Tennessee Gas Pipeline Company, L.L.C. — Pipeline Special Permit

Tennessee Gas KM - Special Permit - LOD Grant, page 1Official PDFU.S. Department of Transportat"1on Pipeline and Hazardous Materials Safety Administration 1200 New Jersey Avenue, SE Washington, D.C. 20590 September I , 20 16 Mr. Gary Buchler Chief Operating Officer Tennessee Gas Pipeline Company, L.L.C. Kinder Morgan Natural Gas Division 100 I Louisiana Street, Suite I 000 Houston. Texas 77002 Docket No. PHMSA-2016-0004 Dear Mr. Buchler: On January 11 , 20 16. T ennessee Gas Pipeline Company, L.L.C. (TGP) wrote to the Pipeline and Hazardous Materials Safety Administration (PHMSA) requesting a special permit to waive compliance from PHMSA ·s pipeline safety regulation in 49 CFR ** 192.6 11 (a) and (d). 192.619(a), and 192.5 for pipeline segments where the class location of the segment had been changed in accordance with* 192.5(c), cluster rule. The regulation requires confirmation or revision of the maximum allowable operating pressure (MAOP) of a pipeline segment where the class location has changed. T he special permit request is for 192 segments and 49.00 miles of the TGP natural gas transmission pipeline system located in the states of Kentucky. Louisiana. Mississippi. New Jersey. New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia. The pipeline segments are generally short in length, not continuous . and are located in multiple states and counties/parishes within those states. T he regulatory relie f from 49 CFR ** 192.611. 192.6 19 and 192.5 through a special permit would include additional time (5-years) to either replace or pressure test the pipeline segments in the class location sliding mile and outside the cluster area. where there arc over I 0 dwellings for human occupancy. Pipeline segments w ith I 0 or fewer dwellings for human occupancy outside the cluster area. but w ithin the sliding mile. would not be replaced and TGP would be required by the special permit conditions to implement procedures to maintain pipeline safety by identifying, assessing, and rcmediating integrit y threats to the pipeline segments. PHMSA is granting this special permit (enclosed). which will allow TGP to continue to operate segments of the TGP pipeline at the ir current MAOPs by implementing integrity management practices as defined in the special permit conditions until the pipe is replaced. pressure tested. or remecliatecl. This special permit provides re lief from the Federal pipe line safety regulations for#

Tennessee Gas KM - Special Permit - LOD Grant, page 2the TGP special permit segments and requires TGP to compl y w ith certain conditions and limitations designed to maintain pipeline safety. PHMSA grants this special permit based on the findings set forth in the "Special Permit Analysis and Findings" document, which can be read in its entirety in Docket No. PHMSA-2016-0004 in the Federal Docket Management System (FDMS) located on the internet at www.Regulations.gov. My staff would be pleased to discuss this matter or any other regulatory matter with you. Mr. John Gale, Director of Standards and Rulemaking Division may be contacted at 202-366-0434, on regulatory matters and Mr. Kenneth Lee. Director of Engineering and Research Division, may be contacted at 202-366-2694. on technical matters specific to this special permit application Sincerely. A~!4/0 Acting Associate Administrator for Pipeline Safety Enclosure : Special Permit - PHMSA-20 16-0004 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C Letter of Decision Page 2 of2#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 1Official PDFU.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION Special Permit Analysis and Findings Special Permit Information: Docket Number: Requested By: Operator ID#: Date Requested: Code Section(s): PHMSA-20I 6-0004 Tennessee Gas Pipeline Company, L.L.C. 19160 January II , 20 I6 49 CFR §§ I92.6 1I (a) and (d), I92.6 I9(a), and I92.5 Purpose: The Pipeline and Hazardous Materials Safety Administration (PHMSA) provides this information to describe the facts of the subject special permit application submitted by Tennessee Gas Pipeline Company L.L.C. 1 (TOP), to discuss any relevant public comments received with respect to the application, to present the engineering/safety analysis of the special permit application, and to make findings regarding whether the requested special permit should be granted and if so under what conditions. TGP requests that PHMSA waive compliance from 49 Code of Federal Regulations (CFR) §§ I92.6 Il (a) and (d), 192.6 19(a), and 192.5 for 192 segments and 49.00 miles of natural gas transmission pipeline as described in Appendix A? Pipeline System Affected: This special permit request applies to 192 pipeline segments and 49.00 miles of natural gas transmission pipeline operated by TOP and located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia where a change has occurred from an original Class 1 location to a Class 3 location. This special 1 Tennessee Gas Pipeline Company L.L.C. is owned by Kinder Morgan, Inc. 2 Appendix A of this special permit lists the pipeline special permit segment location (County and State), MAOP, class location, diameter, wall thickness, grade, seam type, boundaries, and other attributes. Appendix A can be reviewed in Docket PHMSA-20 16-0004 at www.regulations.gov. Page 1 of 10 PHMSA-2016-0004 - Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 2permit allows TGP to continue to operate the 192 pipeline segments and 49.00 mites at their cunent maximum allowable operating pressure (MAOP). Special Permit Request: TGP submitted an application to PHMSA on January II , 20 I6, for a special permit seeking relief from the Federal pipeline safety regulations in §§ 192.6II(a) and (d), I92.6I9(a), and I92.5 for 192 segments and 49.00 miles of natural gas transmission pipeline as described in Appendix A of the Special Permit Conditions. The special permit segments are located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia. This special permit applies to the special permit segments listed in Appendix A. Special permit segments shall be divided into two (2) categories: Type A special permit segments and T ype B special permit segments. • Type A special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § I92.5(c), of more than 10 buildings intended for human occupancy in a "class location unit" and for which the MAOP has.not been confirmed in accordance with 49 CFR § 192.6 11 (a). Type A special permit segments must be replaced or pressure tested so that the MAOP is commensurate with the present class location within five (5) years of issuance of this special permit. There are 11 .22 miles of Type A special permit segments and of this total I 0.59 miles must be replaced and 0.63 miles must be pressure tested as listed on Attachment A. • Type A special permit segments with pipe with integrity issues as determined by Conditions 6(c) and 14 or that have not been pressure tested in accordance with 49 CFR Part 192, Subpart J to 1.25 times MAOP of this special permit must be replaced within two and one-half(2 Y2) years of the grant ofthis special permit or within two (2) years of assessment find ing. • Type B special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § I92.5(c), of 10 or fewer buildings intended for human occupancy in a "class location unit" and for which the MAOP has not been confirmed in accordance with 49 CFR § I92.6 II . There are 3 7. 78 miles of Type B special permit segments and 3.84 miles of this total must be pressure tested as listed on Attachment A. Page 2 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 3• Special permit inspection area3 - is defined as a one ( 1) mile continuous segment on both sides of the special permit segment (Type A and Type B) plus the footage in the special permit segment. Appendix A lists the boundaries for the special permit inspection area associated with each special permit segment. The special permit inspection areas total 433.71 miles of pipe as detailed in Attachment A. Subsequent to the issuance of this special permit, those special permit segments that have been pressure tested or replaced such that the MAOP has been made commensurate with the present class location as defined in 49 CFR § 192.611 would no longer be included in this special permit. This special permit allows TOP to continue to operate the pipeline segments at their current maximum allowable operating pressure (MAOP) until either replaced, hydrostatically tested, or operated in accordance with the special permit conditions. The Federal pipeline safety regulations in 49 CFR § 192.611 (a) require natural gas pipeline operators to confirm or revise the MAOP of a pipeline segment after a change in class location. A special permit would allow TOP to continue to operate each of the 192 special permit segments at their existing MAOP's despite a change in class location for the special permit specified time interval. Public Notice: On February 23, 2016, PHMSA posted a notice of this special permit request in the Federal Register (81 FR 9075). PHMSA received one ( I) public comment letter in response to the draft EA from the '·Pipeline Safety Trust" dated March 24, 2016, concerning this proposed special permit. The public comments are summarized as noted below and the referenced Findings of No Significant Impact (FONSI) can be reviewed on the docket (PHMSA-2016-0004) at www.regulations.Q.ov. • A summary of the questions asked by Pipeline Safety Trust are below: • Only PHMSA announcement of the permit noted the fact that the operator' s previous class locations had been in error. (FONSI Review: Section II) 3 Special permit inspection areas throughout these conditions include special permit segments unless specifically defined as not applicable or if the special permit segment has more stringent conditions. Page 3 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 4• The 5-year waiver to accomplish this seems unreasonably long. (FONSI Review: Section II, Footnote 2) • The Pipeline Safety Trust had several concerns with the information presented in the application and the environmental assessment. • Claimed environmental and safety benefit of the permit would occur from the elimination of the methane emissions from pipeline blowdowns; (FONSI Review: Section Vlll) • Application fails in a couple of cases to provide a complete comparison of the effects of granting or denying the permit including the impact on adjacent right-of-way owners by allowing the existing pipe to remain in- service; (FONSI Review: Section V) • In the section of Safety Risks the operator indicates that the consequence of a failure would be no different if the permit is granted or is denied, without an indication of whether denying the permit would result in a reduction of pressure or pipe replacement; ( FONSI Review: Section V) • There appears to be many segments included in the application which have never been tested in that their MAOP was determined by the Grandfather Clause (§ 192.61 9(c)). (FONSI Review: The special permit conditions would require as a minimum pressure tests for any segments that had not been pressure tested.) • The application fails to give a complete useful response to § 190.341 (c)( 4). (FONSI Review: Section II) • Rather than use the special permit process in a situation like this, PHMSA should consider entering a consent agreement with the operator with both acknowledging the operator is out of compliance. PHMSA risks regulating many individual operators by special permit, without any justification for why the regulations should not be met, in effect negating the safety factors in place under § 192.6 11 or other regulations. (FONSI Review: Section II on pages 3 and 4 of 3 1 of the FONSI notes as follows: "PHMSA considered both a Consent Agreement and Safety Order in reviewing the issues of the TGP request. Since the operator notified PHMSA of the violation, PHMSA considered a special permit with integrity management concepts in a special permit with conditions an appropriate Page 4 of 10 PHMSA-2016-0004 - Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 5mechanism for this situation to maintain safety. Also, the special permit conditions would ensure the special permit segments were maintained while the segments could be upgraded with pipe replacements or pressure tests. With integrity management procedures being effective in other safety situations, PHMSA considers this to be an effective approach for the sliding mile areas with I 0 or fewer dwellings or structures for human occupancy, which is the case for over 89 percent (171 of 192 segments) of the TOP 192 special permit segments." The special permit requires replacement or pressure testing of segments with over 10 dwelling. The special permit has conditions and integrity management procedures for the special permit inspection area, 433.71 miles of pipeline.) The request letter, Federal Register notice, public comments, FONSI, and all other pertinent documents are available for review in Docket No. PHMSA-20 16-0004 in the Federal Docket Management System (FDMS) located on the internet at www.Regulations.gov. Analysis: Background: On June 29, 2004, PHMSA published in the Federal Register (69 FR 38948) the criteria it uses for the consideration of class location change waivers, now being granted through special permits. First, certain threshold requirements must be met for a pipeline section to be further evaluated for a class location change special permit. Second, the age and manufacturing process of the pipe; system design and construction; environmental, operating and maintenance histories; and integrity management program elements are evaluated as significant criteria. These significant criteria are presented in matrix form and can be reviewed in the FDMS, Docket Number PHMSA- RSPA-2004-1740 l. Third, such special permits will only then be granted when pipe conditions and the operator's integrity management program provides a level of safety equal to a pipe replacement or pressure reduction. Threshold Requirements: Each of the threshold requirements published by PHMSA in the June 29, 2004, Federal Register notice is discussed below in regards to the TGP special permit petition. Page 5 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 61) No pipeline segments in a class location changing to Class 4 location will be considered. This special permit request is for 192 segments on the TOP pipeline system where a class location change has occurred from Class 1 to Class 3 locations as defined in § 192.5(c) for cluster locations and segments outside the cluster (and inside the sliding mile for the class location) where an additional dwelling(s) have been identified. TOP has met this requirement. 2) No bare pipe will be considered. These TOP special permit segments are coated with an external protective coating. TOP has met this requirement. 3) No pipe containing wrinkle bends will be considered. There are no wrinkle bends in the special permit segments. TOP has met this requirement. 4) No pipe segments operating above 72% of the specified minimum yield strength (SMYS) will be considered for a Class 3 special permit. The .special permil segments operate at or below 72% SMYS. TOP has met this requirement. 5) Records must be produced that show a hydrostatic test to at least 1.25 x maximum allowable operating pressure (MAOP). TOP will pressure test any segments that do not meet this requirement through the special permit conditions. 6) In~lin inspection (ILl) must have been performed with no significant anomalies identified that indicate systemic problems. TOP will meet this requirement through the special permit conditions. 7) Criteria for consideration of class location change waiver, now being granted through special permits, published by PHMSA in the Federal Register (69 FR 38948), define a waiver inspection area (.special permit inspection area) as up to 25 miles of pipe either side of the waiver segment (special permit segment). The special permit inspection area must be inspected according to TOP's integrity management program and periodically inspected with an in~line inspection technique. The special permit inspection area extends one~mile out from either side of the special permit segments long. This additional length was used since the Type B areas that are not being replaced are locations with 10 or fewer buildings intended for human occupancy in a "class location unit" and are outside the original "cluster area'·. This special permit is contingent upon TOP's incorporation of each of the special permit segments in its written integrity management program as a ··covered segment " in a "high consequence area " (HCA) per 49 CFR § 192.903. e Page 6 of 10 PHMSA-2016-0004 - Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 7Criteria Matrix: The original and supplemental data submitted by TGP for the special permit segment have been compared to the class location change special permit criteria matrix. The special permit segments fall in the probable acceptance column of the criteria matrix for all criteria except for: • Possible acceptance - pipe manufacture and pipe material • Requires substantial justification - pipe coating, Stress Corrosion Cracking Direct Assessment (SCCDA), and several leaks within 20-miles of the special permit segment. The data findings below fall within the "probable acceptance" or the "requires substantial justification" columns of the criteria matrix: 1) Pipe design and construction, including pipe manufacture, material and design stress: • TGP pipeline special permit segments have: o Pipe manufactured with the following pipe seams: low-frequency electric resistance welded, flash welded, double submerged arc welded, seamless, and electric welded pipe seams. o Pipe coatings included: coal tar enamel, hot applied wax, fusion bonded epoxy, and tape. o Pipe design stress was 72% specified minimum yield strength or lower. 2) Pipe coating, SCCDA, and several leaks: TGP will be required to conduct a stress corrosion cracking assessment (SCCDA) of the special permit segments to evaluate where the risk of stress corrosion cracking (SCC) is present. TOP will be required to implement a plan to improve cathodic protection reliability and perform inspections for sec during excavations. • To further address pipe manufacturing, material, construction, pipe coating, SCCDA, and possible pipe leak issues, this special permit will include conditions requiring TOP to treat all special permit segments as "covered segments" in an HCA per 49 CFR § 192.903. • TOP will also be required to perform ILl assessments, anomaly repairs, close interval surveys, identify any pipeline segment that may be susceptible to pipe seam issues because of the vintage of the pipe, the manufacturing process of the pipe, or other issues Page 7 of 10 PHMSA-2016-0004 - Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 8and stress corrosion cracking direct assessment (SCCDA) along the entire length of the special permit inspection areas and special permit segments according to the requirements of 49 CFR § 192.929 after the grant of this special permit. • This special permit will include a condition that TGP must continue to operate each 5pecial permit segment at or below its existing MAOP. PHMSA has determined that imposing the special permit conditions will address these concerns and provide equivalent safety for these areas. Operational Integrity Compliance: PHMSA has reviewed this special permit request to ensure that integrity threats to the pipeline in the special permit segments and special permit inspection areas are addressed in the operator' s operations and management plan (O&M Plan). TGP must have a systematic program to review and remediate pipeline safety concerns. Additional operational integrity review and remediation requirements will be required by this special permit for this special permit segment class location change. The pipeline operational integrity requirements are to ensure that the operator has an ongoing program to locate and remediate safety threats. Some of these threats to integrity and safety are the pipe coating quality, cathodic protection effectiveness, anomalies in the pipe steel, and material and structures either along or near the pipeline that could cause the cathodic protection system to be ineffective. PHMSA carefully designed a comprehensive set of conditions that TGP would be required to meet in order for the special permit to be granted. Among other things, the conditions include: 1) Special permit inspection areas must be incorporated into its TOP's written integrity management program (IMP) as a "covered segment " in a "high consequence area (HCA) " in accordance with 49 CFR § 192.903. 2) A close interval survey to determine the effectiveness of the cathodic protection system must be performed within the 5pecial permit segments and special permit inspection area and all areas with inadequate cathodic protection must be remediated. Close interval surveys must be performed on a seven (7) year reassessment interval. 3) Cathodic protection reliability and inspections for stress corrosion cracking (SCC) must be performed. Page 8 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 94) Stress corrosion cracking surveys on the pipeline will be required to ensure that the pipe steel is not cracking due to the effects of high and near neutral pH SCC within the special permit segments and special permit inspection area. 5) Operations and maintenance (O&M) manual(s) must include the conditions of the special permit including in-line inspection (ILl), close interval inspections (CIS), remediation, and reassessment intervals. 6) Annual reports must be sent by TGP to PHMSA updating compliance. 7) Interference currents from electric transmission lines and other interfering structures in the special permit segments and special permit inspection area must be identified, controlled and mitigated by conducting surveys and installing remediation measures where required. 8) Anomalies and dents on the pipeline must be repaired based upon the special permit repair criteria for the special permit segments and special permit inspection areas. 9) Pipeline longitudinal seams within the special permit segments and special permit inspection areas must have an engineering analysis to determine if there are any threats and remediated if integrity threats are determined. l 0) Data integration of special permit condition findings and remediation must be maintained for the special permit segments and special permit inspection areas. 11 ) Long term pipeline system flow reversals that include a special permit segment must have a written plan that corresponds to those applicable criteria identified in PHMSA Advisory Bulletin (ADB-2014-04), "Guidance for Pipeline Flow Reversals, Product Changes and Conversion of Service" issued on September 18, 20 14 (79 FR 56121, Docket PHMSA-20 14-0400). 12) A senior executive officer, vice president or higher must certify in writing that TGP is complying with the special permit conditions. The special permit will contain numerous conditions to ensure TGP meets or exceeds the threshold requirements with equivalent safety and to ensure that granting the special permit will not be inconsistent with safety. Page 9 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

