2019 EMP Version

Emergency Management  EMG‐PRO‐001, Management of Gas Emergencies  Issued: 7 Mar 19     an industrial accident (occurrence) that causes a death (incident type), a serious injury (incident  type) and a fire (incident type);   an operational malfunction (occurrence) that causes an overpressure (incident type) and a  release of product (incident type); or   an operational malfunction (occurrence) that causes several concurrent or immediately  consecutive overpressures (incident types).  In cases where an incident has occurred, and a second incident occurs during the response to the initial  incident (e.g. a fire occurs during the clean‐up of a spill), the second incident is considered distinct and  should be reported separately.  Incident Costs  Costs for any incident that meets the following definition under any of the NEB’s regulations are to be  reported to the Board as described below:  1. An unintended or uncontrolled release of low‐vapour pressure (LVP) hydrocarbons in excess of  1.5 m³ that extends beyond a company’s property;  2. Significant adverse effect on the environment;  3. rupture;  4. A toxic plume; and/or  5. loss of containment of any fluid from a well.  Companies will be expected to report categorized costs related to the incident as follows:   Category 1 – Actual costs (to be reported separately) related to:   o The emergency response, including containment of the incident;  o The clean‐up and remediation of the incident; and  o The repair or replacement of regulated facilities.   Category 2 – Actual or estimated value of losses or damages not included in Category 1.  Companies are expected to provide the above costs annually (calendar) beginning the year the incident  was reported and ending either when there are no further costs related to the incident or 5 years after  the incident was reported (inclusive of the year that is was reported), whichever occurs first.  Reporting of costs will be integrated into the OERS at a later date and at that time OERS will  automatically determine when companies are required to report costs. However, until the system  changes are made, the NEB will contact companies on an as‐needed basis and will provide instructions  and a standard form to report costs.      EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 49 of 54   

Emergency Management  EMG‐PRO‐001, Management of Gas Emergencies  Issued: 7 Mar 19    Written Notification A Department of Transportation Form RSPA F 7100.2 must be submitted to PHMSA electronically on the  PHMSA Portal (https://portal.phmsa.dot.gov/phmsaportallanding) website (copied to MnOPS) as soon  as practicable but no more than 30 days after discovery of a reportable incident.  When additional relevant information is obtained after the report is submitted, supplemental reports  must be submitted on the PHMSA Portal (https://portal.phmsa.dot.gov/phmsaportallanding) website as  deemed necessary with a clear reference by date and subject to the original report.  Preliminary and detailed incident reports shall be submitted to the NEB using the Event Reporting  System and in accordance with the NEB Event Reporting Guidelines.  If the online event reporting  system is not available, notification shall be made using the TSB Reporting Hotline.   PHMSA NEB/TSB (Canada) Regional Office:   901 Locust Street, Suite 462   National Energy Board  Kansas City, MO 64106‐2641   444 Seventh Avenue SW  Phone:  816‐329‐3800   Calgary, Alberta  Fax:  816‐329‐3831  T2P 0X8    Telephone: 403‐292‐4800    Toll free: 1‐800‐899‐1265    Fax: 1‐403‐292‐5503  Pipeline Emergency  Online Reporting System  24‐hour hot line at 800‐424‐8802  https://apps.neb‐one.gc.ca/ers      TSB Reporting Hotline     24‐hour hot line at 819‐997‐7887.  Fax: 819‐953‐7876  [email protected]     EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 50 of 54   

Emergency Management  EMG‐PRO‐001, Management of Gas Emergencies  Issued: 7 Mar 19    MnOPS Home Office  MnOPS Pipeline Emergency   Twin Cities Metro Area   Minnesota Duty Officer    (651) 649‐5451 (Metro)  MN Office of Pipeline Safety  444 Cedar St., Suite 147   (800) 422‐0798 (Statewide)  St. Paul, MN 55101     (651) 201‐7230   (651) 296‐9641 (FAX)  3.5. Industrial Customers Industrial customers must be contacted as soon as practical when an emergency condition on the  pipeline will impact service to the industrial facilities.  Employees responding to an emergency condition  may be faced with having to make a decision to limit or completely curtail service to industrial  customers in order to protect lives or maintain service to Priority 1 and 2 customers as defined in  Centra’s Gas Curtailment Policy which is attached in Annex 2.  The protection of life is always the  primary objective when responding to a natural gas emergency.   After public safety has been ensured  all reasonable efforts must be made to maintain service to customers in accordance with the gas  curtailment policy.   It is very important to establish and maintain communications with industrial  customers to prevent damage to equipment and protect other customer assets as much as practical.   3.6. LDC Customers LDC customers serve Priority 1 customers as defined in the Gas Curtailment Policy attached in Annex 2.   LDC customers must be contacted as soon as practical when an emergency condition on the pipeline will  impact service to their facilities.  Employees responding to an emergency condition must communicate  and coordinate with LDC and industrial customers to maintain service to as much of the system as  possible while at the same time ensuring that the provisions of the Gas Curtailment Policy are followed.    3.7. Natural Gas Supplier TransCanada must be notified whenever there is an incident that will significantly increase or decrease  the throughput on Centra’s system.    3.8. Failure Investigation – Materials Testing Laboratories     EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 51 of 54   

Emergency Management  EMG‐PRO‐001, Management of Gas Emergencies  Issued: 7 Mar 19    Whenever any material fails or there is a natural gas related incident of significance, it must be  thoroughly investigated as soon as possible to determine the cause of the failure and if any corrective  measures are required.    Material Failure  It shall be reported to Management whenever a piece of material fails to comply with the standards to  which it was originally purchased under, or fails to perform the function for which it was intended.    Management shall initiate the failure investigation.  When an investigation is to be conducted, the failed  material shall be removed with care being taken not to damage or distort the item.  The item will then  be examined to determine the cause of failure, and a report shall be filed on the results of the  examination and possible ways of preventing a recurrence of the failure.  The Custody Transfer Record  shall be used to document the chain of custody of the material as it is transported to the appropriate  testing facility.  As appropriate the Metallurgical Examination Protocol can be used as a guide to  determine the probable causes of failure.  3.9. Public   Radio ‐ US  Radio ‐ Canada  International Falls, MN  Fort Frances, ON  KSDM /KGHS  218 283‐3481   B 93 FM  Phone:    888 283‐1041   Phone :   807 274‐5341  Toll Free:   218 283‐3087  Fax:  807 274‐2033  By Fax:      Email: [email protected]  KBHW ‐Psalm 99.5  Station Manager:  [email protected]                  807‐276‐0832  Phone:    888 285‐7398  Steinbach, MB  Golden West Radio   Warroad, MN  Phone:  (204) 324‐6464  Fax:  888‐765‐7039  KKWQ  Email:    [email protected]   Phone:   218 386‐3024      Roseau, MN  WILD  218 463‐0161  Phone:    218 463‐3360  Studio:    218 463‐1977  Fax:            EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 52 of 54   

