice alleged that BPL violated 49 C.F.R. § 195.571 by failing to ensure that cathodic protection for the company's facilities at the Philadelphia Airport (Airport) complied with one or more of the applicable criteria and other considerations for cathodic protection contained in paragraphs 6.2 and 6.3 of NACE Standard SP 0169 (NACE Standard). Specifically, it alleged that BPL had failed to take any pipe-to-soil readings at the Airport since October 2006 and that therefore the adequacy of cathodic protection at these locations was unknown. In its Response, BPL acknowledged that it did not take pipe-to-soil readings at the Airport test test points at the Airport represented only a small fraction of the points on its entire system.' points, but contended that it had been unable to gain access to the Airport in 2007 and that the BPL stated that all the other test points had been tested in 2007 and that the Airport points were accessed and tested in October 2008. The company also stated that it had now arranged a new method for arranging security escorts at the Airport and that it had made arrangements for the 2009 inspection within the required interval.'° 1? Response at 4. It ld. 15 Response at 4. I Response at 4-5.#

120095002_Final Order _05302012.pdf, page 87 BPL is obligated to ensure that cathodic protection is adequate and complies with the NACE Standard at all times. BPL's failure to gain access to the Airport does not serve to refute the allegation of violation. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.571 by failing to ensure that cathodic protection on its pipeline complied with the applicable criteria and other considerations for cathodic protection contained in the NACE Standard. Item 11: The Notice alleged that Respondent violated 49 C.F.R. § 195.573(e), which states: $ 195.573 What must I do to monitor external corrosion control? (2) Corrective action. You must correct any identified deficiency in corrosion control as required by § 195.401(b). However, if the deficiency involves a pipeline in an integrity management program under § 195.452, you must correct the deficiency as required by § 195.452(h). The Notice alleged that BPL violated 49 C.F.R. § 195.573(e) by failing to correct identified deficiencies in corrosion control, as required by § 195.401(b), which states that an operator must correct, within a reasonable time. any deficiency that could adversely affect the safe operation of the pipeline. Specifically, the Notice alleged that the company's own work orders showed that several locations along the pipeline with low cathodic protection readings had been scheduled for work between 2005 and 2007, but that the work had not been completed by the time of the PHMSA inspections in 2008. BPL did not contest this allegation and explained that it had improved its process for remediating low cathodic protection readings by adding a field in its work order system to show when proposed remediation efforts would fail to be in compliance." Accordingly, after considering all of the evidence. I find that Respondent violated 49 C.F.R. § 195.573(e) by failing to correct identified deficiencies in corrosion control within a reasonable time. Integrity Management Program (IMP) Items Item 14: The Notice alleged that Respondent violated 49 C.F.R. § 195.452(j)(2), which states: § 195.452 Pipeline integrity management in high consequence areas. (a) What is a continual process of evaluation and assessment to maintain a pipeline's integrity?— (1) General. After completing the baseline integrity assessment, an operator must continue to assess the line pipe at specified intervals and periodically evaluate the integrity of each pipeline segment that could affect a high consequence area. (2) Evaluation. An operator must conduct a periodic evaluation as frequently as needed to assure pipeline integrity. An operator must base 1 Response at 5.#

120095002_Final Order _05302012.pdf, page 98 the frequency of evaluation on risk factors specific to its pipeline, including the factors specified in paragraph (e) of this section. The evaluation must consider the results of the baseline and periodic integrity assessments, information analysis (paragraph (g) of this section), and decisions about remediation, and preventive and mitigative actions (paragraphs (h) and (i) of this section). The Notice alleged that BPL violated 49 C.F.R. § 195.452(j)(2) by failing to conduct periodic evaluations as frequently as needed to assure pipeline integrity. Specifically, the Notice alleged hat "BPL could not demonstrate that periodic evaluations of the pipeline integrity program wer ertormed as required by the integrity management regulations. BPL contested the allegation, and compliance with integrity regulations involves its Risk Management Team. "19 The stating that the company's "process for periodic evaluation of the integrity of BPL's pipelines Response broadly described the responsibilities and activities of the team, including ensuring "[clompliance with all regulatory requirements regarding operational risk management" and a "I clontinuous improvement process for BPL's integrity management program."20 BPL also stated that minutes and "action items" from the team's meetings documented the company's periodic evaluation process. BPL did not offer any documentation or evidence of any of its integrity program evaluations. The meeting minutes and actions items which BPL referenced in its Response were not provided, nor did BPL demonstrate that results of any evaluations were used to make decisions about remediation and preventive and mitigative (P&M) actions. BPL offered examples of "programs that were recommended through the periodic evaluations" but did not offer any documentation of the evaluations or the recommendations that they had claimed to have made." Neither party has presented sufficient proof to prove its position, but OPS bears the burden of proving that BPL has committed the violation. Section 195.452(j) requires continuous evaluation and assessment of an operator's individual pipeline segments, not simply its overall IMP. The evidence presented by OPS in the Violation Report and Notice are insufficient to prove that Respondent's IMP failed to include periodic pipe segment evaluations under § 195.452(j). The record contains no documents, procedures, interview notes or any other evidence to support the allegation that the company's IMP was devoid of the sort of continuous evaluations required by the regulation. Accordingly, based upon the foregoing, I find that OPS has failed to meet its burden of proof and hereby order that Item 14 be withdrawn. Item 17: The Notice alleged that Respondent violated 49 C.F.R. $ 195.452(f)(6), which states: 18 Notice at 7. 1° Response at 6. 20 Id. " Response at 7. " Id.#

120095002_Final Order _05302012.pdf, page 10§ 195.452 Pipeline integrity management in high consequence areas. (a) (f) What are the elements of an integrity management program? An integrity management program begins with the initial framework. An operator must continually change the program to reflect operating experience, conclusions drawn from results of the integrity assessments, and other maintenance and surveillance data, and evaluation of consequences of a failure on the high consequence area. An operator must include, at minimum, each of the following elements in its written integrity management program: (1) ... (6) Identification of preventive and mitigative measures to protect the high consequence area (see paragraph (i) of this section). The Notice alleged that BPL violated 49 C.F.R. § 195.452(f)(6) by failing to include in its IMP a process for identifying (P&M) measures to protect HCAs. Under § 195.452(f), an operator's IMP must contain eight separate elements, including a process for identifying HCAs, a baseline assessment plan, an information-integration analysis, criteria for taking remedial action, a continual process of periodic assessments of line pipe segments (see Item 14 above), the identification of P&M measures tailored to the operator's unique system, and methods to measure the IMP's overall effectiveness. The Violation Report stated that the OPS inspection team had found no indication that BPL had ever developed a process within its IMP for identifying P&M measures that would reduce the likelihood and consequences of pipeline releases, had ever identified specific P&M measures to protect HCAs, or had compiled any documentation to show such processes were in place. The Violation Report also noted that BPL's integrity manager had stated that BPL would be developing such procedures in the future. In its Response, BPL contested the alleged violation, stating that its Integrity Management Manual (IMM) did indeed contain a process for identifying potential P&M measures and summarizing the process. It claimed that Section 6 of its IMM fully described the company's process for identifying P&M measures, including the use of a Risk Model to identify high-risk areas, the use of subject matter expert teams to develop and test "various preventive and mitigative scenarios that potentially will provide positive impacts to reducing the identified risk," the selection and evaluation of "physically feasible" measures, and the implementation of those measures having the greatest benefit in terms of risk reduction and financial feasibility?3 In addition, the company contended that the "Exhibit A-01A flowchart in Buckeye's IMM and referenced in Section 6 clearly shows that preventive and mitigative measures are an integral part of the Continual Assessment Program." 24 The company, however, did not submit any of these procedures or any other documentation in either its Response or Supplemental Response. 23 Response at 8. 24 Response at 8.#

120095002_Final Order _05302012.pdf, page 1110 Such general statements do not constitute credible evidence that BPL actually had a process for identifying P&M measures or that it had actually developed specific measures to reduce the likelihood or consequences of failures on HCAs. Not only did BPL fail to produce documentation of a P&M process that was in effect as of the date of the OPS inspection in May 2008, but it also failed to provide any evidence showing that any specific P&M measures had ever been actually identified, evaluated by its subject matter expert team, or implemented by the company• While BPL may indeed have had some general framework of a process for identifying P&M measures, the company failed to produce any evidence that it had implemented any such process or that it had met the requirements of the regulation. Accordingly, based upon a review of all of the evidence. I find that BPL violated 49 C.F.R. § 195.452(f)(6) by failing to include a process for identifying P&M measures to protect HCAs in its written IMP. Item 19: The Notice alleged that Respondent violated 49 C.F.R. § 195.452(i)(4), which states: § 195.452 Pipeline integrity management in high consequence areas. (a) (i) What preventive and mitigative measures must an operator take to protect the high consequence area!- (1) ... (4) Emergency Flow Restricting Devices (EFRD). If an operator determines that an EFRD is needed on a pipeline segment to protect a high consequence area in the event of a hazardous liquid pipeline release, an operator must install the EFRD. In making this determination, an operator must, at least, consider the following factors-the swiftness of leak detection and pipeline shutdown capabilities, the type of commodity carried, the rate of potential leakage, the volume that can be released, topography or pipeline profile, the potential for ignition, proximity to power sources, location of nearest response personnel, specific terrain between the pipeline segment and the high consequence area, and benefits expected by reducing the spill size. The Notice alleged that BPL violated 49 C.F.R. § 195.452(i)(4) by failing to determine whether EFRDs were needed to protect against failures that could affect HAs along its pipeline and, if so, to install them. Specifically, the Notice alleged that, since 2005, BPL had failed to conduct annual EFRD analyses of pipeline segments scheduled for integrity re-assessments, as required by $ 195.452(i) and Section 15 of the company's own IMM. The Notice also alleged that BPL had failed to install certain EFRDs that had been recommended as a result of a 2002 evaluation. In its Response, BPL noted that pipelines scheduled for integrity assessments between 2002 and 2005 had been analyzed for EFRDs and that the recommended devices had been included in BPL's capital plan. The company claimed, however, that it had ultimately decided to allocate funds to other risk-management projects instead.? BPL also noted that its spending on pipeline maintenance had drastically increased since 2000 and that EFRDs were "still being considered '5 Response at 8-9.#