Tennessee Gas Pipeline, LLC - Special Permit Analysis and Findings, page 10Past Enforcement History - 2005 through Mach 28. 2016 The enforcement history is an important reflection of how TGP has been observed to follow pipeline safety regulations and is a major area of focus for the review of this application. Below is a listing of PHMSA closed enforcement matters of all types in all PHMSA Regions for TGP (OPID # 19160) from 2005 through March 28, 20 16: • Letters - of Concern or Warning - 7 matters • Notices - of Amendment or of Probable Violation - 11 matters • Orders - Corrective Action - 5 matters • Orders - Safety - 1 matter • Fines - $227,500- 100% collected • TGP had no repeat offences during this period. PHMSA has determined that imposing the special permit conditions summarized in this document will ensure that granting the special permit will not be inconsistent with safety. Findings: Based on the information submitted by TGP and PHMSA' s analysis of technical, operational and safety issues, and given the conditions that will be imposed in the special permit, PHMSA finds that granting this special permit to TGP to operate special permit segments at the current MAOP, where a change in class location has occurred from an original Class I locati on to a Class 3 location, would not be inconsistent with pipeline safety. Completed in Washington DC on: September 1, 2016 Prepared By: PHMSA - Engineering and Research Division Page 10 of 10 PHMSA-2016-0004- Tennessee Gas Pipeline, L.L.C. Special Permit Analysis and Findings#

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 1Official PDFPIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION SPECIAL PERMIT FINAL ENVIRONMENTAL ASSESSMENT and FINDING OF NO SIGNIFICANT IMPACT (FONSI) Docket Number: #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 2Pursuant to 49 CFR §190.341, Tennessee Gas Pipeline Company, L.L.C. (TGP)1 requests a special permit seeking relief from 49 CFR §§ 192.611(a) and (d), 192.619(a), and 192.5 for pipeline segments where the class location of the segment had been changed in accordance with 192.5(c), cluster rule, and where additional dwellings for human occupancy have been built within the sliding mile for class location changes outside of the cluster area. TGP found a regulatory compliance issue with past TGP procedure methodology for the determination of class location boundaries using the clustering and sliding mile criteria in 49 CFR § 192.5(c) and has updated operating procedures for usage of 49 CFR § 192.5(c), cluster rule, and the sliding mile for confirmation of maximum allowable operating pressure (MAOP). Following the purchase of TGP, Kinder Morgan, notified PHMSA of code violation issues it discovered in the TGP procedures for evaluating class locations, where pipe had been previously updated to meet class location changes from Class 1 to 3 locations in accordance with § 192.5. TGP had rnisapplied the usage of the sliding mile and cluster rule portions of § 192.5. TGP had properly conducted pipe upgrades to meet the cluster provisions in § 192.5, but had not later upgraded the pipe when a single or more dwelling were added in the sliding mile area outside the cluster area. This special permit is requested by TGP in order to postpone in some cases and waive in others cases compliance with certain regulations for the determination of class location boundaries using the clustering criteria in 49 CFR § 192.5(c). This change in clustering methodology due to misapplication of 49 CFR § 192.5(c) in TGP procedures resulted in a number of new class location units, and more specifically class 3 locations, for which pressure testing or pipe replacements are now required. This misapplication impacted 192 special permit segments2 and 49.00 miles of TGP mainline piping located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia as detailed in Attachment A for Type A and B special permit segments. These clustered class location units are identified as "Special Perrnit Segments." The proposed special permit would: 1) require the replacement or pressure testing of approximately 11.22 miles of natural gas transmission pipe (Type A3) and provides a schedule for this replacement or pressure testing work Tennessee Gas Pipeline Company, L.L.C. is owned by Kinder Morgan, Inc. 2 In the 192 segments TGP has 11.22 miles of pipe to replace or pressure test (Type A special permit segments) and other special permit segments including special permit inspection areas will implement integrity management procedures and the special permit conditions during the entire 5-year period. 3 Type A special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § 192.5(c), of more than 10 buildings intended for human occupancy in a "class location unit" and for which the maximum allowable operating pressure (MAOP) has not been confirmed in accordance with 49 CFR § 192.611(a). Type A special permit segments must be replaced so that the MAOP is commensurate with the present class location within five (5) years of issuance of this special permit. There are 21 segments and 11.22 miles of Type A special permit segments and of this total 10.59 miles must be replaced and 0.63 miles must be pressure tested as listed on Attachment A. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 3and 2) establish enhanced integrity management procedures to maintain pipe integrity and protect both the public and the environment for the class location units in which the Special Permit Segments are located for the other 37.78 miles of pipe that are not replaced (Type B4). All of the proposed Special Permit Segments, even those not replaced or pressure tested would be treated as high consequence areas (HCAs) with the implementation of integrity management (1M) practices. In addition, TGP would comply with Conditions as provided in the terms of the special permit for all the impacted Special Permit Segments and the designated "Special Permit Inspection Aree in the proposed special permit. The Special Permit Inspection Area is defined as a one (1) mile continuous segment on both sides of the Special Permit Segment (Type A and Type B) plus the footage in the Special Permit Segment and extending 220 yards on each side of the centerline. In the instance that the pipeline does not extend a full mile either upstream from the beginning of the Special Permit Segment or downstream from the end of the Special Permit Segment, the Special Permit Inspection Area will not extend beyond the pipeline initiation or termination points. The Special Permit Inspection area will total 433.71 miles of pipe as detailed in Attachment A. In those cases where the proposed special permit would allow for the current pipeline segments to remain in place, the Conditions as prescribed in the proposed special permit would provide an additional level of safety without the impacts of excavation to remove existing pipe and install the replacement pipe. Due to the significant number of new class location segments that will require replacement or pressure testing, a special permit with IM based conditions would allow TGP a more reasonable time interval to schedule the required pipeline outages. The replacement and pressure testing of the 11.22 miles of pipe will be in accordance with the applicable sections of 49 CFR §§ 192.105, 192.611, 192.619, and Subpart J for the current class location. PHMSA found in reviewing TGP's response that a misapplication of § 192.5 had been used (under procedures in use before the Kinder Morgan acquisition) after installing upgraded pipe in a cluster area. Attachment A shows the segment locations with the number of dwellings outside of the cluster area but inside the sliding mile area. PHMSA considered both a Consent Agreement and Safety Order in reviewing the issues of the TGP request. Since the operator notified PHMSA of the violation, PHMSA considered a special permit with integrity management concepts in a special permit with conditions an appropriate mechanism for this situation to maintain safety. Also, the special permit conditions would ensure the special permit segments were maintained while the segments could be upgraded with pipe replacements or pressure tests. With integrity management procedures being effective in other safety situations, PHMSA considers this to be an effective approach for the sliding mile areas with 4 Type B special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § I92.5(c), of 10 or fewer buildings intended for human occupancy in a "class location unit" and for which the MAOP has not been confirmed in accordance with 49 CFR § 192.611. There are 171 segments and 37.78 miles of Type B special permit segments and 3.84 miles of this total must be pressure tested as listed on Attachment A. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 410 or fewer dwellings or structures for human occupancy, which is the case for over 89 percent (171 of 192 segments) of the TGP 192 special permit segments. Special permit conditions are measures to assess, evaluate, and implement measures to manage and eliminate threats to pipe integrity and public safety in areas of high consequence such as these sliding mile special permit segments. • List the regulation(s) for which the operator seeks the permit. The special permit would address the requirements of 49 CFR §§ 192.5, 192.611(a) and (d), and 192.619(a). • Describe the need for the requested special permit. How would a special permit benefit the operator? Would a special permit benefit the public? If so, please explain how. Implementation of the special permit conditions would allow TGP to avoid the replacement of 37.78 miles of pipeline. Instead, the special permit would require implementation of the special permit conditions, including enhanced integrity management procedures. The special permit would benefit the public by reducing any disruptions due to construction activities near their homes in the Special Permit Segments. • Indicate whether this is an existing or proposed pipeline. This special permit impacts only existing pipeline facilities as outlined in Attachment A. • Describe pipeline, the materials transported in the pipeline, and specift the counties and states where the affected segments of the pipeline are or would be located. The TGP pipeline transports natural gas in the pipeline segments included in the special permit that are located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia. The pipeline Special Permit Segments are generally short in length, not contiguous and are located in multiple States and counties/parishes within those states. Attachment A (Pipeline Segments and Map) outlines the specific locations — state and county — of the Special Permit Segments. 111. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 5in the Conditions of the special permit and while also treating all of the identified pzpeline segments as high consequence areas. TGP proposes a special permit with conditions that includes two types of class location units (special permit segments) with clusters that impact approximately 49.00 miles of pipe. These units would be designated as either Type A or Type B special permit segments. The Type A special permit segrnents are those with more than 10 dwellings intended for human occupancy and for which the MAOP has not been confirmed in accordance with 49 CFR § 192.611. Approximately 11.22 miles of pipe located in these special permit segments would be replaced or pressure tested. A special permit would provide a schedule for the completion of the required pipe replacements andlor pressure testing for the Type A special permit segments. Type B special permit segments that have 10 or fewer dwellings would also be subject to the Conditions of the special permit for its term. All of these special perrnit segments would be treated as high consequence areas (HCAs) under an integrity management (IM) program (49 CFR Part 192, Subpart 0) as a requirement of the special permit. Approximately 37.7g miles of pipe are located in Type B locations. The special permit would incorporate conditions (enhanced integrity management activities) to maintain pipeline integrity. All of the permit conditions are attributes of a robust IM program (49 CFR Part 192, Subpart 0). These proposed Conditions include conducting periodic: close interval surveys, cathodic protection reliability improvements, stress corrosion cracking direct assessment, running inline inspection (ILI) assessments (srnart pigs), interference current control surveys, remediating ILI findings through anomaly evaluation and repairs, pipe seam evaluations, pipe properties records review and documentation, and maintaining line-of-sight markers. Many of these proposed integrity activities are currently required in 49 CFR Part 192, Subpart 0 for an IM program to manage high consequence areas (HCAs) at specified reassessment intervals. The assessment and reassessment intervals, the level of remediation and the maintenance activities in a proposed special permit would be more stringent to maintain pipe integrity and protect both the public and the environment for the class location units in which the Special Permit Segments are located. The erthanced integrity management activities that TGP would implement as proposed special permit conditions for the pipeline segments include: PIIMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 61. TGP would incorporate the pipeline segments into its written integrity management program (IMP) as a "covered segment" in a "HCA" in accordance with 49 CFR §192.903. 2. TGP would perform a close interval survey (CIS) along the entire length of pipeline segments and remediate any areas of inadequate cathodic protection no later than three (3) years after the issuance of this special permit. TGP will perform periodic CIS of the pipeline segments with a reassessment interval not to exceed seven (7) years. 3. TGP would implement a plan to improve cathodic protection reliability and perform inspections for stress corrosion cracking (SCC) during all excavations. 4. TGP would perform Stress Corrosion Direct Assessments to evaluate pipeline segments where the risk of SCC is present. 5. TGP would perform integrity assessments along the pipeline segments using appropriate assessment methods based on threats identified during the risk assessment process including both high resolution magnetic flux leakage (HR-MFL) and either HR-geometry or HR- deformation tools. TGP would reassess the pipeline segments at an interval not to exceed seven (7) years from the last assessment in accordance with 49 CFR § 192.939. 6. TGP would not let this special permit be a basis for deferring any of its assessments for HCAs in accordance with 49 CFR Part 192, Subpart O. 7. TGP would address induced alternating current (AC) from parallel electric transmission lines and other interference issues such as direct current (DC) along the pipeline segments that may affect the pipeline. 8. TGP would identify any pipeline segment that may be susceptible to pipe seam issues because of the vintage of the pipe, the manufacturing process of the pipe, or other issues. 9. TGP would install and maintain line-of-sight pipeline markers on the pipeline segments except in agricultural areas or large water crossings such as lakes where line-of-sight signage is not practical. 10. TGP would maintain data integration of all integrity findings and remediation along the pipeline segments. 11. For long term pipeline system flow reversals occurring after the effective date of the Special Permit and exceeding 90 days, TGP would prepare a written plan in accordance with Advisory Bulletin (ADB-2014-04) prior to implementing the pipeline system flow reversal through the Special Permit Segment. 12. TGP would maintain the following records for each pipeline segment: documentation showing that each Special Permit Segment has received a 49 CFR § 192.505, Subpart .1, hydrostatic test for eight (8) continuous hours and at a minimum pressure of 1.25 times MAOP, documentation of mechanical and chemical properties including pipe toughness (mill test reports) showing that the pipe in each Special Permit Segment meets the wall thickness, yield strength, tensile PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 7strength and chemical composition of either the API Standard 5L, 5LX, or 5LS in usage at the time of manufacturing. • Alternative 2: Denial of the Request • Describe Alternative: Denial of the special permit would require the replacement and pressure testing of all the pipeline segments associated with this special permit request, which includes approximately 49.00 miles of mainline pipe. If TGP opted not to replace or pressure test the relevant segments of pipeline, 49 CFR § 192.611 requires a reduction in the pipeline maximum allowable operating pressure (MAOP).5 • Summary • A special permit allows TGP to continue to operate the pipeline segments at their current maximum allowable operating pressure (MAOP). However, according to the special permit, the pipeline segments must be replaced, hydrostatically tested, or operated in accordance with the special permit conditions. The Federal pipeline safety regulations in 49 CFR § 192.611(a) require natural gas pipeline operators to confirm or revise the MAOP of a pipeline segment after a change in class location. A special permit would allow TGP to continue to operate each of the 192 special permit segments at their existing MAOP's despite a change in class location for the special permit specified time interval. • A special permit would require TGP to replace or pressure test all segments that have over 10 dwelling in the sliding mile area that are outside the Cluster area to meet § 192.611. Segments within the sliding mile and outside the Cluster area will be allowed to implement the special permit conditions and integrity management procedures with the sliding mile and one-mile on either side of the segment. This would be similar to requiring a Class 1 location to implement integrity management procedures (49 CFR Part 192, Subpart 0) for all mileage, whether it meets the definition of a high consequence area or not. • Background on Class Location Special Permits: On June 29, 2004, PHMSA published in the Federal Register (69 FR 38948) the criteria it uses for the consideration of class location change waivers, now being granted through special permits. First, certain threshold requirements must be met for a pipeline section to be further evaluated for a class location change special permit. Second, the age and manufacturing process of the pipe; system design and construction; environmental, operating and maintenance histories; and integrity management program elements are evaluated as significant criteria. These significant criteria are presented in matrix form and can be reviewed in the FDMS, Docket 5 These regulatory options are specified in 49 CFR § 192.611 Change in class location: Confirmation or revision of maximum allowable operating pressure. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 8Number PHMSA—RSPA-2004-17401. Third, such special permits will only then be granted when pipe conditions and the operator's integrity management program provides a level of safety equal to a pipe replacement or pressure reduction. IV. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 9• Describe Alternative: Describe what PHMSA would do under this alternative. i.e. grant a permit that allows operator to schedule the replacement or pressure testing of certain pipeline segments and leave certain pipeline segrnent in place under added integrity measures defined in the Conditions of the special permit and while also treating all of the identified pipeline segments as high consequence areas.. The special permit includes two types of class location units (units) with clusters that impact approximately 49.00 miles of pipe. These units would be designated as either Type A or Type B special permit segments. The Type A special permit segments are those with more than 10 dwellings intended for human occupancy and for which the MAOP has not been confirmed in accordance with 49 CFR § 192.611. Approximately 11.22 miles of pipe located in these units would be replaced or pressure tested. The special permit provides for a schedule for the completion of the required pipe replacements and/or pressure testing for the Type A special permit segments. Type B special permit segments that have 10 or fewer dwellings would also be subject to the Conditions of the special permit for its term. All of these special permit segments would be treated as high consequence areas (HCAs) under an integrity management (IM) program (49 CFR Part 192, Subpart 0) as a requirement of the special permit. The special permit would incorporate a minimum of 12 enhanced integrity management activities described above. All of the proposed special permit conditions are attributes of a robust IM program. These Conditions include conducting periodic: close interval surveys, cathodic protection reliability improvements, stress corrosion cracking direct assessment, running inline inspection (ILI) assessments (smart pigs), interference current control surveys, remediating ILI findings through anomaly evaluation and repairs, pipe seam evaluations, pipe properties records review and documentation, and maintaining line-of-sight markers. All of these integrity activities are currently required in 49 CFR Part 192 for either normal operational activities or within an IM program at some reassessment intervals. The assessment and reassessment intervals, the level of remediation and the maintenance activities in the special permit are more stringent to maintain pipe integrity and protect both the public and the environment for the class location units in which the pipe segments are located. • Safety Risks: special permit. Describe what, i f any, safety risks would result i f the regulation were waived as compared to the safety risks in the absence of a Sections 192.5, 192.611(a) and (d), and 192.619(a) are in the gas pipeline regulations to maintain the safety of the pipeline based upon maximum PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 10allowable operating pressure (MAOP), population (Class locations) and population growth along the pipeline. Class locations are based upon the population (dwellings for human occupancy) within a "class location unit" which is defined as an onshore area that extends 220 yards on either side of the centerline of any continuous 1-mile of pipeline. These locations are determined by surveying the pipeline for population growth. The more conservative safety factors are required as dwellings for human occupancy (population growth) increases near the pipeline. Pipeline operators must conduct surveys and document population growth within 220 yards on either side of the pipeline. A higher population along the pipeline may trigger any of the following for the pipeline segment with the higher population: a reduced MAOP, a new pressure test at a higher pressure, or new pipe with either or both heavier walled or higher grade pipe to protect against integrity risks to occupants along the pipeline segment. The proposed special permit enhanced integrity management conditions would be designed to identify and mitigate integrity issues that could threaten the pipeline segment and cause failure. The effect of the monitoring and maintenance requirements in the proposed special permit conditions will ensure the integrity of the pipe and protection of the population living near the pipeline segment to a similar degree of a lower MAOP, new pressure test, or a thicker walled or higher grade pipe without the enhanced IM protections. If PHMSA were to deny the special permit request, TGP would be required to reduce the pressure in the affected pipeline segments. In this situation, the consequences, and the PIR (a separate question and response) would be less than if the permit is granted because the pipeline would operate at a higher operating pressure under the special permit. In most cases a pressure reduction would be approximately 20 percent of current operating pressures. This reduction would be the difference in a Class 1 versus Class 2 location