Emergency Management    EMG‐PRO‐001, Management of Gas Emergencies  Issued: 7 Mar 19  4. Emergency Management Program Continuous Review and Improvement The EMP is a living document that must be continuously monitored for changes that may be required in  procedures and stakeholder information and resources.  To accomplish this, Centra personnel will  consider potential changes that may be required in the EMP because of something that may have been  observed or learned in the day to day performance of their duties.  Any potential changes shall be  communicated to the Manager, Pipeline Operations in writing.  Minor changes such as changes in  stakeholder contact information or resources can be submitted for revision without further evaluation.   More significant changes, such as changes in roles, responsibilities and procedures must be reviewed  and evaluated by operations personnel and submitted to the Director, Pipeline operations on a  Management of Change form (Instructions)for approval.  In addition to the continuous monitoring as described above, the EMP will be formally reviewed on an  annual basis by operations staff.  This review is intended to ensure that operations personnel are  familiar with the contents and requirements of the EMP and to determine if any other changes or  revisions may be required.  As a part of the annual review, contact and resource information for all  stakeholders shall be confirmed:     Centra personnel contact information, material and equipment availability   Emergency Response Agency (Fire, Police, Ambulance, Emergency Management Agencies)  contact information and resources   Contractor contact information, qualified personnel, material and equipment availability   Customer contact information   Regulatory agency contact information, changes in regulatory requirements  Changes to the EMP shall be made in accordance with the previous paragraph.   5. Training and Coordination of Resources Centra personnel are trained in accordance with the Operator Qualification Program to ensure that they  have the necessary knowledge and technical skills to perform the tasks that may be required when  responding to an emergency condition on Centra’s system.    Centra personnel will meet with other stakeholders to:  1. Familiarize them with the requirements of the EMP and the hazards that may exist when  responding to an emergency involving Centra facilities.  2. Establish the responsibilities and resources of each of the stakeholders and how to coordinate  those resources in the event of a pipeline emergency to minimize hazards to life or property.  Because each stakeholder will have different roles and responsibilities in the event of an emergency,  training materials and/or informational materials will be developed that are tailored to each stakeholder  audience.  The general focus of the information is outlined below:    EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 53 of 54   

Emergency Management    EMG‐PRO‐001, Management of Gas Emergencies   Issued: 7 Mar 19  Gas Control  o Receiving emergency notifications  o Communications   Emergency personnel   Customers  o Gas Control priorities  o Documentation  Informational materials: EMP, Gas Control PowerPoint presentation   Emergency Response Agencies  o EMP review  o Minimizing hazards to life and property  o Roles and responsibilities  Informational materials: EMP, Pipeline Emergency Video, Emergency Responder PowerPoint  presentation   5.1. Table Top and Mock Emergencies Table top and mock exercises shall include operational elements of Centra’s management and  protection programs to anticipate, prevent, mitigate and manage conditions that may adversely affect  the safety and security of Centra’s pipelines, employees, the public, as well as property and the  environment.  5.1.1. Table Top Emergency Exercise Table top emergency exercises will be conducted on an annual basis to simulate various emergency  scenarios that could potentially occur on the transmission system.  While it is not necessary to conduct  table top exercises for all stakeholder groups, they should be conducted with Centra personnel on an  annual basis and with Emergency Response Agencies as part of the periodic liaison agenda.    5.1.2. Mock Emergency Exercise A Mock Emergency Exercise is an in‐depth enactment of a simulated emergency response scenario that  includes the participation of all stakeholders and may include the public.  The purpose of conducting a  mock emergency exercise is to further the knowledge of stakeholders with respect to what their roles  and responsibilities are when responding to an emergency on the transmission facilities. It is also a tool  used to evaluate the effectiveness of the EMP and its implementation.  Centra will conduct a mock  emergency every 3 years.    EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT.  UNCONTROLLED WHEN PRINTED.    Page 54 of 54   

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 EMG-PRO-002, Management of Non-Gas Emergencies 1.0 Purpose Emergency preparedness and response planning is intended to ensure that responses to emergencies are prompt, organized and effective. This procedure provides and identifies processes for responding to various emergencies to help ensure the safety of employees, contractors and the public, and that company assets and the environment are protected. 2.0 Scope This procedure applies to all areas of Energy Fundamentals Group, Limited Partnership, (abbreviated as EFG) operations, except for emergencies that are related to the transmission of natural gas. It also applies to all EFG employees and, contractors and visitors within EFG areas of operation. 3.0 Definitions For purpose of this procedure, Emergency means a present or imminent event that requires prompt coordination of actions or special regulation of persons or property to protect the health, safety or welfare of people or to limit damage to property or the environment. There are many different events that can create emergencies involving EFG transmission facilities. Those events could be the result of: 1. Human Activities – excavation, accidents, vandalism, terrorism, etc. 2. Acts of Nature – tornadoes, floods, wild fires, severe summer or winter weather conditions, etc. 3. Equipment/material failure – buildings, mobile equipment, tools and equipment, improper installation or operation, etc. A reportable communicable disease is a disease that can be transmitted from person to person, and by law must be reported to the applicable public health authority, e.g., measles, mumps, tuberculosis, hepatitis A, etc. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 1 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 4.0 General EFG operating areas (office/field) shall develop emergency preparedness and response processes to cover activities where there is a risk to the safety of employees and the public or a risk of damage to company assets or the environment. Such events include: • Fire and/or explosion (those not related to natural gas). • Injury or illness. • Hazardous substance release. • Weather related anomalies (e.g., storms, floods, etc.). • Security threats. 5.0 Requirements • Develop appropriate emergency procedures; see References for a list of related procedures. Also, Appendix A, Emergency Prevention, Preparedness & Response, provides additional details. • EFG employees shall be trained in appropriate emergency response situations. • Emergency procedures shall be tested periodically to determine the level of employee knowledge, speed of response and overall efficiency. • Maintain and post General Emergency Plans at designated sites. • Maintain lists of external first responder organizations. • Provide, place and maintain appropriate equipment and materials for emergency response. • Generate and maintain emergency related records in accordance with EFG’s master record retention schedule. • Review emergency preparedness plans at the start of projects and a part of contractor management. • Routinely inspect workplaces and activities. • Maintain facilities and equipment in accordance with original equipment manufacturer’s recommendations. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 2 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 6.0 Responsibilities Management • Ensure appropriate emergency procedures are developed and tested periodically. • Ensure employees are trained in emergency response processes. • Obtain and maintain appropriate equipment and materials for emergency response. • Ensure reportable events are communicated to in accordance with EFG’s GEN-PRO-004G2, Guide to Reportable Events. • Ensure contractors and visitors are aware of, and adhere to, EFG emergency management requirements and directions. Employees • Know and understand how to respond to relevant emergency processes. • Follow emergency response requirements at customer locations. • Identify and report potential and actual hazards and respond to those that are within their capability. • Seek appropriate support for a work-related injury/illness. Manager, Risk Management • Provide support in the development and maintaining of emergency preparedness and response processes. Contractors & Visitors • Adhere to EFG requirements and directions. 7.0 References • EMG-PRO-001, Management of Gas Emergencies. • GEN-PRO-003, Risk Assessment. • GEN-PRO-004, Event Management. • SAF-PRO-001, Health & Safety – General. • SAF-PRO-012, Fire Prevention & Preparedness. • SAF-PRO-018, Violence Prevention. • GEN-WI-001, Responding to Security Events. • EFG General Emergency Plans. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 3 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 9.0 Revisions Revisions are documented and tracked as part of the Integrated Management System (IMS), Business Documents process. Approval of formal company documents are managed under the IMS, Change Management process. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 4 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 Appendix A, Emergency Prevention, Preparedness & Response Prevention & Preparedness The following processes are, among other things, intended and designed to help in the prevention on emergency events: • Policies and procedures. • Training. • Inspection. • Workplace design. • Preventative maintenance. • Hiring practices. Response Possible emergency situations include fire, explosion, injury or illness, a spill or leak of a hazardous substance, weather-related situations, security threat, etc. EFG employees shall be familiar with the following six initial steps of an emergency response: EVACUATE Immediately get to a safe area. ALARM Call for help, warn others in the area. Consider procedures, barriers and PPE. PROTECT Remove victims to safety, provided it can be done safely. RESCUE Provide first aid and life-protecting measures, as warranted. REVIVE Transport to advanced medical support, as warranted. MEDICAL ASSISTANCE The flowchart on Page 7 of this procedure shows the emergency response process, at a high level. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 5 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 Appendix A, Emergency Prevention, Preparedness & Response (Continued) Response (Continued) Event Occurs – Deemed an emergency. Refer to Definitions, Emergency. Activate First Response. • People first – life and limb over things. • Secure and control the scene. Assess the Risk – Identifying exposure to loss. Determine the nature and extent of the emergency: • How widespread is the emergency? Determine if the situation is likely to spread to other operations/locations and how soon this may occur. • Determine the risk of further emergency events or the risk of further deterioration of the current situation. • Determine need to notify internal and external stakeholders, and proceed accordingly. Determine resources needs: • Assess if EFG resources are available to respond and maintain core business operations (people, equipment, materials). • Determine if alternate resources are available from another location if needed EFG resources are not readily available. Examine Feasibility of Options – Select apparently best option. Initiate secondary actions: • Control hazards. • Initiate corrective actions – perhaps initially, temporary controls. • Re-assess the situation. • Initiate secondary responders, as warranted. • Determine if an Emergency Operations Centre (EOC) is warranted, mobile or fixed. Rectify & Remediate – Restore to normal operations. • Continue with corrective actions through to the point that the emergency can be considered closed. • Initiate remediation activities to restore the situation to normal operations. • Repair and/or replace equipment and materials used in the emergency response and return them to a state of readiness. Debrief – Lessons learnt and continual improvement. • Generate formal reports and distribute accordingly (internal and external stakeholders). • Initiate any changes needed to processes as a result of debriefing outcomes. EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 6 of 7

