Pipeline Rules

(Consolidated up to 8/2026) ALBERTA REGULATION 125/2023 Pipeline Act PIPELINE RULES Table of Contents 1 Interpretation Part 1 Administration 2 Exemption from application of Act and Rules 3 Exemption — agents 4 Compliance with directives 5 Notification 6 Eligibility to hold a licence 7 Application for licence 8 Survey of right of way boundaries 9 Notice of construction commencement 10 Notice or application in case of delay or failure to complete construction 11 Emergency management program 11.1 Corporate emergency response plan 11.2 Operation-specific emergency response plan 11.3 Maintenance of plan and training 11.4 Ability to implement plan re water body 11.5 Records, forms and notifications 11.6 Incidents and emergencies 12 Pipeline records and documents 13 Transfer of records 14 Safety and Loss Management System 15 Integrity Management Program 16 Financial information 16.1 Site-specific liability assessment Part 2 Materials and Design 17 Materials to be provided to Regulator 18 CSA standards 19 Approval of non‑standard materials or methods 20 Limits on polymeric or composite pipe 21 Design for maintenance, inspection and purging 22 Pipeline maintenance pigs 23 Emergency shutdown devices and check valves 24 Control systems in blended gas streams 25 Equipment pressure ratings 26 Stress level limitations 27 Maximum noise levels 28 Pipeline crossing highway or road 29 Minimum earth cover 30 Installing surface pipelines 31 Operating pressure Part 3 Pressure Testing 32 Placing pipeline into operation 33 Notice to Regulator 34 Conditions for pressure testing 35 Regulator’s direction on pressure testing 36 Recording pressure test results 37 Unsatisfactory pressure test 38 Minimum test pressure 38.1 Pressure near test head assembly 39 Pressure testing using liquid test media other than fresh water 40 Pressure testing using gaseous test media 41 Duration of pressure test Part 4 Ground Disturbance 42 No fees for ground disturbance 43 Ground disturbance approval 44 Damage prevention service 45 Preparing for ground disturbance 46 Locating and marking of pipelines 47 Supervision of ground disturbance 48 Control of access over right of way 49 Vehicles crossing pipeline 50 Safety of adjacent pipeline 51 Exposing pipeline 52 Inspection prior to backfilling Part 5 Warning Signs 53 Location of pipeline warning signs 54 Installation of pipeline warning signs 55 Maintenance of pipeline warning signs 56 Alternate signage 57 Temporary pipeline warning signs 58 HVP product 59 Group pipeline signs 60 Identification of pipeline installations Part 6 Changes to Pipeline 61 Liner and internal protection installation 62 Liner and internal protection installation in sour service 63 Change in substance or pressure 64 Testing requirements for change in substance or pressure Part 7 Relocation or Alteration of Pipeline or Other Regulator Direction 65 Application for direction under section 33 of Act 66 Notice to Regulator Part 8 Release of Product and Contact Damage 67 Report of leak, break or contact damage 68 Containment of leak or break 69 Repair of leak, break or contact damage 70 Intentional release of gas Part 9 Discontinuance, Abandonment, Removal and Resumption 71 General 72 Duty to maintain and manage as operating 73 Application in case of discontinuance, abandonment or removal 74 Discontinuance or abandonment of entire pipeline system 75 Conducting discontinuance 76 Conducting abandonment 77 Closure quotas 78 Closure plans 79 Mandatory abandonment 80 Responsibility for discontinued or abandoned pipeline 81 Conducting removal 82 Resumption of pipeline operation Part 10 Transitional Provisions, Repeal, Expiry and Coming into Force 83 Transitional 84 Repeal 85 Expiry 86 Coming into force Schedules Interpretation 1 (1) In these Rules, (a) “Act” means the Pipeline Act ; (b) “active flowing service” means a pipeline conveying substances in (i) continuous service, (ii) intermittent service if the pipeline is used regularly at predictable intervals, or (iii) periodic service that occurs irregularly but based on the pipeline’s established actual operational need, but does not include temporarily conveying substances for short periods that are not part of regular operations of a pipeline; (c) “break” means the escape of substance from a pipeline in a manner that immediately impairs the operation of the pipeline; (d) “closure” means the phase of the energy resource development life cycle that involves the permanent end of the operation of a pipeline, and includes abandonment and reclamation of a pipeline; (e) “composite” means consisting of a matrix of reinforcing fibres, strands, wires or strips, encased within a polymeric resin or structure; (f) “contact damage” means damage occurring to an installed pipeline during a ground disturbance and that results in (i) a puncture or crack in the pipeline, (ii) a scratch, gouge, flattening or dent on the pipeline surface, or (iii) damage to the pipeline’s protective coating that compromises the functionality of the coating, with the exception of minor damages that may occur during final hand excavation and external cleaning; (f.1) “corporate ERP” means an ERP that applies to all pipelines of a licensee; (g) “CSA” means the Canadian Standards Association; (h) “dead leg” means a pipeline section open to an operating pipeline on one end and closed at the other end that consequently has no flow; (h.1) “Directive 001” means Directive 001: Requirements for Site‑Specific Liability Assessments; (h.2) “Directive 011” means Directive 011: Estimated Liability; (i) “Directive 038” means Directive 038: Noise Control; (j) “Directive 050” means Directive 050: Drilling Waste Management; (k) “Directive 056” means Directive 056: Energy Development Applications and Schedules; (l) “Directive 058” means Directive 058: Oilfield Waste Management Requirements for the Upstream Petroleum Industry; (m) “Directive 060” means Directive 060: Upstream Petroleum Industry Flaring, Incinerating, and Venting; (n) “Directive 067” means Directive 067: Eligibility Requirements for Acquiring and Holding Energy Licences and Approvals; (o) “Directive 071” means Directive 071: Emergency Preparedness and Response; (p) “Directive 077” means Directive 077: Pipelines — Requirements and Reference Tools; (q) “Directive 088” means Directive 088: Licensee Life‑Cycle Management; (r) “distribution specification gas” means natural gas that does not contain more than an average of 7 milligrams of hydrogen sulphide gas per cubic metre of natural gas at an absolute pressure of 101.325 kilopascals at a temperature of 15 degrees Celsius, equivalent to 5 parts per million; (s) “drilling waste” means the mud and cuttings generated while directional drilling for the purpose of pipeline construction; (t) “emergency” means a present or imminent event, outside the scope of normal operations, that requires prompt coordination of resources to protect the health, safety or welfare of people or to limit damage to property and the environment; (u) “engineering assessment” means an engineering assessment conducted in accordance with CSA Z662; (u.1) “ERP” means an emergency response plan to protect the public and the environment that includes (i) criteria for assessing an emergency, (ii) procedures to mobilize response personnel and agencies, and (iii) procedures to establish communications and ensure coordination of the emergency response; (v) “expanded liner” means either a tight‑fitting or expanded thermoplastic corrosion barrier installed within, and in direct contact with, the metallic pipeline that constitutes the load‑bearing member; (w) “facility surface lease” means the area leased by a licensee for a well, installation or facility connected to a pipeline, but does not include an access road to the well, installation or facility or a pipeline installation lease; (x) “freestanding liner” means a loose‑fitting or stand‑alone polymeric or composite pipeline having its own pressure‑retaining capability installed within a pipeline where the latter serves only as a hollow conduit for the freestanding liner; (y) “group 1 water” means water meeting the criteria for group 1 water in Directive 077; (z) “group 2 water” means water meeting the criteria for group 2 water in Directive 077; (aa) “group 3 water” means water meeting the criteria for group 3 water in Directive 077; (bb) “hand excavation” means excavation of a pipeline or part of a pipeline by (i) manual labour using hand tools, (ii) water or air jets and vacuum extraction equipment, or (iii) any other method authorized by the Regulator; (cc) “HVP product” means a high vapour pressure product, including hydrocarbons or a hydrocarbon mixture, as