Consolidated EMP Website Centra Pipelines

Emergency Management Program ___ __________________________Incident CostsCosts for any incident that meets the following definition under any of the NEB’s regulations are to bereported 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 incidentwas reported and ending either when there are no further costs related to the incident or 5 years afterthe 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 willautomatically determine when companies are required to report costs. However, until the systemchanges are made, the NEB will contact companies on an as-needed basis and will provide instructionsand a standard form to report costs. Date: Manual Title: Page:5 Mar 2018 Emergency Management Program 47/52

Emergency Management Program ___ __________________________Written NotificationA Department of Transportation Form RSPA F 7100.2 must be submitted to PHMSA electronically on thePHMSA Portal (https://portal.phmsa.dot.gov/phmsaportallanding) website (copied to MnOPS) as soonas 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 reportsmust be submitted on the PHMSA Portal (https://portal.phmsa.dot.gov/phmsaportallanding) website asdeemed 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 ReportingSystem and in accordance with the NEB Event Reporting Guidelines. If the online event reportingsystem 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 BoardKansas City, MO 64106-2641 444 Seventh Avenue SWPhone: 816-329-3800 Calgary, AlbertaFax: 816-329-3831 T2P 0X8 Telephone: 403-292-4800Pipeline Emergency Toll free: 1-800-899-126524-hour hot line at 800-424-8802 Fax: 1-403-292-5503 Online Reporting System https://apps.neb-one.gc.ca/ers TSB Reporting Hotline 24-hour hot line at 819-997-7887. Fax: 819-953-7876 [email protected] MnOPS Pipeline Emergency Minnesota Duty OfficerHome Office (651) 649-5451 (Metro)Twin Cities Metro Area (800) 422-0798 (Statewide)MN Office of Pipeline Safety444 Cedar St., Suite 147St. Paul, MN 55101(651) 201-7230(651) 296-9641 (FAX) Date: Manual Title: Page:5 Mar 2018 Emergency Management Program 48/52

Emergency Management Program ___ __________________________ 3.5. Industrial CustomersIndustrial customers must be contacted as soon as practical when an emergency condition on thepipeline will impact service to the industrial facilities. Employees responding to an emergency conditionmay be faced with having to make a decision to limit or completely curtail service to industrialcustomers in order to protect lives or maintain service to Priority 1 and 2 customers as defined inCentra’s Gas Curtailment Policy which is attached in Annex 2. The protection of life is always theprimary objective when responding to a natural gas emergency. After public safety has been ensuredall reasonable efforts must be made to maintain service to customers in accordance with the gascurtailment policy. It is very important to establish and maintain communications with industrialcustomers to prevent damage to equipment and protect other customer assets as much as practical. 3.6. LDC CustomersLDC 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 willimpact service to their facilities. Employees responding to an emergency condition must communicateand coordinate with LDC and industrial customers to maintain service to as much of the system aspossible while at the same time ensuring that the provisions of the Gas Curtailment Policy are followed. 3.7. Natural Gas SupplierTransCanada must be notified whenever there is an incident that will significantly increase or decreasethe throughput on Centra’s system. 3.8. Failure Investigation – Materials Testing LaboratoriesWhenever any material fails or there is a natural gas related incident of significance, it must bethoroughly investigated as soon as possible to determine the cause of the failure and if any correctivemeasures are required.Material FailureIt shall be reported to Management whenever a piece of material fails to comply with the standards towhich 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 failedmaterial shall be removed with care being taken not to damage or distort the item. The item will thenbe examined to determine the cause of failure, and a report shall be filed on the results of theexamination and possible ways of preventing a recurrence of the failure. The Custody Transfer Recordshall be used to document the chain of custody of the material as it is transported to the appropriatetesting facility. As appropriate the Metallurgical Examination Protocol can be used as a guide todetermine the probable causes of failure. Date: Manual Title: Page:5 Mar 2018 Emergency Management Program 49/52