120095002_Final Order _05302012.pdf, page 1211 and installed when the benefits match the expenditure."' For example, it cited the example of a block valve that had been installed as a "risk mitigation project," which showed that BPL was "not opposed to adding EFRDs."' The company, however, did not contest the facts set out in the allegation. BPL's spending on other maintenance projects does not lessen the potential consequences of the violation at hand, nor do budgetary considerations absolve BPL of its obligation to comply with the regulation and its own IMP. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.452(i)(4) by failing to determine whether EFRDs were needed on its pipeline to protect against failures, and, if so, to install them. These findings of violation will be considered prior offenses in any subsequent enforcement action taken against Respondent. ASSESSMENT OF PENALTY Under 49 U.S.C. $ 60122, Respondent is subject to an administrative civil penalty not to exceed $100,000 per violation for each day of the violation, up to a maximum of $1,000,000 for any related series of violations. In determining the amount of a civil penalty under 49 U.S.C. § 60122 and 49 C.F.R. § 190.225, I must consider the following criteria: the nature, circumstances, and gravity of the violation, including adverse impact on the environment; the degree of Respondent's culpability; the history of Respondent's prior offenses; the Respondent's ability to pay the penalty and any effect that the penalty may have on its ability to continue doing business; and the good faith of Respondent in attempting to comply with the pipeline safety regulations. In addition, I may consider the economic benefit gained from the violation without any reduction because of subsequent damages, and such other matters as justice may require. The Notice proposed a total civil penalty of $645,200 for the violations cited above. Item 3: The Notice proposed a civil penalty of $41,500 for Respondent's violation of 49 C.F.R. § 195.402(a), for failing to follow its own manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. As noted above, I found that BPL failed to conduct root cause analyses in 25 accident reports, as required by its O&M procedures. Respondent argued, however. that the penalty should be "rescinded" because BPL had recognized the need to ensure root cause analyses were done, and had created a job position for this purpose two years before the OPS inspection. I fail to see any basis for rescission or reduction of the penalty. Recognizing a need to comply and actually complying are two different things. Respondent's arguments do not mitigate the fact that BPL prepared 25 accident reports during 2002-2007 that did not include a root cause analysis, as required by its own procedures. A root cause analysis is an important tool for identifying safety problems before they cause accidents. Presumably, this is the very reason BPL included the requirement in its O&M manual. The gravity of the violation is not mitigated by the fact that BPL recognized the " Response at 9. " Id.#

120095002_Final Order _05302012.pdf, page 1312 problem and made plans to correct it. On the contrary, it is troubling to see that the violation continued for years because the company apparently did not place a high enough priority on investigating the root causes of 25 separate accidents or complying with its own internal procedures. BPL has not presented any evidence or argument that would justify a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $41,500 for violation of 49 C.F.R. $ 195.402(a). Item 4: The Notice proposed a civil penalty of $29,000 for Respondent's violation of 49 C.F.R. § 195.403(b), for failing to review with company personnel their performance in meeting the objectives of BPL's emergency response training program, at intervals not exceeding 15 months but at least once each calendar year. I found that, while Respondent used a form to document employee responses to emergencies, it did not document such reviews on the forms and did not provide PHMSA with copies of any completed forms to demonstrate that the required reviews had actually been conducted. Adequate emergency response training is essential to the safety of the public and protection of the environment in the event of emergencies. Respondent's failure to review or document the performance of its personnel reduced the safety of its operations insofar as the company had no established method of regularly reviewing employee performance that was related specifically to emergency response. Accordingly, having reviewed the record and considered the assessment criteria. I assess Respondent a civil penalty of $29,000 for violations of 49 C.F.R. § 195.403(b). Item 7: The Notice proposed a civil penalty of $14,000 for Respondent's violation of 49 C.F.R. § 195.583(a), for failing to inspect the above-ground pipeline facilities at the Mantua Station for atmospheric corrosion at least once every three calendar years, but at intervals not exceeding 39 months. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty; therefore, I found that Respondent failed to inspect each pipeline exposed to the atmosphere for atmospheric corrosion at the required intervals. Atmospheric corrosion at the Mantua Station could result in a release of hazardous liquids, thus posing a risk to life, property and the environment. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $14,000 for violation of 49 C.F.R. § 195.583(a). Item 8: The Notice proposed a civil penalty of $14,000 for Respondent's violation of 49 C.F.R. § 195.573(c), for failing to check several rectifiers for proper performance at the required frequency. Respondent contested the allegations relating to the Harristown Shell system but not the others. As discussed above, I found that Respondent was required to check the locked-out rectifiers before putting them back into service. The proposed penalty amount reflects the fact that neither pipeline integrity nor safe operations were seriously affected by the violations. Based upon the foregoing, I assess Respondent a civil penalty of $14,000 for violation of 49 C.F.R. § 195.573(c). Item 9: The Notice proposed a civil penalty of $35,300 for Respondent's violation of 49 C.F.R. § 195.571, for failing to ensure that cathodic protection for the company's pipeline facilities at the Airport complied with the NACE Standard. BPL failed to take any pipe-to-soil readings at the Airport from October 2006 until October 2008, and therefore the adequacy of the#

120095002_Final Order _05302012.pdf, page 1413 cathodic protection at this location was unknown. As noted above, I found that BPL's failure to gain access to the Airport did not serve to refute the allegation of violation. BPL has a responsibility to ensure that its facilities can be operated safely, which includes maintaining adequate cathodic protection. The potential failure of this pipeline in an HCA near the Airport could jeopardize the safety and operation of an important facility where the public often congregates in large numbers. The importance of ensuring adequate cathodic protection at such a facility increases the gravity of the violation, as does its duration. BPL has not presented any evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, 1 assess Respondent a civil penalty of $35,300 for violation of 49 C.F.R. § 195.571. Item 11: The Notice proposed a civil penalty of $29,000 for Respondent's violation of 49 C.F.R. $ 195.573(e), for failing to correct, within a reasonable time, identified deficiencies in corrosion control. Respondent's work orders showed that several locations having low cathodic protection readings along the pipeline had been scheduled for work between 2005 and 2007 but the work had not been completed by the time of the PHMSA inspections in 2008. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty. Inadequate cathodic protection can result in pipeline leaks and the release of hazardous liquid. Two of the identified deficiencies were located within an HCA, thus aggravating the gravity of the violation. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $29,000 for violation of 49 C.F.R. § 195.573(e). Item 13: The Notice proposed a civil penalty of $41,500 for Respondent's violation of 79 C.F.R. $ 195.402(a), for failing to follow its own manual of written procedures for conducting normal O&M activities and for handling abnormal operations and emergencies. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty. As noted above, I found that Respondent failed on two occasions to repair abnormal conditions, as required by its written procedures. These conditions potentially affected HCAs, meaning the safety of the public and the environment were at increased risk. Therefore, the gravity of the violation supports the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $41,500 for violation of 49 C.F.R. § 195.402(a). Item 14: The Notice proposed a civil penalty of $120,300 for Respondent's violation of 49 C.F.R. $ 195.452(j)(2), for failing to conduct periodic evaluations as frequently as needed to assure pipeline integrity. As discussed above, the allegation is withdrawn. Therefore, I also withdraw the proposed penalty for violation of 49 C.F.R. § 195.452(j)(2). Item 17: The Notice proposed a civil penalty of $200,300 for Respondent's violation of 49 C.F.R. $ 195.452(f)(6), for failing to include a process in its IMP for identifying P&M measures to protect HCAs. As noted above, I found that BPL failed to produce evidence of a P&M process that was in effect as of the date the PHMSA inspection began in May 2008. Early identification and implementation of P&M measures can help prevent some or all of the damage that can result from a pipeline failure. The unique features of each pipeline, the terrain#