defined in CSA Z662; (dd) “installed pipeline” means (i) the portion of pipeline that has been (A) backfilled, or (B) mounted to any necessary above‑ground support structures or pipe racks, or (ii) in the case of a licensed surface pipeline, the point at which the pipeline is ready for pressure testing; (ee) “Integrity Management Program” means an Integrity Management Program developed under section 15; (ff) “landowner” means (i) the person in whose name a certificate of title has been issued pursuant to the Land Titles Act , (ii) if no certificate of title has been issued, the Crown or other body administering the land, or (iii) in the case of Metis land, the person registered in the Metis Settlements Land Registry as owner of the Metis title pursuant to the Metis Settlements Land Registry Regulation (AR 361/91); (gg) “leak” means the escape of substance from a pipeline in a manner that does not immediately impair the operation of the pipeline; (hh) “occupant” means (i) a person, other than the owner, who is in actual possession of land, (ii) a person who is shown on a certificate of title or by contract as having an interest in land that confers a right to occupy the land, (iii) an operator granted a right of entry in respect of land pursuant to a right of entry order under the Surface Rights Act , (iv) in the case of Crown land, a person shown on the records of the department or other body administering the land as having an interest in the land, (v) the holder of a permit for a coal mine, or (vi) in the case of Metis land, a person having a right or interest in land recorded on the Metis title register pursuant to the Metis Settlements Land Registry Regulation (AR 361/91); (hh.1) “operation‑specific ERP” means an ERP that applies to a specified geographic area or to a specified pipeline or operation of a licensee; (ii) “% SMYS” means the hoop stress level expressed as a percentage of the specified minimum yield strength of the pipe based on nominal wall thickness; (jj) “polymeric” means consisting of either thermoplastic or thermoset polymer engineering materials; (kk) “regulatory authority” means an entity having lawful authority respecting the regulation of pipelines in a jurisdiction other than Alberta; (ll) “Safety and Loss Management System” means a Safety and Loss Management System developed under section 14; (mm) “temporary surface pipeline” means a pipeline installed primarily on the ground and not to be operated for more than 12 months unless otherwise authorized; (nn) “temporary surface pipeline for water conveyance” means a temporary surface pipeline used only for water conveyance and not operating at a pressure greater than 3500 kilopascals; (oo) “temporary surface pipeline for well testing or bypass” means a temporary surface pipeline used only for well testing or bypass purposes and that is in continuous use for no more than 21 days; (pp) “Uniform Color Code” means the Uniform Color Code for marking underground utilities established and published by the American Public Works Association; (qq) “Utility Safety Partners” means the non‑profit corporation called Utility Safety Partners referred to in Part 4, formerly called Alberta One Call, and includes any successor organization to Utility Safety Partners. (2) Words and expressions used but not defined in these Rules have the meanings assigned to them in the Act and in the standards referred to in subsection (3). (3) A reference in these Rules to CSA Z662 or any other CSA standard refers to the standard with the equivalent identification number issued by CSA, as updated from time to time. (4) For the purposes of section 1(1)(e) of the Act, the controlled area is (a) a strip of land 30 metres wide on each side of the pipeline, measured from the pipe centreline, or (b) the distance from the pipe centreline to the edge of the right of way, whichever is wider. (5) For the purposes of section 19 of the Act and these Rules, (a) a licensee who is an individual is resident in a jurisdiction if the individual makes his or her home in and is ordinarily present in that jurisdiction, and (b) a licensee that is a corporation is resident in a jurisdiction if a director or officer of the corporation or a person employed or retained to provide services to the corporation makes his or her home in that jurisdiction, is ordinarily present in that jurisdiction and is authorized to (i) make decisions respecting a licence for a pipeline issued by (A) the regulatory authority in that jurisdiction, or (B) in the case of Alberta, the Regulator, (ii) operate the pipeline, and (iii) implement directions from the regulatory authority, or in the case of Alberta, the Regulator, relating to the pipeline. (6) Where these Rules refer to a directive by its number or title or both, the reference is to be considered as a reference to that directive as published by the Regulator and amended from time to time. AR 125/2023 s1;11/2025;243/2025;8/2026 Part 1 Administration Exemption from application of Act and Rules 2 (1) A pipeline, regardless of length, that is contained wholly within the boundary of a facility surface lease or of an adjacent and abutting facility surface lease is exempt from the application of the Act and these Rules. (2) A natural gas pipeline that conveys distribution specification gas at pressures of 700 kilopascals or less and that supplies fuel or gas to a facility, scheme or other matter authorized under the Oil and Gas Conservation Act or the Oil Sands Conservation Act from a gas distribution company or a gas utility is exempt from the application of the Act and these Rules. (3) A natural gas pipeline that (a) conveys, on an alternating basis, distribution specification gas at pressures of 700 kilopascals or less to a facility, scheme or other matter authorized under the Oil and Gas Conservation Act or the Oil Sands Conservation Act from a gas distribution company or a gas utility, or (b) supplies distribution specification gas at pressures of 700 kilopascals or less to a gas distribution company or gas utility from a facility, scheme or other matter authorized under the Oil and Gas Conservation Act or the Oil Sands Conservation Act , is exempt from the application of the Act and these Rules. (4) A temporary surface pipeline for water conveyance is exempt from the application of these Rules except for sections 1, 4, 7(3)(b) and (4), 14, 15, 27 and 30(2) and (4). (5) A temporary surface pipeline for well testing or bypass is exempt from the application of these Rules except for sections 1, 4, 7(3)(c) and (4), 14, 15, 20, 23, 26(2), 27 and 30(2) and (4). (6) Section 35 of the Act does not apply to a temporary surface pipeline for water conveyance. Exemption — agents 3 (1) In this section, “mutual recognition agreement” means a valid and subsisting agreement made between the Minister and a regulatory authority of another jurisdiction for the purpose of recognizing substantial regulatory equivalency and enabling reciprocity between Alberta and that jurisdiction. (2) The Regulator may, on application, grant an exemption from the requirement under section 19 of the Act to appoint an agent if the licensee applying for the exemption (a) is resident in a jurisdiction outside Alberta that is a party to a mutual recognition agreement and is subject to the authority of the regulatory authority in that jurisdiction, (b) is in compliance with all applicable legislation in Alberta and in the jurisdiction in which the licensee is resident and all applicable directives, orders, decisions, directions and other instruments of the regulatory authority referred to in clause (a) and of the Regulator, (c) provides evidence satisfactory to the Regulator that the licensee meets, and during the time the licence is in effect will continue to meet, the requirements under subsection (3), and (d) agrees to attorn to the jurisdiction of Alberta with respect to all matters, obligations and liabilities pertaining to licences issued by the Regulator. (3) An exemption under subsection (2) is subject to the condition that, in substitution for the requirements under section 19(2)(a), (b) and (c) of the Act, the licensee must have (a) sufficient numbers of individuals who are trained and competent to (i) carry out work relating to the pipelines for which the licensee has been granted a licence in compliance with the requirements of all applicable legislation and all applicable directives, orders, decisions, directions and other instruments of the Regulator, and (ii) respond sufficiently to incidents, including emergencies, and (b) representatives at a pipeline site during any construction, testing, maintenance, repair, ground disturbance and abandonment