design safety factor (0.72 versus 0.60). A pressure reduction would reduce gas flow volumes to customers. The safety risk with respect to this request for a special permit focuses on maintaining the integrity of the pipeline and on the risk it poses to the increased population to mitigate a failure of this pipeline. Granting this special permit does not increase the potential impact radius (PIR (the radius of a circle within which the potential failure of a pipeline could have significant impact on people or property)) of the pipeline. However, the risk from the increased human population around the pipeline would be mitigated through IM procedures. PIR is the radius of a circle within which the potential failure of a pipeline could have significant impact on people or property. The current PIR's for these pipeline segments are calculated using Section 3 of ASME PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 11B31.8S-2004, "Managing System Integrity of Gas Pipelines, incorporated by reference by 49 CFR §192.903. The formula and resulting calculation are as follows: (see Attachment D for a more in depth discussion of PIR). r = radius of the circular area in feet surrounding the point of failure, otherwise known as the PIR d #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 12used to establish a high consequence area (HCA). Attachment A gives the integrity management PIR for each TGP pipeline segment, which in all eases is less 760 feet or less and is much less than the l-mile length used to establish the Special Permit Inspection Area. Performance of the Conditions in the special permit provides an equivalent or greater level of safety for the public and environment; and imposes no additional safety risks as a result of the waived regulation. As already noted, all of the pipeline segments included under the special perrnit would be treated as HCAs with the additional risk analysis and remedial activities associated with this designation. The special permit also includes a number of conditions that address potential safety risks. Among these are incorporation of these segments into the Kinder Morgan Integrity Management Program, additional close interval corrosion surveys, implementation of a cathodic protection reliability improvernent plan, a more comprehensive stress corrosion cracking direct assessment program, an in-line inspection (ILI) program with intervals not to exceed seven years, anomaly evaluation and repair meeting more stringent criteria, additional testing and remediation of interference currents caused by induced alternating current sources, pipe seam evaluations, criteria for the identification of pipe properties, installation of line-of-sight markers and the integration of all inspection and remediation data. This comprehensive list of additional risk related Conditions incorporated in the special permit is intended to provide for a significant added level of safety for the existing pipeline segments. • Would operation under a special permit change the risk of rupture or failure? Operation under the special permit would not be expected to have an impact on the risk of failure or rupture as the operating conditions of the pipeline segments have not changed. Segments in the special permit would have inspections at intervals similar to IM program intervals, which would maintain the integrity of the pipe segments over the life of the special permit. • If a failure occurred, would consequences and spill or release volumes be different if PHMSA granted the permit? Increase risk, decrease risk no change? The consequences of any spill or release would not be impacted as a result of the special permit and the potential for such an event is expected to be less likely with the added safety programs noted above. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 13a Would the Potential Impact Radius (PIR) of a rupture change under the special permit? Would more people be affected by a failure ifwe granted the permit? The PIR as calculated in accordance with 49 CFR § 192.903 would not change under the special permit since maximum operating pressure and pipe diameter will not change, thus there would be no additional impact on the public. • Would operation under the special permit have an effect on pipeline longevity or reliability? Would there be any life cycle or maintenance issues? Operation under the Special Permit Conditions that provide an additional level of safety is expected to have a positive impact on pipeline longevity and reliability. TGP does not anticipate any deleterious life cycle or maintenance issues related to operation of the pipeline with the special permit and conditions based upon IM type procedures. Implementation of the proposed conditions in the special permit provides an equivalent level of safety for the public and environment; and imposes no additional safety risks as a result of the waived regulation. As already noted, all of the pipeline segments included under the special permit would be replaced with new pipe (Type A) or treated as HCAs with the additional risk analysis and remedial activities associated with this designation (Type B). The special permit also includes a number of proposed Special Permit Conditions that would address potential safety risks. Among these are incorporation of these segments into the Kinder Morgan Integrity Management Program, additional close interval corrosion surveys, implementation of a cathodic protection reliability improvement plan, a more comprehensive stress corrosion cracking direct assessment program, an in-line inspection (ILI) program with intervals not to exceed seven years, anomaly evaluation and repair meeting more stringent criteria, additional testing and remediation of interference currents caused by induced alternating current sources, pipe seam evaluations, criteria for the identification of pipe properties, installation of line-of-sight markers and the integration of all inspection and remediation data. This comprehensive list of additional risk related conditions incorporated in the special permit is intended to provide for a significant added level of safety for the existing pipeline segments. • Environmental Impacts: Explain how operation under the special permit would impact the environment as compared to the status quo in the absence of a special permit. either positively, negatively, or not at all. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 14Approval of the special permit would have a positive impact for those units that do not require pressure testing or replacement, since TGP's activities would have negligible, if any, environmental impact. TGP would avoid disturbing the right of way of property owners except for the additional inspections that may be required to satisfy the conditions of the special permit such those related to the Integrity Management Program for HCAs, additional SCCDA verification digs, and potential anomaly evaluations/repairs. While the special permit would avoid the full replacement of affected pipe, the proposed special permit conditions require monitoring and maintenance that could lead to excavations and repair or replacement of some pipe. TGF will evaluate the potential environmental consequences and affected resources of land disturbances and water body crossings caused by construction activities (including adding, modifying, replacing or removing any facility) for the related environmental permits associated with any TGP activity. This evaluation is outlined in Kinder Morgan's Operating and Maintenance Procedure (O&M) 1205: Land Disturbance, Construction, and Environmental Permits, and referenced forms and procedures, which requires obtaining the required permits prior to conducting any construction activity. These procedures ensure that all activities resulting in land disturbances or construction of new or modified facilities comply with the requirement to obtain all applicable environmental permits and other applicable environmental authorizations. These procedures contain information required to identify activities subject to Federal, State, and Local environmental authorizations related to the work and to obtain those authorizations. The procedures require a review by TGP Environmental Services staff prior to the start of work, incorporation of environmental requirements into the project implementation, and ensuring outstanding (environmental) requirements are incorporated into facility operation. If the activities do not qualify under the requirements of the Federal Energy Regulatory Commission (FERC) "General Rules and Regulations" Section 2.55(a) or 2.55(b) facilities or the blanket certificate, TGP will pursue authorization in accordance with Section 7 of the Natural Gas Act. • Explain whether and how operation under the special permit would impact each of the environmental resources set out in the Site Description portion of this document: land use planning, surface waters (including wetlands), drinking water, soils and vegetation, wildlife habitats (including fisheries), cultural resources, socioeconomics, Native Americans, etc. ? Focus on environmental aspects that are impacted Are there any geologic hazards? Would any of these impacts be significant? PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 15As already noted, this special permit involves pipeline facilities at various locations. Each of the environmental resources potentially impacted that are listed would be addressed in accordance with the applicable Kinder Morgan procedures and FERC requirements. Although the environmental impacts are not expected to be significant it must be kept in mind that for those units requiring pressure testing or pipe replacements (Type A) there will be excavation related activities, along with water sourcing and water disposal issues at a minimum. These impacts will occur whether or not the Special Permit is granted. For the Type B segments, approval of the special permit request would avoid disturbance to the environment, public roadways, businesses and homes since pipe replacement would not be required at this time. PHMSA may require pipe replacement at a later date if integrity issues are found with the pipe or if the segment grows to over 10 dwellings for human occupancy in the sliding mile length that is outside the upgraded Cluster area. • Discuss direct, indirect and cumulative impacts. The majority of the pipeline segments addressed by this special permit have been buried and undisturbed for many years. The current pipeline cover has therefore returned to its original state in most cases. Any activity related to pressure testing or pipe replacement will be temporary in nature and the pipeline right of way would be restored in accordance with required environmental regulations. Direct, indirect, or cumulative impacts associated with activities related to the special permit would not be significant. • Briefly summarize environmental aspects that will not be impacted. Explain why these resources won't be impacted. As already noted, those pipeline segments that do not require pressure testing or pipe replacements will be operated in nearly the same manner as they are currently. The special permit would allow approximately 37.78 miles of Type B7 Special Permit Segments to remain in their current state and not require excavation or disruption of landowner activities. Unless localized excavations are needed, right of way activities (such as additional pipeline markers) may increase in frequency due to the special permit conditions, but it is anticipated that there would be a very minimal added environmental impact related to those activities. 7 Type B special permit segments total 37,78 miles of pipe of which 3.84 miles will require pressure testing. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. FONSI #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 16All ILI Tool inspections to determine any pipeline integrity issues due to corrosion or third party damage would be propelled down the pipeline by gas flow volumes pushing ILI tools through the pipeline segment. Other IM inspections would be performed along the pipeline segment right of way. a #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 17assure compliance with all environmental regulations and requirements as outlined in this prior section. PHMSA has reviewed the Part 192 requirements for replacing the pipeline and the conditions of the special permit including integrity management practices and considers both to have similar environmental and right-of-way impacts. These impacts will be mitigated by following the FERC procedures outlined in Section V. • Alternative 2: Denying the Special Permit Request and Requiring Full Compliance with 49 CFR Part 192. • Describe Alternative: Applicant would be required to comply with 49 CFR §§ 192.5, 192.611(a) and (d), and 192.619(a). TGP would be required to replace existing pipe with heavier walled pipe. Denial of the permit and full adherence to the Code would afford the protections described above that are associated with either: a lower MAOP, new pressure test, or heavier walled or higher grade pipe. Denial of the special permit would mean for most of these pipeline segments that the enhanced integrity management portions of a special permit conditions would probably not be implemented. Denial of the special permit would require excavation to remove existing pipe, acquiring environmental permits where necessary, and pressure testing of the replacement pipeline segments. This action would create an impact to vegetation, soils and possibly waterways due to the excavation, use of public roadways, and the impacted right of way during construction. TGP will evaluate the potential environmental consequences and affected resources of land disturbances and water body crossings caused by construction activities (including adding, modifying, replacing or removing any facility) for the related environmental permits associated with any TGP activity. This evaluation is outlined in Kinder Morgan's Operating and Maintenance Procedure (O&M) 1205: Land Disturbance, Construction, and Environmental Permits, and referenced forms and procedures, which requires obtaining the required permits prior to conducting any construction activity. These procedures ensure that all activities resulting in land disturbances or construction of new or modified facilities comply with the requirement to obtain all applicable environmental permits and other applicable environmental authorizations. These procedures contain information required to identify activities subject to Federal, State, and Local environmental authorizations related to the work and to obtain those authorizations. The procedures require a PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 18review by TGP Environmental Services staff prior to the start of work, incorporation of environmental requirements into the project implementation, and ensuring outstanding (environmental) requirements are incorporated into facility operation. If the activities do not qualify under the requirements of 2.55(a) or 2.55(b) facilities or the blanket certificate, TGP will pursue authorization in accordance with Section 7 of the Natural Gas Act. VI. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 19• The application fails to give a complete useful response to § 190.341(c)(4). (FONSI Review: Section II) • Rather than use the special permit process in a situation like this, PHMSA should consider entering a consent agreement with the operator with both acknowledging the operator is out of compliance. PHMSA risks regulating many individual operators by special permit, without any justification for why the regulations should not be met, in effect negating the safety factors in place under § 192.611 or other regulations. (FONSI Review: Section II - The special permit requires replacement or pressure testing of segments with over 10 dwelling. The special permit has conditions and integrity management procedures for the special permit inspection area, 433.71 miles of pipeline.) VII. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 20• (3) The actual installed cost of each facility item listed pursuant to paragraph (e)(1), separately stating the cost of materials and labor as well as other costs allocable to the facilities; • (4)(i) A description of the contacts made, reports produced, and results of consultations which took place to ensure compliance with the Endangered Species Act, the National Historic Preservation Act and the Coastal Zone Management Act; • (ii) Documentation, including images, that restoration of work areas is progressing appropriately; • (iii) A discussion of problems or unusual construction issues, including those identified by affected landowners, and corrective actions taken or planned; and • (5) For acquisitions of facilities: • (i) A statement referencing the date of issuance, docket number and title of the proceeding for any certificate issued by the Commission authorizing the facilities acquired; and • (ii) The amounts recorded in the accounts of the vendor (seller or lessor) that apply to the facilities acquired and the accumulated provisions for depreciation, depletion, and amortization. VIII. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 21PHMSA will grant TGP a special permit with conditions as outlined in Alternative 1 and Reporting sections above. TGP will implement additional special permit conditions to maintain safety and will follow the FERC and any other applicable Federal, state, and local regulations for evaluating and mitigating the potential environmental consequences and affected resources of land disturbances and water body crossings caused by construction activities (including adding, modifying, replacing or removing any facility) for the related environmental permits associated with any TGP activity. PHMSA has imposed conditions on this special permit designed to protect the public, property, and the environment from the risk of a pipeline leak or failure. These conditions are designed to ensure that the likelihood of a leak or failure is not greater than it would be in the absence of the special permit. Therefore, we believe there are no significant environrnental impacts associated with the issuance of a special permit to TGP. The TGP special permit conditions will maintain safety and the environment for the 49.00 miles of pipe in the special permit segments until replaced with upgraded pipe or pressure tested and will require integrity management concepts to be implemented for 433.71 miles of special permit inspection areas. IX. List of Preparers Amelia Samaras, PHMSA, US DOT, amelia.samaras@dot.gov Steve Nanney, PHMSA, USDOT, steve.nanney@dot.gov X. Agencies and Persons Consulted No other agencies were consulted, but PHMSA considered environmental information, special permit conditions, and documents submitted by TGP. Attachments: Attachment A — Listing of TGP Special Permit Segments Attachment B — Guidance of Repairs to Interstate Natural Gas Pipelines Pursuant to FERC Regulations (July 2005) Location Map: A map showing the geographic location of the Special Permit Segments can be reviewed at: regulations.gov at Docket: PHMSA-2016-0004. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 22Attachment D — Section 3, ASME B31.8S, 2004 MAPAAGIW, SYS-KM INTEGRITY O F GAS PIPLUItES AWL B S1.85 2064 k. #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 23Attachrnent D — Section 3, ASME B31.8S, 2004 A !AAL LI #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 24OPID 19160 A liE a Iri P .f.; tg MR,$—M,M00.2MJRW.MMRUMVVMMMN!OJAHMWI X,AAAAAMRRFAAA;IXR3ii*X%;',ISitRrn'ARRFIRRXX7.474RRRPRAgiAgRF1515i*FtRiiiRFI ------ 1q8888888888898888888R. 15 ]8,VLISFIBR88§8888888888888888888_,S885 g. , 66666d666d6cid6:166666Rgid,i [4 666,1 3 6 4 66666666666666666666a,66 3 ! sgx2 53 F egg aiRkRGWA"R!, 3 4 AOA" r g .. ..^4 8 w . w254.:i0.RE8k b . a Org 101 zgi ge F ARPOMMg.P.7.FAg.4V'Aiggi="70gr548gOWn0% 11 11 a alg 11. 2 #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 25MAOP (psig) 760 790 790 BR888222222 OPID 19160 Diameter 2 2 Dwellings in length not meeting present Class 7 - 9 ~ Pressure Test Length (ft) 0.00 39.90 0.00 154.20 79.50 0.00 2,947.18 0.00 682.08 0.00 36.00 612.00 0.00 12.00 0.00 0.00 .... Replace Length (fe) 1,581.69 1,488.68 1,439.64 2,789.70 1,505.76 1,358.93 0.00 638.34 436.50 436.76 803 33 461.62 950.24 1,229.60 1,723 32 654.33 4,04814 1,492.73 3,153.88 4,139-46 2.601.90 2.044.66 .... Special Permit Segment Length not meeting present Class (ft) 581 CA 1,488.68 1,909.29 1,439.84 2.943.90 1,358.93 496 50 3,318.84 461.62 1,746.24 1.723.32 4,060.24 1,492.73 557.12 1,153.88 1,059.96 4,139.46 2,691.92 2,041.66 ....! Special Permit Inspection Aces Length (ft) 12141 64 12048.68 12409.29 11999.84 12145.26 11928.93 13513.04 11198.57 1 1168864 11383.33 1221 1. 117:3.88 1 1 Latest HCA Assessmen and Data N/A N/A N/A N/A N/A N/A N/A VIFL/Caliper - 2008 N/A N/A N/A N/A MFU/Caliper - 2001 N/A MFU/Caliper - 2014 N/A MFL/Caliper - 2011 N/A sile lina. MFL/Caliper MEL/Caliper N/A 9992 992 (pipe) (present) Special Permit Inspection Area Stationing (Ending) Valve - Station 546-1-41850 530-2- 77307 535-2-4549: 22117 ... Page 25 of 31 324-14 324-1A 126: 136: 213-2- Special Permit Inspection Area Stationing (Beginning) Valve - Station 546-1 - 29708 530-2 - 65751 535-2 - 33024 49724 051. 1107 3544 6452 ... 125-1A 326: 326- 244- 213-1- 215-1- Permit Segment Special Permit (Ending) Valve - Station 546-1 - 36570 530-2 - 72527 64196 7119 15551 • 21827 1200. 530-3- 324-14 324-1A 326-1 243-2- 251-1- segment Stationing Segment Stationin Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments Special Permit (Beginning) Valve - Station 546-1 - 34968 590-2-71038 535-2-38304 540-2 - 77710 540-2 - 83326 546-2 - 34989 630-1. 20810 324-1A - 55004 124-1A - 63558 325-1 - 16351 325-1-17148 325-1A - 38824 328-1 - 29030 - 13357 236-1- 144-1 - 21246 18683 251-1 - 34314 215-1-37377 ... 2E5399 Une Name LOWNDES HANCOCK CORRECT LOWNDES SUSSEX SUSSEX SUSSEX BERGEN ONTARIO MADISON ALBANY ALBANY 922222222 .... PHMSA REGION PHMSA No. KM No. State 8 288882888888888888888233 SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN EASTERN ASTERN#

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 26OPID 19160 11 KIS" Oro 20= mngomm. n 22 2 #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 27Attachrnent A: Listing of Tennessee Gas Pipeline (TGP) special permit segments PI41454 REGION IMAM No. KM No. Mate EASTERN 175 320 WA EASTEAN 176 322 WV EASTERN 177 323 WV EASTERN 178 326 VAI EASTERN 179 327 WV EASTERN 183 328 WV EASTERN 181 326 WV EASTERN 182 393 WV EASTERN 183 391 WV S01.1114WEST 184 334 TX SCRNHINEST 185 335 TX SOUTHWEST 186 336 TX EASTERN 187 340 WV SOUTHERN 188 341 TN SOUTHERN rea or Kr SOIJTHERN 193 343 KY SOuTHEAN 191 348 MS sotnriwur 192 3E0 LA OP1D 19160 Comte One Name Spedel Peenslt Segment Sraellon/ng TENKIEwIne Wee - Motion Sporiol Penult Segment MetIonIng (8901.10 Veer. -Shod. Medal Permit Segment Type Spedal Permit 8140.1 11.0 Mee Stetfaving (BagInning) Wye • Station Medd Permit Impaction Area Stalloning lendinw Vie ws - 5Mtloes ChM Prm4071.1 Oars WOO HCA Uteri HCA Assessment and Dew Medal Pennit Inspection Arla Lehgth(N1 Sporiel Permit 5egnsen1 Length not meeting present Gm 1121 Pressure Test Iteplece length 9111 ERROR 10) 11.61 ill nee in length not meeting present Elms Pipe Ofarnater (101 MAO' (Mlle KANAWHA 100.1 118-1 - 71E035 118, 1 #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 28Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments PHMSA No. KM No. OPID 19160 ___, i- Pipe . #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 2911111MM-Vi111111-11111MMIlilliWill11111111MM11- ftlly OPID 19160 2t Zkm “r!-IM5U51 .U.M.55MUUUUUUM.UUUMMU.UU 00 -1U11111:::222i11 - 622221122222222221MMS2n. 111 .... #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 30Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments #

2016-0004 Tennessee Gas Pipeline LLC FONSI, page 31Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments OPID 19160 Pipe Distance to MPS only T. Design Pipe Wall Pipe MLV Compressor MAOP Segment PNMSA -- No. PM No. Pressure {Oil PIIINIUND Thidtne ss PIR (ft) Pipe Grade (psig) Pipe S4.11TI Type Pipe Cooties Installation Upstream/ Station Established per Aerial Photography Material/ Pressure Leak/SCC/S5WC (w/i 20 rni Pressure Tested Inspect. OO MPS record Test Documents of segment) alter 00.72 (1.) Date DoemsPea Spadng (rni) 192.619 d (to bads Leak/SCCISSWC (OW rn (rid) up 'test) 175 320 1320 936 025 416 52000 DSAW USION BC N DE 0 EPDXY 1984 2.4 / 7.1 87.8 la)(1) 2012 Leak (11/1/1983) YES YES N/A 176 322 1209 936 025 422 520581 OSAW FUSION BO N E D EPDXY 1984 3.8/ L1 87.8 (4)11) 201.2 Y/Y Leak (11/1/1583) YES YES N/A 177 323 1222 973.44 0312 517 52000 FW COAL TAR ENAMEL 1944 3.5/ 8.2 87.7 (4)(3) 2012 Y/ Y Leak (5/15/1978) YES YES N/A 178 326 1222 973.44 0.312 507 52002 FW COAL TAR ENAMEL 1948 0.8/9.2 87.7 1.113) 2012 Y/ Y Leak (5/1 5/1 693) YES YES N/A 179 327 1222 973.44 0312 507 521100 FW COAL TAR ENAMEL 1948 2.5/ 7.3 87.7 1.113) 2012 / Y Leah (5/15/1958) YES YES N/A 180 328 1244 990.72 0344 565 52000 FW TAPE- UNKNOWN BACKING 1959 10.0 / 7.5 89.1 1.)13) 2012 9/ Y Leak (12/15/1966) 905 YES N/A 181 329 1269 1246.15 0375 541 60001 FW COAL TAR ENAMEL 19E6 7.0/ 3.5 89.1 1.0(2) 2012 Y/ Y Leak (12/15/1966) YES YES N/A 182 330 1151 910 08 0.316 624 60000 DSAW FUSION BONDED EPDXY 1972 4.8/ 7.5 89.1 (a)(1) 2011 Y/ V N/A YES N/A 183 331 1151 91008 0316 624 60Z00 [MAW FUSION BONDED EPDXY 1972 6.0/ 6.5 89.1 1.0) 2012 V/ N/A YES N/A 184 334 1054 350 025 454 50000 FW COAL TAR ENAMEL 1944 1.61 01.8 (OM 1012 8(9 Leak (4(5/7012) SCe NO /YES YES N/A 185 335 1054 750 025 454 50000 FW COAL TAR ENAMEL 1944 4.3 / 00 80.8 (4)131 2012 V /9 Leak (4/5/2012)/ sce NO /YES YES N/A 186 336 1044 750 0.25 454 50000 FW COAL TAR ENAMEL 1966 0.0/ 7.3 80.8 (4)(31 2012 Y/ Y Leak (4/5/2012)/ sce NIP / NSLP YES N/A 187 340 1228 973.44 0.312 500 52000 FW COAL TAR ENAMEL 1948 10.2 / 10 87.7 (4)(3) 2012 Y/ Y Leak (2/15/1969) YES YES N/A 188 341 1024 778.75 0.312 567 52030 OSAW COAL TAR ENAMEL 1952 8.8/115 91.7 ())1( 2012 Y/Y Leak (7/1 5/1 581) NO YES N/A 189 342 993 778.75 0312 567 52000 DSAW FUSION BONDED EPDXY 1951 14 / 7.5 88.7 (4(31 2012 Y/ Y Leak (90 5/1 995) NO YES N/A 190 343 993 778.75 0.312 567 52000 DSAW COAL TAR ENAMEL 1951 1.6/ 7.2 88.7 (.)131 2012 9/ Y Leak (9/2 5/1 99S) NO YES el/A 191 348 1302 974.88 Ol4062 760 60000 FW TAPE- UNKNOWN BACKING 1963 00/ 15.3 59.9 (.)(3) 7012 1./Y N/A YES N/A 192 360 1338 936 0.375 633 5200) DSAW COAL TAR ENAMEL 1955 15.0/46 51.1 (a)131 2012 SCe YES YES N/A Page 31 of 31#

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 1Official PDFU.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION SPECIAL PERMIT Special Permit Information: Docket Number: #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 2miles of natural gas transmission pipeline as described in Appendix A. This special permit allows TGP to continue to operate each special permit segment listed in Appendix A at its current listed maximum allowable operating pressure (MAOP). The Federal pipeline safety regulations in 49 CFR § 192.611(a) require natural gas pipeline operators to confirm or revise the MAOP of a pipeline segment after a change in class location. This special permit applies to the special permit segments listed in Appendix A. Special permit segments shall be divided into two (2) categories: Type A special permit segments and Type B special permit segments. Type A special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § 192.5(c), of more than 10 buildings intended for human occupancy in a "class location unif and for which the MAOP has not been confirmed in accordance with 49 CFR § 192.611(a). Type A special permit segments must be replaced so that the MAOP is commensurate with the present class location within five (5) years of issuance of this special permit. Type A special permit segments3 total 11.22 miles of pipe as described in Attachment A. Type A special permit segments with pipe with integrity issues as determined by Conditions 6(c) and 14 or that have not been pressure tested in accordance with 49 CFR Part 192, Subpart J to 1.25 times MAOP of this special permit must be replaced within two and one-half (21/4) years of the grant of this special permit or within two (2) years of assessment finding. Type B special permit segments include those special permit segments where there is a cluster, as described in 49 CFR § 192.5(c), of 10 or fewer buildings intended for human occupancy in a "class location unit" and for which the MAOP has not been confirmed in accordance with 49 CFR § 192.611. Type B special permit segments4 total 37.78 miles of pipe as described in Attachment A. 3 There are 11.22 miles of Type A special permit segments and of this total 10.59 miles must be replaced and 0.63 miles must be pressure tested as listed on Attachment A, see Condition 16 for pressure test requirements. 4 There are 37.78 miles of Type B special permit segments and 3.84 miles of this total must be pressure tested as listed on Attachment A, see Condition 16 for pressure test requirements. Four (4) Type B special permit segments (KM segment number 103, 181, 310, and 311) are § 192.619(c) Grandfathered segments and will require pressure testing. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 3Subsequent to the issuance of this special permit, those special permit segments that have been pressure tested or replaced such that the MAOP has been made commensurate with the present class location as defined in 49 CFR § 192.611 would no longer be included in this special permit. Special permit inspection area5 — is defined as a one (1) mile continuous segment on both sides of the special permit segment (Type A and Type B) plus the footage in the special permit segment. Appendix A lists the boundaries for the special permit inspection area associated with each special permit segment. The TGP special permit inspection area totals 433.71 miles of pipe as described in Attachment A. PHMSA hereby grants this special permit for the pipeline special permit segments listed in Appendix A based on the findings set forth in the "Special Permit Analysis and Findings" document, which can be read in its entirety in Docket No. PHMSA-2016-0004 in the Federal Docket Management System (FDMS) located on the internet at www.Regulations.gov. II. Conditions: PHMSA OPS grants this special permit subject to the following conditions: 1) Maximum Allowable Operating Pressure: TGP must continue to operate the special permit segments at or below their existing MAOP as noted in Appendix A. 2) Integrity Management Program: TGP must incorporate the special permit inspection areas into its written integrity management program (IMP) as a "covered segment" in a "high consequence area (HCA)" in accordance with 49 CFR § 192.9036. 3 ) Close Inten. al Surveys: TGP must perform a close interval survey (CIS) along the entire 5 Special permit inspection areas throughout these conditions include special pertnit segments unless specifically defined as not applicable or if the special permit segment has more stringent conditions. 6 TGP is not required to report the mileage included as part of this special permit in its annual report per the requirements of 49 CFR § 191.17, unless it is in a high consequence area. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 4length of all special permit inspection areas7 and remediate any areas of inadequate cathodic protection no later than three (3) years after the issuance of this special permit. However, a CIS need not be performed if TGP has performed a CIS and completed remediation8 including damaged coating repair along the entire length of all special permit inspection areas less than seven (7) years9 prior to the issuance of this special permit. If environmental permitting or right-of-way factors beyond TGP control should prevent the completion of the CIS within three (3) years from the issuance of this special permit, a CIS and subsequent remediation including coating repair must be completed as soon as practicable and a letter justifying the delay and providing the anticipated date of completion must be submitted to the appropriate PHMSA OPS Region Director no later than three (3) months prior to the end of three (3) years after the issuance of this special permit and must receive a "no objection" from the PHMSA OPS Region Director for a delay. CIS remediation activities must be completed within one (1) year of the finding. Any extended evaluation and remediation schedules submitted to PHMSA from TGP must receive a "no objection" from the appropriate PHMSA OPS Region Director to implement an extended CIS and remediation interval. 4) Close Interval Sur% evs — Reassessment Interval: TGP must perform a periodic close interval survey (CIS) of the special permit inspection areas at the applicable reassessment interval(s) for a "covered segment" in accordance with 49 CFR Part 192, Subpart 0, for reassessment intervals as contained in 49 CFR §§ 192.937(a) and (b) and 192.939, not to exceed a seven (7) year reassessment interval I°. CIS data shall be integrated with in-line inspection (ILI) data. Condition 15(b) — Data Integration — gives a complete description of 7 Each condition that requires TGP to perform an action with respect to the special permit inspection areas shall also require TGP to perform that action on all special permit segments within such areas. Type A special permit segments that will be replaced within three (3) years of this special permit issuance do not require a CIS. 8 The terms "remediate" or "remediatior of pipe coating shall include repair of damaged external pipe coating, where required to maintain cathodic protection of the pipeline in accordance with 49 CFR §192.463. 9 If 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. 1° If 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 5data integration information that an operator must maintain for a special permit in the special permit inspection areas which includes CIS and ILI data. CIS assessments within the reassessment interval are not required to be performed in the same year as ILI reassessments. 5) Cathodic Protection Reliability Improvement Plan: TGP shall implement a plan to improve cathodic protection reliability and perform inspections for stress corrosion cracking (SCC). a) Cathodic Protection Reliability Improvement Plan i) TGP must perform a periodic CIS of special permit inspection areas as part of Condition 4, Close Interval Surveys, with reassessment intervals at an increased frequency, not to exceed a seven (7) year reassessment interval with CIS data integrated with the most-recent in-line inspection data' I ; ii) TGP must integrate the most current CIS data with in-line inspection results in the special permit inspection area in accordance with Condition 15(b) timing requirements; iii) Within 90 days of the issuance of this special permit, TGP must amend applicable sections of its operations and maintenance (O&M) manual(s) to prohibit future use of coating that is known to shield cathodic protection along the entire length of the special permit inspection areas; and iv) TGP must perform a run comparison analysis of in-line inspection results subsequent to the baseline inspection in the special permit inspection areas to identify areas of external corrosion growth after each new tool run when the same in-line inspection vendor is used for consecutive inspections. Areas with corrosion growth over 30% in depth must be remediated within one (1) year of the finding or direct current voltage gradient (DCVG) survey run to locate problem coating areas within six (6) months of the finding with remediation completed within six (6) months of the DCVG survey. I I 1f 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 6v) Within one (1) year of the issuance of this special permit, TGP must install cathodic protection remote monitoring units (RMUs) at all impressed current sources directly influencing the special permit segments; vi) TGP must configure the RMUs in the special permit segments with alarms to notify TGP immediately in the event of any interruption in cathodic protection current output; and vii) TGP must respond and correct any interruption in cathodic protection current output immediately (within two (2) working days). If a systemic issue is present, then TGP must investigate and remediate the problem within one (1) month or less or TGP must receive a "no objection" from the appropriate PHMSA OPS Region Director for issues that require longer to remediate. b) Stress Corrosion Cracking Inspections i) TGP must review historical records to determine if SCC inspections have been performed in the special permit segments and from these inspections evaluate the threat of stress-corrosion cracking as part of the SCCDA Pre- Assessment Step in Condition 6(a). ii) TGP must perform magnetic particle inspection on any pipe (with the exception of pipe coated with fusion-bonded or liquid-applied epoxy coatings, which are not at risk for SCC) excavated in the special permit inspection areas to evaluate the pipe for SCC where disbonded coating is removed in order to perform the inspection. 6) Stress Corrosion Cracking_ Direct Assessment: TGP must evaluate pipelines along the entire length of the special permit inspection areas for SCC as follows: a) TGP must perform a stress corrosion cracking direct assessment (SCCDA) or other appropriate assessment method for SCC [such as pressure test or in-line inspection (ILI) with a crack detection tool] of pipelines along the entire length of all special permit inspection areas according to the requirements of 49 CFR § 192.929 and NACE SP 0204-2008 no later than three (3) years after of the issuance of this special PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 7permit. The SCCDA or other approved method must address high pH SCC and near neutral pH SCC. The SCCDA Pre-Assessment Step will include the results of all close-interval surveys and coating surveys required in Conditions 3, 4, and 5. i) If environmental permitting or right-of-way factors beyond TGP control prevent the completion of the SCCDA survey and remediation within three (3) years from the issuance of this special permit, a SCCDA and remediation must be performed as soon as practicable and a letter justifying the delay and providing the anticipated date of completion must be submitted to the appropriate PHMSA OPS Region Director no later than three (3) months prior to the end of three (3) years after the issuance of this special permit and must receive a "no objection" from the PHMSA OPS Region Director for a delay. ii) TGP may eliminate this Condition 6(a), provided TGP provides an engineering assessment showing that the pipeline does not meet the criteria for either near neutral or high pH SCC in accordance with the applicable edition of the American Society of Mechanical Engineers Standard B31.8S, "Managing System Integrity of Gas Pipelines" (ASME B31.8S), Appendix A3, or NACE SP 0204-2008, "Stress Corrosion Cracking (SCC) Direct Assessment Methodology", Section 1.2.1.1 and 1.2.2. iii) A SCCDA need not be performed if TGP has performed a SCCDA of pipelines along the entire length of the special permit inspection areas within the timeframe for SCCDA re-assessments specified in 49 CFR Part 192, Subpart 0, not to exceed seven (7) years12 prior to the issuance of this special permit. b) If the SCCDA required in Condition 6(a) demonstrates SCC, TGP must directly examine pipe in the special permit inspection areas for SCC using an accepted industry detection practice, such as dry or wet magnetic particle tests, anytime the pipelines are exposed for any reason, including damage prevention activities. Poor coating is coating losing adhesion to the pipe which is shown by falling off the pipe, 12 If 49 CFR § I 92.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessrnent interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 8and/or shields the cathodic protection. TGP must keep coating records' 3 of all excavation locations for the special permit inspection areas to demonstrate the coating condition. c) #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 9d) If any SCC activity is discovered in the special permit inspection area, TGP must submit a SCC remediation plan to the appropriate PHMSA OPS Region Director with a copy to the Director, PHMSA OPS Engineering and Research Division no later than 60 days after the finding of SCC: i) That meets Condition 6(c), including a SCC remediation/repair plan with SCC characterization and timing, or ii) Technical justification that shows that the threat for SCC in the special permit segment is being addressed. 7) O&M Manual — In-line Inspections, Close Interval Survey Inspections, and Reassessment Intervals: TGP must amend applicable sections of its operations and maintenance (O&M) manual(s) to incorporate the in-line inspection (ILI), close interval inspections (CIS), and reassessment intervals by the appropriate integrity assessment method including both high resolution metal loss and deformation/geometry tools along the entire length of the special permit inspection areas at a frequency consistent with 49 CFR Part 192, Subpart 0, but not to exceed a seven (7) year reassessment intervali6. 8) In-Line Inspection Initial Assessment: TGP must perform integrity assessments along the entire length of the special permit inspection areas using appropriate assessment methods based on threats identified during the risk assessment process including both high resolution magnetic flux leakage (HR-MFL) and either HR-geometry or HR-deformation tools. If integrity assessments have not been performed within seven (7) years prior to the issuance of this special permit, TGP must complete initial integrity assessments along the entire length of the special permit inspection areas within three (3) years of the issuance of this special permit. Subsequent integrity assessments along the entire length of the special permit inspection areas must conform to the required maximum reassessment intervals specified in 49 CFR § 192.939, but may not exceed a seven (7) year reassessment interval". 16 lf 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. 17 lf 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 109) Integrity Reassessment Intervals: TGP must schedule integrity reassessment dates for the entire length of the special permit inspection areas according to 49 CFR § 192.939 by adding the required time interval to the previous assessment date, but may not exceed a seven (7) year reassessment interval 18. 10) High Consequence Area Assessments: TGP must not let this special permit be a basis for deferring any of its assessments for HCAs in accordance with 49 CFR Part 192, Subpart O. 11) Annual Reports to PHMSA: Within three (3) months following the issuance of this special permit and annuallyt9 thereafter, TGP must report the following to the appropriate PHMSA OPS Region Director with copies to the Deputy Associate Administrator, PHMSA Field Operations; Deputy Associate Administrator, PHMSA Policy and Programs; Director, PHMSA Engineering and Research Division; and Director, PHMSA Standards and Rulemaking Division: a) The number of new residences, other structures intended for human occupancy and public gathering areas built within the special permit segment and also within one (1) mile on either end of the special permit segment. b) Any new integrity threats identified during the previous year and the results of any ILI or direct assessments performed (including any un-remediated anomalies over 30% wall loss, cracking found in the pipe body, weld seam or girth welds, and dents with metal loss, cracking or stress riser) during the previous year in the special permit c) inspection segment. Any reportable incident or any leak normally indicated on the DOT Annual Report, and all repairs on the pipeline that occurred during the previous year in the special permit inspection areas. 18 If 49 CFR § 192.939(a) integrity management reassessment interval should change from seven (7) years to some other reassessment interval under eight (8) years, TGP may use that reassessment interval instead of seven (7) years. 19 Annual reports must be received by PHMSA by the last day of the month in which the Special Permit is dated. For example, the annual report for a modified Special Permit dated November, 2012, must be received by PHMSA no later than November 30, each year beginning in 2013. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 11d) e) f) g) h) i) Summary report of any fatigue analysis performed on all in-service, non-remediated dents over 6% and with total strain < 5%, as required in Condition 13(b). Annual data integration information, as required in Condition 15(b) - Data Integration must be submitted beginning with the 2nd annual report that includes an annual overview of any new threats, or if requested by PHMSA a full information package. Any mergers, acquisitions, transfer of assets, or other events affecting the regulatory responsibility of the company operating the pipeline. An updated Appendix A reflecting changes in Special Permit Segment boundaries including extensions, deletions, or modifications. In the first annual report, TGP must describe the estimated economic benefits of the special permit including both the capital and operational costs avoided from not replacing the pipe and the estimated incremental operational costs of any inspection program requirements of the special permit for the 5-year grant period that are not already being conducted by TGP through their operational procedures. In the first annual report, TGP must describe whether the public benefits from enemy availability. This should address the benefits of any avoided disruptions as a consequence of pipe replacement and the benefits of maintaining system capacity. 12) Interference Currents Control: TGP must address induced alternating current (AC) from parallel electric transmission lines and other interference issues such as direct current (DC) in the special permit inspection areas that may affect the pipeline. An induced AC or DC program and remediation plan to protect the pipeline from corrosion caused by stray currents must be in place within one (1) year of the date of this special permit. a) At least once every seven (7) years not exceeding 90 months, TGP must perform an engineering analysis on the effectiveness of the AC and DC mitigation measures and must evaluate any AC interference between 20 and 50 Amps per meter squared. In evaluating such interference, TGP must integrate AC interference data with the most recent ILI results to determine remediation measures. Any AC interference between 20 and 50 Amps per meter squared must be remediated within six (6) months of the finding. If TGP does not remediate AC interference between 20 and 50 Amps per PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 12b) c) d) meter squared, TGP must provide an engineering justification for not remediating such interference to the appropriate PHMSA OPS Region Director, who may accept or reject the justification and require remediation. In special permit inspection areas with co-located high voltage alternating current (HVAC) power lines, TGP must take interference readings (continuous 24-hour recordings) during the calendar quarter of the known or anticipated highest voltage reading. If there are any significant increases to the amount of electricity/current flowing in any co-located high voltage altemating current (HVAC) power lines, such as from additional generation, a voltage up-rating, additional lines, or new or enlarged substations, TGP must perform an AC mitigation survey along the entire co-located pipeline special permit inspection area right of way within six (6) months of any such change. Within six (6) months of the engineering analysis, TGP must remediate any AC interference greater than 50 Amps per meter squared. Remediation means the implementation of performance measures including, but not limited to, additional grounding along the pipeline to reduce interference currents. Any DC interference that results in CP levels that do not meet the requirements of 49 CFR Part 192, Subpart I, must be remediated within six (6) months of this evaluation. If environmental permitting or right-of-way factors beyond TGP control prevent the completion of rernediation within six (6) months of the interference evaluation, remediation must be completed as soon as practicable and a letter justifying the delay and providing the anticipated date of completion must be submitted to the appropriate PHMSA OPS Region Director no later than one (1) month prior to the end of the six (6) months completion date. Any extended evaluation and remediation schedules submitted to PIIMSA from TGP must receive a "no objection" from the appropriate PHMSA OPS Region Director. 