120095002_Final Order _05302012.pdf, page 1514 and environment around the pipeline, and the particular features of the surrounding community mean that each operator must implement a process uniquely tailored to its own individual system. This process is a critical element of the IMP and helps to ensure its efficacy. Such a process was required to be in BPL's written IMP no later than March 2002, but there is no evidence that it was in place by the time of the inspection in May 2008. More than half of BPL's pipelines are either located within or could affect HCAs. The company is therefore required to implement and maintain a complete IMP to protect the public and the environment in HCAs from potentially dangerous pipeline failures. The failure to do so is a serious violation of the integrity management regulations, as a pipeline failure in or near an HCA could have catastrophic consequences for the public and the environment. Therefore the nature and gravity of the violation and BPL's culpability justify the proposed penalty. This violation continued for years, yet the amount of the proposed penalty is far below the limit of $100,000 per violation per day. BPL has not presented any other evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $200,300 for violation of 49 C.F.R. § 195.452(f)(6). Item 19: The Notice proposed a civil penalty of $120,300 for Respondent's violation of 49 C.F.R. § 195.452(i)(4), for failing to determine whether EFRDs were needed on its pipeline to protect against failures that could affect HCAs. Specifically, it alleged that BPL had failed to conduct annual EFRD analyses of pipeline segments scheduled for integrity re-assessments and to install EFRDs that the company had previously determined were needed. BPL's defense was that instead of installing the EFRDs, the company had allocated funds to other repairs with greater risk-mitigation benefits. In addition, Respondent noted that it had dramatically increased spending on pipeline maintenance between 2000 and 2008. EFRDs have been shown to be effective in mitigating the consequences of many hazardous liquid pipeline releases. If the need for EFRDs is not assessed and appropriate action taken, a pipeline failure can cause additional damage that could have been prevented, thereby putting the environment and public safety at unnecessary risk. Spending on other maintenance activities. while commendable, does not mitigate an operator's duty to conduct EFRD evaluations and install them as needed, as required under both § 195.452(i)(4) and the company's own procedures. That BPL did not complete the EFRD installations that were recommended in its own 2002 evaluation is particularly troubling because the company recognized a safety hazard but consciously decided to forego action that could mitigate the effects of a spill. Therefore, the nature and gravity of the violation and the culpability of the operator justify the proposed penalty amount. BPL has not presented any other evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $120,300 for violation of 49 C.F.R. § 195.452(i)(4).#

120095002_Final Order _05302012.pdf, page 1615 In summary, having reviewed the record and considered the assessment criteria for each of the Items cited above, I assess Respondent a total civil penalty of $524,900. Payment of the civil penalty must be made within 20 days of service. Federal regulations (49 C.F.R. § 89.21(b)(3)) require such payment to be made by wire transfer through the Federal Reserve Communications System (Fedwire), to the account of the U.S. Treasury. Detailed instructions are contained in the enclosure. Questions concerning wire transfers should be directed to: Financial Operations Division (AMZ-341), Federal Aviation Administration, Mike Monroney Aeronautical Center, P.O. Box 269039, Oklahoma City, Oklahoma 73125. The Financial Operations Division telephone number is (405) 954-8893. Failure to pay the $524,900 civil penalty will result in accrual of interest at the current annual rate in accordance with 31 U.S.C. § 3717, 31 C.F.R. § 901.9 and 49 C.F.R. § 89.23. Pursuant to those same authorities, a late penalty charge of six percent (6%) per annum will be charged if payment is not made within 110 days of service. Furthermore, failure to pay the civil penalty may result in referral of the matter to the Attorney General for appropriate action in a district court of the United States. COMPLIANCE ORDER The Notice proposed a compliance order with respect to Items 3, 9, 17, and 19 in the Notice for violations of 49 C.F.R. $$ 195.402(a), 195.571, 195.452(f)(6), and 195.452(i)(4), respectively. Under 49 U.S.C. § 60118(a), each person who engages in the transportation of hazardous liquids or who owns or operates a pipeline facility is required to comply with the applicable safety standards established under chapter 601. Pursuant to the authority of 49 U.S.C. § 60118(b) and 49 C.F.R. § 190.217, Respondent is ordered to take the following actions to ensure compliance with the pipeline safety regulations applicable to its operations: 1. With respect to the violation of § 195.402(a) (Item 3), Respondent must develop a plan to ensure that a root cause analysis is conducted and documented for all accidents, as required by BPL's O&M Manual, and that any corrective actions recommended by each analysis are implemented. 2. With respect to the violation of § 195.571 (Item 9), Respondent must establish and implement a plan to gain access to BPL facilities at the Philadelphia Airport in order to ensure its cathodic protection complies with paragraphs 6.2 and 6.3 of NACE Standard SP 0169. 3. With respect to the violation of § 195.452(f)(6) (Item 17), Respondent must establish and implement processes to evaluate its pipeline segments for additional P&M measures. Upon completion of the evaluation of pipeline segments, a schedule for implementing any needed P&M actions must be submitted. 4. With respect to the violation of § 195.452(i)(4) (Item 19), Respondent must establish an improved process to evaluate the need for additional EFRDs. Upon establishment of the improved process, Respondent must perform EFRD evaluations on its pipeline#

120095002_Final Order _05302012.pdf, page 1716 segments, develop a schedule for installing EFRDs where necessary, and document the reasoning for why EFRDs are not necessary for all locations Respondent considered. 5. Respondent must submit a plan and schedule for completing the Compliance Order items listed above to PHMSA for review and approval within 60 days after receipt of the Final Order. Upon receiving approval of the plan and schedule, Respondent must submit evidence of completion for the Compliance Order items listed above to PHMSA within 180 days after receipt of the Final Order. Submit all correspondence for review and approval to the Director, Eastern Region, Office of Pipeline Safety. PHMSA, 820 Bear Tavern Road, Suite 306, West Trenton, NJ 08628. 6. It is requested that Respondent maintain documentation of the safety improvement costs associated with fulfilling this Compliance Order and submit that total to the Director, Eastern Region, PHMSA. It is requested that costs be reported in two categories: (1) total cost associated with preparation and revision of plans, procedures, studies and analyses: and (2) total cost associated with replacements, additions and other changes to pipeline infrastructure. The Director may grant an extension of time to comply with any of the required items upon a written request timely submitted by the Respondent and demonstrating good cause for an extension. Failure to comply with this Order may result in the administrative assessment of civil penalties not to exceed $100,000 per violation for each day the violation continues or in referral to the Attorney General for appropriate relief in a district court of the United States. WARNING ITEMS With respect to Items 1, 2, 5, 6, 10, 12, 15, 16, 18, 20, 21, and 22, the Notice alleged probable violations of Part 195 but did not propose a civil penalty or compliance order for these items. Therefore, these are considered to be warning items. The warnings were for: 49 C.F.R. § 195.401(b) (Item 1) - Respondent's alleged failure to correct four conditions that could have adversely affected the safe operation of its pipeline within a reasonable time. 19 C.F.R. § 195.402(a) (Item 2) - Respondent's alleged failure to review and update its operations, maintenance, and emergency manuals at intervals not exceeding 15 months, but at least once each calendar year. Respondent claimed that its manual review process satisfied the requirements of $ 195.402(a) and that it had revised its procedures to include a documented annual review of its manuals.? However, Respondent did not provide any evidence that the reviews had been conducted at the required intervals. 18 Response at 2.#

120095002_Final Order _05302012.pdf, page 1817 49 C.F.R. § 195.412(a) (Item 5) - Respondent's alleged failure to inspect the surface conditions on or adjacent to each pipeline right-of-way at intervals not exceeding 3 weeks, but at least 26 times a year. 19 C.F.R. § 195.557 (Item 6) - Respondent's alleged failure to provide coating for external corrosion control as required for certain pipelines. 49 C.F.R. § 195.573(e) (Item 10) - Respondent's alleged failure to correct identified deficiencies in external corrosion control within a reasonable time period. Cathodic protection survey test results in 2006 and 2007 identified inadequate levels of cathodic protection, but this condition was not addressed until 2008. In its Response, BPL claimed these test results were not indicative of a deficiency in corrosion control, but were simply the result of defective test leads." Regardless of the cause of the test results, the condition needed to be corrected before the next annual test. 49 C.F.R. § 195.438 (Item 12) - Respondent's alleged failure to prohibit smoking and open flames at each pump station and breakout tank area where there was a possibility of leakage of a flammable hazardous liquid or the presence of flammable vapors. BPL had "No Smoking" signs at some, but not all, tank areas, and not at the entrance to tank dikes at the Booth Station, an inconsistency that could confuse workers and visitors regarding where it was safe to smoke within the facility. In its Response, BPL claimed that signs were not required at each tank dike since the company had signs on its perimeter fences and its written policy prohibited smoking inside the fenced areas.*° While it is necessary and appropriate for operators to have written policies prohibiting does not constitute compliance with the regulation.?" In addition, the presence of "No smoking and open flames in pump station areas, the existence of such procedures alone Smoking" signs at some, but not all, tank areas could lead to confusion and an ineffective implementation of the "no smoking" policy. 49 C.F.R. § 195.452(b)(2) (Items 15 and 16) - Respondent's alleged failure to identify all pipelines that could affect a HCA. 49 C.F.R. $ 195.452(i)(2) (Item 18) - Respondent's alleged failure to properly consider all relevant risk factors in its evaluation of what P&M measures were needed to protect HCAs in the event of a pipeline release. 49 C.F.R. § 195.452(f)(3) (Item 20) - Respondent's alleged failure to continually update its IMP to reflect relevant operating experience. " Response at 5. 30 Response at 6. 3 See In the Matter of Nustar Logistics. L.P.. F/K/A Valero Logistics Operations. L. P.., CPF No. 4-2005-5048 (March 11. 2009). Final orders are generally available on PHMSA website at http://primis.phmsa.dot.gov/comm/reports/enforce/Actions_opid_0.html?nocache=8998#_TP_|_tab_2.#