activities at the pipeline site who are authorized to make decisions respecting all aspects of those activities. (4) An exemption under subsection (2) ceases to have effect immediately on (a) the licensee ceasing to meet a requirement referred to in subsection (2)(a), (b) or (d), or (b) the Regulator determining that it is no longer satisfied that the licensee meets or will continue to meet the requirements set out in subsection (3). AR 125/2023 s3;8/2026 Compliance with directives 4 (1) A licensee must comply with the requirements of (a) Directive 001, (a.1) Directive 011, (a.2) Directive 060, subject to section 70(3), (b) Directive 077, and (c) Directive 088. (2) A person using a pipeline under section 7(3)(b) or (c) must comply with the requirements of Directive 077. (3) A person using a pipeline under section 7(3)(c) must comply with the requirements of Directive 060. (4) Unless otherwise authorized by the Regulator, a licensee, or a person using a pipeline under section 7(3)(b) or (c), must manage drilling waste in accordance with Directive 050 and Directive 058. AR 125/2023 s4;11/2025 Notification 5 (1) Unless otherwise authorized by the Regulator, a licensee who is required to notify the Regulator under these Rules must send the notice electronically through the Regulator’s applicable electronic submission system. (2) Despite subsection (1), a licensee who is required to notify the Regulator of a pipeline leak, break or contact damage must immediately do so by telephoning the Energy and Environmental Response Line or applicable contact as amended from time to time. AR 125/2023 s5;8/2026 Eligibility to hold a licence 6 (1) An applicant must meet the licence eligibility requirements set out in Directive 067 in order to be eligible to hold a licence under the Act. (2) If an applicant meets the licence eligibility requirements of Directive 067 to the satisfaction of the Regulator, the Regulator may grant licence eligibility subject to any restrictions, terms or conditions the Regulator considers appropriate. (3) If an applicant does not meet the licence eligibility requirements of Directive 067 to the satisfaction of the Regulator, the Regulator may refuse to grant licence eligibility. (4) The Regulator may revoke or restrict the licence eligibility of an applicant if the applicant fails to acquire licences under the Act within a year of the day of the licence eligibility being granted by the Regulator. (5) A licensee must continue to meet the licence eligibility requirements of Directive 067. (6) The Regulator may restrict a licensee’s eligibility to hold a licence if a licensee does not continue to meet the licence eligibility requirements of Directive 067. Application for licence 7 (1) Unless otherwise authorized by the Regulator, an application under Part 4 of the Act for a licence to construct and operate a pipeline, including any applicable installation, must be in accordance with the requirements of Directive 056. (2) Unless otherwise authorized by the Regulator, and in addition to the requirements of subsection (1), for a steam distribution pipeline having an internal aggregate capacity greater than 0.5 cubic metres or a pipeline having a design temperature greater than 230 degrees Celsius, the licensee must (a) confirm in its application to the Regulator that the licensee has received design registration of the pipeline and associated fittings in accordance with the Pressure Equipment Safety Regulation (AR 49/2006), and (b) obtain all required approvals from the Alberta Boilers Safety Association (ABSA) prior to putting the pipeline into operation. (3) No application for a licence is required (a) for the replacement of parts of a pipeline or parts of an expanded liner or freestanding liner if (i) the length of each individual replacement section is less than 100 metres, or longer in exceptional circumstances, as the Regulator may allow, (ii) the replacement sections are equivalent to the original material or exceed the requirements and suitability for the purpose of the original material, (iii) the replaced sections of pipeline or pipeline liner are removed, and (iv) the replacement work is carried out wholly within the existing right of way, (b) for a temporary surface pipeline for water conveyance that conveys only group 1 water, group 2 water or group 3 water if the pipeline meets all applicable requirements of Directive 077, and (c) for a temporary surface pipeline for well testing or bypass if the pipeline meets all applicable requirements of Directive 077. (4) An approval is required in accordance with Directive 077 before deploying and operating a temporary surface pipeline for water conveyance that conveys group 2 water or group 3 water or a temporary surface pipeline for well testing or bypass. Survey of right of way boundaries 8 (1) The applicant for a licence must ensure that right of way boundaries for the pipeline are surveyed in accordance with the Surveys Act . (2) An applicant or licensee is exempt from the requirements of subsection (1) with respect to repairs or modifications to a pipeline within the existing right of way unless the repairs or modifications require an additional right of way. (3) The Regulator may exempt an applicant or licensee from the requirements of subsection (1) or (2) in exceptional circumstances. Notice of construction commencement 9 (1) Licensees must provide notice of the commencement of construction to the Regulator at least 24 hours but not more than 14 days before the commencement of any construction of a pipeline. (2) The commencement of construction in subsection (1) includes (a) the fabrication, assembly or installation of a permitted or licensed pipeline, (b) the fabrication, assembly, installation or modification of a pipeline or part of a pipeline as approved in a licence amendment, (c) the installation of a freestanding liner or expanded liner, or the in‑situ application of thin‑film internal coating, as approved in a licence amendment, and (d) the resumption of delayed construction following a licence expiry and reapplication. Notice or application in case of delay or failure to complete construction 10 (1) A licensee must notify the Regulator if the pipeline construction has commenced but there is a delay of 3 months or more in the construction of the pipeline. (2) A licensee must apply to the Regulator for approval in accordance with Directive 056 if (a) the licence has expired or will expire without the pipeline construction having been commenced, or (b) the construction of the pipeline will not be completed. Emergency management program 11 (1) In this section, “EMP” means a corporate emergency management program to (a) identify, assess and mitigate hazards associated with all pipelines of a licensee, and (b) manage the preparation for and response to an emergency. (2) A licensee must, in accordance with Directive 071, develop, implement and maintain an EMP. AR 125/2023 s11;8/2026 Corporate emergency response plan 11.1 A licensee must, in accordance with Directive 071, (a) develop a corporate ERP, and (b) submit the corporate ERP to the Regulator. AR 8/2026 s5 Operation‑specific emergency response plan 11.2 (1) If required by Directive 071, a licensee must, in accordance with Directive 071, develop an operation-specific ERP. (2) A licensee must, in accordance with Directive 071, submit each operation‑specific ERP to the Regulator for approval. AR 8/2026 s5 Maintenance of plan and training 11.3 A licensee must, in accordance with Directive 071, (a) maintain the corporate ERP and any operation‑specific ERP, and (b) undertake training and exercises related to the corporate ERP and any operation‑specific ERP. AR 8/2026 s5 Ability to implement plan re water body 11.4 If, in the opinion of the Regulator, a pipeline is a risk to a water body due to its location near the water body, the Regulator may require the licensee of the pipeline to demonstrate that the licensee has the equipment and the ability to implement all applicable ERPs. AR 8/2026 s5 Records, forms and notifications 11.5 A licensee must, in accordance with Directive 071, (a) maintain and submit records to the Regulator, (b) submit forms to the Regulator, and (c) provide notifications to the Regulator in relation to emergency preparedness and responses. AR 8/2026 s5 Incidents and emergencies 11.6 A licensee must, in accordance with Directive 071, (a) manage incidents, and (b) in the case of an incident that is an emergency, (i) implement all applicable ERPs, and (ii) report the emergency to the Regulator. AR 8/2026 s5 Pipeline records and documents 12 (1) A licensee must maintain records and documents pertaining to the