Emergency Management Program ___ __________________________ 3.9. PublicRadio - US Radio - CanadaInternational Falls, MN Fort Frances, ONKSDM /KGHS 218 283-3481 B 93 FM 807 274-5341Phone: 888 283-1041 Phone : 807 274-2033Toll Free: 218 283-3087 Fax:By Fax:KBHW -Psalm 99.5 Email: [email protected] Station Manager: [email protected]: 888 285-7398 807-276-0832Warroad, MN Steinbach, MB Golden West RadioKKWQ 218 386-3024 Phone: (204) 324-6464Phone: Fax: 888-765-7039Roseau, MN Email: [email protected] 218 463-0161Phone: 218 463-3360Studio: 218 463-1977Fax: Date: Manual Title: Page: 5 Mar 2018 Emergency Management Program 50/52

Emergency Management Program ___ __________________________4. Emergency Management Program Continuous Review and ImprovementThe EMP is a living document that must be continuously monitored for changes that may be required inprocedures and stakeholder information and resources. To accomplish this, Centra personnel willconsider potential changes that may be required in the EMP because of something that may have beenobserved or learned in the day to day performance of their duties. Any potential changes shall becommunicated to the Manager, Pipeline Operations in writing. Minor changes such as changes instakeholder 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 reviewedand evaluated by operations personnel and submitted to the Director, Pipeline operations on aManagement of Change form (Instructions)for approval.In addition to the continuous monitoring as described above, the EMP will be formally reviewed on anannual basis by operations staff. This review is intended to ensure that operations personnel arefamiliar with the contents and requirements of the EMP and to determine if any other changes orrevisions may be required. As a part of the annual review, contact and resource information for allstakeholders 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 requirementsChanges to the EMP shall be made in accordance with the previous paragraph.5. Training and Coordination of ResourcesCentra personnel are trained in accordance with the Operator Qualification Program to ensure that theyhave the necessary knowledge and technical skills to perform the tasks that may be required whenresponding 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 stakeholderaudience. The general focus of the information is outlined below: Date: Manual Title: Page:5 Mar 2018 Emergency Management Program 51/52

Emergency Management Program ___ __________________________Gas Control o Receiving emergency notifications o Communications ❖ Emergency personnel ❖ Customers o Gas Control priorities o DocumentationInformational materials: EMP, Gas Control PowerPoint presentationEmergency Response Agencies o EMP review o Minimizing hazards to life and property o Roles and responsibilitiesInformational materials: EMP, Pipeline Emergency Video, Emergency Responder PowerPointpresentation 5.1. Table Top and Mock EmergenciesTable top and mock exercises shall include operational elements of Centra’s management andprotection programs to anticipate, prevent, mitigate and manage conditions that may adversely affectthe safety and security of Centra’s pipelines, employees, the public, as well as property and theenvironment. 5.1.1. Table Top Emergency ExerciseTable top emergency exercises will be conducted on an annual basis to simulate various emergencyscenarios that could potentially occur on the transmission system. While it is not necessary to conducttable top exercises for all stakeholder groups, they should be conducted with Centra personnel on anannual basis and with Emergency Response Agencies as part of the periodic liaison agenda. 5.1.2. Mock Emergency ExerciseA Mock Emergency Exercise is an in-depth enactment of a simulated emergency response scenario thatincludes the participation of all stakeholders and may include the public. The purpose of conducting amock emergency exercise is to further the knowledge of stakeholders with respect to what their rolesand responsibilities are when responding to an emergency on the transmission facilities. It is also a toolused to evaluate the effectiveness of the EMP and its implementation. Centra will conduct a mockemergency every 3 years. Date: Manual Title: Page:5 Mar 2018 Emergency Management Program 52/52