13) Anomaly Evaluation and Repair: a) General: TGP must account for ILI tool tolerance and corrosion growth rates in scheduled response times and repairs and document and justify the values used. TGP must demonstrate ILI Tool tolerance accuracy for each ILI Tool run by usage of PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 13calibration excavations and unity plots that demonstrate ILI Tool accuracy to meet the tool accuracy specification provided by the vendor (typical for depth within +10% accuracy for 80% of the time). The unity plots must show: a) actual anomaly depth versus predicted depth and b) actual failure pressure/MAOP versus predicted failure pressure/MAOP. Discovery date must be within 120 days of an ILI Tool run for each type ILI Tool (HR-geometry, HR-deformation, or HR-MFL). i) ILI tool evaluations for metal loss must use "6t x 6t" interaction criteria (or more conservative criteria) for determining anomaly failure pressures and remediation response timing with "6t" being pipe wall thickness times six. b) Dents: TGP must repair dents in the special permit segment and special permit inspection area in accordance with 49 CFR § 192.933 if it is located in a HCA and in accordance with 49 CFR §§ 192.933(a)-(c) repair criteria and "Table 1 — Special Requirements for Scheduling Remediation of Dents" if it is not located in an HCA. Table 1 — Special Requirements for Scheduling Remediation of Dents Defect Type Orientation Required Response Special Permit Segment Required Response Special Permit Inspection Area - Dent Associated with Cracks or Stress Risers Top or Bottom Immediate Immediate Dent Associated with Metal Loss Top or Bottom 1 Year Scheduled 2 Year Scheduled Plain Dent > 6 % OD Deep or that exhibits Top 1 Year Scheduled 2 Year Scheduled total strain > 5 % Plain Dent > 2% OD Deep Associated with Top or Bottom 1 Year Scheduled 2 Year Scheduled Girth or Seam Weld Plain Dent > 6 % OD Deep and that exhibits Top or Bottom Monitored Monitored total strain < 5 % Plain Dent < 2% OD Deep Associated with Top or Bottom Monitored Monitored Girth or Seam Weld PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 14Definitions 1. Plain Dent — Dent without metal loss, crack or stress riser. 2. Immediate Response — Reduce pressure to 80% of recent maximum pressure. hmnediate dents require an immediate pressure reduction and / or restriction and examination and remediation as required in conformance with TGP requirements within five (5) calendar days from the date of discovery. If the remediation cannot be met according to the response schedule, a technical justification must be prepared that explains the reasons why the remediation cannot be met according to the schedule and indicate how the changed schedule will not jeopardize public safety. Any extended response schedules must be submitted to PHMSA from TGP within 14 days of pressure reduction after discovery and must receive a "no objection" from the appropriate PHMSA OPS Region Director. 3. Scheduled Response — Schedule excavation within an appropriate time frame based on the opinion of the TGP SME (not to exceed 365 days for special permit segments and 730 days for special permit inspection areas). 4. 5. 6. Monitored — Catalog data for future monitoring. Top — located between 8 o'clock and 4 o'clock positions (upper 2/3 of the pipe). Bottom — located between 4 o'clock and 8 o'clock positions (bottom 1/3 of pipe). • Special permit segments and special permit inspection areas must have a HR- geometry or HR-deformation tool inspection as part of the initial ILI or these ILI inspections must be completed within two (2) years after issuance of this special permit. All dent repairs must be made in accordance with 49 CFR §§ 192.933(a) through (c) repair criteria and "Table 1 — Special Requirements for Scheduling Remediation of Dents" on page 13 of 24. TGP must conduct the following fatigue analysis of dents in special permit segments and special permit inspection areas: i) TGP must conduct a fatigue analysis of all in-service, non-remediated dents above 6% and with total strain ~ 5% after each high resolution MFL and high resolution caliper or deformation ILI evaluations. Dent fatigue analysis must include as a minimum the following: gross geometry of dent; orientation of dent; soil cover and type; pressure and temperature; including cycles; and stress and strains caused by terrain. The fatigue analysis must be completed within the time frames in "Table 1 — Special Requirements for Scheduling Remediation of Dents" of this special permit. ii) The overall remaining fatigue life of all in-service, non-remediated dents over 6% and with total strain 5% must be either twice the designated PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 15remaining life of the pipeline or at least 500 years. c) Investigation and Repair Criteria: In-line inspection anomalies in the special permit inspection areas with a safe pressure less than MAOP (e.g. Failure Pressure Ratio (FPR) < 1.39) or an anomaly depth greater than 80% of pipe wall thickness require an immediate pressure reduction and/or restriction and continuous action until the anomaly is examined, evaluated, and remediated. d) Response Time for ILI Results: TGP will follow Kinder Morgan O&M Procedure 916 (In-Line Inspections)2° for excavating, investigating, and remediating anomalies based on ILI data results in accordance with 49 CFR §§ 192.485 and 192.933. TGP must evaluate ILI data by using either the ASME Standard B31G, -Manual for Determining the Remaining Strength of Corroded Pipelines" (ASME B31G), the modified B31G (0.85dL), or R-STRENG for calculating the predicted FPR to determine anomaly responses. • Special permit seements and special permit inspection areas: Immediate response: Any anomaly within a special permit segment and special permit inspection areas operating up to 72% SMYS that meets either: (1) an FPR equal to or less than 1.1; or (2) an anomaly depth equal to or greater than 80% wall thickness loss. One-year response: Any anomaly within a special permit segment and special permit inspection areas with original Class 1 location pipe in a Class 3 location (cluster area) operating up to 72% SMYS that meets either: (1) an FPR less than 1.39; or (2) an anomaly depth greater than 40% wall thickness loss. Monitored response: Any anomaly within a special permit segment and special permit inspection areas with original Class 1 location pipe in a Class 3 location (cluster area) operating up to 72% SMYS that meets both: (1) an FPR equal to or greater than 1.39; or (2) an anomaly depth equal to or less than 40% wall thickness loss. e) Special permit seements and special permit inspection areas: Upon issuance of this 20 The requirements of this Special Permit and 49 CFR § 192.485 and 192.933 supersedes Kinder Morgan O&M Procedure 916 (1n-Line Inspections). 21 The tinting intervals for dent remediation in non-HCAs are in Condition 6(b). PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 16special permit, TGP must implement the repair and remediation of any pipe anomalies or dents that are not in compliance with Condition 13 based upon existing ILI assessment results from the high resolution MFL and geometry/deformation tools used to previously assess pipelines in the special permit segments and special permit inspection areas. TGP must review existing ILI assessment results within 18 months from the issuance of this special permit according to the following schedule: 30% of pipelines in the special permit segments and special permit inspection areas must be reviewed within six (6) months of the issuance of this Special Permit, 65% of pipelines in the special permit segments and special permit inspection areas must be reviewed within 12 months of the issuance this special permit, and 100% of pipelines in the special pennit segments and special permit inspection areas must be reviewed within 18 months of the issuance of this Special permit. Anomalies and dents discovered during this review must be remediated in accordance with Condition 13 timing requirements. 14) Pipe Seam Evaluations: a) TGP must identify any pipe in the specia 1 permit segmentthat may be susceptible to pipe seam issues (e.g., due to the vintage of the pipe, the manufacturing process of the pipe, or other issues). If TGP identifies a pipe seam issue, TGP must complete Condition 14(a). If the engineering analysis required in Condition 14(a) reveals that there is a threat to the pipeline, then TGP must complete all of the applicable condition requirements in Condition 14(a)(ii), (a)(iii), (a)(iv), (a)(v), (a)(vi), (a)(vii), and (a)(viii): i) #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 17Michael Baker Jr., and Kiefner and Associates, et. al. under PHMSA Contract DTRS56-02-D-70036 were utilized along with other relevant materials. If the engineering analysis shows that the pipe seam issues on pipelines located in the special permit segment are not a threat to the integrity of the pipeline, TGP does not have to complete Conditions 14(a) (ii) through (vii), but must complete Conditions 14(a)(viii) and (ix). ii) If a 49 CFR Part 192, Subpart J hydrostatic test has not been perforrned, the special permit segments rnust be hydrostatically tested to a minimum pressure of 100 percent SMYS, in accordance with 49 CFR Part 192, Subpart J requirements for eight (8) continuous hours, within two and one- half (21/2) years of issuance of this special permit. The hydrostatic test must confirm no systemic issues with the weld seam or pipe. A root cause analysis, including metallurgical examination of the failed pipe, must be performed for any failure22 experienced to verify that it is not indicative of a systemic issue. The results of this root cause analysis must be reported to the appropriate PHMSA Region Director with a copy to the Director, PHMSA Engineering and Research Division, within 60 days of the failure; iii) Special permit segments with low frequency electric resistance welded (LF- ERW) pipe with a history of leaks or failures without a "spike test" within the special permit inspection area must be pressure tested23 with a "spike test" within two and one-half (21/2) years of the issuance of this special permit. iv) Special permit segments24 with pressure tests less than 1.25 times MAOP that may be susceptible to pipe seam issues must be tested with a Subpart J pressure test within two and one-half (21/2) years of issuance of this special 22 A root cause analysis, including metallurgical examination of the pipe, must be performed for any leaks that are removed from the special permit segment. 23 A root cause analysis, including metallurgical examination of the pipe, must be performed for any pressure test failures or leaks from the special permit segment. 24 TGP must implement the replacement of all Type A special permit segments as defined on page 2 of this special permit as noted: "Type A special permit segments with pipe with integrity issues as determined by Conditions 6 and 14 or that have not been pressure tested in accordance with 49 CFR Part 192, Subpart J to 1.25 times MAOP of this special permit must be replaced within two and one-half (2!/2) years of the grant of this special permit or within two (2) years of assessment finding." PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 18permit or the pipe must be replaced with pipe that meets § 192.619 within two and one-half (2%2) years of issuance of this special permit. If the pipe is then commensurate with the Class location in accordance with § 192.611(a)(3)(ii) the segment is no longer part of this Special Permit. v) If the pipeline in the special permit inspection area has experienced a seam leak or failure in the last five (5) years and no hydrostatic test meeting the conditions of 49 CFR Part 192, Subpart J was performed after the seam leak or failure, then a hydrostatic test must be performed within two and one-half (2Y2) years after the issuance of this special permit on the special permit segment pipeline25; vi) If the pipeline in any special permit segment has pipe seam conditions as noted below in (A), (B), or (C), such special permit segment pipeline shall not be eligible for this special permit: A) has unknown manufacturing processes without the greater of a 49 CFR Part 192, Subpart J hydrostatic test or a 1.25 times MAOP pressure test, or B) has low fracture toughness pipe that will not ensure ductile fracture and arrest, or C) has known manufacturing or construction issues that are unresolved [such as concentrated hard spots, hard heat-affected weld zones, selective seam corrosion, pipe movement that has led to buckling, have had past leak and rupture issues, or any other systemic issues]. vii)If the pipeline in any special permit segment has a reduced longitudinal joint seam factor, below 1.0, as defined in 49 CFR § 192.113 the special permit segment pipeline must be replaced. viii) Pipe in the special permit segments must have all weld seam or girth weld repairs that have been made by the usage of fittings such as weldolets, threadolets, repair clamps and pipe sleeves removed and replaced with pipe in accordance with 49 CFR Part 192 requirements. 25 A root cause analysis, including metallurgical examination of the pipe, must be performed for any pressure test failures or leaks from the special permit segment. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 19b) TGP must submit a seam remediation plan for the special permit segments to the appropriate PHMSA Region Director no later than 30 days after finding a seam leak in the special permit segment: i) Longitudinal weld seam remediation/repair plan that meets Condition 14(a) and includes either replacement, hydrostatic testing, or in-line inspection (ILI), and timing of the plan not to exceed six (6) months, or ii) Technical justification that shows that the special permit segment is not at risk for future longitudinal seam leaks or failures. 15) Special Permit SeRment Specific Conditions: TGP must comply with the following requirements. a) Line-of-Sight Markers: TGP must install and maintain line-of-sight markings on the pipeline in the special permit inspection areas except in agricultural areas or large water crossings such as lakes where line-of-sight signage is not practical. Line-of- sight markers must be installed within three (3) months of issuance of this special permit and replaced as necessary by TGP within 30 days after identification. b) Data Integration: TGP must maintain data integration of special permit condition findings and remediation in the special permit inspection areas. Data integration must include the following information: Pipe diameter, wall thickness, grade, and seam type; pipe coating; maximum allowable operating pressure (MAOP); class location (including boundaries on aerial photography); high consequence areas (HCAs) (including boundaries on aerial photography); hydrostatic test pressure including any known test failures; casings; any in-service ruptures or leaks; in-line inspection (ILI) survey results including HR-MFL, HR-geometry/caliper or deformation tools; close interval survey (CIS) surveys — most recent; rectifier readings; cathodic protection test point survey readings; AC/DC interference surveys; pipe coating surveys; pipe coating and anomaly evaluations from pipe excavations; stress corrosion cracking (SCC) excavations and findings; and pipe exposures from encroachments. Data integration must be outlined on pipeline route drawings with parallel sections for each integrity category and recent aerial photography (recent photography, within three (3) years of initial filing and every PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 20three (3) years thereafter). i) Data integration documentation and drawings to meet Condition 15(b) must be completed and must be submitted, if requested by PHMSA, beginning with the 2"d annual report of this special permit with four (4) years of prior data. ii) Data integration rnust be updated on an annual basis and with at least an annual review of integrity issues to be remediated. c) #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 21d) e) manufacturing dates (within a two (2) year interval) and construction dates (within a two (2) year interval). iv) The material properties determined from either destructive or non-destructive tests required by this Condition cannot be used to raise the original grade or specification of the material, which must be based upon the applicable standard referenced in 49 CFR § 192.7. v) For future special permit segments with missing MTRs or mill inspection reports, the above methodology shall be applied or TGP may elect to remove pipe joints for destructive testing27. Such testing shall be performed within one (1) year of identification of the new special permit segment. Pipeline System Flow Reversals: For long term pipeline system flow reversals exceeding 90 days where either 49 CFR § 192.619(a)(1) or § 192.611 MAOP for class location changes are exceeded28 in a speck' I permit segment, TGP shall prepare a written plan that corresponds to those applicable criteria identified in PHMSA Advisory Bulletin (ADB-2014-04), "Guidance for Pipeline Flow Reversals, Product Changes and Conversion of Service" issued on September 18, 2014 (79 FR 56121, Docket PHMSA-2014-0400). The written flow reversal plan must be submitted to the appropriate PHMSA OPS Regional Director with a copy of the plan submitted to the Federal Docket for this special permit at www.regulations.gov. TGP must receive a "no objectioe from the appropriate PHMSA OPS Region Director prior to implementing the pipeline system flow reversal through the special permit segment. Environmental Assessments and Permits: TGP must evaluate the potential environmental consequences and affected resources of any land disturbances and water body crossings needed to implement the special permit conditions for a special permit segment or a special permit inspection area prior to the disturbance. If a land disturbance or water body crossings is required, TGP must obtain and adhere to all applicable (Federal, State, and Local) environmental permit requirements when conducting the special permit conditions activity. 27 TGP must prepare a procedure in accordance with Condition 15(c) for material documentation and submit to PHMSA's OPS Region Director for "no objection". 28 An example of exceedance of 49 CFR § 192.619(a)(1) is a Grandfathered MAOP which has a design factor above 0.72. An example of exceedance of 49 CFR § 192.611 is a Class I to 3 location change. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 2216) Documentation: TGP must maintain the following records for each special permit segment and special permit inspection areas: a) b) c) Documentation showing that each special permit segment has received a 49 CFR § 192.505, Subpart J, hydrostatic test for eight (8) continuous hours and at a minimum pressure of 1.25 times MAOP (1.25 x MAOP). If TGP does not have hydrostatic test documentation, then: Type A special permit segments must be hydrostatically tested to meet this requirement within two and one-half (2 Y2) years of the issuance of this special permit, and Type B special permit segments must be hydrostatically tested to meet this requirement within five (5) years of the issuance of this special permit. Documentation of mechanical and chemical properties including pipe toughness (mill test reports) showing that the pipe in each special permit segment meets the wall thickness, yield strength, tensile strength and chemical composition of either the American Petroleum Institute Standard 5L, 5LX or 5LS, "specification for Line Pipe" (API 5L) referenced in the 49 CFR Part 192 code at the time of manufacturing or if pipe was manufactured and placed in-service prior to the inception of 49 CFR Part 192 then the pipe meets the API 5L standard in use at that time. Documentation of compliance with all the conditions of this special permit must be kept for the applicable life of this special permit for the referenced special permit segments and special permit inspection areas. 17) Extension of Special Permit Seements: PHMSA may extend each original Type B special permit segment to include contiguous segments of pipeline on either side of the Type B special permit segment where, following the issuance of this special permit, an increase in population density indicates a change in class location. Type A special permit segments may not be extended. Type B special permit segments may not be extended if the extension would redefine the extended segment as a Type A special permit segment as described in Section I of this special permit. TGP must: a) Provide notice to the Director, PHMSA OPS Standards and Rulemaking Division; PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 23b) c) d) e) Director, PHMSA OPS Engineering and Research Division; and appropriate PHMSA OPS Region Director of a requested special permit segment or ex1ension29 based on actual class location change and include a schedule of inspections, of any anticipated remedial actions and the location of the new request including survey stationing. All requests for a special permit segment or extension must be submitted in the first nine (9) months of the 49 CFR § 192.611(d) timing limits, and must include data integration (see Condition 15(b)) and information on the potential environmental impacts of the extension to determine whether an environmental assessment is required for the special permit segment extension. Complete all inspections and remediation of the proposed special permit segment extension to the extent required of the original special permit segment. Comply with all the special permit conditions and limitations included herein to all future special permit segments or extensions. New Type A special permit segments created following the grant date of this special permit must be replaced or pressure tested so that the MAOP is commensurate with the present class location as defined in 49 CFR § 192.611 within two (2) years of the class location change. Comply with all conditions of this special permit for the contiguous new special permit segments or extensions required for implementation and certification in accordance with 49 CFR § 192.611(d) timing limits, including submittal of documents to PHMSA required in Condition 18 - Certification. 