120095002_Final Order _05302012.pdf, page 1918 49 C.F.R. $ 195.561(b) (Item 21) - Respondent's alleged failure to properly repair any coating damage discovered during an inspection of external pipe. 49 C.F.R. $ 195.406(b) (Item 22) - Respondent's alleged failure to provide adequate controls and protective equipment to keep the surge pressure on the pipeline below 110% of the operating pressure limit established under § 195.406(a). The Notice listed three documented events where the surge pressure exceeded 110% of the MOP. In its Response, BPL stated that in two of these instances, the pressure did not actually exceed 110% of the MOP, and that the company's Abnormal Operating Event forms had mismarked the pressure due to an employee's miscalculation. However, BPL did not provide any evidence to substantiate this explanation. The third event was not disputed.2 BPL presented information in its Response showing that it had taken certain actions to address the cited items. Accordingly, having considered such information, I find. pursuant to 49 C.F.R. § 190.205, that probable violations of 49 C.F.R. § 195.401(b) (Item 1), § 195.402(a) (Item 2), $ 195.412(a) (Item 5), § 195.557 (Item 6), § 195.573(e) (Item 10), § 195.438 (Item 12), $ 195.452(b)(2) (Items 15 and 16), § 195.452(i)(2) (Item 18), § 195.452(f) (Item 20), $ 195.561(b) (Item 21), and § 195.406(b) (Item 22) have occurred and Respondent is hereby advised to correct such conditions. In the event that OPS finds a violation of any of these items in a subsequent inspection, Respondent may be subject to future enforcement action. Under 49 C.F.R. § 190.215, Respondent has a right to submit a Petition for Reconsideration of this Final Order. The petition must be sent to: Associate Administrator, Office of Pipeline Safety, PHMSA, 1200 New Jersey Avenue. SE, East Building, 2'd Floor, Washington, DC 20590, with a copy sent to the Office of Chief Counsel, PHSA, at the same address. PHMSA will accept petitions received no later than 20 days after receipt of service of this Final Order by the Respondent, provided they contain a brief statement of the issue(s) and meet all other requirements of 49 C.F.R. § 190.215. The filing of a petition automatically stays the payment of any civil penalty assessed. Unless the Associate Administrator, upon request, grants a stay, all other terms and conditions of this Final Order are effective upon service in accordance with 49 C.F.R. $ 190.5. Busese MAY 302012 Jeffrey D. Wiese Date Issued Associate Administrator for Pipeline Safety 32 Response at 10.#

120095002_Final_Order_05302012_text.pdf, page 1Official PDFMAY 30 2012 Mr. Clark Smith President and CEO Buckeye Partners, LP One Greenway Plaza, Suite 600 Houston, TX 77046 Re: CPF No. 1-2009-5002 Dear Mr. Smith: Enclosed please find the Final Order issued in the above-referenced case. It withdraws one of the allegations of violation, makes other findings of violation, assesses a civil penalty of $524,900, and specifies actions that need to be taken by Buckeye Partners, LP, to comply with the pipeline safety regulations. The penalty payment terms are set forth in the Final Order. When the civil penalty has been paid and the terms of the compliance order completed, as determined by the Director, Eastern Region, this enforcement action will be closed. Service of the Final Order by certified mail is deemed effective upon the date of mailing, or as otherwise provided under 49 C.F.R. § 190.5. Thank you for your cooperation in this matter. Sincerely, Jeffrey D. Wiese Associate Administrator for Pipeline Safety Enclosure cc: Mr. Byron Coy, PE, Director, Eastern Region, OPS Mr. Alan Mayberry, Deputy Associate Administrator for Field Operations, OPS Mr. Scott Collier, Vice President, Buckeye Partners, LP, 5 TEK Park, 9999 Hamilton Boulevard, Breinigsville, PA 18031 CERTIFIED MAIL – RETURN RECEIPT REQUESTED#

120095002_Final_Order_05302012_text.pdf, page 2U.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION OFFICE OF PIPELINE SAFETY WASHINGTON, D.C. 20590 ____________________________________ ) In the Matter of ) ) Buckeye Partners, LP, ) CPF No. 1-2009-5002 ) Respondent. ) ____________________________________) FINAL ORDER During the period from May to December, 2008, pursuant to 49 U.S.C. § 60117, representatives of the Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), and the New York Public Service Commission conducted on-site pipeline safety inspections of the facilities and records of Buckeye Partners, LP (BPL or Respondent), in several states, including Pennsylvania, Ohio and Michigan. BPL owns and operates approximately 6,000 miles of pipelines transporting refined petroleum products and highly volatile liquids, principally in the Northeastern and upper Midwestern states. 1 Approximately 3,558 of those pipeline miles are in or could affect High Consequence Areas (HCAs)2 and are covered by BPL’s integrity management program. 3 As a result of the inspection, the Director, Eastern Region, PHMSA (Director), issued to Respondent, by letter dated June 26, 2009, a Notice of Probable Violation, Proposed Civil Penalty, and Proposed Compliance Order (Notice). In accordance with 49 C.F.R. § 190.207, the Notice proposed finding that BPL had committed various violations of 49 C.F.R. Part 195, assessing a civil penalty of $645,200 for the alleged violations, and ordering Respondent to take certain measures to correct the alleged violations. The Notice also proposed finding that Respondent had committed other probable violations of 49 C.F.R. Part 195 and warning the company to take appropriate corrective action or be subject to future enforcement action. BPL responded to the Notice by letters dated September 25, 2009 (Response), and January 6, 2010 (Supplemental Response). The company contested some of the allegations of violation and requested reduction or elimination of the associated penalties. BPL did not contest other allegations and provided information concerning the corrective actions it had taken. Respondent did not request a hearing and therefore has waived its right to one. 1 http://www.buckeye.com/BusinessOperations/tabid/56/Default.aspx and http://www.buckeye.com/AboutUs/tabid/54/Default.aspx (last accessed on March 22, 2012). 2 49 C.F.R. § 195.450. 3 49 C.F.R. § 195.452.#

120095002_Final_Order_05302012_text.pdf, page 32 FINDINGS OF VIOLATION The Notice alleged that Respondent violated 49 C.F.R. Part 195, as follows: Operations and Maintenance Items: Item 3: The Notice alleged that Respondent violated 49 C.F.R. § 195.402(a), which states in relevant part: § 195.402 Procedural manual for operations, maintenance, and emergencies. (a) General. Each operator shall prepare and follow for each pipeline system a manual of written procedures for conducting normal operations and maintenance activities and handling abnormal operations and emergencies. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year, and appropriate changes made as necessary to insure that the manual is effective…. The Notice alleged that BPL violated 49 C.F.R. § 195.402(a) by failing to follow its manual of written procedures for conducting normal operations and maintenance (O&M) activities and handling abnormal operations and emergencies. Specifically, it alleged that BPL had failed to conduct root-cause analyses in 25 accident reports, as required by its own O&M procedures. The BPL Safety Manual, Section A-04, required that a root cause analysis be conducted for each product release that required regulatory reporting.4 In its Response, BPL did not contest the allegation of violation but contended that in August 2006, it had created six new positions within the company and that one of the duties of these new positions was to conduct root cause analyses for accidents.5 BPL also stated that the 25 accident reports which lacked a root cause analysis had all been performed before the creation of the new positions.6 BPL stated that it had “recognized that there was a need to ensure that root cause analyses were conducted… almost two years prior to the integrated inspection” and requested potential reduction in the amount of the penalty, it is discussed in the “Assessment of Penalty” that the penalty associated with this Item be “rescinded.”7 Since this argument relates to a section below. Accordingly, based upon a review of all of the evidence, I find that Respondent violated 49 C.F.R. § 195.402(a) by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Item 4: The Notice alleged that Respondent violated 49 C.F.R. § 195.403(b), which states: 4 Pipeline Safety Violation Report (Violation Report), Exhibit A (on file with PHMSA). 5 Response at 2. 6 Id. 7 Id.#