Emergency Management OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 17EMG-PRO-002, Management of Non-Gas Emergencies1.0 PurposeEmergency preparedness and response planning is intended to ensure that responses toemergencies are prompt, organized and effective. This procedure provides and identifiesprocesses 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 ScopeThis procedure applies to all areas of Energy Fundamentals Group, Limited Partnership,(abbreviated as EFG) operations, except for emergencies that are related to the transmission ofnatural gas. It also applies to all EFG employees and, contractors and visitors within EFG areasof operation.3.0 DefinitionsFor purpose of this procedure, Emergency means a present or imminent event that requiresprompt coordination of actions or special regulation of persons or property to protect thehealth, safety or welfare of people or to limit damage to property or the environment. Thereare 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 toperson, 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 OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 174.0 GeneralEFG operating areas (office/field) shall develop emergency preparedness and responseprocesses to cover activities where there is a risk to the safety of employees and the public or arisk 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 OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 176.0 ResponsibilitiesManagement• 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• EFG Emergency Management Program.• 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 OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 179.0 RevisionsRevisions are documented and tracked as part of the Integrated Management System (IMS),Business Documents process. Approval of formal company documents are managed under theIMS, 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 OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 17Appendix A, Emergency Prevention, Preparedness & ResponsePrevention & PreparednessThe following processes are, among other things, intended and designed to help in theprevention on emergency events:• Policies and procedures.• Training.• Inspection.• Workplace design.• Preventative maintenance.• Hiring practices.ResponsePossible emergency situations include fire, explosion, injury or illness, a spill or leak of ahazardous substance, weather-related situations, security threat, etc. EFG employees shall befamiliar 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 ASSISTANCEThe flowchart on Page 7 of this procedure shows the emergency response process, at a highlevel.EFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 5 of 7

Emergency Management OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 17Appendix 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 OriginalEMG-PRO-002, Management of Non-Gas EmergenciesIssued: 11 Jul 17Appendix A, Emergency Prevention, Preparedness & Response(Continued)Emergency Response – Non-Natural Gas EventsDiscovery Event involving, or Hazards potentially involving,• 1st. Hand emergency other than a • Fire, explosion• Security system monitors natural gas emergency • Security threat• 3rd. party • Injury/illness Assess risk • Hazardous substance release Protect • Weather anomaly/threat (Hazard ID & Assessment) • People Determine • Environment Determine initial • Property response • Risk level • Regulatory nNotification needs Considerations • In-house responders • External responders • EOC needs • Materials/equipment • Accessibility • Weather Activate responseRe-assess & No Emergency CONTROL – MITIGATE - ELIMINATE revise controlled response ? Yes Restore to normal service Repair & remediate Debrief Lessons learned Continual improvement EXTERNAL COMMUNICATIONS Regulators INTERNAL Customers Suppliers Sr. Management Employees WCBEFG’S ELECTRONIC DOCUMENT SYSTEM CONTAINS THE MOST CURRENT VERSION OF THIS DOCUMENT. UNCONTROLLED WHEN PRINTED. Page 7 of 7

EMP  Hazard Risk Assessment  Gas Curtailment Policy List of Annexes   Maps  Forms  Annex 01  Landowner Information  Annex 02  Community Emergency Plans  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  Annex 09  Annex 10  Annex 11   

EMP  Hazard Risk Assessment   List of Annexes       Annex 01                                     

4/26/2016 EmergencyRisk Management : Screening Level Risk Assessment Management Risk AssessmentEmergency Management Risk Assessment Assessment Date Residual Residual Residual Frequency Consequence Risk Hazard 12-01-2015 36 12-01-2015 3 12 24 Unqualified employees 12-01-2015 3 8 24 Inadequate tools, equipment, and readily available materials. 12-01-2015 3 8 24 Inadequate procedures 12-01-2015 3 8 24 Inadequate public awareness measures 12-01-2015 2 24 Explosion near or directly involving pipeline facility 12-01-2015 2 12 16 Hazardous Gas Levels Inside Buildings 12-01-2015 2 12 16 Inadequate financial resources 12-01-2015 2 12 Hazardous leak outside 12-01-2015 3 8 12 Inadequate liaison with emergency response agencies 12-01-2015 1 8 8 Dangerously high system pressures 12-01-2015 2 4 4 Unreliable communications 12-01-2015 2 12 4 Fire near or directly involving pipeline facilitey 1 4 Dangerously low system pressures 2 4