18) Certification: A senior executive officer, vice president or higher, of TGP must certify in writing the following: a) b) c) TGP pipeline special pertnit inspection areas and special permit segments meet the conditions described in this special permit, The written manual of O&M procedures (required by § 192.605) for the TGP pipeline has been updated to include all additional requirements of this special permit; and TGP has implemented all Conditions as required by this special permit. 29 For a new special permit segment or extension to be considered by PHMSA, TGP must notify the appropriate PHMSA OPS Region Director to determine the need for a draft environmental assessment. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 24TGP must send the certifications required in Condition 18(a) through (c) with completion date, compliance documentation summary, and the required senior executive signature and date of signature to the PHMSA OPS Associate Administrator with copies to the Deputy Associate Administrator, PHMSA OPS Policy and Programs; appropriate PHMSA OPS Region Director; Director, PHMSA OPS Standards and Rulemaking Division; Director, PHMSA OPS Engineering and Research Division; and to the Federal Register Docket (PHMSA-2016-0004) at www.Regulations.gov within one (1) year of the issuance date of this special permit. HI. Limitations: PI IMSA modifies this special permit subject to the following limitations: 1) PHMSA has the sole authority to make all determinations on whether TGP has complied with the specified conditions of this special permit. 2) Failure to submit the certifications required by Condition 18 within the time frames specified may result in revocation of this special permit. 3) PHMSA may revoke, suspend or modify a special permit based on any finding listed in 49 CFR § 190.341(h)(1) and require TGP to comply with the regulatory requirements in 49 CFR § 192.611. As provided in 49 U.S.C. Chapter 601 and 49 CFR Part 190, PHMSA may also issue an enforcement action for failure to comply with this Order. Any work plans and associated schedules shall be automatically incorporated into this order and are enforceable in the same manner. 4) Should PHMSA revoke, suspend, or modify a special permit under 49 CFR § 190.341(h)(1), PHMSA will notify TGP in writing of the proposed action and provide TGP an opportunity to show cause why the action should not be taken. In accordance with 49 CFR § 190.341(h)(3), if necessary to avoid the risk of significant harm to persons, property, or the environment, PHMSA will not give advance notice and will declare the proposed action (revocation, suspension, or modification) immediately effective. PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 255) The terms and conditions of any corrective action order, compliance order or other order applicable to a pipeline facility covered by this special permit will take precedence over the terms of this special permit in accordance with 49 CFR § 190.341(h)(4). 6) If TGP sells, merges, transfers, or otherwise disposes of the assets known as the special permit segments or the special permit segment extension, TGP must provide PHMSA with written notice of the transfer within 30 days of the consummation date. In the event of such transfer, PHMSA reserves the right to revoke, suspend, or modify the permit if the transfer constitutes a material change in conditions or circumstances pursuant to 49 CFR § 190.341(h)(1)(ii) or any other circumstances listed under 49 CFR § 190.341(h)(1). 7) PHMSA grants this special permit to limit it to a term of no more than five (5) years from the issuance date. If TGP elects to seek renewal of this special permit, as modified. TGP must submit its renewal request at least 180 days prior to expiration of the five (5) year period to the PHMSA Associate Administrator with copies to the Deputy Associate Administrator, PHMSA Policy and Programs; appropriate PHMSA OPS Region Director; Director, PHMSA OPS Standards and Rulemaking Division; and Director, PHMSA OPS Engineering and Research Division. PHMSA will consider requests for a special permit renewal for up to an additional five (5) year period. All requests for a special permit renewal must include a summary report in accordance with the requirements in Condition 11 (Annual Report) above and must demonstrate that the special permit is still consistent with pipeline safety. PHMSA may seek additional information from TGP prior to granting any request for special permit renewal. AUTHORITY: 49 U.S.C. 60118 (c)(1) and 49 CFR § 1.97. Issued in Washington, DC on September 1, 2016. Acting Associate Administrator for Pipeline Safety PHMSA-2016-0004 Tennessee Gas Pipeline, L.L.C. Special Permit #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 26(psig) 888888888888888 750 936 088888888882888 OPID 19160 Diameter Dwellings in length not meeting present Cass Pressure Test Length (ft) 19.86 0.00 0,00 000 11.70 0.00 0.00 38: 20 321.90 6:0.76 Replace Length (ft) $43.90 12.70 168.31 606.60 1,5% 9 51530 341.20 3,157.39 674.03 536.30 1,054.07 338,70 912.96 3,130 6S 655.37 49440 521.39 607.56 1,690.82 337.90 1,118.30 ... Special Permit Segment Length not meeting resent Class (ft) 623.76 12.70 168.34 506.60 1,596.90 1,515.30 341.20 1,157.31 30672 338.70 912.96 3,142.35 655.37 494.40 521.39 607.56 1.090 82 1,349.64 659.80 1,118.30 610.76 ..... Special Permit Inspection Area Length (ft) 11183.76 10728.34 121569 10895.85 13717.39 11234.03 11366.72 11614.07 11230.87 12250.82 1240964 Latest HCA Assessment and Date N/A N/A N/A N/A N/A N/A N/A IL - 2008 N/A N/A N/A N/A 1L)/Caliper - 2009 N/A MFL/Caliper - 2013 N/A N/A N/A N/A N/A N/A N/A .... g YES 9999999999 98892999999999999999999 Class (pipe) present) pecial Permit Inspectior Area Stationing (Ending) Valve . Station 102-1A - 74753 102-1A - 76450 102-1A - 82454 108-2-39:56 108-2-40799 108-2-47319 109-2-6747 109-2 - 27586 103-3-5236 1011. 7733 109-3-14657 1093-4870 109-3 - 5277 :09-3 - 6665 109-3-32663 112-34 - 53705 112-3A - 54299 103-1. 21720 103-4-23141 874-2-76773 361 - 52190 36-1 - 53520 391 - 64182 41-1 - 1753 Page 26 of 33 chagali!: Special Permit Inspection Area Stationing (Beginning) Valve - Station 1C2-1A - 63569 102-1A - 65877 102-1A - 71756 1082-27990 108-2-28642 108-2-35243 108-2 - 39275 103-2. 35133 102-3-48140 (08-3-47663 1093 - 18960 112.2. 45273 112-3-43245 ARA. 10S1 03-4-11974 874-2-64522 36 1 - 39780 36-1-42300 40-10 - 20309 12-1 Special Permit Segment Special Permit (Ending) Valve - Station 102-1A - 69473 102-1A - 71170 102-1A - 77204 106-2-33876 108-2-35519 108-2-42039 108-2-44899 1092-22306 102-3-54095 103-3-2440 1033.0177 108-3-53995 108-3-54902 1093 - 1385 109-3-27383 112-3-48425 112-34 - 49019 103-4 - 16455 103-4-17861 874-2-71493 36-1-46310 36-1-48240 39-1-58902 3010-26,200 Segment Stationing Segment Stationing Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments Special Permit (Beginning) Valve - Station 02.1A 20R80 102-1A - 71157 102-14 - 77036 108-2-33270 108-2-33922 108-2-40523 108-2-44555 1092 - 1131 109-2-19148 102-3-53420 103-3 - 1904 103-3-8570 106-3-52941 108-3-54035 109-3-472 109-3-24240 112-3-47754 112-34 - 48525 103-4-15933 103.4. 17154 874-2-69602 36-1 - 45060 36-1-47580 39-1-57781 НЕНАИНАИННІ 833231 Une Name 1004 100-1 MADISON MADISON MADISON BATH BATH BATH ROWAN MADISON ROWAN ROWAN BOYD BOYD MADISON MADISON MADISON SABINE NATCHTOCHES State 5555555555555555555883588229333932 KM No 888888888888223333 PHMSA REGION |PHMSA No. SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHWEST SOUTHWEST SOUTHWEST#

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 27(psig) 1170 1170 8R88888888 OPID 19160 Diameter (in) Dwellings in length not meeting present Class ANY ACN Pressure Test Length (ft) 0.00 39,90 154.20 79.50 0.00 2,947.18 0.00 682.08 0.00 796.00 612.00 12.00 557.12 0.00 .......... Replace Length (t) 1,581.69 1,488.68 1,869.39 1 410 д. 2,789.70 1,505.76 1.358.93 638.14 486.50 436.76 823.33 $61.62 950.24 1,229.60 1,723.32 654.33 4,048.14 1,492.73 1,153.88 1,059.96 4,139.46 2,691.92 !.... Special Permit Segment Length not meeting present Class (ft) 1.581.69 1,488.68 1,909.29 1,439.84 2,943,90 1,585.26 2,947.18 638.34 186.50 1,118.84 823.33 461.62 1,746.24 1,541.60 1,723.32 654.33 4,060.14 1,492.73 557.12 1,059.96 4,139.45 2,691.92 ...! Special Permit Inspection Area Length (ft) 12141.69 12048.68 12069.29 11999.54 12145.26 13513.04 11688.64 11383.33 11021.62 12306.24 12413.5 1228332 11214.33 11117.12 11713.88 11619.96 14699.45 13251.92 nast MCA Antestment and Dete ... 99 9 9 9 9 9988999999899922999992 ipecial Permit Inspection Area Stationing (Ending) Valve - Station 546-1-41850 530-2 - 77807 535-2-45494 540-2 - 84430 541-2 - 5214 546-2-41854 530-3 - 77458 324-1A - 63237 324-1A - 69176 325-1A - 22117 325- 1A - 23557 326-1 - 3531 326-1 - 18759 244-1 - 27063 S1.:. 25113 252-1 - 2901 13-1-4366 14716 1046 Page 27 of 33 213-4 2154 Special Permit Inspection Area ning (Beginning 546-1 - 29708 530-2 - 65758 535-2 - 33004 78046 540 2- 530-3-65539 324-14-49724 324-1A - 58278 01. 1107 325-1 - 11B68 25-1A- 11514 326-1 - 2841 326-1 - 6452 328-1 - 23750 136-1-116 9224 15-4 154 i1111ă Special Permit segment Special Permit Segment Stationing (Ending) Valve - Station 546-3 - 36570 530-2 - 72527 535-2-40214 540-2 - 79150 540-2 - 86270 546-2 - 36574 530-1-72178 324-1A -57957 324-1A - 64196 325-1-16837 325-1-18277 325-14 - 39647 3261 - 8582 326-1 - 13479 328-1 - 30681 2361 - 7119 236-1-14012 243-1-15551 243-1-21827 244-1 - 21803 251-1 - 19837 251-1 - 35374 213-1-32095 213-1-38385 Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments Special Permit segment stationing (Beginning) Valve - Station 546-1 - 34988 530-2-71038 40-2-77730 40-2-83326 46-2-34989 530-3-70619 324-1A - 55004 24-1A - 63558 125-1-16351 21. 17135 125-1A - 38824 3261 - 8121 326-1 - 11732 128-1-29030 236-1-5396 236-1-13357 421, 11201 243-1 - 2033: 244-1-21246 251-1 - 18683 251-1-34314 213-1-27955 213-1-35693 215-1-37377 215-1-44383 TELE 46470 215-1-* 215-4- Une Name 500-2 500-2 500-2 County LOWNDES HANCOCK FORREST LAUDERDALE LAUDERDALE DOWNDES tANCOCK ¡USSEX SUSSEX USSEX ALBANY ARROLL COLUMBIANA COLUMBIANA 290222227 22 2 2= = PHIMSA REGION PHMSA No. KM No. State 3 8 0 = 308088858238858888888888888838388 OUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN SOUTHERN EASTERN EASTERN ASTERN EASTERN EASTERN EASTERN EASTERN EASTERN ASTERN#

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 28OPID 19160 ,IlleVgMMIMegiMeVgeggMMUMM.M.MRROJW,aRg?g , 17FIRWIRRIFIFWIAA:RgIgiAAAAA*AAARSIViiPPRRSLIXIng'ARSPRSIFIRRPRWIRXXX9fil ills • -• n #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 29Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments OPID 19160 PHIMANIGION PIIPASI, IDANR. Sow COmtlY Une Wit Spedel P.M* Special Permit Special Speciel Permit Special P.m* trispection SerrearitSbeharile g Segment st artloolM 94holt loo944t0 mM. K a Ste An tliselog (Entine( 10.10.0.41 ((nding) Segment Stationing IlleglimMg1 Valve - Sagan Wee -Sbtlen Wire -Station Type Valve - Union den am USIA HCAPaslisment and OM. Special Permit Special Permit Segment Length Ine spction Area not meeting benign ITN present Oen (1 t) Pressum Test Replace Ungth (ft) Oweflings In Floe length not meeting VW te r (In( present Class MAOP EASTERN 115 130 wi SAWA:A% EASTERN 176 3/2 wv KANAWHA EASTERN 177 323 sw WAYNE EASTERN 178 326 569 PUTNAM EASTERN 179 377 WV PLITRIAM EASTERN 1E0 328 WV CAREL EASTERN 1131 379 WV CABELI. EASTERN 1E2 330 XIV PIJTNAM EASTERN 183 331 WV PUTNAM SOUTHWEST 181 334 13 WALLER SOUTHWEST 195 335 HARRIS SOUTHWEST 186 336 TS HARRIS EASTERN 137 34E1 wv KANAWHA SOUTHERN 186 341 144 CHEATHAM SOUTHERN 189 342 KY MADISON SOUTHER% 190 343 KV NA.045014 SOUTHERN 193 348 MS LAUDERDALE 5001 -MESE 192 303 LA CALCASIEU {WPM) i64619) Length IN( (Ps1 12 103-1 1151 36116 118-1 - 10533 O 1161 . 64725 118-1 - 75969 YES 4,41./Caaper - 2012 11144.46 5E4.46 584 46 000 20 910 1011 121-1 - 19193 123-1-21342 6 121-1 - 13313 1214 - 26622 1 #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 30750 876.72 750 809.28 13C9.213 809.28 809.28 809.28 809.28 778.75 778.75 77875 809.28 809.24 809.28 80928 809.28 809.28 778.75 77875 936 750 750 750 1012.5 85E162 858.62 603.87 809.28 778.75 778 75 778.75 858.62 778.75 973.44 973.44 973.44 97844 936 936 936 936 936 75E17 758.7 809 28 80928 778.75 778.75 936 936 936 936 936 936 936 936 936 0.25 0.281 0.25 0.281 0.281 0.1131. 0.281 0.281 0.281 0.312 0.312 0.312 0.281 0.281 0.281 0281 0.281 0281 0.312 031.2 0.39 075 025 025 03/5 0334 0.344 025 0.281 0.312 0.312 0312 0344 0312 0 117 am) 0312 0.313 0.375 0375 0375 0.375 0.375 0.281 0.281 0.281 0.281 0312 0312 0.375 0375 0.375 0375 0.375 0.375 0.375 0.375 0.375 454 454 434 491 491 491 491 491 491 567 567 567 491 491 491 491 504 504 567 567 760 854 454 454 454 567 567 526 491 567 567 567 567 567 517 517 517 517 633 633 633 633 633 454 454 491 491 567 567 633 633 633 633 533 633 633 633 633 511410) 52000 50010 52000 52042 52000 52001 521130 52000 52000 52000 520X) 52000 621310 5.9333 52000 52000 52000 52000 52000 60000 S0003 50020 50000 45010 52000 52000 52003 5201) 52000 52007 52000 52000 52000 52000 520011 52000 52000 52000 521300 52000 52000 52003 45000 45000 52000 52000 52000 52000 52000 52000 52000 52000 52000 52003 52000 52000 52000 FW SAW Fw FW FW FW FW FW Fw ()SAW DSAW DSAW Fw FW FW FW FW FW MANN DSAW DSAW FW FW FW SNILS DSAW DSAW DSAW FW DSAW DSAW OSAW OSAW DSAW DSAW DSAW DSAW ()SAW DSAW DSAW DSAW DSAW DSAW SMLS WES FW FW MAW OSAW FW EW Fw SAW SAW DSAW SAW SAW DSAW Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 31Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segrnents OPID 19160 Pipe Distance to Segment MPS only In One orMPS. Design PliMSA No. KM No. Te st Pressum Pressure (Pail 0472 Pipe Well Thieknens (In) Pipe MLV Compressor MAOP PIR (ft) PM* Grade (PAO Pi pe Seam Type Pipe Coating installation Upstream/ Station Established per Aerial Photography Material/ Pressure Test Documents Le a k/SCC/55WC (w/I 20 rril of segment) Date Downstm• Spedng (mi) 192.619 Pressure Tested after Leak/SCC/SSWC Inspecte retold d a (to bck (11s1g) m (nti) up 'test) _ 59 150 1340 936 0.375 633 52000 DSAW COAL TAR ENAIVIEL 7959 6.6/ 89 57.5 4)13 1 7312 /1 Leak16/15/19841 NIP YES N/A 68 152 1360 936 039 760 60000 FW LIQUID EPDXY 1955 13.5 / 11 58.7 (011 1 2012 1/1 Leak (3/15/1964) YES YES N/A 61 1.53 12% 936 039 760 60000 ERW TAPE. UNKNOWN BACKING 1966 7.3 / 7.8 53.1 (MO 2012 Y / Y Leak (7/15/19E6) YES YES N/A 62 154 1294 916 0.39 7671 60000 DSAW TAPE UNKNOWN BACKING 1966 14,7 / 14 602 (a)(1) 2012 1/ Y N/A YES NIA 63 155 1E24 936 0.39 760 60 ERW TAPE- UNKNOWN BACKING 1966 15.7/ 0.0 60.2 14111 ) 2017 Y/ Y N/A YES N/A 64 1.57 139) 974.88 0.4062 7E0 50 DSAW TAPE- UNKNOWN BACKING 1964 6.6 /89 57.5 14)131 2012 Y / Y N/A YES N/A 65 158 1345 938.4 0.391 760 60000 DSAW FUSION BONDED EPDXY 1972 13.4/ 11 59.7 (a)11 1 2012 9 / 1 N/A YES N/A 66 159 1471 1560 0.5 566 52000 SAILS COAL TAR ENAMEL 195S 3.6/ 7.9 38 la)(3) 2012 9 /1 19/6 YES NIA 67 160 1471 1170 0375 566 52000 WES COAL TAR ENAMEL 1956 51/6.8 38 14110 2012 Y/Y N/A YES RI/A 68 162 1467 1170 (1375 566 52000 WES COAL TAR ENAMEL 1955 3.1 / 40 304 4113) 2012 X/ 1' N/A YES N/A 63 163 1467 1170 0.375 566 52000 SMIS COALTAR ENAMEL 19% 12/0.2 30.4 (4)(3) 2012 Y/ Y N/A YES N/A 70 164 1466 1170 0.375 566 52000 56113 COAL TAR ENAMEL 1955 17/ 0.3 30.4 (41(31 2012 1/ Y Leak (12/15/2(613) NO YES N/A 71 166 1470 1170 0.375 666 52000 SMIS COAL TAR ENAMEL 1955 1.5/ 54 814 1 41(3) 2012 1/ Y Leak (12/15/2008) NO YES N/A 72 167 1478 1170 0.375 566 52000 SMLS COAL TAR ENAMEL 1955 12/ 4.5 30.4 01(31 2012 Y /1 Leak (12/15/70081 NO YES N/A 73 168 1479 1170 0.375 566 52030 DSAW COAL TAR ENAMEL 1955 5.5 / 16 30.4 0)(3) 7012 Leak 112/15/2024) NO YES 14/ A. 74 177 1174 876.72 0.281 457 52000 FW COAL TAR ENAMEL 1951 10/ 7.6 53.6 0)131 2012 y/ y Leak (7/11/20021 NLP YES N/A 75 178 1174 876.72 13.281 457 52003 FW COAL TAR ENAMEL 1951 15/6.3 53.6 (a)(3) 2012 / Y Leak (7/11/2002) NLP YES N/A 76 179 1096 87672 0.281 451 52003 OSAW COM. TAR ENAMEL 1951 22 9.7 681 01(3) 2012 Y/y Leak (8/15/1954) YES YES N/A 77 18(1 1096 876.72 0.281 457 52000 DSAW COAL TAR ENAMEL 1951 3.9/ 66 689 1.1(3) 2012 3/ y Leak (8/15/1954) YES YES N/A 76 181 64Ps 876.72 0.281 457 52000 DSAW COAL TAR ENAMEL 1951 4.0/ 115 68-8 141 2012 1/ Ws Leak (7/15/1954) YES YES YES 79 182 1158 87672 0.281 457 52000 DSAW COAI TAR ENAMEL 1951 15/3.4 65.8 (01 31 2012 Y/ Y Leak (6/15/1972) YES YES N/A 80 183 1158 876.72 0.281 457 525831 ()SAW COAL TAR ENAMEL 1951 85/05 65.8 181(3) 2012 1/ Y leak )6/15/1972) rEs YES ti/A 81 186 11)49 809.28 0.281 504 52070 FW COAL TAR ENAMEL 1991 53/ 36 62.8 1011 ) .2012 1/ Y Leak (8/15/1974) YES YES N/A 82 187 1049 809 28 0.281 504 52000 FW COAL TAR ENAMEL 1950 6.7 / 2.8 62.8 14111 ) 2012 / Leak (8/15/1974) YES YES N/A 83 188 1073 809.28 0.281 504 52000 SW COAL TAR ENAMEL 1993 7.1 / 5.11 64.4 (RIM 2012 11 Leak (6/1 5/13771 NO YE5 N/A 64 189 1073 809.28 0281 504 52000 FW COAL TAR ENAMEL 1950 8.4 / 3.9 64.4 141(1 ) 2012 Y/y Leak 16/15/1977) NO YES N/A es 190 1073 809.28 a 281 504 52000 FW COAL TAR ENAMEL 1950 86/ 3.5 64.4 141(1 1 2012 Y/ Y Leali (5115/1977) NO YES N/A 86 191 1073 809.28 0.280 504 5E00 FW COAL TAR ENAMEL 1952 1-7/ 14.3 64.1 10(31 2012 Y/ Y Leak (5/19/2006) NO YES N/A 87 192 toss 809.28 0.2m 504 52000 FW COAL TAR ENAMEL 1952 51/4.1 626 (a)1 1 ( 11112 Y/Y N/A YES 61/6 88 193 1104 809.28 0.281 504 5200 FW FUSION BONDED EPDXY 1952 6.8/ 28 62.8 (i)(11 2012 Y/Y N/A YES N/A 89 194 1077 80128 0.281 504 521832 FW COAL TAR ENAMEL 7954 3.0/ 12.1 64.4 (4)(1 1 2012 1/ 1 , Leak (8/15/1969) NCt YES (4/A 90 195 1018 809 28 0.281 504 52000 DSAW COALTAR ENAMEL 1%6 05/ 4.7 618 W(š) 2012 1 / 9 14414 (5/20/2032) 50 YES N/A 91 196 1018 809,28 0.281 504 52000 DSAW COAL TAR ENAMEL 1956 0.8 / 4.1 62.8 )01 31 2012 Y / Y Leak (5/20/2002) NO YES N/A 92 197 1018 809.28 0.281 504 52000 MAW COAL TAR ENAMEL 1956 2.1 / 3.1 62.8 0)131 2012 Y / Y Leak (5/20/2002) NO YES N/A 93 198 1086 825.6 0.344 698 6CCOO DSAW COAL TAR ENAMEL 7963 5.3 / 3.9 62.8 (011) 2012 Y Y Leak (1 /1 0/2011) NO YES N/A 94 200 1123 825.6 0.344 698 68030 DSAW COAL TAR ENAMEL 198 6.7/ 2.8 6273 1011 ) 2012 Y/ y Leak (1110/2011) NO YEs N/A 95 201 lose 825.6 0.344 698 60000 DSAW COAL TAR ENAMEL 1963 7.1 / 5.0 648 la)(3) 2012 Y/ Y Leak 12/10/20111 NO YES PI/A 96 202 1058 8256 0.344 698 6C000 CISAW COAL TAR ENAMEL 1%3 8.4/ 31 64 4 la1131 2012 Y/ Y Leak (2/10/2011) NO YES N/A 97 203 1058 825.6 0.344 698 60000 DSAW COAL TAR ENAMEL 1963 18/ 35 64.4 lall3) 2012 I Le ak 52/ 101701.11 140 YES NIA 98 2c6 1064 809.28 0.281 504 52000 DSAW COAL TAR ENNIO. 1950 7.2/ 5.0 64.4 (a)(1) 2012 1/ Y Leak (6/15/1977) 610 YES N/A 99 206 1144 876.72 0.281 490 52000 DSAW COAL TAR ENAMEL 1953 4.3/63 70.2 1.)(1) 2012 1/ Y Le43 (V18E19571 / SCe YES / NO YES N/A 1.00 207 1144 876.72 0.261 4%1 52000 05AW COAL TAR ENAMEL 1953 5.4/ 53 70.2 M( 1 ) 2012 Y/ Leak (2/1 5/1957) / SCC1 YES / NO YES N/A 101 208 1286 898 56 0.312 613 01960 DSAW COAL TAR ENAMEL 1965 4.1 / 6.3 70.2 (0(1) 2012 Y/ Y N/A YES N/A 102 209 1286 898,56 0.312 613 6COCK) DSAW COAL TAR ENAMEL 1965 5.2/ 5.3 70.2 1 2 .1(1 .1 2012 Y / Y N/A YES N/A 103 213 1037 758.7 0.281 4)4 45000 SFALS COAL TAR ENAMEL 1944 3.5/ 14 89.8 141(1) 2012 Y / Y 1 -4. 15 (1 /1 5/1482) NO YES N/A 154 215 964 758.7 0.281 454 45000 SMLS COAL TAR ENAMEL 1944 4.0/ 6.6 89.8 (011 ) 2012 /1r '4. 1, 11 /3/192 E YES YES 1 . 06 105 216 964 758.7 0.281 454 45000 SKS COAL TAR ENAMEL 1944 7.6/ 13 89.8 4)11) 2012 Y/ Y Leak (1/3/1%13( YES YES N/A 106 217 964 758.7 0.281 454 45000 SMLS COAL TAR ENAMEL 1944 9.0/ 21 89.8 (a))1) 2012 1/ Y Leak (1/61958) YES YES N/A 100 220 964 758.7 0.281 too 45003 MALS CCIALTAREOLAMEL 1944 9.3/ 0.0 898 (A)(1 I 2012 Y / Y Leak (1/3/1888) NO YES N/A 108 221 956 758.7 0.781 454 45000 SM1.5 COAL TAR ENAMEL 1944 00/ 9.2 89.8 (031 2012 Y /1 Leak (7/3/1983) YES YES N/A 109 223 1036 809.28 0.281 491 52000 FW COAL TAR ENAMEL 1943 3.5 / 24 89.8 103( 2012 / Y Leak (10/16/1996) NO YES N/A 110 224 1036 809.28 0.281 491 52000 FW COAL TAR ENAMEL 1948 5.3 / 0.6 89.8 (0131 2012 Y/ Y Leak (10/16/1996) NO YES 111 226 1224 936 0.375 633 52903 SAW COAL TAR ENAMEL 1959 5.1/ 8.9 61.2 (0(3) 2012 Y Y Leak (6/20/2012) NIP YES N/A 112 227 1224 936 0.375 633 52000 SAW COAL TAR ENAMEL 1959 6.1 / 7.9 612 10(3) 2012 1/ Y Leak (6/20/7012) N LP YES N/A 113 228 1224 936 0375 633 52003 SAW CDAL TAR ENAMEL 1959 63/ 7.5 612 14113) 2012 Y /1 Leak (6/20/2012) NLP YES N/A 114 232 1182 936 0.375 633 52000 DSAW COAL TAR ENAMEL 1953 1.0 / 118 75.5 1683) 2012 Y 1-4.k (o/15/1966) YES YES 61/4, 115 233 1182 936 0.375 633 52000 DSAW COAL TAR ENAMEL 1959 BEI/ 10.8 75.9 103/ 2012 1/ Y Leak (6/15/1966) YES YES N/A 116 234 1182 936 0.375 633 5200D MAW COAL TAR ENAMEL 1959 82/ 106 75.9 1a03) 2012 Y/ Y Leak (W15/1%6) YES YES N/A Page 31 of 33#

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 32OPID 19160 tr.T1C g28.0 2t 1 -62 gt 11115-11illi1111-11111111 4 < 4 l444 441111111i111111111U11111.1 r".4..U5M.W,L",gU-MU;UM.MUPI:UUrt.0 ;41111111U1141112222222:- ;;;;';1;""i z 1gF_ 1% gAMMM 32 StI2S2±,2: 1411411111,-uu-L,r191!! 5 #