120095002_Final_Order_05302012_text.pdf, page 43 § 195.403 Emergency response training. (a) Each operator shall establish and conduct a continuing training program to instruct emergency response personnel… (b) At the intervals not exceeding 15 months, but at least once each calendar year, each operator shall: (1) Review with personnel their performance in meeting the objectives of the emergency response training program set forth in paragraph (a) of this section; and (2) Make appropriate changes to the emergency response training program as necessary to ensure that it is effective. The Notice alleged that BPL violated 49 C.F.R. § 195.403(b) by failing to review with company personnel their performance in meeting the objectives of the company’s emergency response training program, at intervals not exceeding 15 months but at least once each calendar year. In its Response, BPL did not explicitly contest the allegation but argued that it had reviewed the performance of its employees in responding to emergencies through the use of a form which had been “approved by the government” and which had documented personnel “responses and follow up actions to emergencies.”8 The company further explained that its Training Manual called for a critique of employee responses after all emergencies and response drills but acknowledged that it did not “specifically document the review of the performance of its employees on the form.” Notwithstanding these existing procedures, BPL indicated that it had revised the form to include a check box to document specifically that the performance of company personnel had been reviewed. The company provided OPS with a blank copy of the revised form.9 While BPL indicated that the form had been approved by the government, there is no indication that the form had ever been approved by PHMSA for purposes of satisfying this regulatory requirement. In addition, BPL did not provide any completed forms to demonstrate that the required reviews had actually been conducted. Therefore, it is impossible to tell whether the reviews were properly completed in a timely manner. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.403(b) by failing to review with company personnel, at the required intervals, their performance in meeting the objectives of BPL’s emergency response training program. Item 13: The Notice alleged that Respondent violated 49 C.F.R. § 195.402(a), as quoted above, by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Specifically, it alleged that BPL failed to follow its Maintenance Manual, Procedure E-08, Damaged or Defective Non-Leaking Pipe, on two occasions. On March 22, 2005, the company allegedly failed to repair a sharp dent at Sta. 913+96 on its 209 Line in Wayne, Michigan, using a sleeve required by its own written procedures. Similarly, the Notice alleged that on June 1, 2005, the company allegedly failed to repair a wrinkle bend in accordance with BPL’s own written procedures.10 8 Response at 3. 9 Id. 10 Violation Report, Exhibit B.#

120095002_Final_Order_05302012_text.pdf, page 54 According to the Notice, BPL’s procedures stated that at the pipeline’s listed Maximum Operating Pressure (MOP) of 1233 psig, the wrinkle bend had to be repaired in accordance with the company’s Procedure MA E-08, Exhibit 1. The company allegedly decided, however, that no repair was needed for the wrinkle bend because the line did not normally operate at over 900 psig. However, BPL did not subsequently lower the MOP on the line to 900 psig. BPL did not contest the alleged violations. The company acknowledged that in August 2009, it had excavated and re-evaluated the sharp dent in the 209 line and had installed a repair sleeve.11 As for the wrinkle bend, the company stated that it was in the process of conducting an engineering evaluation to determine the appropriate MOP for this line segment.12 Accordingly, based upon a review of all of the evidence, I find that Respondent violated 49 C.F.R. § 195.402(a) by failing to follow its manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. Corrosion Control Items Item 7: The Notice alleged that Respondent violated 49 C.F.R. § 195.583(a), which states: § 195.583 What must I do to monitor atmospheric corrosion control? (a) You must inspect each pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion, as follows: If the pipeline is located: Then the frequency of inspection is: Onshore..................... At least once every 3 calendar years, but with intervals not exceeding 39 months. Offshore……………. At least once each calendar year, but with intervals not exceeding 15 months. The Notice alleged that BPL violated 49 C.F.R. § 195.583(a) by failing to inspect the above- ground pipeline facilities at the company’s Mantua Station for atmospheric corrosion at least once every three calendar years, but at intervals not exceeding 39 months. Specifically, it alleged that BPL’s own records showed inspections had been conducted on May 4, 2004, and January 29, 2008, an interval that exceeded 39 months. BPL did not contest this allegation. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.583(a) by failing to inspect, at the required intervals, each pipeline exposed to the atmosphere for atmospheric corrosion. It is noted that BPL represents that it has improved its process for conducting such inspections. 11 Response at 6. 12 Id.#

120095002_Final_Order_05302012_text.pdf, page 65 Item 8: The Notice alleged that Respondent violated 49 C.F.R. § 195.573(c), which states: § 195.573 What must I do to monitor external corrosion control? (a) …. (c) Rectifiers and other devices. You must electrically check for proper performance each device in the first column at the frequency stated in the second column. Device Check frequency Rectifier……………………. Reverse current switch. Diode. Interference bond whose failure would jeopardize structural protection. At least six times each calendar year, but with intervals not exceeding 2½ months. Other interference bond……. At least once each calendar year, but with intervals not exceeding 15 months. The Notice alleged that BPL violated 49 C.F.R. § 195.573(c) by failing to electrically check several rectifiers for proper performance at the required frequency. Specifically, it alleged the following failures: 1. Three rectifiers in the Harristown Shell system were not inspected at the required intervals twice during 2006, each time exceeding the 2½-month maximum by 1½ months; 2. The rectifiers in the BPL Trans PA, Malvern Station Tank Farm, Paulsboro Deep Well, and Chester Park systems were not checked at least six times each year during 2006- 2007; 3. The Booth rectifier LP-07 for Tank #15 was not inspected between March 5, 2006, and May 26, 2006, an interval that exceeded 2½ months; and 4. The Booth rectifier LP-08 STA40009 BH724SK was not inspected between September 5, 2006, and January 12, 2007, an interval that exceeded 2½ months. In its Response, BPL only contested the portion of the allegation relating to the rectifiers on the Harristown Shell system. The company asserted that during the March and July inspections, the Harristown rectifiers were out of service due to tank projects and were noted as “locked#

120095002_Final_Order_05302012_text.pdf, page 76 out/tagged out” on the company’s inspection records. documents included comments for the Harristown rectifiers for the March and July inspections. In March, the rectifiers were noted as “Locked out – Due to cleaning tank” and in July they were listed as “Down – Due to construction.” Based on these records and BPL’s explanation for them, it is plausible that the rectifiers were out of service during these inspections. 13 BPL’s rectifier output-history To remain in compliance with the regulation, however, BPL was obliged to check the rectifiers before they were put back into service. The company failed to inspect them until the next scheduled inspection two months later, resulting in a four-month interval between inspections. BPL stated that it had subsequently revised its procedures to require that rectifiers be checked both prior to and after being locked out and that the company had added a field in its work order system to show when an inspection would be out of compliance with § 195.573(c).14 Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.573(c) by failing to check several rectifiers for proper performance within the required intervals. Item 9: The Notice alleged that Respondent violated 49 C.F.R. § 195.571, which states: § 195.571 What criteria must I use to determine the adequacy of cathodic protection? Cathodic protection required by [Subpart H] must comply with one or more of the applicable criteria and other considerations for cathodic protection contained in paragraphs 6.2 and 6.3 of NACE SP 0169 (incorporated by reference, see § 195.3). The Notice alleged that BPL violated 49 C.F.R. § 195.571 by failing to ensure that cathodic protection for the company’s facilities at the Philadelphia Airport (Airport) complied with one or more of the applicable criteria and other considerations for cathodic protection contained in paragraphs 6.2 and 6.3 of NACE Standard SP 0169 (NACE Standard). Specifically, it alleged that BPL had failed to take any pipe-to-soil readings at the Airport since October 2006 and that therefore the adequacy of cathodic protection at these locations was unknown. In its Response, BPL acknowledged that it did not take pipe-to-soil readings at the Airport test points, but contended that it had been unable to gain access to the Airport in 2007 and that the test points at the Airport represented only a small fraction of the points on its entire system. 15 BPL stated that all the other test points had been tested in 2007 and that the Airport points were accessed and tested in October 2008. The company also stated that it had now arranged a new method for arranging security escorts at the Airport and that it had made arrangements for the 2009 inspection within the required interval. 16 13 Response at 4. 14 Id. 15 Response at 4. 16 Response at 4-5.#

120095002_Final_Order_05302012_text.pdf, page 87 BPL is obligated to ensure that cathodic protection is adequate and complies with the NACE Standard at all times. BPL’s failure to gain access to the Airport does not serve to refute the allegation of violation. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.571 by failing to ensure that cathodic protection on its pipeline complied with the applicable criteria and other considerations for cathodic protection contained in the NACE Standard. Item 11: The Notice alleged that Respondent violated 49 C.F.R. § 195.573(e), which states: § 195.573 What must I do to monitor external corrosion control? (a) . . . (e) Corrective action. You must correct any identified deficiency in corrosion control as required by § 195.401(b). However, if the deficiency involves a pipeline in an integrity management program under § 195.452, you must correct the deficiency as required by § 195.452(h). The Notice alleged that BPL violated 49 C.F.R. § 195.573(e) by failing to correct identified deficiencies in corrosion control, as required by § 195.401(b), which states that an operator must correct, within a reasonable time, any deficiency that could adversely affect the safe operation of the pipeline. Specifically, the Notice alleged that the company’s own work orders showed that several locations along the pipeline with low cathodic protection readings had been scheduled for work between 2005 and 2007, but that the work had not been completed by the time of the PHMSA inspections in 2008. BPL did not contest this allegation and explained that it had improved its process for remediating low cathodic protection readings by adding a field in its work order system to show when of the evidence, I find that Respondent violated 49 C.F.R. § 195.573(e) by failing to correct proposed remediation efforts would fail to be in compliance.17 Accordingly, after considering all identified deficiencies in corrosion control within a reasonable time. Integrity Management Program (IMP) Items Item 14: The Notice alleged that Respondent violated 49 C.F.R. § 195.452(j)(2), which states: § 195.452 Pipeline integrity management in high consequence areas. (a) . . . (j) What is a continual process of evaluation and assessment to maintain a pipeline’s integrity?— (1) General. After completing the baseline integrity assessment, an operator must continue to assess the line pipe at specified intervals and periodically evaluate the integrity of each pipeline segment that could affect a high consequence area. (2) Evaluation. An operator must conduct a periodic evaluation as frequently as needed to assure pipeline integrity. An operator must base 17 Response at 5.#