EMP    Gas Curtailment Policy List of Annexes           Annex 02                                 

Natural Gas Curtailment PolicyPURPOSEIn the unlikely event that Energy Fundamentals Group (EFG) determines the natural gas supplycontained within the natural gas transmission line is insufficient to meet the total customerdemands; the public interest requires that the curtailment of gas to customers be controlled in amanner which will consider customer priority consistent with guidelines established byregulatory authorities. EFG shall determine the quantity of gas which each customer shall beentitled to receive and promptly notify each affected customer regarding the curtailment andperiod covered. Such notice shall be given as far in advance as possible. EFG may change thecurtailment period and quantity of gas the customer may be entitled to if conditions require.APPLICABILITYThe Natural Gas Curtailment policy applies to all EFG customers and is premised on the fact thatnatural gas deliveries will be curtailed in consideration of the end-use of the natural gas.DEFINITIONSPriority 1 CustomerAny person who uses natural gas or local distribution company (LDC) who resells natural gas foruse in the following high priority classifications:1. In a residence;2. In a small commercial establishment;3. In a school or a hospital; or4. 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 receiveshall be based on the amount of gas required to serve high-priority classifications as definedabove.Examples of small commercial establishments are businesses that are primarily engaged inwholesale or retail trade, agriculture, forestry, fisheries, transportation, communications, sanitaryservices, finance, insurance, real estate, personal services, government, etc.Priority 2 CustomerAny customer whose use of natural gas has been certified by the United States Secretary ofAgriculture as an essential agricultural use unless the use of an alternative fuel is economicallypracticable and reasonably available as determined by FERC in conjunction with the Secretary ofAgriculture.Priority 3 CustomerDate: IMS Program: Manual Title: Section: Page: Annex 2 1/222 April 2015 2 Emergency Management Program Controlled Copy - Do Not Duplicate Confidential - Not to be released outside of Energy Fundamentals Group

Natural Gas Curtailment PolicyLarge commercial and industrial customers primarily engaged in power production or in aprocess which creates or changes raw or unfinished materials into another form or product. Thisincludes 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 2/222 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   Maps            Annex 03                             

Annex 03 – Maps {Redacted – Security Threat} 

EMP     List of Annexes     Forms              Annex 04                         

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

Custody Transfer RecordProject NumberOwner of MaterialOrigin of RecordDescription of Item(s)Date: By: Released by: Received by: CompanyName Date Name Company DateNote alterations to materials:By:



FIELD DAMAGE REPORTDate: Report By:Company: Representative Name:Address: Other Phone:City, State, Zip:Phone:Damage Date & Time: Facility Damaged: Photographs: Y NExtent of Damage: Nearest Intersection:Damage Location:Municipality:Locate #: Joint Trench: Y N Marked w/ Paint Flags Stakes No Marks VisibleMarkings: N/A Accurate Not Accurate, marks off by (distance):_________________Excavation Type: Plowing Boring Drilling Open TrenchingOn Going/Extended Project Y N Emergency Response to Incident Y N Injury or Property Damage Y NExcavator reported damageTo Utility Owner Y N White Markings Used Y N Facility Maps / Records Accurate Y NCause of Damage and Reason for Excavation – Check one each Category and one each SubcategoryCause Reason1) 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) Landscaping2) No Hand Digging /Hit While Excavating3) Marks Not Maintained By Excavator4) Failure to Support and Protect Facility5) Damage Done by Non Power Equipment6) Mis-locate 6a) Not Marked 6b) Mis-MarkedRoot 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