design, materials, construction, commissioning, operation, maintenance, repair, engineering assessments and decommissioning of pipelines in accordance with CSA Z662. (2) All pipeline records and documents required under subsection (1) must be provided to the Regulator on request in a manner and form acceptable to the Regulator. Transfer of records 13 (1) On transfer of ownership of a pipeline, a licensee must transfer to the successor licensee all available and existing records and documents referred to in section 12(1) applicable to the pipeline. (2) The successor licensee must incorporate all records and documents transferred under subsection (1) into its Safety and Loss Management System and Integrity Management Program and determine if there is additional work or information required to effectively manage the pipeline. (3) If relevant records or documents referred to in section 12(1) are lost, damaged, destroyed or incomplete, the successor licensee must conduct an engineering assessment and be able to demonstrate that the pipeline is fit for service. Safety and Loss Management System 14 (1) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must develop and implement a documented Safety and Loss Management System for its pipeline as described in Annex A of CSA Z662. (2) The Safety and Loss Management System must include (a) abandoned pipelines identified under section 25 of the Act and these Rules, (b) temporary surface pipelines, and (c) pipelines that are not in active flowing service. (3) The Regulator may, on request, allow a licensee, or a person using a pipeline under section 7(3)(b) or (c), to use a Safety and Loss Management System that is structured differently than described in Annex A of CSA Z662 if the Safety and Loss Management System is already developed and the licensee or the person using the pipeline under section 7(3)(b) or (c) can demonstrate to the Regulator that the system achieves an equivalent level of protection as described in Annex A of CSA Z662. (4) On request from the Regulator, a licensee, or a person using a pipeline under section 7(3)(b) or (c), must be able to demonstrate to the Regulator that the Safety and Loss Management System of the licensee or the person using the pipeline under section 7(3)(b) or (c), as the case may be, provides for the protection of people, the environment and property and includes a continuous improvement process as required in CSA Z662. (5) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must provide any records and documents related to the Safety and Loss Management System developed under this section to the Regulator on request in a manner and form acceptable to the Regulator. Integrity Management Program 15 (1) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must develop and implement a documented Integrity Management Program for its pipeline as described in Annex N of CSA Z662. (2) The Integrity Management Program must include programs for (a) abandoned pipelines according to section 25 of the Act and these Rules, (b) temporary surface pipelines, and (c) pipelines that are not in active flowing service. (3) On request from the Regulator, a licensee, or a person using a pipeline under section 7(3)(b) or (c), must be able to demonstrate to the Regulator that its Integrity Management Program provides safe, environmentally responsible and reliable pipeline service and is being evaluated at appropriate set intervals. (4) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must provide any records and documents related to the Integrity Management Program to the Regulator on request in a manner and form acceptable to the Regulator. Financial information 16 (1) A licensee must provide financial information to the Regulator, as and when directed by the Regulator, for the purposes of (a) assessing the licensee’s eligibility for holding a licence, (b) administering the liability management programs set out in directives by the Regulator, or (c) ensuring the development of safe, orderly and environmentally responsible energy resources and their closure in Alberta. (2) Subject to subsections (3) and (4), any information provided under this section must be kept confidential by the Regulator for a period of 5 years. (3) The Regulator may make the results of any licensee assessment conducted by the Regulator under Directive 088 available to the public. (4) If requested by an applicant for a transfer of a licence, the Regulator shall make available to the applicant the estimated liability of that licence as determined by the Regulator under Directive 011. AR 125/2023 s16;11/2025 Site‑specific liability assessment 16.1 (1) Subject to subsection (2), a site‑specific liability assessment conducted and submitted by a licensee under Directive 001 must be kept confidential by the Regulator. (2) The Regulator may make the magnitude of estimated liability of a licensee available to the public. AR 11/2025 s5 Part 2 Materials and Design Materials to be provided to Regulator 17 (1) A licensee who is required to (a) take and analyze a representative sample of a substance being conveyed by a pipeline under section 34(1) of the Act, or (b) make inspections, investigations or tests of a pipeline under section 34(2) of the Act must, on request, submit to the Regulator the analysis, inspections, investigations or tests in a manner and form acceptable to the Regulator. (2) The inspections, investigations or tests referred to in subsection (1)(b) may include (a) representative physical samples of materials used in the construction or repair of a pipeline, (b) cut‑outs from a pipeline, or (c) representative physical samples of defective materials. CSA standards 18 (1) Except as otherwise specified by these Rules, the minimum requirements for the design, materials, construction, commissioning, operation, maintenance, repair, engineering assessments and decommissioning of pipelines are set out in CSA Z662. (2) A licensee wishing to incorporate materials manufactured in accordance with a previous edition of a CSA Z245 series standard other than those referred to in the current CSA Z662 may use those materials if an engineering assessment demonstrates equivalency with the current CSA Z245 series standard. Approval of non‑standard materials or methods 19 (1) Despite section 18, if an applicant or licensee proposes to use a polymeric or composite material for pipeline construction or repair, other than those that are included in CSA Z662 or previously reviewed and authorized for use by the Regulator, the applicant or licensee must provide to the Regulator an engineering assessment concerning the material and its potential application to allow the Regulator to determine whether the material is acceptable for the proposed use. (2) Despite section 18, if an applicant or licensee proposes to use pipeline materials, pipeline components, joining methods, construction methods, repair methods or maintenance methods, other than those that are included in CSA Z662 or previously reviewed and authorized for use by the Regulator, the applicant or licensee must provide to the Regulator an engineering assessment concerning the pipeline material, pipeline components, joining methods, construction methods, repair methods or maintenance methods and their potential application to allow the Regulator to determine whether they are acceptable for the proposed use. (3) If the Regulator is satisfied that the materials, components or methods referred to in either subsection (1) or (2) are acceptable for the proposed use, the Regulator may approve the use of the materials, components or methods, subject to such restrictions on or conditions regarding their use as the Regulator considers necessary. Limits on polymeric or composite pipe 20 (1) Unless authorized by the Regulator, a licensee, or a person using a pipeline under section 7(3)(c), must not install polymeric or composite pipe as either freestanding liner inside another pipeline or as a freestanding pipe for the purpose of conveying natural gas containing more than 10 moles of hydrogen sulphide gas per kilomole of natural gas. (2) A licensee, or a person using a pipeline under section 7(3)(c), installing polymeric or composite pipe or changing the service conditions of such installed pipe must ensure the pipe employed is suitable for the intended service conditions and intended service according to the pipe manufacturer or its representative or, in the absence of an available pipe manufacturer or representative, must verify the suitability for use by conducting an engineering assessment. Design for maintenance, inspection and purging 21 (1) Unless otherwise authorized by the Regulator, all new pipelines