Emergency Management Revision 1 EMG-PRO-002, Management of Non-Gas Emergencies Issued: 13 Sep 18 Appendix A, Emergency Prevention, Preparedness & Response (Continued) Emergency Response – All Events Discovery Event occurs that may Hazards constitute on • 1st. Hand emergency • Gas leak • Gas Control • Fire, explosion • 3rd. party • Over/under pressure • Natural disaster • Injury/illness • Security threat • Weather anomaly/threat • Hazardous substance release Protect Gather information & assess risk • People • Environment (Hazard ID & Assessment) • Property Respond NO Classified Determine & Declare accordingly as an • Emergency Level (1-5) emergency • Regulatory Notification ? Resources YES • In-house responders Determine initial • External responders response • EOC needs • Materials/equipment • Accessibility • Weather Command structure (single/unified) Activate response CONTROL – MITIGATE - ELIMINATE Re-assess & NO Emergency revise controlled response ? YES Restore to normal operations Repair & remediate Debrief Lessons learned Continual improvement COMMUNICATIONS EXTERNAL INTERNAL Gas Control Sr. Management Regulators Workers’ Compensation Insurers Employees Shippers LDC Suppliers (TCPL) Land Owners General Public EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 7 of 7

EMP  Hazard Risk Analysis  Gas Curtailment Policy  List of Annexes   Facility Emergency Plans  Forms  Annex 01  Landowner Information  Annex 02  (Empty)  Annex 03  Metallurgical Failure Examination  Annex 04  Planholder List  Annex 05  Contact Reference  Annex 06  EMP Summary for Emergency Responders  Annex 07  External Resources  Annex 08  Maps  Annex 09  Annex 10  Annex 11  Annex 12     

EMP  Hazard Risk Assessment    List of Annexes       Annex 01                                       

Risk Management :  Screening Level Risk Assessment 2017 Emergency 2017 Emergency Managment Risk Assessment  Trigger Assessment Hazard Hazard Description Date Emergency Management - General - 2017  (13 Risk Assessments)  09-25-2017 Unqualified Employees lack training and experience Lack of Training 09-25-2017 employees required for a qualified response to an Insufficient exerc 09-25-2017 emergency. Inadequate tools, 09-25-2017 equipment, and Tools, equipment and materials required to Inadequate tools 09-25-2017 readily available mitigate an emergency, either owned by the materials to resp 09-25-2017 materials. company or available through purchase, are minimize the effe Unreliable not readily available. emergency. communications Unreliable communications due to Lack of reliable c Inadequate inadequate access to reliable methods in the a procedures communications technologies in remote areas may prevent timely response of Inadequate public personnel and external resources to an awareness measures emergency. Hazardous Gas Levels Emergency Program and Procedures lack Employees do no Inside Buildings necessary information to assist personnel procedures that when responding to an emergency. provide an adeq an emergency co Insufficient communication with the public Public does not k and other stakeholders regarding respond in the e recognizing and reporting emergency emergency. conditions and preventing an emergency condition. Explosive/flammable levels of gas inside a Gas leak inside b structure caused by leaks inside the structure migrating gas fro or gas migrating from a leak outside the structure. 09-26-2017 Fire near or directly Fire associated with a gas facility or fire from Weather Related involving pipeline an external source that jeopardizes the safe Third Party Dama facility operation of the facility. Outside Force Incorrect Operat Equipment defec Sabotage and te 09-26-2017 Explosion near or Explosion associated with the gas facility or Blasting near pip directly involving an explosion from an external source that Weather Related pipeline facility jeopardizes the safe operation of the facility/ Third Party Dama Outside Force Incorrect Operat Equipment defec Sabotage and te

y Managment Risk Assessment FEB-19-2019 2:57 PM Current Process Controls Residual Residual Residual Frequency Consequence Risk cises conducted Training 3 12 36 Conduct exercises 3 12 36 Contractor orientation 3 24 8 s, equipment, Emergency Tools, Materials and 3 24 pond to and Equipment List 3 8 24 Emergency Tools, Materials and 2 8 24 ects of an Equipment Inventory 12 3 24 communications Multiple modes of 8 area of the pipeline. communication (cell, onstar, 2 24 fleetnet radios) 12 Gas Control ot have the Emergency Management are required to Procedures quate response to Program Audits and Reviews ondition. Public Awareness Program know how to Landowner Mailings event of an Community Events Newspaper ads building or Integrity Management Program om an outside leak (including integrity procedures which include operations and maintenance procedures) Employee Training Gas detection equipment d Damage Vegetation Management age Public Awareness Employee Training tions Emergency Responder liaison cts and malfunction Security Management errorism peline Public Awareness/Damage d Damage Prevention Employee Training age Integrity Management Security tions Gas Control cts and malfunction errorism