120095002_Final_Order_05302012_text.pdf, page 98 the frequency of evaluation on risk factors specific to its pipeline, including the factors specified in paragraph (e) of this section. The evaluation must consider the results of the baseline and periodic integrity assessments, information analysis (paragraph (g) of this section), and decisions about remediation, and preventive and mitigative actions (paragraphs (h) and (i) of this section). The Notice alleged that BPL violated 49 C.F.R. § 195.452(j)(2) by failing to conduct periodic evaluations as frequently as needed to assure pipeline integrity. Specifically, the Notice alleged that “BPL could not demonstrate that periodic evaluations of the pipeline integrity program were performed as required by the integrity management regulations.”18 BPL contested the allegation, stating that the company’s “process for periodic evaluation of the integrity of BPL’s pipelines and compliance with integrity regulations involves its Risk Management Team.”19 The Response broadly described the responsibilities and activities of the team, including ensuring “[c]ompliance with all regulatory requirements regarding operational risk management” and a “[c]ontinuous improvement process for BPL’s integrity management program.”20 BPL also stated that minutes and “action items” from the team’s meetings documented the company’s periodic evaluation process. 21 BPL did not offer any documentation or evidence of any of its integrity program evaluations. The meeting minutes and actions items which BPL referenced in its Response were not provided, nor did BPL demonstrate that results of any evaluations were used to make decisions about remediation and preventive and mitigative (P&M) actions. BPL offered examples of “programs that were recommended through the periodic evaluations” but did not offer any documentation of the evaluations or the recommendations that they had claimed to have made.22 Neither party has presented sufficient proof to prove its position, but OPS bears the burden of proving that BPL has committed the violation. Section 195.452(j) requires continuous evaluation and assessment of an operator’s individual pipeline segments, not simply its overall IMP. The evidence presented by OPS in the Violation Report and Notice are insufficient to prove that Respondent’s IMP failed to include periodic pipe segment evaluations under § 195.452(j). The record contains no documents, procedures, interview notes or any other evidence to support the allegation that the company’s IMP was devoid of the sort of continuous evaluations required by the regulation. Accordingly, based upon the foregoing, I find that OPS has failed to meet its burden of proof and hereby order that Item 14 be withdrawn. Item 17: The Notice alleged that Respondent violated 49 C.F.R. § 195.452(f)(6), which states: 18 Notice at 7. 19 Response at 6. 20 Id. 21 Response at 7. 22 Id.#

120095002_Final_Order_05302012_text.pdf, page 109 § 195.452 Pipeline integrity management in high consequence areas. (a) . . . (f) What are the elements of an integrity management program? An integrity management program begins with the initial framework. An operator must continually change the program to reflect operating experience, conclusions drawn from results of the integrity assessments, and other maintenance and surveillance data, and evaluation of consequences of a failure on the high consequence area. An operator must include, at minimum, each of the following elements in its written integrity management program: (1) … (6) Identification of preventive and mitigative measures to protect the high consequence area (see paragraph (i) of this section). The Notice alleged that BPL violated 49 C.F.R. § 195.452(f)(6) by failing to include in its IMP a process for identifying (P&M) measures to protect HCAs. Under § 195.452(f), an operator’s IMP must contain eight separate elements, including a process for identifying HCAs, a baseline assessment plan, an information-integration analysis, criteria for taking remedial action, a continual process of periodic assessments of line pipe segments (see Item 14 above), the identification of P&M measures tailored to the operator’s unique system, and methods to measure the IMP’s overall effectiveness. The Violation Report stated that the OPS inspection team had found no indication that BPL had ever developed a process within its IMP for identifying P&M measures that would reduce the likelihood and consequences of pipeline releases, had ever identified specific P&M measures to protect HCAs, or had compiled any documentation to show such processes were in place. The Violation Report also noted that BPL’s integrity manager had stated that BPL would be developing such procedures in the future. In its Response, BPL contested the alleged violation, stating that its Integrity Management Manual (IMM) did indeed contain a process for identifying potential P&M measures and summarizing the process. It claimed that Section 6 of its IMM fully described the company’s process for identifying P&M measures, including the use of a Risk Model to identify high-risk areas, the use of subject matter expert teams to develop and test “various preventive and mitigative scenarios that potentially will provide positive impacts to reducing the identified risk,” the selection and evaluation of “physically feasible” measures, and the implementation of those measures having the greatest benefit in terms of risk reduction and financial feasibility. 23 In addition, the company contended that the “Exhibit A-01A flowchart in Buckeye’s IMM and referenced in Section 6 clearly shows that preventive and mitigative measures are an integral part procedures or any other documentation in either its Response or Supplemental Response. of the Continual Assessment Program.” 24 The company, however, did not submit any of these 23 Response at 8. 24 Response at 8.#

120095002_Final_Order_05302012_text.pdf, page 1110 Such general statements do not constitute credible evidence that BPL actually had a process for identifying P&M measures or that it had actually developed specific measures to reduce the likelihood or consequences of failures on HCAs. Not only did BPL fail to produce documentation of a P&M process that was in effect as of the date of the OPS inspection in May 2008, but it also failed to provide any evidence showing that any specific P&M measures had ever been actually identified, evaluated by its subject matter expert team, or implemented by the company. While BPL may indeed have had some general framework of a process for identifying P&M measures, the company failed to produce any evidence that it had implemented any such process or that it had met the requirements of the regulation. Accordingly, based upon a review of all of the evidence, I find that BPL violated 49 C.F.R. § 195.452(f)(6) by failing to include a process for identifying P&M measures to protect HCAs in its written IMP. Item 19: The Notice alleged that Respondent violated 49 C.F.R. § 195.452(i)(4), which states: § 195.452 Pipeline integrity management in high consequence areas. (a) . . . (i) What preventive and mitigative measures must an operator take to protect the high consequence area?- (1) …. (4) Emergency Flow Restricting Devices (EFRD). If an operator determines that an EFRD is needed on a pipeline segment to protect a high consequence area in the event of a hazardous liquid pipeline release, an operator must install the EFRD. In making this determination, an operator must, at least, consider the following factors—the swiftness of leak detection and pipeline shutdown capabilities, the type of commodity carried, the rate of potential leakage, the volume that can be released, topography or pipeline profile, the potential for ignition, proximity to power sources, location of nearest response personnel, specific terrain between the pipeline segment and the high consequence area, and benefits expected by reducing the spill size. The Notice alleged that BPL violated 49 C.F.R. § 195.452(i)(4) by failing to determine whether EFRDs were needed to protect against failures that could affect HCAs along its pipeline and, if so, to install them. Specifically, the Notice alleged that, since 2005, BPL had failed to conduct annual EFRD analyses of pipeline segments scheduled for integrity re-assessments, as required by § 195.452(i) and Section 15 of the company’s own IMM. The Notice also alleged that BPL had failed to install certain EFRDs that had been recommended as a result of a 2002 evaluation. In its Response, BPL noted that pipelines scheduled for integrity assessments between 2002 and 2005 had been analyzed for EFRDs and that the recommended devices had been included in BPL’s capital plan. The company claimed, however, that it had ultimately decided to allocate funds to other risk-management projects instead.25 BPL also noted that its spending on pipeline maintenance had drastically increased since 2000 and that EFRDs were “still being considered 25 Response at 8-9.#

120095002_Final_Order_05302012_text.pdf, page 1211 and installed when the benefits match the expenditure. ”26 For example, it cited the example of a block valve that had been installed as a “risk mitigation project,” which showed that BPL was the allegation. “not opposed to adding EFRDs.”27 The company, however, did not contest the facts set out in BPL’s spending on other maintenance projects does not lessen the potential consequences of the violation at hand, nor do budgetary considerations absolve BPL of its obligation to comply with the regulation and its own IMP. Accordingly, after considering all of the evidence, I find that Respondent violated 49 C.F.R. § 195.452(i)(4) by failing to determine whether EFRDs were needed on its pipeline to protect against failures, and, if so, to install them. These findings of violation will be considered prior offenses in any subsequent enforcement action taken against Respondent. ASSESSMENT OF PENALTY Under 49 U.S.C. § 60122, Respondent is subject to an administrative civil penalty not to exceed $100,000 per violation for each day of the violation, up to a maximum of $1,000,000 for any related series of violations. In determining the amount of a civil penalty under 49 U.S.C. § 60122 and 49 C.F.R. § 190.225, I must consider the following criteria: the nature, circumstances, and gravity of the violation, including adverse impact on the environment; the degree of Respondent’s culpability; the history of Respondent’s prior offenses; the Respondent’s ability to pay the penalty and any effect that the penalty may have on its ability to continue doing business; and the good faith of Respondent in attempting to comply with the pipeline safety regulations. In addition, I may consider the economic benefit gained from the violation without any reduction because of subsequent damages, and such other matters as justice may require. The Notice proposed a total civil penalty of $645,200 for the violations cited above. Item 3: The Notice proposed a civil penalty of $41,500 for Respondent’s violation of 49 C.F.R. § 195.402(a), for failing to follow its own manual of written procedures for conducting normal O&M activities and handling abnormal operations and emergencies. As noted above, I found that BPL failed to conduct root cause analyses in 25 accident reports, as required by its O&M procedures. Respondent argued, however, that the penalty should be “rescinded” because BPL had recognized the need to ensure root cause analyses were done, and had created a job position for this purpose two years before the OPS inspection. I fail to see any basis for rescission or reduction of the penalty. Recognizing a need to comply and actually complying are two different things. Respondent’s arguments do not mitigate the fact that BPL prepared 25 accident reports during 2002–2007 that did not include a root cause analysis, as required by its own procedures. A root cause analysis is an important tool for identifying safety problems before they cause accidents. Presumably, this is the very reason BPL included the requirement in its O&M manual. The gravity of the violation is not mitigated by the fact that BPL recognized the 26 Response at 9. 27 Id.#