must be constructed in a manner that can accommodate the passage of maintenance, inspection and purging pigs if pigging is (a) determined to be necessary by the licensee’s Integrity Management Program, or (b) required by CSA Z662. (2) A new pipeline that may require pigging as determined by the licensee’s Integrity Management Program must either be initially constructed with pigging equipment included or be constructed in a manner that can readily accept the addition of pigging equipment. (3) Where a change in operating conditions or an addition or modification is being made to an existing pipeline, the licensee must reassess whether it is necessary for the pipeline to accommodate the passage of maintenance, inspection and purging pigs, either in accordance with the licensee’s Integrity Management Program or under CSA Z662, and must implement the passage of maintenance, inspection and purging pigs accordingly prior to operation under the new operating conditions. Pipeline maintenance pigs 22 Where a licensee determines that pigging is required under its Integrity Management Program, the licensee must ensure that pigs used for pipeline cleaning, corrosion control and purging are appropriate for the intended purpose, properly sized and replaced if worn beyond limits specified in the Integrity Management Program. Emergency shutdown devices and check valves 23 (1) A licensee, or a person using a pipeline under section 7(3)(c), must ensure that a pipeline conveying a substance that under operating conditions contains a separate gas phase having gas containing more than 10 moles of hydrogen sulphide gas per kilomole of natural gas, or any lesser hydrogen sulphide content that the Regulator may stipulate, is equipped with automatically actuated emergency shutdown devices or check valves. (2) A licensee, or a person using a pipeline under section 7(3)(c), must conduct an engineering assessment to define the pipeline operating conditions and the closure parameters of the automatically actuated emergency shutdown devices or check valves referred to in subsection (1) to ensure the release volume used in calculating the emergency planning zone in the event of a pipeline leak or break is as low as reasonably practicable. (3) A licensee, or a person using a pipeline under section 7(3)(c), must ensure that the automatically actuated emergency shutdown devices or check valves referred to in subsection (1) (a) isolate the pipeline into segments whose volumes are in accordance with the emergency response plan prepared under section 11, and (b) automatically close as defined by the engineering assessment required in subsection (2) if a pipeline leak or break occurs. (4) A licensee, or a person using a pipeline under section 7(3)(c), must ensure that the automatically actuated emergency shutdown devices referred to in subsection (1) (a) close on the failure of any control or operating component, (b) remain closed once the devices have closed due to actuation or failure, and (c) require on‑site human intervention to reopen once they have closed unless they were closed due to a planned pipeline shutdown. (5) A licensee, or a person using a pipeline under section 7(3)(c), must not allow the pipeline or the automatically actuated emergency shutdown devices to operate outside of the conditions defined within the engineering assessment conducted under subsection (2). (6) If the licensee, or a person using a pipeline under section 7(3)(c), determines that the pipeline or the automatically actuated emergency shutdown devices could be operating outside of the conditions defined by the engineering assessment conducted under subsection (2), the licensee, or the person using a pipeline under section 7(3)(c), must shut down the pipeline until (a) the pipeline and the automatically actuated emergency shutdown devices can be operated within the defined conditions, or (b) the licensee, or the person using a pipeline under section 7(3)(c), completes an engineering assessment, as specified in subsection (2), and revises the emergency planning zone, as required by Directive 071. (7) Unless otherwise authorized by the Regulator, a licensee, or a person using a pipeline under section 7(3)(c), must maintain a record of the current engineering assessment conducted under subsection (2) and the actions taken under subsection (6) until the pipeline is abandoned. (8) A licensee, or a person using a pipeline under section 7(3)(c), must conduct all preventative maintenance required to ensure operability of the automatically actuated emergency shutdown devices and check valves referred to in subsection (1) and maintain a record of all preventive maintenance. (9) A licensee must conduct an annual inspection, assessment and test, with a maximum interval of 18 months between such activities, of the automatically actuated emergency shutdown devices and check valves referred to in subsection (1) to ensure that the devices are operating as required and maintain a record of the inspection, assessment and test. Control systems in blended gas streams 24 (1) Unless otherwise authorized by the Regulator, where gas streams are blended for the purpose of maintaining a lower hydrogen sulphide content in the final blended gas stream, and any inlet stream conveys gas containing hydrogen sulphide, the licensee must ensure that there are 2 independent safety systems to prevent a greater hydrogen sulphide content in the blended gas stream than permitted in the licence. (2) A licensee must ensure that one of the 2 independent safety systems referred to in subsection (1) provides, as a minimum, the process control to achieve the blend ratio and that the other system provides, as a minimum, monitoring and automatic shutdown. (3) A licensee must (a) conduct an annual inspection, assessment and test, with a maximum interval of 18 months between such activities, of the 2 independent safety systems referred to in subsection (1) to ensure that the safety systems are operating as required, and (b) maintain a record of the inspection, assessment and test referred to in clause (a). Equipment pressure ratings 25 A licensee must ensure that any new construction or modification of a pipeline complies with the following: (a) all components have pressure ratings equal to or greater than the licensed maximum operating pressure and account for the maximum design temperature of the pipeline; (b) the licensed maximum operating pressure for any pipeline components, if manufactured using other non‑CSA standards as allowed by CSA Z662, must not exceed the values expressed for the corresponding pressure nominal (PN) class designations as expressed in the CSA Z245 series standards, unless otherwise authorized by the Regulator. Stress level limitations 26 (1) For pipelines designed to convey gas with a content of more than 10 moles of hydrogen sulphide gas per kilomole of natural gas, the design stress levels may not be greater than 60% SMYS for all underground and above‑ground piping. (2) For temporary surface pipelines, including temporary surface pipelines for well testing or bypass that are used under section 7(3)(c), designed to convey gas with a content of more than 10 moles of hydrogen sulphide gas per kilomole of natural gas, the design stress levels may not be greater than 50% SMYS. Maximum noise levels 27 A licensee, or a person using a pipeline under section 7(3)(b) or (c), must operate pipeline facilities and conduct pipeline construction and operations in accordance with the maximum noise level limitations specified in Directive 038. Pipeline crossing highway or road 28 (1) When constructing a pipeline across a road, highway right of way or road allowance, the licensee must apply the CSA Z662 pipeline design requirements applicable to the crossing for the full width of the road, highway right of way or road allowance. (2) Prior to the initiation of any construction related to the building, improving or widening of a road or highway over an existing pipeline, or extending a road or highway right of way over an existing pipeline, the pipeline at such locations must either be upgraded or otherwise meet the requirements of CSA Z662 respecting crossings of existing pipelines. Minimum earth cover 29 (1) Unless otherwise required by the Regulator, and subject to subsection (2), the minimum earth cover for any operating or discontinued pipeline must be the greater of (a) the earth cover specified in CSA Z662, (b) the applicable specified minimum of (i) 1.4 metres within the entire right of way of a highway, (ii) 1.2 metres within the entire right of way of a road, and (iii) 0.8 metres in any other place, and (c) the earth cover necessary to sufficiently