Assessment Hazard Hazard Description Trigger Date Inadequate financial resources Company financial resources including Lack of financial 09-25-2017 working capital, insurance, etc. are not Inadequate insur adequate to cover the cost of mitigating the 09-26-2017 Hazardous leak emergency and resulting consequences. Pipeline failure re outside hazards identifie Explosive/flammable levels of gas outside Integrity Manage causing a safety hazard and potential assessment disruption of service. 09-25-2017 Inadequate liaison Insufficient liaison activities between Emergency resp with emergency company personnel and emergency knowledge to ad response agencies response personnel  to learn each others to an emergency capabilities, responsibilities and resources for responding to an emergency. Employees lack k response capabi of emergency re 09-26-2017 Dangerously high Pressures exceeding the maximum operating Pressure regulat system pressures pressure of piping and equipment Process control f potentially causing failure or damage. Sabotage or terr 09-26-2017 Dangerously low Low system pressures that jeopardize the Service interrupt system pressures safe operation of the system potentially TCPL resulting in loss of service to shippers and Weather Related their customers. Third Party Dama Outside Force Incorrect Operat Equipment defec Sabotage and te

reserve Current Process Controls Residual Residual Residual rance Emergency reserves Frequency Consequence Risk Insurance 2 8 16 resulting from Integrity Management Program 2 8 16 ed in Public Awareness/Damage Prevention Program ement risk Employee Training Gas detection equipment ponse agencies lack Informational mailings to 3 4 12 dequately respond emergency response agencies. y. Meetings with response agencies (three years) knowledge of the Mock exercises involving ilities response agencies. esponse agencies. ing and relief failure Integrity Management Program 1 12 12 failure Pressure regulating and relief rorism systems Employee training Gas Control Security Management tion/reduction from Integrity Management Program 1 44 Employee Training d Damage Gas Control age tions cts and malfunction errorism

EMP    Gas Curtailment Policy  List of Annexes           Annex 02                                   

Natural Gas Curtailment Policy PURPOSE In the unlikely event that Energy Fundamentals Group (EFG) determines the natural gas supply contained within the natural gas transmission line is insufficient to meet the total customer demands; the public interest requires that the curtailment of gas to customers be controlled in a manner which will consider customer priority consistent with guidelines established by regulatory authorities. EFG shall determine the quantity of gas which each customer shall be entitled to receive and promptly notify each affected customer regarding the curtailment and period covered. Such notice shall be given as far in advance as possible. EFG may change the curtailment period and quantity of gas the customer may be entitled to if conditions require. APPLICABILITY The Natural Gas Curtailment policy applies to all EFG customers and is premised on the fact that natural gas deliveries will be curtailed in consideration of the end-use of the natural gas. DEFINITIONS Priority 1 Customer Any person who uses natural gas or local distribution company (LDC) who resells natural gas for use in the following high priority classifications: 1. In a residence; 2. In a small commercial establishment; 3. In a school or a hospital; or 4. For police protection, for fire protection, in a sanitation facility or a correctional facility. In the case of an LDC, if necessary, the volume of natural gas that LDC’s are entitled to receive shall be based on the amount of gas required to serve high-priority classifications as defined above. Examples of small commercial establishments are businesses that are primarily engaged in wholesale or retail trade, agriculture, forestry, fisheries, transportation, communications, sanitary services, finance, insurance, real estate, personal services, government, etc. Priority 2 Customer Any customer whose use of natural gas has been certified by the United States Secretary of Agriculture as an essential agricultural use unless the use of an alternative fuel is economically practicable and reasonably available as determined by FERC in conjunction with the Secretary of Agriculture. Priority 3 Customer Date: IMS Program: Manual Title: Section: Page: Annex 2 1/2 22 April 2015 2 Emergency Management Program Controlled Copy - Do Not Duplicate Confidential - Not to be released outside of Energy Fundamentals Group

Natural Gas Curtailment Policy Large commercial and industrial customers primarily engaged in power production or in a process which creates or changes raw or unfinished materials into another form or product. This includes mining and manufacturing. CURTAILMENT PROCEDURES 1. Deliveries to Priority 1 customers will not be reduced until deliveries to Priority 2 and Priority 3 customers have been fully reduced. 2. Deliveries to Priority 2 customers will not be reduced until deliveries to Priority 3 customers have been fully reduced. 3. Available capacity will be divided between Priority 3 customers on a pro rata basis according to customers’ current contract entitlements unless another mutually agreeable arrangement can be negotiated between the customers for an alternative capacity distribution that better serves the needs of the customers at the time of curtailment. 4. In the event that a delivery capacity limitation is applicable only to a specific segment of the pipeline or area then the reductions prescribed above may be limited to that segment or area. 5. Variations in the reduction of deliveries as described above shall be permitted by EFG when necessary to respond to emergency situations where supplemental deliveries are required to forestall irreparable injury to life or property; provided, however, that when supplemental deliveries are made EFG shall balance out such supplemental deliveries by increased delivery reductions as long as those reductions do not result in an emergency situation on another part of the system. Date: IMS Program: Manual Title: Section: Page: Annex 2 2/2 22 April 2015 2 Emergency Management Program Controlled Copy - Do Not Duplicate Confidential - Not to be released outside of Energy Fundamentals Group

EMP      List of Annexes   Facility Emergency Plans            Annex 03                               

Annex 03 – Facility Emergency Plans   {Redacted – Security} 

EMP      List of Annexes     Forms              Annex 04                           

Annex 04 – Forms   Custody Transfer  Emergency Response Checklist  Material Safety Data Sheet  MnOPS Field Damage Report 

Custody Transfer Record Project Number Owner of Material Origin of Record Description of Item(s) Date: By: Released by: Received by: Company Name Date Name Company Date Note alterations to materials: By:

Emergency Response Checklist Below are the basic steps to be followed by Centra personnel when responding to an emergency involving the natural gas system: Initial Response: Depending on who receives initial notification Gas Control or Centra personnel will act to respond to and confirm the emergency by: □If Gas Control receives the initial call evaluate the validity and impact of the emergency by assessing system throughput and checking available system monitoring points for abnormal operating conditions. □Centra personnel are dispatched to the site of the potential emergency. □Upon arrival make an immediate assessment for protection of people (including yourself). □Declare initial emergency level: □ Level 5 No identified hazard to life or property (contained to Centra facilities) □Level 4 Potential hazard to life or property (outside assistance required call 911) □Level 3 Immediate hazard to life or property (major response required call 911) Protect Life □Move people and personnel away from the immediate area of the emergency to a safe location. (800 foot EPZ unless an assessment results in a greater or lesser distance) □Call 911 to dispatch required emergency response agencies to scene if not already on site and inform of any existing injuries or casualties. □Determine the extents or perimeter of the emergency by checking the surrounding area for hazardous conditions such as leaks inside and outside buildings and immediately evacuate areas that are found to be hazardous or could potentially become hazardous.