120095002_Final_Order_05302012_text.pdf, page 1312 problem and made plans to correct it. On the contrary, it is troubling to see that the violation continued for years because the company apparently did not place a high enough priority on investigating the root causes of 25 separate accidents or complying with its own internal procedures. BPL has not presented any evidence or argument that would justify a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $41,500 for violation of 49 C.F.R. § 195.402(a). Item 4: The Notice proposed a civil penalty of $29,000 for Respondent’s violation of 49 C.F.R. § 195.403(b), for failing to review with company personnel their performance in meeting the objectives of BPL’s emergency response training program, at intervals not exceeding 15 months but at least once each calendar year. I found that, while Respondent used a form to document employee responses to emergencies, it did not document such reviews on the forms and did not provide PHMSA with copies of any completed forms to demonstrate that the required reviews had actually been conducted. Adequate emergency response training is essential to the safety of the public and protection of the environment in the event of emergencies. Respondent’s failure to review or document the performance of its personnel reduced the safety of its operations insofar as the company had no established method of regularly reviewing employee performance that was related specifically to emergency response. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $29,000 for violations of 49 C.F.R. § 195.403(b). Item 7: The Notice proposed a civil penalty of $14,000 for Respondent’s violation of 49 C.F.R. § 195.583(a), for failing to inspect the above-ground pipeline facilities at the Mantua Station for atmospheric corrosion at least once every three calendar years, but at intervals not exceeding 39 months. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty; therefore, I found that Respondent failed to inspect each pipeline exposed to the atmosphere for atmospheric corrosion at the required intervals. Atmospheric corrosion at the Mantua Station could result in a release of hazardous liquids, thus posing a risk to life, property and the environment. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $14,000 for violation of 49 C.F.R. § 195.583(a). Item 8: The Notice proposed a civil penalty of $14,000 for Respondent’s violation of 49 C.F.R. § 195.573(c), for failing to check several rectifiers for proper performance at the required frequency. Respondent contested the allegations relating to the Harristown Shell system but not the others. As discussed above, I found that Respondent was required to check the locked-out rectifiers before putting them back into service. The proposed penalty amount reflects the fact that neither pipeline integrity nor safe operations were seriously affected by the violations. Based upon the foregoing, I assess Respondent a civil penalty of $14,000 for violation of 49 C.F.R. § 195.573(c). Item 9: The Notice proposed a civil penalty of $35,300 for Respondent’s violation of 49 C.F.R. § 195.571, for failing to ensure that cathodic protection for the company’s pipeline facilities at the Airport complied with the NACE Standard. BPL failed to take any pipe-to-soil readings at the Airport from October 2006 until October 2008, and therefore the adequacy of the#

120095002_Final_Order_05302012_text.pdf, page 1413 cathodic protection at this location was unknown. As noted above, I found that BPL’s failure to gain access to the Airport did not serve to refute the allegation of violation. BPL has a responsibility to ensure that its facilities can be operated safely, which includes maintaining adequate cathodic protection. The potential failure of this pipeline in an HCA near the Airport could jeopardize the safety and operation of an important facility where the public often congregates in large numbers. The importance of ensuring adequate cathodic protection at such a facility increases the gravity of the violation, as does its duration. BPL has not presented any evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $35,300 for violation of 49 C.F.R. § 195.571. Item 11: The Notice proposed a civil penalty of $29,000 for Respondent’s violation of 49 C.F.R. § 195.573(e), for failing to correct, within a reasonable time, identified deficiencies in corrosion control. Respondent’s work orders showed that several locations having low cathodic protection readings along the pipeline had been scheduled for work between 2005 and 2007 but the work had not been completed by the time of the PHMSA inspections in 2008. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty. Inadequate cathodic protection can result in pipeline leaks and the release of hazardous liquid. Two of the identified deficiencies were located within an HCA, thus aggravating the gravity of the violation. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $29,000 for violation of 49 C.F.R. § 195.573(e). Item 13: The Notice proposed a civil penalty of $41,500 for Respondent’s violation of 49 C.F.R. § 195.402(a), for failing to follow its own manual of written procedures for conducting normal O&M activities and for handling abnormal operations and emergencies. BPL neither contested the allegation nor presented any evidence or argument justifying a reduction in the proposed penalty. As noted above, I found that Respondent failed on two occasions to repair abnormal conditions, as required by its written procedures. These conditions potentially affected HCAs, meaning the safety of the public and the environment were at increased risk. Therefore, the gravity of the violation supports the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $41,500 for violation of 49 C.F.R. § 195.402(a). Item 14: The Notice proposed a civil penalty of $120,300 for Respondent’s violation of 49 C.F.R. § 195.452(j)(2), for failing to conduct periodic evaluations as frequently as needed to assure pipeline integrity. As discussed above, the allegation is withdrawn. Therefore, I also withdraw the proposed penalty for violation of 49 C.F.R. § 195.452(j)(2). Item 17: The Notice proposed a civil penalty of $200,300 for Respondent’s violation of 49 C.F.R. § 195.452(f)(6), for failing to include a process in its IMP for identifying P&M measures to protect HCAs. As noted above, I found that BPL failed to produce evidence of a P&M process that was in effect as of the date the PHMSA inspection began in May 2008. Early identification and implementation of P&M measures can help prevent some or all of the damage that can result from a pipeline failure. The unique features of each pipeline, the terrain#

120095002_Final_Order_05302012_text.pdf, page 1514 and environment around the pipeline, and the particular features of the surrounding community mean that each operator must implement a process uniquely tailored to its own individual system. This process is a critical element of the IMP and helps to ensure its efficacy. Such a process was required to be in BPL’s written IMP no later than March 2002, but there is no evidence that it was in place by the time of the inspection in May 2008. More than half of BPL’s pipelines are either located within or could affect HCAs. The company is therefore required to implement and maintain a complete IMP to protect the public and the environment in HCAs from potentially dangerous pipeline failures. The failure to do so is a serious violation of the integrity management regulations, as a pipeline failure in or near an HCA could have catastrophic consequences for the public and the environment. Therefore the nature and gravity of the violation and BPL’s culpability justify the proposed penalty. This violation continued for years, yet the amount of the proposed penalty is far below the limit of $100,000 per violation per day. BPL has not presented any other evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $200,300 for violation of 49 C.F.R. § 195.452(f)(6). Item 19: The Notice proposed a civil penalty of $120,300 for Respondent’s violation of 49 C.F.R. § 195.452(i)(4), for failing to determine whether EFRDs were needed on its pipeline to protect against failures that could affect HCAs. Specifically, it alleged that BPL had failed to conduct annual EFRD analyses of pipeline segments scheduled for integrity re-assessments and to install EFRDs that the company had previously determined were needed. BPL’s defense was that instead of installing the EFRDs, the company had allocated funds to other repairs with greater risk-mitigation benefits. In addition, Respondent noted that it had dramatically increased spending on pipeline maintenance between 2000 and 2008. EFRDs have been shown to be effective in mitigating the consequences of many hazardous liquid pipeline releases. If the need for EFRDs is not assessed and appropriate action taken, a pipeline failure can cause additional damage that could have been prevented, thereby putting the environment and public safety at unnecessary risk. Spending on other maintenance activities, while commendable, does not mitigate an operator’s duty to conduct EFRD evaluations and install them as needed, as required under both § 195.452(i)(4) and the company’s own procedures. That BPL did not complete the EFRD installations that were recommended in its own 2002 evaluation is particularly troubling because the company recognized a safety hazard but consciously decided to forego action that could mitigate the effects of a spill. Therefore, the nature and gravity of the violation and the culpability of the operator justify the proposed penalty amount. BPL has not presented any other evidence or argument justifying a reduction or elimination of the proposed penalty. Accordingly, having reviewed the record and considered the assessment criteria, I assess Respondent a civil penalty of $120,300 for violation of 49 C.F.R. § 195.452(i)(4).#