2016-0004 Tennessee Gas Pipeline LLC Special Permit, page 33Attachment A: Listing of Tennessee Gas Pipeline (TGP) special permit segments OPID 19160 Pipe Distance to MPS only PHMSA No. KM No. Test Pressure (psig) Design Pressure Bk 0.72 Pipe Wall Thickness (in) PIR (It) Pipe Grade (prig) Pipe Seam Type Pipe Coating Pipe Installation Data MLV Upstream/ Downstrea Compressor Station Spacing (rni) MAOP Established per 192.619 Aerial Photography Material/ Pressure Test Documents Leak/SCC/SSWC (w/i 10 mi ol segment) Segment Pressure Tested atter Leak/SCC/SSVI/C In-Line inspect. d or MPS record (to back (lksik) .1 00) up 'test') 1320 936 0.76 416 520X1 LISAW FUSION BONDED EPDXY 1984 24/ 7.1 878 1.0) 2012 Y / Y Leak (11/1/1983) Y(S YES N/A 176 322 1209 936 422 52003 DSAW FUSION BONDED EPDXY 1984 3.8 / 11 87.8 laHll 2012 Y/Y Leak (11/1/1983) YES YES N/A 177 323 1222 973.44 0.312 517 520(3) FW COAL TAR ENAMEL 1988 3.5/ 8.2 87.7 laH31 2012 V/ Y Leak (5/15/1978) YES YES N/A 178 326 1222 973.44 0 312 507 52000 FW COAL TAR ENAMEL 1948 0.11/9• 2 87.7 1.1(3) 2012 V/ V Leak (5/15/1953) YES YES N/A 179 327 1222 973.44 a312 507 52000 FW COAL TAR ENAMEL 1948 2.5/ 23 87,7 laH31 2012 Y/ Y Leak 13/15/1958) YES YES N/A 180 328 1244 990 72 0344 565 52000 FW TAPE• UNKNOWN BACKING 1559 10.0/ 7.5 89,1 MD) 2011 914 Ltak 12/1 .5/13661 YES YES N/A 181 329 1269 1246.15 0375 541 60000 Fw COAL TAR ENAMEL 19E6 70 / 15 891 lai(2) 2012 Y/Y Leak (12/15/1966) YES YES N/A 182 330 1151 910.08 0316 624 COMO DSAW FUSION BONDED EPDXY 1972 4.6/ 7.5 89.1 IM(1) 2012 Y/Y N/A YES N/A 183 331 1151 910.08 0316 624 60300 DSAW FUSION BONDED EPDXY 1972 6.0/6.5 89.1 (a)(1) 2012 Y/Y N/A YES N/A 184 334 1054 750 025 454 50000 FW COAL TAR ENAMEL 1944 2.6/ 1.1 Dig 14(3) 2012 9/ Leak M/5/20121/ Sat NO / YES YES N/A 185 335 1054 750 0.25 454 50000 FW COAL TAR ENAMEL 1944 4.3 ao 89.8 lal(3) 2012 Y /V Leak (45/20121/ SCe NO / YES YES N/A 186 336 1044 750 1125 454 5.X.30 FW COA( TAR ENAMEL 1%6 Do/ 7.3 130.8 (4131 2012 1 /V Leak (4/5/2017) I Ste NU , / 1451P YES N/A 187 340 1228 973.44 11312 508 52003 FW COAL TAR ENAMEL 1948 10.2 / 1.0 87.7 (4)13) 2012 1/ Leak (2/15/1969) YES YES N/A 188 341 1024 778.75 0.312 567 52000 (UAW COAL TAR ENAMEL 1952 8.8/ 05 91.7 (MU 2012 Y/ Y Leak (7/1 5/1331) NO YES N/A 189 342 993 778.75 0312 567 52000 MAW FUSION BONDED EPDXY 1951 14/ 7.5 88.7 (4)13) 2012 Y/ Y Leak (3/76/1995) NO YES N/A 190 343 993 778.75 0312 567 52E03 OSAW COAL TAR ENAMEL 1951 18/ 7.2 8E17 (P)13) 2012 Y/ Y Leak (3/25/1995) NO YES N/A 191 348 1302 974.88 0.4052 760 (0003 FW TAPE- UNKNOWN BACKING 1963 0.0/ 15.3 59.9 OP/ 2012 Y/ Y N/A YES N/A 192 360 1338 936 0.375 633 52000 DIAW COAL TAR ENAMEL 1955 150/ 4.6 51.1 18)113) 2012 Y/ Y sce YES YES N/A Page 33 of 33#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 1Official PDFU.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION Special Permit Analysis and Findings Class 1 to 3 Location Special Permit Information: Docket Number: PHMSA-2016-0004 Requested By: Tennessee Gas Pipeline Company, LLC Operator ID#: 19160 Original Date Requested: January 11, 2016 1st Renewal Issuance Date: March 17, 2023 Code Section(s): 49 CFR 192.611(a) and (d), 192.619(a), and 192.5 Purpose: The Pipeline and Hazardous Materials Safety Administration (PHMSA) provides this information to describe the facts of the subject special permit application submitted by Tennessee Gas Pipeline Company LLC1 (TGP), to discuss any relevant public comments received with respect to the application, to present the engineering/safety analysis of the special permit application, and to make findings regarding whether the requested renewal of this existing special permit should be granted, and if so, under what conditions. TGP requests that PHMSA waive compliance from 49 Code of Federal Regulations (CFR) 192.611(a) and (d), 192.619(a), and 192.5 for 162 segments and 36.901 miles of natural gas transmission pipeline segments. Pipeline System Affected: This special permit renewal request applies to 162 special permit segments and 36.901 miles of natural gas transmission pipeline operated by TGP and located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas, and West Virginia where a change has occurred from an original Class 1 location to a Class 3 location. 1 Tennessee Gas Pipeline Company LLC is owned by Kinder Morgan, Inc. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 1 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 2This special permit allows TGP to continue to operate the 162 special permit segments at their current maximum allowable operating pressure (MAOP). Special Permit Request: TGP submitted an application to PHMSA on March 4, 2021, for a special permit renewal seeking relief from the Federal pipeline safety regulations in 192.611(a) and (d), 192.619(a), and 192.5 for 162 special permit segments and 36.901 miles of natural gas transmission pipeline. The special permit segments are located in the states of Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas and West Virginia. Special permit segments are divided into two (2) categories: Type A special permit segments and Type B special permit segments. • Type A special permit segments include those special permit segments as described in Attachment A - Type A Special Permit Segments and Inspection Areas, where there is a cluster, as described in 49 CFR 192.5(c), of more than 10 buildings intended for human occupancy in a “class location unit” and for which the MAOP has not been confirmed in accordance with 49 CFR 192.611(a) or where the pipe installed has been identified to have a seam type or manufacturer type that is problematic for maintaining pipeline integrity. Type A special permit segments total approximately 10.192 miles (53,813.09 feet) of pipe in this proposed special permit renewal. Type A special permit segments must meet Condition 1(d) and Conditions 8(b)(i) and (c) of the Special Permit Conditions. • Type B special permit segments include those special permit segments where there is a cluster, as described in 49 CFR 192.5(c), of 10 or fewer buildings intended for human occupancy in a “class location unit” and for which the MAOP has not been confirmed in accordance with 49 CFR 192.611. Type B special permit segments total approximately 26.348 miles (139,115.00 feet) of pipe as described in Attachment A – Type B Special Permit Segments and Inspection Areas. • Special permit inspection areas are defined as a one (1) mile continuous segment on both sides of the special permit segment (Type A and Type B) plus the footage in the special permit segment. Attachment A lists the boundaries for the special permit inspection area associated with each special permit segment. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 2 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 3Subsequent to the issuance of this special permit, those special permit segments that have been pressure tested or replaced such that the MAOP has been made commensurate with the present class location as defined in 49 CFR 192.611 would no longer be included in this special permit. This special permit allows TGP to continue to operate the pipeline segments at their current maximum allowable operating pressure (MAOP) until either replaced, hydrostatically tested, or operated in accordance with the special permit conditions. The Federal pipeline safety regulations in 49 CFR 192.611(a) require natural gas pipeline operators to confirm or revise the MAOP of a pipeline segment after a change in class location. A special permit would allow TGP to continue to operate each of the 162 special permit segments at their existing MAOP’s despite a change in class location for the special permit specified time interval. Public Notice: On May 27, 2022, PHMSA posted a notice of this special permit request in the Federal Register (87 FR 32227) with a closing date of June 27, 2022. PHMSA has reviewed all public comments received for Docket Number PHMSA-2016-0004. PHMSA received public comments concerning this special permit request that have been addressed in the Final Environmental Assessment and Finding of No Significant Impact (FEA and FONSI). The TGP special permit application letter, Federal Register notice, Final Environmental Assessment, Finding of No Significant Impact, and all other pertinent documents are available for review in Docket No. PHMSA-2016-0004 in the Federal Docket Management System (FDMS) located at www.Regulations.gov. Analysis: Background: On June 29, 2004, PHMSA published in the Federal Register (69 FR 38948) the criteria it uses for the consideration of class location change waivers, now being granted through special permits. First, certain threshold requirements must be met for a pipeline section to be further evaluated for a class location change special permit. Second, the age and manufacturing process of the pipe; system design and construction; environmental, operating and maintenance histories; and integrity management program elements are evaluated as significant criteria. These significant criteria are presented in matrix form and can be reviewed in the FDMS, Docket PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 3 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 4Number PHMSA–RSPA-2004-17401. Third, such special permits will only then be granted when pipe conditions and the operator’s integrity management program provides a level of safety equal to a pipe replacement or pressure reduction. Threshold Requirements: Each of the threshold requirements published by PHMSA in the June 29, 2004, Federal Register notice is discussed below in regards to the TGP special permit petition. 1) No pipeline segments in a class location changing to Class 4 location will be considered. This special permit request is for 162 special permit segments on the TGP pipeline system where a class location change has occurred from Class 1 to Class 3 locations as defined in49 CFR 192.5(c) for cluster locations and segments outside the cluster (and inside the sliding mile for the class location) where an additional dwelling(s) have been identified. TGP has met this requirement. 2) No bare pipe will be considered. These TGP special permit segments are coated with an external protective coating. TGP has met this requirement. 3) No pipe containing wrinkle bends will be considered. There are no wrinkle bends in the special permit segments. TGP has met this requirement. 4) No pipe segments operating above 72% of the specified minimum yield strength (SMYS) will be considered for a Class 3 special permit. The special permit segments operate at or below 72% SMYS. TGP has met this requirement. 5) Records must be produced that show a hydrostatic test to at least 1.25 x maximum allowable operating pressure (MAOP). TGP will pressure test any segments that do not meet this requirement through the special permit conditions. 6) In-line inspection (ILI) must have been performed with no significant anomalies identified that indicate systemic problems. TGP will meet this requirement through the special permit conditions. 7) Criteria for consideration of class location change waiver, now being granted through special permits, published by PHMSA in the Federal Register (69 FR 38948), define a waiver inspection area (special permit inspection area) as up to 25 miles of pipe either side of the waiver segment (special permit segment). The special permit inspection area must be inspected according to TGP’s integrity management program and periodically inspected with PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 4 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 5an in-line inspection technique. The special permit inspection area extends one-mile out from either side of the special permit segments long. This additional length was used since the Type B areas that are not being replaced are locations with 10 or fewer buildings intended for human occupancy in a “class location unit” and are outside the original “cluster area”. This special permit is contingent upon TGP’s incorporation of each of the special permit segments in its written integrity management program as a “covered segment” in a “high consequence area” (HCA) per 49 CFR 192.903. Criteria Matrix: The original and supplemental data submitted by TGP for the special permit segments have been compared to the class location change special permit criteria matrix. The special permit segments fall in the probable acceptance column of the criteria matrix for all criteria except for: • Possible acceptance – pipe manufacture and pipe material • Requires substantial justification – pipe coating, Stress Corrosion Cracking Direct Assessment (SCCDA), and several leaks within 20-miles of the special permit segment. The data findings below fall within the “probable acceptance” or the “requires substantial justification” columns of the criteria matrix: 1) Pipe design and construction, including pipe manufacture, material and design stress: • TGP pipeline special permit segments have: o Pipe manufactured with the following pipe seams: low-frequency electric resistance welded, flash welded, double submerged arc welded, seamless, and electric welded pipe seams. o Pipe coatings included: coal tar enamel, hot applied wax, fusion bonded epoxy, and tape. o Pipe design stress was 72% specified minimum yield strength or lower. 2) Pipe coating, SCCDA, and several leaks: TGP will be required to conduct a stress corrosion cracking assessment (SCCDA) of the special permit segments to evaluate where the risk of stress corrosion cracking (SCC) is present. TGP will be required to implement a plan to improve cathodic protection reliability and perform inspections for SCC during excavations. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 5 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 6• To further address pipe manufacturing, material, construction, pipe coating, SCCDA, and possible pipe leak issues, this special permit will include conditions requiring TGP to treat all special permit segments as “covered segments” in an HCA per 49 CFR 192.903. • TGP will also be required to perform ILI assessments, anomaly repairs, close interval surveys, identify any pipeline segment that may be susceptible to pipe seam issues because of the vintage of the pipe, the manufacturing process of the pipe, or other issues and stress corrosion cracking direct assessment (SCCDA) along the entire length of the special permit inspection areas and special permit segments according to the requirements of 49 CFR 192.929 after the grant of this special permit. • This special permit will include a condition that TGP must continue to operate each special permit segment at or below its existing MAOP. PHMSA has determined that imposing the special permit conditions will address these concerns and provide equivalent safety for these areas. Operational Integrity Compliance: To inform PHMSA’s decision about whether a special permit could provide a level of safety greater than or equal to a pipe replacement or pressure reduction and is consistent with pipeline safety, PHMSA reviewed this special permit request to understand the known type of integrity threats that are in the special permit segments and special permit inspection areas. This integrity information was used to consider special permit conditions to provide a systematic program to review and remediate the pipeline for safety concerns. Additional operational integrity review and remediation requirements are required by this special permit to ensure that the operator has an ongoing program to locate and remediate safety threats. These threats to integrity and safety include any issues with the pipe coating quality, cathodic protection effectiveness, operations damage prevention program, pipe depth of soil cover, weld seam and girth weld integrity, anomalies in the pipe steel and welds, and material and structures either along or near the pipeline that could cause the cathodic protection system to be ineffective. PHMSA has carefully designed a comprehensive set of conditions that TGP must implement to comply with this special permit. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 6 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 7Past Enforcement History – January 1, 2011 through July 31, 2022: During January 1, 2011 through July 31, 2022, TGP was cited in 27 enforcement actions with a total of $257,600 in assessed civil penalties. PHMSA issued four (4) Corrective Action Order, six (6) Notice of Amendments, 10 Notice of Probable Violations, one (1) Safety Order, and six (6) Warning Letters to TGP. Tables 1 and 2 below shows PHMSA’s enforcement actions and civil penalties for TGP: Table 1: TGP Enforcement Matters from January 1, 2011 through July 31, 2022 Notice of Status Corrective Action Order Notice of Safety Probable Amendment Order Warning Letter Total Violation CLOSED 3 6 10 1 6 26 OPEN 1 0 0 0 0 1 Total 4 6 10 1 6 27 Table 2: TGP Enforcement Civil Penalty Status January 1, 2011 through July 31, 2022 Proposed Awaiting Order Assessed Withdrawn/Reduced Collected $384,200 $257,600 $126,600 $257,600 Summary of Enforcement Findings for TGP includes: • Atmospheric Corrosion Control: General and Monitoring; Construction: Compliance with Standards; Control Room Management: Alarm Management, Fatigue Mitigation, and Roles and Responsibilities; External Corrosion Control: Protective Coating and Test Stations; Integrity Management: Continual Process Evaluation and Assessment and High Consequence Area Identification; Maintenance: Compressor Stations-Gas Detection, Compressor Stations-Storage of Combustible Materials, Leak Surveys, Permanent Field Repair of Damage, Pressure Limiting and Regulating Stations Inspection and Testing, Relief Devices, Patrolling, Record Keeping, and Valve Maintenance; OME Procedural Manual: Emergency Plans, General, and Maintenance and Normal Operations; Operations: Continual Surveillance, Emergency Plans, General, and MAOP; Operator Qualification: Qualification Program; Public Awareness: General; Reporting: Incident Reports, Construction, and Pipeline Condition Report; Welding: Limitations on Welders and Procedures. • 49 CFR 191.15, 191.22, 191.27, 192.225, 192.229, 192.303, 192.361, 192.461, 192.469, PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 7 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 8192.479, 192.481, 192.603, 192.605, 192.613, 192.615, 192.616, 192.619, 192.631, 192.705, 192.706, 192.709, 192.713, 192.735, 192.736, 192.739, 192.743, 192.745, 192.805, 192.905, 192.921, and 192.937. Table 3 below shows PHMSA’s enforcement actions and civil penalties for TGP and the specific 49 CFR Parts 191 and 192 violations: Table 3: Summary of Enforcement Findings from TGP January 1, 2011 to July 31, 2022 Notice of Amendment Construction 1 Control Room Management 3 OME Procedural Manual 2 Operation and/or Maintenance 2 Reporting 2 Welding of Steel in Pipelines 1 Notice of Amendment Total: 11 Notice of Probable Violation Control Room Management 1 Corrosion Control 3 Integrity Management 3 OME Procedural Manual 6 Operation and/or Maintenance 3 Operator Qualification 2 Public Awareness 1 Reporting 1 Welding of Steel in Pipelines 1 Notice of Probable Violation Total: 21 Warning Letter OME Procedural Manual 3 Operation and/or Maintenance 9 Operator Qualification 1 Reporting 1 Warning Letter Total: 14 Grand Total: 46 Summary of Enforcement Findings for the Kinder Morgan Gas Pipelines Companies - CIG, EPNG, NGPL, SNG, Tejas, and TGP: From January 1, 2011, through July 31, 2022, Kinder Morgan, the operator of SNG, was cited in 64 enforcement actions with a total of $1,077,800 in assessed civil penalties on its Colorado Interstate Gas Company (CIG), El Paso Natural Gas Company (EPNG), Natural Gas Pipeline of America (NGPL), Southern Natural Gas Company (SNG), Tejas Pipeline (Tejas), and Tennessee Gas Pipeline Company (TGP) pipeline systems. PHMSA issued seventeen (17) Notice of Amendments, twenty-two (22) Notices of Probable Violations, twenty-two (22) Warning Letters, one (1) Safety Order, and nine (9) Corrective Action Orders to Kinder Morgan. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 8 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 9Tables 4 and 5 below show PHMSA’s enforcement actions and civil penalties for Kinder Morgan on these pipeline systems – CIG, EPNG, NGPL, SNG, Tejas, and TGP - with operator identification numbers (OPID#) 2564, 4280, 13120, 18516, 4900, and 19160. Table 4: Kinder Morgan Enforcement Matters from January 1, 2011 through July 31, 2022 Notice of Status Corrective Action Order Notice of Safety Probable Amendment Order Warning Letter Total Violation CLOSED 5 17 22 1 22 67 OPEN 4 0 0 0 0 4 Total 9 17 22 1 22 71 Table 5: Kinder Morgan Enforcement Civil Penalty Status January 1, 2011 through July 31, 2022 Proposed Awaiting Order Assessed Withdrawn/Reduced Collected $1,461,500 $0 $1,077,800 $383,700 $1,077,800 The type of 49 CFR Part 192 enforcement violations against Kinder Morgan on these six (6) pipeline systems from January 1, 2011 through July 31, 2022 were as follows: Summary of Enforcement Findings for CIG, EPNG, NGPL, SNG, Tejas, and TGP includes: • Atmospheric Corrosion Control: General and Monitoring; Construction: Compliance with Standards; Control Room Management: Alarm Management, Fatigue Mitigation, and Roles and Responsibilities; Design: Compressor Station Design and Construction, Pressure Relieving and Limiting Stations, and Supports and Anchors; External Corrosion Control: Cathodic Protection, Examination of Buried Pipe, Maintenance and Normal Operations, Monitoring, Protective Coating, and Test Stations; Gas Transportation: Conversion of Service, and Underground Natural Gas Storage; Internal Corrosion Control: General, Inspection Internal Surface, and Records; Integrity Management: Addressing Integrity Issues, Continual Process Evaluation and Assessment, High Consequence Area Identification, Preventative and Mitigative Measures, Program Elements, and Threat Identification; Maintenance: Compressor Stations-Gas Detection, Compressor Stations- Inspection and Testing of Relief Devices, Compressor Stations-Storage of Combustible Materials, Leak Surveys, Line Markers, Permanent Field Repair of Damage, Pressure PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 9 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 10Limiting and Regulating Stations Inspection and Testing, Relief Devices, Patrolling, Record Keeping, and Valve Maintenance; OME Procedural Manual: Emergency Plans, General, Maintenance and Normal Operations, Safety Related Conditions Reporting (SRCR); Operations: Change in Class Location, Continual Surveillance, Emergency Plans, General, MAOP, Odorization of Gas, and Overpressure Safety Devices; Operator Qualification: Qualification Program and Recordkeeping; Public Awareness: Develop and Implement Public Awareness and Documentation; Reporting: Incident Reports, Immediate Reporting Incident, Filing SRCR, Offshore Pipeline Condition Report; Welding: Limitations on Welders, Procedures, and Qualifications. • 49 CFR 191.3, 191.5, 191.15, 191.22, 191.23, 191.25, 191.27, 191.605, 192.3, 192.12, 192.14, 192.161, 192.163, 192.199, 192.201, 192.225, 192.227, 192.229, 192.303, 192.436, 192.459, 192.461, 192.463, 192.465, 192.469, 192.475, 192.479, 192.481, 192.491, 192.603, 192.605, 192.611, 192.613, 192.615, 192.616, 192.619, 192.625, 192.631, 192.705, 192.706, 192.707, 192.709, 192.713, 192.731, 192.735, 192.736, 192.739, 192.743, 192.745, 192.805, 192.807, 192.905, 192.911, 192.917, 192.921, 192.933, 192.935, and 192.937. Table 6 below gives a complete summary of the findings and the specific 49 CFR Parts 191 and 192 violations: Table 6: Summary of Enforcement Findings for CIG, EPNG, NGPL, SNG, Tejas, and TGP January 1, 2011 through July 31, 2022 Notice of Amendment Construction 1 Control Room Management 4 Integrity Management 10 OME Procedural Manual 11 Operation and/or Maintenance 2 Operator Qualification 3 Public Awareness 8 Reporting 3 Transportation of Gas 5 Welding of Steel in Pipelines 3 Notice of Amendment Total: 50 Notice of Probable Violation Control Room Management 1 Corrosion Control 13 Design 2 Integrity Management 10 OME Procedural Manual 14 Operation and/or Maintenance 26 Operator Qualification 7 Public Awareness 2 Reporting 5 Welding of Steel in Pipelines 1 Notice of Probable Violation Total: 81 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 10 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 11Table 6: Summary of Enforcement Findings for CIG, EPNG, NGPL, SNG, Tejas, and TGP January 1, 2011 through July 31, 2022 Warning Letter Corrosion Control 11 Design 1 Integrity Management 1 OME Procedural Manual 10 Operation and/or Maintenance 31 Operator Qualification 2 Public Awareness 4 Reporting 1 Transportation of Gas 1 Warning Letter Total: 62 Grand Total: 193 Findings: Based on the information submitted by TGP and PHMSA’s analysis of the technical, operational, and safety issues, PHMSA finds that granting this special permit with conditions that requires TGP to operate the 162 special permit segments on the 20-inch diameter, 24-inch diameter, 26- inch diameter, 30-inch diameter, 31-inch diameter, and 36-inch diameter Pipelines located in Kentucky, Louisiana, Mississippi, New Jersey, New York, Ohio, Pennsylvania, Tennessee, Texas, and West Virginia at their current MAOP for a Class 1 to Class 3 location change segment is not inconsistent with pipeline safety. PHMSA has designed the special permit conditions to effectively assess and remediate threats to the special permit segments and special permit inspection areas, including pressure testing, obtaining pipe material records, and conducting assessments to evaluate pipe girth welds that have not been non-destructively tested, any pipe with missing material records, and SCC. To ensure TGP properly implements the special permit conditions, TGP will be required to give PHMSA an annual review of their compliance with the special permit. PHMSA finds the issuance and full implementation of this special permit that waives the requirements of 49 CFR 192.611(a) and (d) and 192.619(a) for a class location change to a Class 3 location is not inconsistent with pipeline safety. This special permit requires TGP to implement the special permit conditions that include safety requirements on the operations, maintenance, and integrity management of the special permit segments and the special permit inspection areas. TGP will be required to implement the special permit conditions along the PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 