FIELD DAMAGE REPORTDate: Report By:Company: Representative Name:Address: Other Phone:City, State, Zip:Phone:Damage Date & Time: Facility Damaged: Photographs: Y NExtent of Damage: Nearest Intersection:Damage Location:Municipality:Locate #: Joint Trench: Y N Marked w/ Paint Flags Stakes No Marks VisibleMarkings: N/A Accurate Not Accurate, marks off by (distance):_________________Excavation Type: Plowing Boring Drilling Open TrenchingOn Going/Extended Project Y N Emergency Response to Incident Y N Injury or Property Damage Y NExcavator reported damageTo Utility Owner Y N White Markings Used Y N Facility Maps / Records Accurate Y NCause of Damage and Reason for Excavation – Check one each Category and one each SubcategoryCause Reason1) 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) Landscaping2) No Hand Digging /Hit While Excavating3) Marks Not Maintained By Excavator4) Failure to Support and Protect Facility5) Damage Done by Non Power Equipment6) Mis-locate 6a) Not Marked 6b) Mis-MarkedRoot 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             Community Emergency Plans              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 ProtocolIntroductionThe objective of a metallurgical analysis of a line pipe failure is to assign one or more probablecauses for the failure. The failure analysis may identify issues that must be remediated to ensurethe integrity of other sections of the failed line pipe as well as other pipeline segments withsimilar characteristics (i.e. pipe manufacturer, seam type, grade, other specifications, coatingtype, and environmental conditions). This protocol specifically addresses the failure analysis ofline pipe. Failure analysis of pipeline appurtenances (such as valves, flanges, bolts, etc.) may usethe same methodologies as those outlined herein, but a unique test plan should be developed tohandle the unique characteristics of the appurtenance.Besides a metallurgical analysis of the line pipe, the internal and external environment of the linepipe 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 thefailure must be considered and collected for analysis, as appropriate. For example, soil in theimmediate area of the failure, dislodged soil adjacent to the ejected pipe, and soil that hadadhered 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 theaccident site and upon its arrival at the testing facility must be available to ensure any damagefrom mishandling is appropriately noted. Before the shipment of the failed section, properpreservation 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 achain 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 destructivetesting of the failed section has been approved. Only non-destructive testing is allowed in someinstances to preserve the pipe intact for evidentiary purposes. In some instances destructivetesting can only occur when all interested parties agree to its necessity and a consensus protocolcan be crafted establishing those that can witness the destructive tests.A typical sequence of analysis is discussed in this document. Engineering decisions must bemade during any failure analysis, and the results of each step dictate the next procedure to beperformed. The need for other tests to be performed is a determination that should be madeduring the course of the investigation. In this instance, the proposed test plan should be modifiedto reflect these changes. It is a waste of resources to routinely perform a test or analysis that hasno 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 propertiesMetallurgical Laboratory Failure Examination Protocol 01/06/2004