Emergency Response Checklist □Manage the system operation by assisting with both manual and remote adjustments to primarily minimize hazards to life and then property (including emergency shutdown or pressure reduction as necessary) and to meet the requirements of Field Operations and customers on a best efforts basis. □If long term facilities are required to safely accommodate evacuees, employees will work with local officials to locate appropriate accommodations. Protect Property After life safety concerns have been addressed, initiate actions that will protect property that may be involved in the emergency: □Remove ignition sources and ventilate structures that contain hazardous levels of natural gas if it can be done safely. □Identify the source of the leak or other hazard and take actions to mitigate the hazards implementing any operational changes such as isolating facilities or reducing pressures as can be accomplished safely to reduce or eliminate the hazard while minimizing the effect on service to customers. In extreme emergencies, the decision may have to be made to make operational changes that curtail services to customers. This shall be done in accordance with the company’s Gas Curtailment Policy. □Coordinate communications between operations personnel, Gas Control and emergency responders to ensure that two-way communications are maintained. For larger emergencies establish an Emergency Operations Center (EOC) and implement the Incident Command System section of the Emergency Management Program. □Any emergency that meets the criteria for an “Incident” as defined by PHMSA or the NEB must be reported in accordance with Section 2.5.4 of the Emergency Management Program. Contact EFG Management Personnel as soon as practicable with detailed information about the event for reportable incident determination. Management personnel will make notifications to regulatory authorities as required (within 1 hour of determining that the incident is reportable). □Utilize members of the Gas Control Emergency Team in order to advise customers and suppliers of any reduction in system capacity that affect either supply or delivery and recommend initiation of curtailment of interruptible customers and/or Force Majeure to the Project Team Leader in order to match consumption to impaired throughput. □Request support as needed by the operations personnel

Emergency Response Checklist □Re-assess Emergency Level and revise as appropriate informing other responders of any changes. □Level 5 □Level 4 □Level 3 □Initiate Remedial Operations After life and property are protected remedial operations may begin. In some cases, this will include contacting contractors, consultants, engineers, pipeline operators and other additional resources that will be necessary to conduct remedial operations to further control the emergency and repair the facilities involved in the emergency. Contact information for various resources can be found in the Communications Protocol section of the Emergency Management Program. □Use the Communications Protocol in the Emergency Management Program to keep the appropriate stakeholders including customers, public officials, regulatory agencies and the general public apprised of ongoing emergency operations. □Restoration of Service After the emergency is rendered safe and if service to any segment of the system is interrupted, employees shall follow procedures to safely reinstate service. Restoration of service shall be done in accordance with INT-PRO-017 System Startup and Shutdown. □Conduct post event assessment and initiate Management of Change Procedures to modify procedures as necessary to prevent recurrence.

Material Safety Data Sheet – Natural Gas 24 Hr. Company Contact: . . . . . . . . . . . . . . . Operations - (888) 852-3194 Emergency Contact: . . . . . . . . . . . . . . . . . . Gas Control - (800) 770-3039 SECTION #1 - IDENTIFICATION Product: Natural Gas CAS Number: 74-82-8 Chemical Family: Aliphatic Hydrocarbon, Alkane Series Synonyms: Methane, Fuel Gas, Marsh Gas SECTION #2 - HAZARDOUS CHEMICAL COMPONENTS % Material CAS# Exposure Limit Simple asphyxiant (ACGIH) > 90 Methane 74-82-8 Simple asphyxiant (ACGIH) <5 Ethane 74-84-0 1000 ppm PEL (OSHA) Simple asphyxiant (ACGIH) <1 Propane 74-98-6 This product is hazardous according to OSHA, 29 CFR 1910.1200. This product normally contains no hazardous components, other than methane, as defined in OSHA 29 CFR §1910.1200 (i.e., greater than 1%). This product may contain small amounts of heavier hydrocarbons. This product and/or components present at concentrations greater than 0.1% are not carcinogenic according to OSHA, IARC, or NTP. Components of this product are normally within the ranges listed above, however, depending on the geographical source, gas composition may vary. SECTION #3 - PHYSICAL DATA Boiling Point: -259 F, 162 C Vapor Pressure: N/A - Gas Gas Density (Air = 0.6 1) Specific Gravity: N/A - Gas Solubility (H2O): Very slightly soluble Evaporation Rate: Gas at normal ambient conditions Appearance: Colorless gas at normal temperature Odor: Odorless. If the local utility company has added an odorant, then an unpleasant smell resembling that of rotten eggs or garlic, is present.

SECTION #4 - FIRE FIGHTING & EXPLOSION DATA Flash Point: 306 F, 187.8 C Auto Ignition: 1004 F, 540 C Flammable Limits in 5% (lower) Air: 15% (upper) Unusual Fire and This gas is extremely flammable and forms flammable mixtures with air. It will burn in the Explosion Hazards: open or be explosive in confined spaces. Its vapors are lighter than air and will disperse. A hazard of re-ignition or explosion exists if flame is extinguished without stopping the gas flow. Extinguishing Stop the flow of gas. Dry chemical, CO2, or halon. Water can be used to cool the fire but Media: may not extinguish the fire. Special Fire Fighting Evacuate area upwind of source. Stop gas flow and extinguish fire. If gas source cannot be Instructions: shut off immediately, equipment and surfaces exposed to the fire should be cooled with water to prevent overheating and explosions. Control fire until gas supply can be shut off. SECTION #5 - HEALTH HAZARD DATA Exposure Limits: See Section # 2. Effects of Single Overexposure: Swallowing: This product is a gas at normal temperature/pressure. No potential for ingestion expected. Solid and liquefied forms of this material and pressurized gas can cause freeze burns. Skin Absorption: This material is not expected to be absorbed through the skin. Solid and liquefied forms of this material and pressurized gas can cause freeze burns. Inhalation: Exposure may produce rapid breathing, headache, dizziness, visual disturbances, muscular weakness, tremors, narcosis, unconsciousness, and death, depending on the concentration and duration of exposure. Skin Contact: Non-irritating, but liquid forms of this material and pressurized gas can cause frostbite, blisters and redness. Eye Contact: This gas is non-irritating; but direct contact with liquefied/pressurized gas or frost particles may produce severe and possible permanent eye damage from freeze burns. Effects of Repeated Overexposure: Medical Conditions Personnel with pre-existing chronic respiratory diseases should avoid exposure to this Aggravated by material. Overexposure: Emergency and First Aid Procedures:

Swallowing: This product is a gas at normal temperature/pressure and not expected to present a swallowing hazard. Skin: Frozen tissues should be flooded or soaked with warm water. DO NOT USE HOT WATER. Cryogenic burns that result in blistering or deeper tissue freezing should be promptly seen by a doctor. Inhalation: Immediately move personnel to area of fresh air. For respiratory distress, give air, oxygen, or administer CPR (Cardiopulmonary Resuscitation) if necessary. Obtain medical attention if breathing difficulties continue. Eyes: Methane gas is not expected to present an eye irritation hazard. If contacted by liquid/solid, immediately flush the eye(s) gently with warm water for at least 15 minutes. Seek medical attention if pain or redness persists. SECTION #6 - REACTIVITY & POLYMERIZATION Stability: Stable Conditions to Avoid:High heat, open flames and other sources of ignition. Explosive reactions can occur between natural gas and oxidizing agents. Spontaneous ignition with chlorine dioxide. Incompatibility Barium peroxide, chlorine dioxide and strong oxidizing agents. (materials to avoid): Hazardous Combustion may produce carbon monoxide, carbon dioxide and other harmful substances. Combustion or Decomposition Products: Hazardous None Polymerization: SECTION #7 - SPILL, LEAK, & DISPOSAL PROCEDURES Steps to be Taken in Eliminate all potential sources of ignition. Handling equipment and tools must be the Event of Spills, grounded to prevent sparking. Evacuate all non-essential personnel to an area upwind. Leaks, or Release: Equip responders with proper protection equipment (as specified in Section # 8) and advise of hazards. Stop sources of release with non-sparking tools before attempting to put out any fire. Ventilate enclosed areas to prevent formation of flammable or oxygen- deficient atmospheres. Water spray may be used to cool equipment or reduce gas accumulation. Waste Disposal Disposal of containerized gas may be disposal of a hazardous waste. Disposal should be Procedures: made in accordance with all applicable federal, state, and local laws and regulations. SECTION # 8 - SPECIAL PROTECTION MEASURES Ventilation: Local exhaust and general room ventilation may both be essential in work areas to prevent accumulation of explosive mixtures. If mechanical ventilation is used, electrical equipment must meet National Electric Code requirements. Eye Protection: Use chemical-type goggles and face shields when handling liquefied gases. Safety glasses

and/or face shields are recommended when handling high-pressure cylinders and piping systems or whenever gases are discharged. Skin Protection: Use of fire retardant clothing (FRC) is advised when an ignitable mixture may be present due to leaks or other releases. If there is a potential for contact with high concentrations of compressed gas, use insulated, impervious plastic or neoprene-coated canvas gloves and protective gear (apron, face shield, etc.) to protect hands and other skin areas. Respiratory For excessive gas concentrations, use only NIOSH/MSHA approved, self-contained Protection: breathing apparatus. Work/Hygiene Emergency eye wash fountains and safety showers for first aid treatment of potential Practices: freeze burns should be available in the vicinity of any significant exposure from compressed gas release. Personnel should not enter areas where the atmosphere is below 19.5 vol. % oxygen without special procedures/equipment. Respirator use should comply with OSHA 29 CFR 1910.134 or equivalent. SECTION #9 - SPECIAL PRECAUTIONS - STORAGE & HANDLING Storage and Store and use cylinders and tanks in well-ventilated areas, away from heat and sources of Handling ignition. No smoking near storage or use. Follow standard procedures for handling Conditions: cylinders, tanks, and loading/unloading. See NFPA #58 and API 2510. Fixed storage containers must be grounded and bonded during transfer of product. Naturally Occurring This product may contain Naturally Occurring Radioactive Material (NORM) and Radioactive Material customers should be aware of the potential for NORM within their processing system. The (NORM): actual concentration of NORM in the product is dependent on the geographical source of the natural gas and storage time prior to its delivery. Process equipment (e.g., lines, filters, pumps and reaction units) may accumulate radioactive daughters and emit gamma radiation during operation. Equipment emitting gamma radiation may be presumed to be internally contaminated with alpha-emitting decay products that may be a hazard if inhaled or ingested. Consult applicable NORM regulations for worker protection guidelines and handling requirements before initiating maintenance operations that require opening contaminated equipment. SECTION #10 - SHIPPING INFORMATION Proper Shipping Name: Methane, Compressed Hazard Class: 2.1 DOT Identification Number: UN1971 DOT Shipping Label: Flammable Gas (red)

FIELD DAMAGE REPORT Date: Report By: Company: Representative Name: Address: Other Phone: City, State, Zip: Phone: Damage Date & Time: Facility Damaged: Photographs: Y N Extent of Damage: Nearest Intersection: Damage Location: Municipality: Locate #: Joint Trench: Y N Marked w/ Paint Flags Stakes No Marks Visible Markings: N/A Accurate Not Accurate, marks off by (distance):_________________ Excavation Type: Plowing Boring Drilling Open Trenching On Going/Extended Project Y N Emergency Response to Incident Y N Injury or Property Damage Y N Excavator reported damage To Utility Owner Y N White Markings Used Y N Facility Maps / Records Accurate Y N Cause of Damage and Reason for Excavation – Check one each Category and one each Subcategory Cause Reason 1) No Locate Requested 1) Street / Road Work 1a) Locates were not requested 2) Sewer / Water Work 1b) Relying on someone else’s ticket 3) Utility Installation / Maintenance 1c) Excavated prior to legal start time 4) Commercial / Industrial Construction 1d) Expired Locate / Ticket 5) Residential Construction 1e) Excavation outside requested area 6) Landscaping 2) No Hand Digging /Hit While Excavating 3) Marks Not Maintained By Excavator 4) Failure to Support and Protect Facility 5) Damage Done by Non Power Equipment 6) Mis-locate 6a) Not Marked 6b) Mis-Marked Root Causes: ___________________________________________________________________________________ ______________________________________________________________________________________________ ______________________________________________________________________________________________ Comments: ____________________________________________________________________________________ ______________________________________________________________________________________________ ______________________________________________________________________________________________ (please use other side for sketch or attach a sketch) Field Damage Report.doc - Page 1 of 1 1/16/04 MN Office Of Pipeline Safety

EMP      List of Annexes         Landowner Information              Annex 05                       

Annex 05 – Landowner Information   {Redacted – Privacy} 

EMP      List of Annexes             (Empty)              Annex 06                   

Annex 06 – Community Emergency Plans – Please See Community Websites:   Chapple   Dawson  Emo  Fort Frances  Morley  Piney  Rainy River 

EMP      List of Annexes                 Metallurgical Failure Examination              Annex 07               