protect the pipeline, as demonstrated by an engineering assessment. (2) Unless otherwise required by the Regulator, if the earth cover permitted by the construction standards and regulatory requirements in place at the time of a pipeline’s construction was lesser than the one referred to in subsection (1), and an engineering assessment demonstrates the existing cover sufficiently protects the pipeline in its present situation, that earth cover is acceptable. (3) In addition to subsections (1) and (2), for pipelines constructed after the Code of Practice for Pipelines and Telecommunication Lines Crossing a Water Body came into force, the minimum earth cover for any pipeline must comply with the applicable requirements of the Code of Practice for Pipelines and Telecommunication Lines Crossing a Water Body for ensuring scour protection of pipelines at pipeline crossings of a water body. (4) Where the earth cover for a pipeline does not meet the minimum requirements under this section, a licensee must address any deficiency by lowering the pipeline, adding the required earth cover or implementing additional protective actions as may be allowed by the applicable legislation. (5) A licensee must ensure that any abandoned pipeline has adequate earth cover so that (a) the pipeline does not interfere with the intended usage of any land or water body it crosses, and (b) the earth cover complies with any applicable requirements under the Water Act . (6) Where a licensee becomes aware that any portion of a licensed pipeline is exposed for any reason other than a planned ground disturbance, the licensee must (a) immediately advise the appropriate regional field centre of the Regulator, and (b) restore the earth cover as required under this section or remove the exposed pipeline. Installing surface pipelines 30 (1) A licensee who intends to install a surface pipeline must do so in accordance with the requirements set out in this section, section 26(2) and Directive 056. (2) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must install (a) a form of pressure‑relieving device if any possibility of a pressure increase above the allowable maximum operating pressure exists due to a rise in ambient air temperature or solar heating, (b) a system to allow for adequate expansion or contraction due to temperature change, (c) temperature monitoring equipment if the pipeline material has temperature limitations, (d) suitable restraints to adequately control lateral or vertical movement, and (e) any other safety or operational systems as the Regulator considers appropriate. (3) A licensee must bury the pipeline at all road and trail crossings and must install pipeline warning signs at the point of pipeline entry and exit of each crossing. (4) A licensee, or a person using a pipeline under section 7(3)(b) or (c), must take additional precautions, including adding extra pipeline warning signs or providing other warnings to indicate the presence of a surface line when (a) equipment may be operating in the vicinity of the pipeline, (b) off‑road vehicular traffic may endanger the pipeline, or (c) any conditions may obscure or endanger the pipeline. Operating pressure 31 (1) Unless otherwise authorized by the Regulator, a licensee must design and maintain each pipeline segment in a manner suitable for the maximum operating pressure permitted in the licence. (2) Unless otherwise authorized by the Regulator, the operating pressure of a pipeline at all points must not exceed the licensed maximum operating pressure except as allowed by CSA Z662. (3) Where 2 or more pipelines or pipeline segments having different licensed maximum operating pressures are connected and the difference between the licensed maximum operating pressures is greater than 5% of the lowest licensed maximum operating pressure, the licensee must either (a) amend the licensed maximum operating pressure as necessary to not exceed a difference of 5% of the lowest licensed maximum operating pressure, or (b) install a pressure control system and overpressure protection system in accordance with CSA Z662 to ensure that the lower licensed maximum operating pressure pipeline is operated in accordance with the maximum operating pressure permitted in its licence.

(4) The requirements in subsection (3) do not apply (a) if the pipeline incorporates point‑specific pressure design due to varying elevation, (b) where the pressure source or sources, with or without pumping or compression, cannot exceed the lowest licensed maximum operating pressure of any of the connected pipelines, or (c) where the pressure source or sources, with or without pumping or compression, can exceed the lowest licensed maximum operating pressure of any of the connected pipelines, but each pressure source is equipped with individual pressure control and overpressure protection in accordance with CSA Z662 that prevents exceeding the lowest licensed maximum operating pressure of any of the connected pipelines. (5) Unless otherwise authorized by the Regulator, the maximum operating pressure of a section of a pipeline must be determined using the test pressure recorded or calculated at the highest point in the section. Part 3 Pressure Testing Placing pipeline into operation 32 (1) Unless otherwise authorized by the Regulator, a licensee must not place a newly constructed or modified pipeline into operation until a satisfactory pressure test has been completed in accordance with CSA Z662, as applicable, and these Rules. (2) Unless otherwise authorized by the Regulator, a licensee resuming the operation of a pipeline from licensed discontinuance, abandonment or a period of non‑use must confirm pipeline integrity by conducting an engineering assessment in accordance with CSA Z662 and these Rules. (3) Unless otherwise authorized by the Regulator, a licensee returning a pipeline to service following repair must confirm pipeline integrity by conducting an engineering assessment in accordance with CSA Z662 and these Rules. (4) If an engineering assessment conducted under subsection (2) or (3) demonstrates a lack of integrity in any part of the pipeline, or if the pipeline is otherwise not fit for service, the licensee must take corrective action respecting the pipeline in accordance with CSA Z662 and these Rules before resuming operation of the pipeline or returning the pipeline to service, as the case may be. AR 125/2023 s32;243/2025 Notice to Regulator 33 (1) A licensee must notify the Regulator at least 48 hours before the commencement of any pressure test. (2) Despite subsection (1), no notice is required to conduct a pressure test that does not exceed the licensed maximum operating pressure of the pipeline. (3) A licensee must immediately notify the Regulator of any leak or break that occurs in a pipeline during any pressure test. Conditions for pressure testing 34 (1) A licensee must pressure test a pipeline that will be buried during operation with the full depth of earth cover applied other than at the bell-holes where joints are intended to be visually inspected or the test heads. (2) A licensee is exempted from the requirements in subsection (1) if the pipeline is a pull section being pre‑tested on the surface of the land, prior to trenchless or open cut installation techniques and is to be followed by a pressure test after final installation. Regulator’s direction on pressure testing 35 (1) The Regulator may specify the maximum length of pipe to be pressure tested in any pressure test. (2) The Regulator may prohibit a pressure test if the Regulator believes it to be unsafe or unsuitable. (3) The Regulator may require a pipeline to be retested if in the opinion of the Regulator it may be unsafe for the pipeline to continue to operate. Recording pressure test results 36 (1) A licensee must record the data during a pressure test and retain the record or chart of the results in accordance with the licensee’s Integrity Management Program and Safety and Loss Management System. (2) A licensee’s record or chart of a pressure test must be continuous and legible over the full test period, regardless of the type of recording equipment used, and include start and end dates and times, a continuous pipeline temperature trace, a legal land description of to and from locations, the licence number, the segment number and any additional information required by CSA Z662 and the Regulator. (3) A licensee may use electronic pressure‑recording and charting instruments if (a) a permanent copy of the pressure test data is retained by the licensee in a manner accessible to the Regulator on request, and (b) the sampling rate, resolution and instrument range are sufficient to properly