Page 2 of 10Background InformationBackground information should be collected on the pipeline operating history, pipelineattributes, operating pressure, and failure pressure. Background information provides theinvestigators data crucial to understanding the technical environment the pipeline was operatingin and it assists in identifying potential contributors to the failure. Table 1 provides guidance ondata that may be collected and used during the failure investigation.Photographic evidence should be collected to document the failure site and other pertinent detailsregarding the failure. At the least, items of interest for photographic documentation may includethe 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 damageWhen removing the failed section, any indication of residual stress in the line should bedocumented. Spring or movement of the pipe when the first circumferential cut is completedwould indicate the presences of residual stress. Document the relative location and distancebetween the cut ends after the first cut is completed.Visual and Nondestructive Examination1. 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 surfaces2. 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 defectsMetallurgical 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 analysis3. 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 pipe4. 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 Measurements1. 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 104. 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 ExaminationSurface deposits and residues associated with the fracture area and adjacent areas should becollected and analyzed to characterize and determine the origin of the deposits.Based on the results of the visual, non-destructive, and metallographic examinations, thepresence of corrosion should be documented, and the type and characteristics of any corrosionpresent should be evaluated. Remaining strength calculations (RSTRENG/ASME B31G) maybe performed on corroded areas to support the failure investigation.Fractographic Examination1. 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 necessaryMetallurgical 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 examination4. 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 Examination1. 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-zone2. Perform micro-hardness profiles at appropriate locations such as the following: • At or near the fracture origin • Weld seams3. 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 damageMechanical PropertiesTesting should be performed to determine the mechanical properties of the pipe and anyappurtenances. Mechanical properties of test specimens should not be taken from areas of thepipe that have been plastically deformed as a result of the failure. These mechanical tests shouldat least include the following: • Tensile testing • Charpy V-notch testing • Chemical analysisTensile TestingTensile 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 yieldstrength, ultimate tensile strength, and elongation. The pipe base metal should, at a minimum betested in the transverse direction, and weld seam specimens should be taken across the weldseam.Charpy V-notch Impact TestingCharpy 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 ofthe pipe in the L-T (transverse) direction. In some cases (depending on pipe size and wallthickness) it may be necessary to use sub-size specimens. Results from CVN testing may bereported 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 energymeasurements to obtain a more accurate transition temperature. A sample testing methodologyfor 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 10Chemical AnalysisThe chemical composition of the pipe material should be determined using an appropriatemethod 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 employedto determine steel chemical compositions. Wet chemical methods may also be used.Energy dispersive spectroscopy (EDS) and either x-ray diffraction (XRD) or x-ray photoelectronspectroscopy (XPS) analyses may be used to determine elements and compounds present insurface 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 Data1 Operating Company2 Product Transported3 Line Name and Number and/or System Name4 Survey Station and Mile Post5 Date of Failure / Incident / Anomaly6 How Failure / Incident / Anomaly was found7 Closest City or town, County, and State8 Pipe Nominal Outside Diameter9 Pipe Nominal Wall Thickness10 Pipe Grade11 Pipe Seam Type and approx. Joint Length12 Pipe Manufacturer13 Year of Installation14 Depth of Cover in area of failure15 Coating Type16 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 and19 Downstream Compressor or Pumping Station20 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 / Anomaly23 Normal Operating Pressure at Location of Failure / Incident / Anomaly24 MOP, MAOP, Design Factor, and/or Location ClassMetallurgical Laboratory Failure Examination Protocol 01/06/2004

No. Line Pipe Attribute Page 9 of 1025 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 Observations28 Name, Telephone, and Fax Numbers of contact for Operator for further Questions29 Name, Telephone, and Fax Numbers of contact for OPS for further Questions30 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 steelsNote: The following is an example test protocol to generate a Charpy V-notch (CVN) Curve andto determine the Ductile-to-Brittle Transition Temperature (DBTT) for API-X52 and lower gradeline pipe. Prepare a minimum of 12 Charpy V-notch specimens (preferably 16 specimens) in theL-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

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Annex 8 – Plan Holder ListAnnex 8 Plan Holder ListEFG Employees and Gas ControlThe Emergency Management Program (EMP) is available to all EFG employees and Gas Control throughSharePoint. Employees should ensure that the EMP is synced to their computers so the most currentrevision of the EMP is available even if offline. Plan Location Revision Date Distribution DateMnOPS – St. Paul, MN Electronic Copy March 31, 2017 Next InspectionNEB – Calgary, Alberta March 31, 2017 March 24, 2017 Hard Copy March 31, 2017 March 24, 2017 Electronic Copy Mobile EOC March 31, 2017 August 1, 2017 Hard Copy Community Emergency March 31, 2017 July 20, 2017 Response and Public Officials Hard Copy

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