Page 1 of 10 Metallurgical Laboratory Failure Examination Protocol Introduction The objective of a metallurgical analysis of a line pipe failure is to assign one or more probable causes for the failure. The failure analysis may identify issues that must be remediated to ensure the integrity of other sections of the failed line pipe as well as other pipeline segments with similar characteristics (i.e. pipe manufacturer, seam type, grade, other specifications, coating type, and environmental conditions). This protocol specifically addresses the failure analysis of line pipe. Failure analysis of pipeline appurtenances (such as valves, flanges, bolts, etc.) may use the same methodologies as those outlined herein, but a unique test plan should be developed to handle the unique characteristics of the appurtenance. Besides a metallurgical analysis of the line pipe, the internal and external environment of the line pipe must be considered to arrive at the causal factors that may have caused the line pipe to fail. Therefore, the presence of corrosion products inside and outside the line pipe in the area of the failure must be considered and collected for analysis, as appropriate. For example, soil in the immediate area of the failure, dislodged soil adjacent to the ejected pipe, and soil that had adhered to the line pipe may have to be collected for analysis. Photographic documentation of the failed section of line pipe prior to its departure from the accident site and upon its arrival at the testing facility must be available to ensure any damage from mishandling is appropriately noted. Before the shipment of the failed section, proper preservation techniques for the fracture surfaces and the section (including coating), if required, should be identified (such as Visqueen®, SaranWrap®, oils, and other protective covers), and a chain of custody should be established for transfer of the failed section to the testing facility. Before the failed section arrives at the testing facility, it should be determined if destructive testing of the failed section has been approved. Only non-destructive testing is allowed in some instances to preserve the pipe intact for evidentiary purposes. In some instances destructive testing can only occur when all interested parties agree to its necessity and a consensus protocol can be crafted establishing those that can witness the destructive tests. A typical sequence of analysis is discussed in this document. Engineering decisions must be made during any failure analysis, and the results of each step dictate the next procedure to be performed. The need for other tests to be performed is a determination that should be made during the course of the investigation. In this instance, the proposed test plan should be modified to reflect these changes. It is a waste of resources to routinely perform a test or analysis that has no relevance to the failure. The following steps are suggested as guidance. • Background information • Visual and non-destructive examination • Physical measurements • Corrosion examination • Fractography examination • Metallographic examination • Mechanical properties Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 2 of 10 Background Information Background information should be collected on the pipeline operating history, pipeline attributes, operating pressure, and failure pressure. Background information provides the investigators data crucial to understanding the technical environment the pipeline was operating in and it assists in identifying potential contributors to the failure. Table 1 provides guidance on data that may be collected and used during the failure investigation. Photographic evidence should be collected to document the failure site and other pertinent details regarding the failure. At the least, items of interest for photographic documentation may include the following: • Overview of failure site including local topography • Overview of line pipe failure area • Detail of fracture surface(s), magnified appropriately to show all relevant features at the fracture surfaces and the fracture origin • Detail of coating in area of failure • Detail of areas of internal and external corrosion near the fracture surface • Details of residues or corrosion products near the fracture surface • Details of areas indicating outside force damage When removing the failed section, any indication of residual stress in the line should be documented. Spring or movement of the pipe when the first circumferential cut is completed would indicate the presences of residual stress. Document the relative location and distance between the cut ends after the first cut is completed. Visual and Nondestructive Examination 1. Photographically document the pipe in the “as-received” condition before initiating the metallurgical analysis. Documentation may include the following: • Fracture area and surface • Seams • Girth welds • Coating condition • Anomalies • Manufacturing flaws or defects • Pitting and/or evidence of corrosion on internal and external pipe surfaces 2. Perform visual examination of the internal and external pipe surfaces in the “as-received” condition, and document any anomalies that may be present in the pipe such as the following: • Cracks • Crevices • Dents • Bends • Buckles • Gouges • Manufacturing defects Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 3 of 10 • Wrinkles, tents or damage to the coating • Pitting and/or evidence of corrosion on internal and external pipe surfaces • Presence of corrosion products and/or deposits • Describe coating, and coating damage (disbonding) if any, in the vicinity of fracture origin and at other locations in the failed pipe sample • Describe any internal coating or linings (if used) • Examine the pipe sample surface for evidence of stress corrosion cracking • Examine for evidence of arc burns, excessive grinding around the surface area near the crack • If corrosion is evident, collect corrosion products for analysis 3. Collect solid and liquid samples, if present, from the pipe surface, and conduct elemental analysis and microbial tests on these samples, as appropriate. Examples of samples that may be collected are, but not limited to, the following: • Liquid accumulated underneath the coating • Corrosion products and/or deposits from the internal and external surfaces of pipe surface • Soil adhering to the pipe 4. If coating is to be removed, it should be removed in a manner that will not be injurious to the pipe. Photographically document and visually inspect the pipe again following coating removal (see 1. and 2. above for guidance). 5. It may be necessary to inspect the failed section of pipe for cracking, stress corrosion cracking, or any other condition that could affect the long term integrity of the pipeline using nondestructive testing techniques. The surfaces of the pipe surrounding the rupture should be cleaned with an appropriate non-abrasive cleaner and subsequently inspected using a wet fluorescent magnetic particle inspection (WFMT) method. The WFMT method is preferred because internal and external defects can be readily identified. Other nondestructive examination techniques such as Fluorescent Penetrant, Radiographic, Eddy-Current, Ultrasonic Inspection, and Alternating Current Potential Drop may also be used. 6. The physical location of all samples to be removed from the pipe for examination and metallurgical analysis should be documented such that all relevant features are visible (graphically and/or photographically). Physical Measurements 1. Measure the diameter and wall thickness on undisturbed areas of the pipe to confirm the information provided in the “Background Information Data Sheet”. 2. Measure the diameter and wall thickness at selected locations to determine actual values at these selected locations. Measure and record the diameter and wall thickness of the pipe at each end of each sample. (Wall thickness should be determined based upon four measurements taken 90 degrees apart.) 3. Verify roundness and geometry of pipe at the extremeties and closer to the failed surface. Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 4 of 10 4. Measure the wall thickness around fracture surfaces and any damaged areas. If corrosion is identified near or around the fracture surfaces, a “corrosion map” should be produced detailing the extent of the corrosion on the pipe surfaces and the pipe wall thicknesses in those areas. This information may be needed to support remaining strength calculations, if required. 5. Align the pipe samples to conform to the pre-fracture bend geometry. 6. Determine and mark the location of the electric-resistance weld at each end of each sample. 7. Determine whether or not any part of each rupture falls within the electric-resistance weld zone. 8. Measure and record the length of each sample. 9. Record any markings detected on the inside or outside surfaces of the pipes. 10. Measure rupture lengths tip-to-tip. 11. Measure the shortest circumferential distance from each fracture origin to the nearest electric-resistance weld. 12. Measure the axial distance from each fracture origin to the nearest girth weld, if any. 13. Map wall thickness of each sample within 12 inches upstream and downstream of each rupture origin. Measurements will be taken on a 2-inch square grid pattern that is centered on the fracture origin and that encompasses 100 percent of the pipe circumference at each origin. 14. Determine depths of cracks using direct exploration (grinding), shear wave ultrasonic testing (UT), Alternating Current Potential Drop (ACPD) or other suitable methods. Corrosion Examination Surface deposits and residues associated with the fracture area and adjacent areas should be collected and analyzed to characterize and determine the origin of the deposits. Based on the results of the visual, non-destructive, and metallographic examinations, the presence of corrosion should be documented, and the type and characteristics of any corrosion present should be evaluated. Remaining strength calculations (RSTRENG/ASME B31G) may be performed on corroded areas to support the failure investigation. Fractographic Examination 1. Visually examine the fracture surfaces in detail to identify the characteristics of the fracture, the nature of the original defect, and the failure initiation point(s). It may become necessary Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 5 of 10 to open the fracture surface in order to conduct part of the examination, and a suitable technique that is dependent upon the particular circumstances of the failure should be used to open the fracture surface. 2. Clean samples in an Endox or Citronox solution to remove loose rust, scale, etc. as necessary. 3. Utilize a suitable method to thoroughly document the fracture surface including dimensional documentation. Suitable methods to document the fracture surface include, but are not limited to, the following: • Foil method • Photographs of macroscopic examination 4. Remove selected fractographic samples as necessary for detailed microscopic examination using optical or scanning electron microscope. Examine and document the fracture surface morphology. When chevron marks are present on the fracture surface, they typically point back towards the fracture origin in steels with an ultimate tensile strength of 60,000 psi and less. It is important to be able to characterize the fracture surface morphology, and fractures can be classified into four groups on a macroscopic scale, as follows: • Ductile fractures • Brittle fractures • Fatigue fractures • Fractures resulting from combined effects of stress and environment • Under low magnification under TLM, observe if there is evidence of fatigue, and ridges to indicate application of high pressure, such as due to hydrostatic testing. Metallographic Examination 1. Identify metallographic sample origin (sample identification, location, orientation, etc.), perform metallographic evaluation, and take representative photomicrographs. Areas of particular concern are: • At or near the fracture origin • Fracture surfaces • Weld seams • Anomalies • Areas with indications of defects or cracks identified through visual and/or non- destructive testing • Areas exhibiting “typical” microstructures of the base metal, weld metal, and heat- affected-zone 2. Perform micro-hardness profiles at appropriate locations such as the following: • At or near the fracture origin • Weld seams 3. Metallographic samples should be examined to characterize and validate any appropriate issues specific to the failure such as: Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 6 of 10 • Pipe specification, grade, and heat treatment • Weld seam in area of fracture • Weld seam in un-affected area • Corrosion • Indications of outside force damage Mechanical Properties Testing should be performed to determine the mechanical properties of the pipe and any appurtenances. Mechanical properties of test specimens should not be taken from areas of the pipe that have been plastically deformed as a result of the failure. These mechanical tests should at least include the following: • Tensile testing • Charpy V-notch testing • Chemical analysis Tensile Testing Tensile test specimens should be prepared and tested in accordance with ASTM A370 (Mechanical Testing of Steel Products) for the pipe base metal and weld seams to measure yield strength, ultimate tensile strength, and elongation. The pipe base metal should, at a minimum be tested in the transverse direction, and weld seam specimens should be taken across the weld seam. Charpy V-notch Impact Testing Charpy V-notch (CVN) specimens should be prepared and tested in accordance with ASTM E23 (Notched Bar Impact Testing of Metallic Materials) to determine the toughness characteristics of the pipe in the L-T (transverse) direction. In some cases (depending on pipe size and wall thickness) it may be necessary to use sub-size specimens. Results from CVN testing may be reported in some or all of the following forms depending on the testing results: • Upper-Shelf Energy (in ft-lbs) • Lower-Shelf Energy (in ft-lbs) • Ductile-to-Brittle Transition Temperature (in °F) determined from graphical representation of testing results • Test Temperature corresponding to 15 ft-lbs of absorbed impact energy • Fracture Appearance Transition Temperature (in °F) corresponding to 50 % shear • Lateral expansion (to measure notch toughness) In some steels it may be difficult to measure percent shear because of “woody” fracture surfaces. In these cases it would be more appropriate to use lateral expansion and absorbed energy measurements to obtain a more accurate transition temperature. A sample testing methodology for generating Charpy V-notch Curves for line pipe steels is provided in Table 2. Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 7 of 10 Chemical Analysis The chemical composition of the pipe material should be determined using an appropriate method to validate the pipe specification and grade, as well as, to determine its carbon equivalent (for weldability issues). Spectrochemical methods (i.e. optical emission) are usually employed to determine steel chemical compositions. Wet chemical methods may also be used. Energy dispersive spectroscopy (EDS) and either x-ray diffraction (XRD) or x-ray photoelectron spectroscopy (XPS) analyses may be used to determine elements and compounds present in surface deposits that were collected during the visual examination. . Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 8 of 10 Table 1 – Background Information Data Sheet (fill in all applicable fields) No. Line Pipe Attribute Data 1 Operating Company 2 Product Transported 3 Line Name and Number and/or System Name 4 Survey Station and Mile Post 5 Date of Failure / Incident / Anomaly 6 How Failure / Incident / Anomaly was found 7 Closest City or town, County, and State 8 Pipe Nominal Outside Diameter 9 Pipe Nominal Wall Thickness 10 Pipe Grade 11 Pipe Seam Type and approx. Joint Length 12 Pipe Manufacturer 13 Year of Installation 14 Depth of Cover in area of failure 15 Coating Type 16 Cathodic Protection Type and Year installed (if applicable) 17 Distance to nearest rectifier or anode bed (if applicable) 18 Terrain and Soil Conditions, including Soil Ph (if applicable) Distance to Upstream and 19 Downstream Compressor or Pumping Station 20 Distance to Upstream and Downstream Girth Welds Position of Failure / Incident / 21 Anomaly on Pipe (from top or bottom and/or O’clock position) 22 Pressure at time and location of Failure / Incident / Anomaly 23 Normal Operating Pressure at Location of Failure / Incident / Anomaly 24 MOP, MAOP, Design Factor, and/or Location Class Metallurgical Laboratory Failure Examination Protocol 01/06/2004