record the expected data. (4) Each pressure‑recording instrument must be periodically calibrated in accordance with CSA Z662, and the Regulator may require verification of such calibration. Unsatisfactory pressure test 37 If evidence of a satisfactory pressure test is not provided to the Regulator on request, or the Regulator does not find the test satisfactory, the Regulator may order that the pipeline be (a) depressurized, (b) purged, if necessary, and (c) pressure tested as directed by the Regulator. Minimum test pressure 38 For a pressure test, a licensee must use a minimum test pressure of (a) not less than 700 kilopascals for any pipeline, unless the Regulator approves a lower test pressure, and (b) not less than 1.4 times the maximum operating pressure for gas pipelines conveying gas containing more than 10 moles of hydrogen sulphide gas per kilomole of natural gas. Pressure near test head assembly 38.1 The test pressure for any part of a pipeline that is within 20 metres of the connection with the test head assembly must be limited to a hoop stress level not greater than 90% SMYS. AR 243/2025 s4 Pressure testing using liquid test media other than fresh water 39 A licensee intending to pressure test a pipeline using a liquid test media other than fresh water must comply with the liquid test media pressure testing requirements of Directive 077. Pressure testing using gaseous test media 40 A licensee intending to pressure test a pipeline using air or other gaseous test media must comply with the gaseous media pressure testing requirements of Directive 077. Duration of pressure test 41 A licensee, in exceptional circumstances, may apply to the Regulator to pressure test a pipeline or section of a pipeline for a shorter period than the minimum specified in CSA Z662. Part 4 Ground Disturbance No fees for ground disturbance 42 A licensee must locate and mark its pipeline, execute consents and approvals required for ground disturbance and perform supervision and inspections of ground disturbance as required by this Part without charging any fee or requiring the party undertaking the ground disturbance to pay for expenses. Ground disturbance approval 43 (1) No ground disturbance may be undertaken in the right of way of a pipeline until an approval specified in section 42 of the Act is obtained. (2) No person shall undertake a ground disturbance within 5 metres of the centreline of a pipeline where there is no pipeline right of way until an approval is obtained (a) from the licensee of the pipeline, or (b) from the Regulator, if approval cannot reasonably be obtained from the licensee. (3) A request for an approval under this section is to be made (a) to the licensee, who must respond in writing within 21 days from the date of the request, or (b) to the Regulator, if the licensee is unable to respond to the request, who may grant approval on such terms and conditions as the Regulator considers appropriate in the circumstances. Damage prevention service 44 Every licensee must register with the Utility Safety Partners’ damage prevention service and must (a) register all of its licensed pipeline with Utility Safety Partners regardless of the operational status of the pipeline, (b) for new construction, register the pipeline prior to putting it into operation, and (c) update the registered inventory as often as necessary to ensure the licensee’s pipeline data is accurate. Preparing for ground disturbance 45 (1) For the purposes of section 32(1)(a)(i)(B) of the Act, the distance from the perimeter of the area in which a person proposes to undertake a ground disturbance within which the person must take all precautions reasonably necessary to ascertain whether a pipeline exists before commencing any work, operation or activity is 30 metres. (2) A person proposing to undertake a ground disturbance within either the controlled area of a pipeline or within the right of way of a pipeline must notify Utility Safety Partners at least 3 days and not more than 10 days, excluding Saturdays, Sundays and holidays, before commencing the ground disturbance to allow Utility Safety Partners to notify the licensee of any buried pipeline of the intent to disturb the ground and request that the licensee identify and mark the location of the pipeline. (3) Should Utility Safety Partners be unable to notify the licensee of any buried pipeline, the person proposing to undertake the ground disturbance must make reasonable efforts to directly notify the licensee of the pipeline to request that the licensee identify and mark the location of the pipeline. Locating and marking of pipelines 46 (1) A licensee who has been given notice of a proposed ground disturbance in the controlled area or right of way of its pipeline must, before the commencement of the ground disturbance, accurately locate and mark on the surface of the ground the horizontal position and alignment of the pipeline with clearly distinguishable warning signs and markers at adequate intervals in accordance with the Uniform Color Code, and provide documentation of the markings to the person conducting the ground disturbance. (2) The locating and marking referred to in subsection (1) must be provided no later than 3 days, excluding Saturdays, Sundays and holidays, after the licensee is notified of the proposed ground disturbance, unless a longer period is necessary due to locator availability constraints, or as the licensee and the person conducting the ground disturbance agree otherwise. (3) If the person proposing to undertake the ground disturbance wishes to carry out the locating and marking of the pipeline in accordance with the requirements under subsection (1) and obtains the prior agreement of the licensee to do so, the licensee may delegate its responsibility and associated expenses under subsection (1) and the supervision of the ground disturbance in the absence of the licensee to that person. (4) If the person conducting the ground disturbance requests the locating and marking of the pipeline by contacting Utility Safety Partners and also by attempting to contact the licensee directly, and neither effort succeeds, the person conducting the ground disturbance is responsible for arranging for the accurate locating and marking of the pipeline in accordance with subsection (1) and for the supervision of the ground disturbance in the absence of the licensee. (5) The person conducting the ground disturbance must (a) keep all pipeline warning signs or markers referred to in subsection (1) visible and legible and in their original position for the duration of the ground disturbance, and (b) in the event that any warning sign, marking or marker is moved or becomes illegible, (i) restore or re‑mark it if the original position is exactly known, or (ii) request for new locating and marking if the original position is uncertain. (6) Despite subsection (1), alternative methods of locating and marking a pipeline may be used if the licensee and the person conducting the ground disturbance agree. (7) The locating and marking referred to in subsection (1) is not required if (a) the ground disturbance is proposed to be undertaken in the controlled area outside the right of way of an existing pipeline, (b) the right of way or pipeline is clearly separated from the proposed ground disturbance by a highway, road or other visible improvement, and (c) the licensee of any affected pipeline agrees to the exemption from the requirements under subsection (1). (8) The requirements under subsections (1) and (2) do not apply if the Regulator is satisfied that (a) a ground disturbance is undertaken in connection with the restoration of essential public services in an emergency or containment of an environmental emergency, and (b) the licensee of any affected pipeline agreed to alternative notification, location and excavation procedures to ensure the safe excavation of the pipeline. Supervision of ground disturbance 47 A licensee of an existing pipeline who has been notified under section 32(1)(b) of the Act of a proposed ground disturbance must (a) have a representative inspect the pipeline before the commencement of the ground disturbance to ensure that the locating and marking referred to in section 46(1) have been properly carried out, (b) if the ground disturbance is within the right of way, ensure that its representative on‑site at the time of the ground disturbance has a copy of the written approval for the ground disturbance in the representative’s possession, (c) ensure that its representative is certified in supervisory level ground disturbance, and (d) carry out, document and retain any inspections of the ground disturbance that are