11 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 12special permit segments and special permit inspection areas in pipeline segments that are not high consequence areas and would not normally be required by 49 CFR Part 192 to be assessed on a periodic interval for threats. Completed in Washington DC on: March 17, 2023. Prepared By: PHMSA – Engineering and Research Division PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 12 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 13Attachment A – Special Permit Segments and Special Permit Inspection Areas Type A Special Permit Segments and Inspection Areas Special Permit Segment Number Outside Line Name Inspection Area Diameter Segment Length (feet) Start Survey Station End Survey Station (Valve - SS) Inspection Area Start SS Inspection Area End SS County or Parish, State No. Year (inches) (Valve - SS) (Valve – SS) (Valve – SS) 1 (KM 69) 24 100-1 526.27 102-1A - 68947 102-1A - 69473 102-1A - 63667 102-1A - 74753 Length (Miles) 2.10 Dwellings Installed Madison, KY 3 1971 3 (KM 71) 24 100-1 168.34 102-1A - 77036 102-1A - 77204 102-1A - 71756 102-1A - 82484 2.03 Madison, KY 1 1971 4 (KM 72) 26 100-2 606.6 108-2 - 33270 108-2 - 33876 108-2 - 27990 108-2 - 39156 2.11 Bath, KY 5 1948 6 (KM 74) 26 100-2 1,515.3 108-2 - 40523 108-2 - 42039 108-2 - 35243 108-2 - 47319 2.29 Bath, KY 3 1948 7 (KM 75) 26 100-2 344.2 108-2 - 44555 108-2 - 44899 108-2 - 39275 109-2 - 597 2.07 Bath, KY 6 1948 8 (KM 76) 26 100-2 252.39 109-2 - 1131 109-2 - 1384 108-2 - 45434 109-2 - 6664 2.05 Rowan, KY 0 1948 13 (KM 82) 26 100-3 1,054.07 108-3 - 52941 108-3 - 53995 108-3 - 47661 109-3 - 4870 2.20 Rowan, KY 6 1949 14 (KM 83) 26 100-3 338.7 108-3 - 54035 108-3 - 54402 108-3 - 48755 109-3 - 5277 2.06 Rowan, KY 4 1949 15 (KM 84) 26 100-3 912.96 109-3 - 472 109-3 - 1385 108-3 - 49597 109-3 - 6665 2.17 Rowan, KY 3 1949 17 (KM 86) 26 100-3 655.37 112-3 - 47754 112-3 - 48425 112-3 - 42474 112-3A - 53705 2.12 Boyd, KY 0 1950 18 (KM 87) 26 100-3 494.4 112-3A - 48525 112-3A - 49019 112-3 - 43245 112-3A - 54299 2.09 Boyd, KY 1 1950 23 (KM 101) 24 100-1 598.4 36-1 - 47642 36-1 - 48240 36-1 - 42362 36-1 - 53520 2.11 Sabine, LA 3 1944 24 (KM 102) 24 100-1 1,118.3 39-1 - 57784 39-1 - 58902 39-1 - 52504 39-1 - 64182 2.21 Natchitoches, LA 6 1944 29 (KM 109) 26 100-2 920.8 47-2D - 10183 47-2D - 11104 47-2D - 4903 47-2D - 16384 2.17 Ouachita, LA 1 1947 46 (KM 134) 26 100-2 112.4 53-2B - 95230 53-2B - 95230 53-2B - 89950 53-2B - 100623 2.02 Washington, MS 1 1948 47 (KM 135) 26 100-2 2,073.94 53-2B - 95383 53-2B - 97457 53-2B - 90103 53-2B - 102737 2.39 Washington, MS 2 1948 50 (KM 139) 30 500-1 1,471.05 530-1 - 71188 530-1 - 72659 530-1 - 65908 530-1 - 77939 2.28 Hancock, MS 2 1959 51 (KM 140) 30 500-1 482.4 535-1 - 38349 535-1 - 38831 535-1 - 33069 535-1 - 44111 2.09 Forrest, MS 2 1959 52 (KM 141) 30 500-1 1,370.49 535-1 - 38884 535-1 - 40254 535-1 - 33604 535-1 - 45534 2.26 Forrest, MS 2 1959 60 (KM 152) 36 500-2 1,488.68 530-2 - 71038 530-2 - 72527 530-2 - 65758 530-2 - 77807 2.28 Hancock, MS 2 1965 61 (KM 153) 36 500-2 1,909.29 535-2 – 38304 535-2 – 40214 535-2 – 33024 535-2 – 45494 2.36 Forrest, MS 2 1966 75 (KM 178) 24 200-1 654.33 236-1 - 13357 236-1 - 14012 236-1 - 8077 236-1 - 19292 2.12 Ontario, NY 2 1951 82 (KM 187) 26 200-1 2,658.16 213-1 - 35693 213-1 - 38351 213-1 - 30413 213-1 - 43631 2.50 Carroll, OH 5 1950 83 (KM 188) 26 200-1 2,044.66 215-1 - 37377 215-1 - 39422 215-1 - 32097 215-1 - 44702 2.39 Columbiana, OH 8 1950 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 13 of 20 Seam Type FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW FW LF- ERW FW FW FW MAOP (psig) 750 750 750 750 750 750 750 750 750 790 790 750 750 750 750 750 936 936 936 936 936 760 790 790#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 14Type A Special Permit Segments and Inspection Areas Special Permit Segment Number Outside Diameter Line Name Segment Length (feet) Start Survey Station End Survey Station (Valve - SS) Inspection Area Start SS Inspection Area End SS Inspection Area County or Parish, State No. Year Seam MAOP (inches) (Valve - SS) (Valve – SS) (Valve – SS) 84 (KM 189) 26 200-1 1,270.1 215-1 - 44383 215-1 - 45653 215-1 - 39103 215-1 - 50933 Length (Miles) 2.24 Dwellings Installed Type (psig) Columbiana, OH 2 1950 FW 790 85 (KM 190) 26 200-1 1,382.31 215-1 - 46382 215-1 - 47765 215-1 - 41102 215-1 - 53045 2.26 Columbiana, OH 1 1950 FW 790 86 (KM 191) 26 200-2 1,513.05 205-2 - 8795 205-2 - 10308 205-2 - 3515 205-2 - 15588 2.29 Athens, OH 3 1952 FW 790 88 (KM 193) 26 200-2 2,680.73 213-2 - 35739 213-2 - 38419 213-2 - 30459 213-2 - 43699 2.51 Carroll, OH 5 1952 FW 790 89 (KM 194) 26 200-2 1,296.36 216-2 - 15651 216-2 - 16947 216-2 - 10371 216-2 - 22227 2.25 Columbiana, OH 5 1954 FW 790 109 (KM 223) 26 100-2 554.05 82-2C - 49652 82-2C - 50206 82-2C - 44372 82-2C - 55486 2.10 Dickson, TN 1 1948 FW 750 110 (KM 224) 26 100-2 177.44 82-2C - 59530 82-2C - 59708 82-2C - 54250 83-2 - 2036 2.03 Dickson, TN 1 1948 FW 750 120 (KM 238) 30 500-1 9.9 562-1 - 1259 562-1 - 1269 560-1 - 97810 562-1 - 6549 2.00 Cheatham, TN 1 1959 FW 936 128 (KM 250) 36 500-2 1,318.68 560-2 – 37151 560-2 – 38470 560-2 – 31871 560-2 – 43750 2.25 Cheatham, TN 4 1968 LF- ERW 936 129 (KM 251) 36 500-2 381.21 560-2 – 43790 560-2 – 44171 560-2 – 38510 560-2 – 49451 2.07 Cheatham, TN 5 1968 LF- ERW 936 130 (KM 252) 36 500-2 420.56 560-2 – 99604 560-2 – 100024 560-2 – 94324 562-2 – 3915 2.08 Cheatham, TN 1 1968 LF- ERW 936 151 (KM 290) 24 100-1 1,677.99 19-1 - 21876 19-1 - 24570 19-1 - 16596 19-1 - 29850 2.32 Waller, TX 5 1944 FW 750 152 (KM 291) 24 100-1 753.7 20-1 - 36048 20-1 - 36801 20-1 - 30768 20-1 - 41976 2.14 Harris, TX 2 1944 FW 750 153 (KM 292) 24 100-1 675 36-1 - 13320 36-1 - 13995 36-1 - 8040 36-1 - 19275 2.13 Sabine, TX 1 1944 FW 750 160 (KM 300) 30 100-3 1,531.99 19-3 -20924 19-3 - 23684 19-3 - 15644 19-3 - 28964 2.29 Waller, TX 4 1952 EFW 750 161 (KM 301) 30 100-3 1,727.52 19-3 - 41139 19-3 - 42867 19-3 - 35859 19-3 - 48147 2.33 Waller, TX 3 1952 EFW 750 162 (KM 302) 30 100-3 1,024.5 169 (KM 312) 24 409A-100 DONNA LINE 1,237.01 409A-101.1 - 5411 409A-101.1 - 6648 409A-101.1 - 131 171 (KM 316) 24 409A-100 DONNA LINE 1,523.74 19-3 - 49125 409A-102 - 10119 409A-102 - 4839 19-3 - 48100 19-3 - 42820 409A-102 - 11643 20-3 - 5225 2.19 Harris, TX 7 1952 EFW 750 409A-101.1 - 11928 2.23 Hidalgo, TX 76 1950 FW 933 409A-102 - 16923 2.29 Hidalgo, TX 4 1950 FW 933 172 (KM 317) 24 409A-100 DONNA LINE 1,787.31 409A-102 - 35417 409A-102 - 37204 409A-102 - 30137 409A-102 - 42484 2.34 Hidalgo, TX 9 1950 FW 933 177 (KM 323) 24 100-2 2,657.51 115-2 - 18573 115-2 - 21231 115-2 - 13293 115-2 - 26511 2.50 Wayne, WV 3 1948 FW 973 178 (KM 326) 24 100-2 1,833.55 119-2 - 3970 119-2 - 5881 118-3 - 65930 119-2 - 11161 2.35 Putnam, WV 3 1948 FW 938 181 (KM 329) 26 100-3 438.1 117-3 - 37414 117-3 - 37852 117-3 - 32134 117-3 - 43132 2.08 Cabell, WV 2 1966 FW 910 185 (KM 335) 24 100-1 1,181.7 19-1 - 47777 19-1 - 48959 19-1 - 42497 20-1 - 5235 2.22 Harris, TX 8 1944 FW 750 186 (KM 336) 24 100-1 1,351.66 20-1 - 0034 20-1 - 1386 19-1 - 43757 20-1 - 6666 2.26 Harris, TX 8 1966 FW 750 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 14 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 15Type A Special Permit Segments and Inspection Areas Special Permit Segment Number Outside Diameter Line Name Segment Length (feet) Start Survey Station End Survey Station (Valve - SS) Inspection Area Start SS Inspection Area End SS Inspection Area County or Parish, State No. Year Seam MAOP (inches) (Valve - SS) (Valve – SS) (Valve – SS) 187 (KM 340) 24 100-2 1,233.7 121-2 - 54382 121-2 - 55616 121-2 - 49102 121-2 - 60896 Length (Miles) 2.23 Dwellings Installed Type (psig) Kanawha, WV 1 1948 FW 910 191 (KM 348) 36 500-2 311.51 541-2 - 72 541-2 - 383 540-2 - 81127 541-2 - 5663 2.06 Lauderdale, MS 3 1963 FW 936 Note: FW is a flash welded pipe longitudinal seam. EFW is electric flash welded pipe longitudinal seam. LF-ERW is low frequency electric welded longitudinal seam pipe. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 15 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 16Type B Special Permit Segments and Inspection Areas Inspection Special Permit Outside Start Survey End Survey Inspection Area Inspection Area Line Length Area County or No. Year Seam MAOP Segment Diameter Station Station Start SS End SS Name (feet) Length Parish, State Dwellings Installed Type (psig) Number (inches) (Valve - SS) (Valve - SS) (Valve – SS) (Valve – SS) (Miles) 2 (KM 70) 24 100-1 12.7 102-1A – 71157 102-1A – 71170 102-1A – 65877 102-1A – 76450 2.00 Madison, KY 1 1971 SAW 750 10 (KM 78) 30 100-3 824.32 102-3 – 53270 102-3 – 54095 102-3 – 47990 103-3 – 5236 2.16 Madison, KY 4 1950 DSAW 750 11 (KM 79) 30 100-3 536.3 103-3 – 1904 103-3 – 2440 102-3 – 50762 103-3 – 7720 2.10 Madison, KY 1 1950 DSAW 750 12 (KM 80) 30 100-3 806.72 103-3 – 8570 103-3 – 9377 103-3 – 3290 103-3 – 14657 2.15 Madison, KY 1 1950 DSAW 750 19 (KM 88) 30 100-4 521.39 103-4 – 15933 103-4 – 16455 103-4 – 10653 103-4 – 21735 2.10 Madison, KY 1 1951 DSAW 750 20 (KM 89) 30 100-4 607.56 103-4 – 17254 103-4 – 17861 103-4 – 11974 103-4 – 23141 2.12 Madison, KY 2 1951 DSAW 750 21 (KM 90) 36 800-2 1,690.82 874-2 – 69802 874-2 – 71493 874-2 – 64522 874-2 – 76773 2.32 Madison, KY 3 1969 DSAW 936 27 (KM 106) 30 100-2 272.2 36-2 – 47634 36-2 – 47906 36-2 – 42354 36-2 – 53186 2.05 Sabine, LA 2 1949 DSAW 750 28 (KM 108) 31 100-2 1,121.16 39-2 – 57758 39-2 – 58879 39-2 – 52478 39-2 – 64159 2.21 Natchitoches, LA 6 1948 DSAW 604 31 (KM 111) 30 100-3 740.5 36-3 – 47480 36-3 – 48221 36-3 – 42200 36-3 – 53501 2.14 Sabine, LA 2 1951 DSAW 750 32 (KM 113) 30 100-3 1,772.33 39-3 – 57098 39-3 – 58870 39-3 – 51818 39-3 – 64150 2.34 Natchitoches, LA 6 1951 DSAW 750 33 (KM 115) 30 100-3 907.8 47-3D – 10212 47-3D – 11120 47-3D – 4932 47-3D – 16400 2.17 Ouachita, LA 1 1949 DSAW 750 34 (KM 116) 30 100-4 1,414.14 47-4D – 9988 47-4D – 11056 47-4D – 4708 47-4D – 16337 2.27 Ouachita, LA 1 1951 DSAW 750 36 (KM 118) 24 500-1 872.7 511-1 – 10843 511-1 – 11716 511-1 – 5572 511-1 – 16996 2.17 Vermillion, LA 8 1956 DSAW 973 37 (KM 119) 24 500-1 3,005.66 511-1 – 15728 511-1 – 18734 511-1 – 10448 511-1 – 24014 2.57 Vermillion, LA 10 1956 DSAW 973 38 (KM 120) 24 500-1 858.45 512-1 – 45271 512-1 – 46129 512-1 – 39991 512-1 – 51409 2.16 Iberia, LA 4 1956 DSAW 973 41 (KM 124) 30 800-1 102.57 834-1 – 77999 834-1 - 78101 834-1 – 72719 834-1 – 83381 2.02 Franklin, LA 0 1954 DSAW 936 42 (KM 125) 30 800-1 1,259.31 834-1 - 78142 834-1 - 79401 834-1 – 72862 834-1 – 84682 2.24 Franklin, LA 1 1954 DSAW 936 43 (KM 126) 30 800-1 75.63 835-1 – 694 835-1 – 797 834-1 – 80806 835-1 – 6050 2.01 Franklin, LA 1 1954 DSAW 936 44 (KM 131) 24 100-1 731.04 53-1B1 – 95339 53-1B1 – 96070 53-1B1 – 90059 53-1B1 – 101350 2.14 Washington, MS 1 1944 SMLS 750 45 (KM 132) 24 100-1 964.23 53-1B1 – 101333 53-1B1 – 102270 53-1B1 – 96053 53-1B1 – 107550 2.18 Washington, MS 1 1944 SMLS 750 48 (KM 136) 30 100-3 1,198.98 69-3 – 3436 69-3 – 4635 68-3 – 59355 69-3 – 9915 2.23 Benton, MS 2 1949 DSAW 750 49 (KM 137) 30 100-4 1,234.46 69-4 – 3494 69-4 – 4728 68-4 – 59426 69-4 – 10008 2.23 Benton, MS 2 1952 DSAW 750 53 (KM 142) 30 500-1 1,474.9 540-1 – 77758 540-1 – 79233 540-1 – 72478 540-1 – 84513 2.28 Lauderdale, MS 5 1959 SAW 936 55 (KM 144) 30 500-1 257.2 541-1 - 00042 541-1 – 00313 540-1 – 81096 541-1 – 5593 2.05 Lauderdale, MS 4 1959 DSAW 936 58 (KM 148) 30 500-1 959.21 546-1 – 26190 546-1 – 27149 546-1 – 20910 546-1 – 32429 2.18 Lowndes, MS 1 1959 DSAW 936 59 (KM 150) 30 500-1 1,581.69 546-1 – 34988 546-1 – 36570 546-1 – 29708 546-1 – 41850 2.30 Lowndes, MS 3 1959 DSAW 936 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 16 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 17Type B Special Permit Segments and Inspection Areas Inspection Special Permit Outside Start Survey End Survey Inspection Area Inspection Area Line Length Area County or No. Year Seam MAOP Segment Diameter Station Station Start SS End SS Name (feet) Length Parish, State Dwellings Installed Type (psig) Number (inches) (Valve - SS) (Valve - SS) (Valve – SS) (Valve – SS) (Miles) 62 (KM 154) 36 500-2 1,439.84 540-2 – 77710 540-2 – 79150 540-2 – 72430 540-2 – 84430 2.27 Lauderdale, MS 6 1966 DSAW 936 64 (KM 157) 36 500-2 1,585.26 546-2 – 34989 546-2 – 36574 546-2 – 29709 546-2 – 41854 2.30 Lowndes, MS 3 1964 DSAW 936 65 (KM 158) 36 500-3 1,347.37 530-3 – 70819 530-3 – 72167 530-3 – 65539 530-3 – 77447 2.26 Hancock, MS 2 1972 DSAW 936 66 (KM 159) 24 300-1 2,953.04 324-1A - 55004 324-1A – 57957 324-1A – 49724 324-1A - 63237 2.56 Sussex, NJ 10 1955 SMLS 1,170 67 (KM 160) 24 300-1 638.57 324-1A - 63558 324-1A – 64196 324-1A – 58278 324-1A - 69476 2.12 Sussex, NJ 1 1955 SMLS 1,170 68 (KM 162) 24 300-1 471.55 325-1 – 16365 325-1 – 16837 325-1 – 11085 325-1A - 22117 2.09 Sussex, NJ 5 1955 SMLS 1,170 69 (KM 163) 24 300-1 1,121.11 325-1 – 17148 325-1 – 18277 325-1 – 11868 325-1A - 23557 2.21 Sussex, NJ 8 1955 SMLS 1,170 70 (KM 164) 24 300-1 811.71 325-1A – 38824 325-1A – 39635 325-1A – 33544 326-1 – 3519 2.15 Sussex, NJ 2 1955 SMLS 1,170 71 (KM 166) 24 300-1 373.7 326-1 – 8209 326-1 – 8582 326-1 – 2929 326-1 – 13862 2.07 Sussex, NJ 2 1955 SMLS 1,170 72 (KM 167) 24 300-1 1,729.51 326-1 – 11749 326-1 – 13479 326-1 – 6469 326-1 – 18759 2.33 Sussex, NJ 2 1955 SMLS 1,170 77 (KM 180) 24 200-1 1,478.51 243-1 – 20348 243-1 – 21827 243-1 – 15068 243-1 – 27107 2.28 Madison, KY 3 1951 DSAW 760 79 (KM 182) 24 200-1 1,153.88 251-1 – 18683 251-1 – 19837 251-1 – 13403 251-1 – 25117 2.22 Albany, NY 1 1951 DSAW 760 80 (KM 183) 24 200-1 1,059.96 251-1 – 34314 251-1 – 35374 251-1 – 29034 252-1 – 2901 2.20 Albany, NY 1 1951 DSAW 760 90 (KM 195) 26 200-3 1,081.17 213-3 – 26889 213-3 – 27970 213-3 – 21609 213-3 – 33250 2.20 Carroll, OH 4 1956 DSAW 790 92 (KM 197) 26 200-3 974.2 213-3 – 35492 213-3 – 364478 213-3 – 30212 213-3 – 41746 2.18 Carroll, OH 5 1956 DSAW 790 94 (KM 200) 36 200-4 2,648.75 213-4 – 35689 213-4 – 38338 213-4 – 30409 213-4 – 43618 2.50 Carroll, OH 5 1963 DSAW 790 95 (KM 201) 36 200-4 1,950.62 215-4 – 37485 215-4 – 39436 215-4 – 32205 215-4 – 44716 2.37 Columbiana, OH 8 1963 DSAW 790 96 (KM 202) 36 200-4 1,248.52 215-4 – 44504 215-4 – 45753 215-4 – 39224 215-4 – 51033 2.24 Columbiana, OH 2 1963 DSAW 790 97 (KM 203) 36 200-4 1,358.28 215-4 – 46492 215-4 – 47844 215-4 – 41212 215-4 – 53124 2.26 Columbiana, OH 1 1963 DSAW 790 98 (KM 205) 26 200-1 1,935.75 217-1 – 38468 217-1 – 40404 217-1 – 33188 217-1 – 45684 2.37 Lawrence, PA 5 1950 DSAW 790 99 (KM 206) 24 300-1 839.87 219-2D – 22733 219-2D – 23573 219-2D – 17453 219-2D – 28853 2.16 Mercer, PA 2 1953 DSAW 877 100 (KM 207) 24 300-1 491.7 219-2D – 28609 219-2D – 29100 219-2D – 23329 219-2D – 34380 2.09 Mercer, PA 1 1953 DSAW 877 101 (KM 208) 30 300-2 875.56 219-3 – 22847 219-3 – 23723 219-3 – 17567 219-3 – 29003 2.17 Mercer, PA 2 1965 DSAW 877 102 (KM 209) 30 300-2 573.79 219-3 – 28627 219-3 – 29201 219-3 – 23347 219-3 – 34507 2.11 Mercer, PA 1 1965 DSAW 877 103 (KM 213) 24 100-1 533.33 82-1C – 18316 82-1C – 18849 82-1C – 13036 82-1C – 24129 2.10 Dickson, TN 2 1944 SMLS 750 104 (KM 215) 24 100-1 2,782.53 83-1A – 78304 83-1A – 81086 83-1A – 73024 83-1A – 86366 2.53 Cheatham, TN 10 1944 SMLS 750 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 17 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 18Type B Special Permit Segments and Inspection Areas Inspection Special Permit Outside Start Survey End Survey Inspection Area Inspection Area Line Length Area County or No. Year Seam MAOP Segment Diameter Station Station Start SS End SS Name (feet) Length Parish, State Dwellings Installed Type (psig) Number (inches) (Valve - SS) (Valve - SS) (Valve – SS) (Valve – SS) (Miles) 105 (KM 216) 24 100-1 1,490.6 83-1A – 97294 83-1A – 98785 83-1A – 92014 83-1A - 104065 2.28 Cheatham, TN 7 1944 SMLS 750 106 (KM 217) 24 100-1 28.61 83-1A – 105135 83-1A – 105164 83-1A – 99855 83-1A - 110444 2.01 Cheatham, TN 1 1944 SMLS 750 107 (KM 220) 24 100-1 668.38 84-1 – 49147 84-1 – 49815 84-1 – 438667 85-1 – 5224 2.13 Robertson, TN 5 1944 SMLS 750 108 (KM 221) 24 100-1 1,953.93 85-1 – 150 85-1 – 2103 84-1 – 44741 85-1 – 7383 2.37 Robertson, TN 10 1944 SMLS 750 111 (KM 226) 30 500-1 566.83 557-1 – 27037 557-1 – 27604 557-1 – 21757 557-1 – 32884 2.11 Lewis, TN 2 1959 SAW 936 112 (KM 227) 30 500-1 686.45 557-1 – 32179 557-1 – 32866 557-1 – 26899 557-1 – 38146 2.13 Lewis, TN 1 1959 SAW 936 113 (KM 228) 30 500-1 1,376.94 557-1 – 33305 557-1 – 34682 557-1 – 28025 557-1 – 39962 2.26 Lewis, TN 3 1959 SAW 936 114 (KM 232) 30 500-1 732.13 560-1 – 37152 560-1 – 37885 560-1 – 31872 560-1 – 43165 2.14 Cheatham, TN 1 1959 DSAW 936 115 (KM 233) 30 500-1 1006 560-1 – 42304 560-1 – 43310 560-1 – 37024 560-1 – 48590 2.19 Cheatham, TN 10 1959 DSAW 936 116 (KM 234) 30 500-1 757.26 560-1 – 43428 560-1 – 44185 560-1 – 38148 560-1 – 49465 2.14 Cheatham, TN 7 1959 DSAW 936 117 (KM 235) 30 500-1 1,332.21 560-1 - 98120 560-1 – 99452 560-1 – 92840 562-1 – 2902 2.25 Cheatham, TN 1 1959 DSAW 936 118 (KM 236) 30 500-1 633.98 560-1 – 99846 560-1 – 100480 560-1 – 94566 562-1 – 3930 2.12 Cheatham, TN 2 1959 DSAW 936 119 (KM 237) 30 500-1 994.45 562-1 – 66 562-1 – 1061 560-1 – 96617 562-1 – 6341 2.19 Cheatham, TN 5 1959 SAW 936 121 (KM 239) 30 500-1 1,339.84 562-1 – 6239 562-1 – 7579 562-1 – 959 562-1 – 12859 2.25 Cheatham, TN 1 1959 SAW 936 122 (KM 240) 30 500-1 2,474.52 563-1 – 29453 563-1 – 31925 563-1 – 24173 563-1 – 37205 2.47 Robertson, TN 6 1959 DSAW 936 123 (KM 241) 30 500-1 4,358.19 563-1 – 42160 563-1 – 46519 563-1 – 36880 563-1 – 51799 2.83 Robertson, TN 124 (KM 242) 30 500-1 1,929.95 564-1 – 14368 564-1 – 16298 564-1 – 9088 564-1 – 21578 2.37 Robertson, TN 125 (KM 243) 30 500-1 3,262.84 564-1 – 20668 564-1 – 23931 564-1 – 15388 564-1 – 29211 2.62 Robertson, TN 10 1959 10 1959 DSAW 936 4 1959 DSAW 936 DSAW 936 126 (KM 244) 36 500-2 469.38 557-2 – 27013 557-2 – 27483 557-2 – 21733 557-2 – 32763 2.09 Lewis, TN 2 1964 DSAW 936 127 (KM 245) 36 500-2 738.42 557-2 – 32134 557-2 – 32872 557-2 – 26854 557-2 – 38152 2.14 Lewis, TN 1 1964 DSAW 936 131 (KM 253) 36 500-2 502.7 562-2 – 551 562-2 – 1054 560-2 – 96661 562-2 – 6334 2.10 Cheatham, TN 6 1963 DSAW 936 132 (KM 254) 36 500-2 16.9 562-2 – 1253 562-2 – 1270 560-2 – 97362 562-2 – 6550 2.00 Cheatham, TN 1 1963 DSAW 936 133 (KM 255) 36 500-2 2,062.21 562-2 – 5535 562-2 – 7598 562-2 – 255 562-2 – 12878 2.39 Cheatham, TN 2 1963 DSAW 936 134 (KM 256) 36 500-2 1,001.81 563-2 – 29422 563-2 – 30424 563-2 – 24142 563-2 – 35704 2.19 Robertson, TN 4 1965 DSAW 936 135 (KM 257) 36 500-2 1,426.43 563-2 – 30503 563-2 – 31930 563-2 – 25223 563-2 – 37210 2.27 Robertson, TN 5 1965 DSAW 936 136 (KM 258) 36 500-2 303.7 563-2 – 42134 563-2 – 42438 563-2 – 36854 563-2 – 47718 2.06 Robertson, TN 2 1965 DSAW 936 137 (KM 259) 36 500-2 3,257.08 563-2 – 42518 563-2 – 46423 563-2 – 37238 563-2 – 51703 2.62 Robertson, TN 6 1965 DSAW 936 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 18 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 19Type B Special Permit Segments and Inspection Areas Inspection Special Permit Outside Start Survey End Survey Inspection Area Inspection Area Line Length Area County or No. Year Seam MAOP Segment Diameter Station Station Start SS End SS Name (feet) Length Parish, State Dwellings Installed Type (psig) Number (inches) (Valve - SS) (Valve - SS) (Valve – SS) (Valve – SS) (Miles) 138 (KM 260) 36 500-2 1,899.22 564-2 – 14427 564-2 – 16326 564-2 – 9147 564-2 – 21606 2.36 Robertson, TN 4 1965 DSAW 936 139 (KM 261) 36 500-2 219.1 564-2 – 20671 564-2 – 20890 564-2 – 15391 564-2 – 26170 2.04 Robertson, TN 4 1965 DSAW 936 140 (KM 262) 36 500-2 2,970.93 564-2 – 20965 564-2 – 23936 564-2 – 15685 564-2 – 29216 2.56 Robertson, TN 6 1965 DSAW 936 141 (KM 271) 30 800-1 384.62 861-1 – 44265 861-1 – 44649 861-1 – 38985 861-1 – 49929 2.07 Cheatham, TN 1 1954 EW 936 142 (KM 272) 30 800-1 581.5 861-1 – 99945 861-1 – 100526 861-1 – 94665 863-1 – 3910 2.11 Cheatham, TN 2 1954 EW 936 143 (KM 273) 30 800-1 1,104.3 863-1 – 94 863-1 – 1199 861-1 – 96711 863-1 – 6479 2.21 Cheatham, TN 6 1954 EW 936 144 (KM 275) 30 800-1 1,366.34 863-1 – 6197 863-1 – 7564 863-1 – 917 863-1 – 12844 2.26 Cheatham, TN 1 1954 EW 936 145 (KM 276) 30 800-1 968.97 864-1 – 29457 864-1 – 30426 864-1 – 24177 864-1 – 35706 2.18 Robertson, TN 4 1954 EW 936 146 (KM 277) 30 800-1 1,797.26 864-1 – 30649 864-1 – 32446 864-1 – 25369 864-1 – 37726 2.34 Robertson, TN 5 1954 EW 936 147 (KM 278) 30 800-1 4253 864-1 – 42177 864-1 – 46430 864-1 – 36897 864-1 – 51710 2.81 Robertson, TN 10 1954 EW 936 148 (KM 279) 30 800-1 1,978.36 865-1 – 14349 865-1 – 16327 865-1 – 9069 865-1 – 21607 2.37 Robertson, TN 4 1954 EW 936 149 (KM 280) 30 800-1 3,133.48 865-1 – 20783 865-1 – 23888 865-1 – 15503 865-1 – 29168 2.59 Robertson, TN 6 1954 EW 936 154 (KM 293) 24 100-1 1,539.3 36-1 – 18211 36-1 – 19750 36-1 – 12931 36-1 – 25030 2.29 Sabine, TX 8 1964 DSAW 750 155 (KM 294) 24 100-1 573.4 36-1 – 20133 36-1 – 20706 36-1 – 14853 36-1 – 25986 2.11 Sabine, TX 3 1964 DSAW 750 156 (KM 295) 30 100-2 1,574.15 19-2 – 20806 19-2 – 23619 19-2 – 15526 19-2 – 28898 2.30 Waller, TX 4 1948 DSAW 750 157 (KM 297) 30 100-2 1,220.9 19-2 – 47755 19-2 – 48976 19-2 – 42475 20-2 – 5205 2.23 Harris, TX 8 1948 DSAW 750 158 (KM 298) 30 100-2 1,962.45 20-2 – 0048 20-2 – 2010 19-2 – 43818 20-2 – 7290 2.37 Harris, TX 9 1948 DSAW 750 159 (KM 299) 30 100-2 2,597.7 36-2 – 17089 36-2 – 19687 36-2 – 11809 36-2 – 24967 2.49 Sabine, TX 7 1949 SAW 750 163 (KM 303) 30 100-3 217 20-3 – 61 20-3 – 278 19-3 – 43960 20-3 – 5558 2.04 Harris, TX 8 1952 DSAW 750 164 (KM 304) 30 100-3 1,733.65 20-3 – 398 20-3 – 2162 19-3 – 44297 20-3 – 7442 2.33 Harris, TX 8 1952 DSAW 750 165 (KM 306) 30 100-3 1,101.34 20-3 – 36121 20-3 – 37211 20-3 – 30841 20-3 – 42491 2.21 Harris, TX 2 1952 DSAW 750 166 (KM 307) 30 100-3 1,502.4 36-3 – 18156 36-3 – 19658 36-3 – 12876 36-3 – 24938 2.28 Sabine, TX 8 1964 DSAW 750 173 (KM 318) 20 100-1 1,349.06 118-1 – 50528 118-1 – 51883 118-1 – 45216 118-1 - 57075 2.26 Kanawha, WV 2 1984 DSAW 910 174 (KM 319) 20 100-1 1,228.73 118-1 – 54017 118-1 – 55245 118-1 – 48737 118-1 – 60525 2.23 Kanawha, WV 3 1984 DSAW 910 175 (KM 320) 20 100-1 584.46 118-1 – 70516 118-1 – 70534 118-1 – 64688 118-1 – 75964 2.11 Kanawha, WV 1 1984 DSAW 910 176 (KM 322) 20 100-1 2,249.91 121-1 – 19064 121-1 – 21305 121-1 – 13822 121-1 – 26546 2.43 Kanawha, WV 3 1984 DSAW 936 PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 19 of 20#

2016-0004 - Tennessee Gas Pipeline - Class 1 to 3 SP Renewal - SPAF, page 20Type B Special Permit Segments and Inspection Areas Inspection Special Permit Outside Start Survey End Survey Inspection Area Inspection Area Line Length Area County or No. Year Seam MAOP Segment Diameter Station Station Start SS End SS Name (feet) Length Parish, State Dwellings Installed Type (psig) Number (inches) (Valve - SS) (Valve - SS) (Valve – SS) (Valve – SS) (Miles) 182 (KM 330) 30 100-3 1,415.75 118-3 – 25714 118-3 – 27130 118-3 – 20434 118-3 – 32410 2.27 Putnam, WV 2 1972 DSAW 910 183 (KM 331) 30 100-3 891.2 118-3 – 31972 118-3 – 32863 118-3 – 26692 118-3 – 38143 2.17 Putnam, WV 2 1972 DSAW 910 188 (KM 341) 30 100-4 497.5 83-4B – 114836 83-4B – 115333 83-4B – 109556 84-4 – 3287 2.09 Cheatham, TN 7 1952 DSAW 750 189 (KM 342) 30 100-4 1,342.49 103-4 – 7517 103-4 – 8889 103-4 – 2237 103-4 – 14169 2.25 Madison, KY 1 1951 DSAW 750 190 (KM 343) 30 100-4 242.74 103-4 – 9445 103-4 – 9687 103-4 – 4165 103-4 – 14967 2.05 Madison, KY 1 1951 DSAW 750 Note: DSAW is double submerged arc welded pipe longitudinal seam. EW is a submerged arc welded pipe longitudinal seam. SAW is single submerged arc welded pipe longitudinal seam. SMLS is seamless longitudinal seam. PHMSA-2016-0004 – Tennessee Pipeline Gas Company, LLC Special Permit Analysis and Findings Page 20 of 20#