No. Line Pipe Attribute Page 9 of 10 25 Date, Test Pressure, and Duration Data of most recent Hydrostatic Test (if applicable) 26 Hydrostatic Test Pressure at Location of Failure / Incident / Anomaly (if applicable) 27 Other Comments or Observations 28 Name, Telephone, and Fax Numbers of contact for Operator for further Questions 29 Name, Telephone, and Fax Numbers of contact for OPS for further Questions 30 NRC Report Number (if applicable) Sketch a schematic of the failure area showing direction of flow and other prominent features: Metallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 10 of 10 Table 2 – A testing methodology for generating Charpy V-notch Curves for line pipe steels Note: The following is an example test protocol to generate a Charpy V-notch (CVN) Curve and to determine the Ductile-to-Brittle Transition Temperature (DBTT) for API-X52 and lower grade line pipe. Prepare a minimum of 12 Charpy V-notch specimens (preferably 16 specimens) in the L-T (transverse) direction and perform CVN testing according to ASTM E23. Test 1 specimen at -20°F Test 1 specimen at 0°F If CVN values are less than 4 ft-lbs. (full scale), then consider this a part of the lower shelf temperatures Test 1 specimen at 70°F Test 1 specimen at 100°F If CVN values are greater than 20 ft-lbs. and are close together, then consider this part of the upper shelf temperatures. If the difference in CVN values is more than 5 ft-lbs., then: Test 1 specimen at 70°F Test 1 specimen at 50°F If CVN values are close together, then the DBTT is likely to be around 50°F, then: Test 1 specimen at 50°F Test 1 specimen at 40°F Test 1 specimen at 20°F If the difference in CVN values at 50°F and 70°F is greater than 5ft-lbs., then Test 1 specimen at 50°F Test 1 specimen at 60°F Test the remaining specimens at other temperatures, as appropriate, to ensure that data has been collected at temperatures that the testing has shown to be of importance. Draw the CVN Curve to a best-fit curve plotting Impact Energy (ft-lbs.) versus Temperature (°F). Determine the DBTT from the CVN Curve (in °F). Determine the Temperature (in °F) corresponding to 15 ft-lbs. absorbed impact energy. Determine the Fracture Appearance Transition Temperature (in °F) corresponding to 50% and/or 80% shear. Determine the Upper-Shelf Energy (in ft-lbs.). Determine the Lower-Shelf Energy (in ft-lbs) Metallurgical Laboratory Failure Examination Protocol 01/06/2004