120095002_Final_Order_05302012_text.pdf, page 1615 In summary, having reviewed the record and considered the assessment criteria for each of the Items cited above, I assess Respondent a total civil penalty of $524,900. Payment of the civil penalty must be made within 20 days of service. Federal regulations (49 C.F.R. § 89.21(b)(3)) require such payment to be made by wire transfer through the Federal Reserve Communications System (Fedwire), to the account of the U.S. Treasury. Detailed instructions are contained in the enclosure. Questions concerning wire transfers should be directed to: Financial Operations Division (AMZ-341), Federal Aviation Administration, Mike Monroney Aeronautical Center, P.O. Box 269039, Oklahoma City, Oklahoma 73125. The Financial Operations Division telephone number is (405) 954-8893. Failure to pay the $524,900 civil penalty will result in accrual of interest at the current annual rate in accordance with 31 U.S.C. § 3717, 31 C.F.R. § 901.9 and 49 C.F.R. § 89.23. Pursuant to those same authorities, a late penalty charge of six percent (6%) per annum will be charged if payment is not made within 110 days of service. Furthermore, failure to pay the civil penalty may result in referral of the matter to the Attorney General for appropriate action in a district court of the United States. COMPLIANCE ORDER The Notice proposed a compliance order with respect to Items 3, 9, 17, and 19 in the Notice for violations of 49 C.F.R. §§ 195.402(a), 195.571, 195.452(f)(6), and 195.452(i)(4), respectively. Under 49 U.S.C. § 60118(a), each person who engages in the transportation of hazardous liquids or who owns or operates a pipeline facility is required to comply with the applicable safety standards established under chapter 601. Pursuant to the authority of 49 U.S.C. § 60118(b) and 49 C.F.R. § 190.217, Respondent is ordered to take the following actions to ensure compliance with the pipeline safety regulations applicable to its operations: 1. With respect to the violation of § 195.402(a) (Item 3), Respondent must develop a plan to ensure that a root cause analysis is conducted and documented for all accidents, as required by BPL’s O&M Manual, and that any corrective actions recommended by each analysis are implemented. 2. With respect to the violation of § 195.571 (Item 9), Respondent must establish and implement a plan to gain access to BPL facilities at the Philadelphia Airport in order to ensure its cathodic protection complies with paragraphs 6.2 and 6.3 of NACE Standard SP 0169. 3. With respect to the violation of § 195.452(f)(6) (Item 17), Respondent must establish and implement processes to evaluate its pipeline segments for additional P&M measures. Upon completion of the evaluation of pipeline segments, a schedule for implementing any needed P&M actions must be submitted. 4. With respect to the violation of § 195.452(i)(4) (Item 19), Respondent must establish an improved process to evaluate the need for additional EFRDs. Upon establishment of the improved process, Respondent must perform EFRD evaluations on its pipeline#

120095002_Final_Order_05302012_text.pdf, page 1716 segments, develop a schedule for installing EFRDs where necessary, and document the reasoning for why EFRDs are not necessary for all locations Respondent considered. 5. Respondent must submit a plan and schedule for completing the Compliance Order items listed above to PHMSA for review and approval within 60 days after receipt of the Final Order. Upon receiving approval of the plan and schedule, Respondent must submit evidence of completion for the Compliance Order items listed above to PHMSA within 180 days after receipt of the Final Order. Submit all correspondence for review and approval to the Director, Eastern Region, Office of Pipeline Safety, PHMSA, 820 Bear Tavern Road, Suite 306, West Trenton, NJ 08628. 6. It is requested that Respondent maintain documentation of the safety improvement costs associated with fulfilling this Compliance Order and submit that total to the Director, Eastern Region, PHMSA. It is requested that costs be reported in two categories: (1) total cost associated with preparation and revision of plans, procedures, studies and analyses; and (2) total cost associated with replacements, additions and other changes to pipeline infrastructure. The Director may grant an extension of time to comply with any of the required items upon a written request timely submitted by the Respondent and demonstrating good cause for an extension. Failure to comply with this Order may result in the administrative assessment of civil penalties not to exceed $100,000 per violation for each day the violation continues or in referral to the Attorney General for appropriate relief in a district court of the United States. WARNING ITEMS With respect to Items 1, 2, 5, 6, 10, 12, 15, 16, 18, 20, 21, and 22, the Notice alleged probable violations of Part 195 but did not propose a civil penalty or compliance order for these items. Therefore, these are considered to be warning items. The warnings were for: 49 C.F.R. § 195.401(b) (Item 1) – Respondent’s alleged failure to correct four conditions that could have adversely affected the safe operation of its pipeline within a reasonable time. 49 C.F.R. § 195.402(a) (Item 2) – Respondent’s alleged failure to review and update its operations, maintenance, and emergency manuals at intervals not exceeding 15 months, but at least once each calendar year. Respondent claimed that its manual review process satisfied the requirements of § 195.402(a) and that it had revised its procedures to include a documented annual review of its manuals.28 However, Respondent did not provide any evidence that the reviews had been conducted at the required intervals. 28 Response at 2.#

120095002_Final_Order_05302012_text.pdf, page 1817 49 C.F.R. § 195.412(a) (Item 5) – Respondent’s alleged failure to inspect the surface conditions on or adjacent to each pipeline right-of-way at intervals not exceeding 3 weeks, but at least 26 times a year. 49 C.F.R. § 195.557 (Item 6) – Respondent’s alleged failure to provide coating for external corrosion control as required for certain pipelines. 49 C.F.R. § 195.573(e) (Item 10) – Respondent’s alleged failure to correct identified deficiencies in external corrosion control within a reasonable time period. Cathodic protection survey test results in 2006 and 2007 identified inadequate levels of cathodic protection, but this condition was not addressed until 2008. In its Response, BPL claimed these test results were not indicative of a deficiency in corrosion control, but were simply the result of defective test leads.29 Regardless of the cause of the test results, the condition needed to be corrected before the next annual test. 49 C.F.R. § 195.438 (Item 12) – Respondent’s alleged failure to prohibit smoking and open flames at each pump station and breakout tank area where there was a possibility of leakage of a flammable hazardous liquid or the presence of flammable vapors. BPL had “No Smoking” signs at some, but not all, tank areas, and not at the entrance to tank dikes at the Booth Station, an inconsistency that could confuse workers and visitors regarding where it was safe to smoke within the facility. In its Response, BPL claimed that signs were not required at each tank dike since the company had signs on its perimeter fences and its written policy prohibited smoking inside the fenced areas. 30 While it is necessary and appropriate for operators to have written policies prohibiting smoking and open flames in pump station areas, the existence of such procedures alone does not constitute compliance with the regulation.31 In addition, the presence of “No Smoking” signs at some, but not all, tank areas could lead to confusion and an ineffective implementation of the “no smoking” policy. 49 C.F.R. § 195.452(b)(2) (Items 15 and 16) – Respondent’s alleged failure to identify all pipelines that could affect a HCA. 49 C.F.R. § 195.452(i)(2) (Item 18) – Respondent’s alleged failure to properly consider all relevant risk factors in its evaluation of what P&M measures were needed to protect HCAs in the event of a pipeline release. 49 C.F.R. § 195.452(f)(3) (Item 20) – Respondent’s alleged failure to continually update its IMP to reflect relevant operating experience. 29 Response at 5. 30 Response at 6. 31 See In the Matter of Nustar Logistics, L.P., F/K/A Valero Logistics Operations, L.P., CPF No. 4-2005-5048 (March 11, 2009). Final orders are generally available on PHMSA website at http://primis.phmsa.dot.gov/comm/reports/enforce/Actions_opid_0.html?nocache=8998#_TP_1_tab_2.#

120095002_Final_Order_05302012_text.pdf, page 1918 49 C.F.R. § 195.561(b) (Item 21) – Respondent’s alleged failure to properly repair any coating damage discovered during an inspection of external pipe. 49 C.F.R. § 195.406(b) (Item 22) – Respondent’s alleged failure to provide adequate controls and protective equipment to keep the surge pressure on the pipeline below 110% of the operating pressure limit established under § 195.406(a). The Notice listed three documented events where the surge pressure exceeded 110% of the MOP. In its Response, BPL stated that in two of these instances, the pressure did not actually exceed 110% of the MOP, and that the company’s Abnormal Operating Event forms had mismarked the pressure due to an employee’s miscalculation. However, BPL did not provide any evidence to substantiate this explanation. The third event was not disputed.32 BPL presented information in its Response showing that it had taken certain actions to address the cited items. Accordingly, having considered such information, I find, pursuant to 49 C.F.R. § 190.205, that probable violations of 49 C.F.R. § 195.401(b) (Item 1), § 195.402(a) (Item 2), § 195.412(a) (Item 5), § 195.557 (Item 6), § 195.573(e) (Item 10), § 195.438 (Item 12), § 195.452(b)(2) (Items 15 and 16), § 195.452(i)(2) (Item 18), § 195.452(f) (Item 20), § 195.561(b) (Item 21), and § 195.406(b) (Item 22) have occurred and Respondent is hereby advised to correct such conditions. In the event that OPS finds a violation of any of these items in a subsequent inspection, Respondent may be subject to future enforcement action. Under 49 C.F.R. § 190.215, Respondent has a right to submit a Petition for Reconsideration of this Final Order. The petition must be sent to: Associate Administrator, Office of Pipeline Safety, PHMSA, 1200 New Jersey Avenue, SE, East Building, 2nd Floor, Washington, DC 20590, with a copy sent to the Office of Chief Counsel, PHMSA, at the same address. PHMSA will accept petitions received no later than 20 days after receipt of service of this Final Order by the Respondent, provided they contain a brief statement of the issue(s) and meet all other requirements of 49 C.F.R. § 190.215. The filing of a petition automatically stays the payment of any civil penalty assessed. Unless the Associate Administrator, upon request, grants a stay, all other terms and conditions of this Final Order are effective upon service in accordance with 49 C.F.R. § 190.5. ___________________________________ __________________________ Jeffrey D. Wiese Date Issued Associate Administrator for Pipeline Safety 32 Response at 10.#