necessary to ensure the continued safety of the pipeline. Control of access over right of way 48 (1) Before commencing a ground disturbance in the controlled area of a pipeline where uncontrolled access over the pipeline by equipment may cause damage to the pipeline, the person conducting the ground disturbance must consult with the licensee and install any access controls needed to protect existing pipelines. (2) Before commencing a ground disturbance referred to in subsection (1), the licensee and the person conducting the ground disturbance must determine and agree on the location of crossings and the precautions to be taken to protect pipelines from damage during ground disturbance. Vehicles crossing pipeline 49 (1) Except where otherwise provided in this section, no person shall operate a vehicle or equipment across a pipeline at a point that is not within the upgraded and traveled portion of a highway or public road without first obtaining consent from the licensee of the pipeline. (2) A person seeking consent in subsection (1) must notify the licensee at least 7 days, not including Saturday, Sunday or holidays, before the proposed crossing. (3) On receiving notification under subsection (2), a licensee must respond to the person proposing the crossing within 7 days, not including Saturday, Sunday or holidays, and the response must include any precautionary measures that must be applied to safeguard the pipeline from potential damage before the crossing is made. (4) The consent of the licensee under subsection (1) is not required for a vehicular crossing by (a) a vehicle or equipment designed to minimize ground pressure, (b) a vehicle used for agricultural operations, (c) an off‑highway vehicle as defined in section 117(a)(iii) to (viii) of the Traffic Safety Act , or (d) a commercial vehicle or a private passenger vehicle as defined in the Traffic Safety Act , having a nominal chassis rating of not greater than 2 tonnes. Safety of adjacent pipeline 50 The Regulator may require that an existing pipeline located adjacent to a ground disturbance in the controlled area of the pipeline be depressurized, operated at a reduced pressure or otherwise protected throughout the period of the ground disturbance. Exposing pipeline 51 (1) When a ground disturbance approaches within 5 metres of a pipeline, the person conducting the ground disturbance must expose the existing pipeline using hand excavation methods until positive identification and orientation of the pipeline is achieved, and before any further mechanical excavation may continue. (2) If hand excavation of polymeric or composite pipelines is being conducted by high‑pressure water or air excavation methods, those methods and procedures must be in accordance with the pipeline manufacturer’s recommendations or industry best practices, as available, and must be acceptable to the licensee of the existing pipeline. (3) Under this section, at the time the pipeline is being exposed, either a representative of the licensee of the existing pipeline or a designated delegate the licensee agreed to accept, who meets the requirements of section 47(c), must be present. (4) Despite subsection (1) and subject to subsection (5), an existing pipeline does not need to be fully exposed if (a) the existing pipeline is located, marked and inspected in accordance with sections 46(1) and 47, and hand excavation to a distance of 5 metres on each side of the centreline of the marked position and to a depth at least 0.6 metres greater than that required for the ground disturbance has not exposed the pipeline, (b) the position of the existing pipeline has been verified to the satisfaction of the licensee of the existing pipeline by comparison with recorded measurements of the pipeline taken during a previous exposure, (c) the proposed ground disturbance will be parallel to and within 5 metres of an existing pipeline, in which case the pipeline must be exposed at intervals along the pipeline, with the length of the intervals being at the discretion of the licensee of the existing pipeline, or (d) in the case of a trenchless excavation technique, the drill or bore path is confirmed during the drilling process to be more than 5 metres deeper than the confirmed depth of the existing pipeline. (5) After an existing pipeline has been exposed in accordance with this section, no mechanical excavation equipment shall be used within 0.6 metres of the pipeline or within any distance beneath a pipeline, except under the direct supervision of either a representative of the licensee of the existing pipeline or a designated delegate the licensee agreed to accept, who meets the requirements of section 47(c). (6) Where a ground disturbance is conducted using trenchless excavation techniques and the intended tool path is expected to pass within 5 metres of the existing pipeline, that pipeline must be first exposed to allow for its identification and confirmation of direction and depth, and to allow for confirmation that the trenchless tool path does not encroach on and endanger the pipeline. (7) For the purpose of subsection (6), for a trenchless excavation crossing the path of the existing pipeline, the hand excavation must (a) be located within 5 metres of the existing pipeline, (b) extend to a depth of at least one metre deeper than the existing pipeline, (c) run parallel to the existing pipeline for a distance of at least 2 metres on each side of the intended tool path, and (d) be of adequate width to allow for effective visual monitoring of the tool path. (8) For the purpose of subsection (6), for a trenchless excavation running parallel to, or otherwise not crossing the path of the existing pipeline, the hand excavation must (a) run parallel to and be offset from the existing pipeline, (b) extend to a depth of at least one metre deeper than the existing pipeline, (c) be located between the intended tool path and the existing pipeline, (d) be installed at intervals adequate to identify any critical deviation of the tool from the intended tool path, and (e) be of adequate width and length to monitor for deviation of the tool path. (9) If a pipeline is to be exposed by the licensee of the pipeline, the licensee may make a written request to the Regulator for approval to use alternate pipeline exposure methods and procedures in exceptional situations. Inspection prior to backfilling 52 A person undertaking a ground disturbance who exposes any part of a pipeline must notify the licensee at least 24 hours before backfilling the pipeline, and on being so notified, a representative of the licensee who meets the requirements of section 47(c) must inspect without delay the exposed part of the pipeline before backfilling to ensure that no damage has occurred. Part 5 Warning Signs Location of pipeline warning signs 53 A licensee must install pipeline warning signs as follows: (a) at each side of the crossing where a pipeline crosses (i) a highway, road, railway, irrigation canal, or (ii) a creek, stream or river where water is present year‑round; (b) where a pipeline right of way meets the right of way of a highway, road or railway, on the common boundary of the rights of way but not within the right of way of the highway, road or railway; (c) where a pipeline is located in a ditch or unpaved area and running parallel to the right of way of a highway or road, at intervals that clearly and continuously mark the location of the pipeline; (d) where the pipeline is conveying HVP products, carbon dioxide or hydrogen in an urban area, at intervals that will clearly and continuously mark the location of the pipeline. AR 125/2023 s53;243/2025 Installation of pipeline warning signs 54 Pipeline warning signs required by section 53 must be installed (a) prior to the commencement of operation of the pipeline, (b) in accordance with any of the formats set out in Schedule 1 that is consistent for the entire pipeline under the licence, (c) within the land acquired for the pipeline and with writing facing towards the most likely point of viewing, (d) no more than 0.3 metres from a fence line, if one exists, (e) as close to the centreline of the pipeline as reasonable without risking striking the pipeline, (f) so that each sign is fully visible, (g) as a freestanding structure not attached to any structure other than fencing surrounding the licensee’s equipment or facility, and (h) without indicating on the sign that a pipeline is abandoned. Maintenance of pipeline warning signs 55 A licensee must, for all pipelines, including abandoned pipelines, (a) replace or restore any pipeline warning sign that becomes defaced, illegible, missing or destroyed, (b) update the information on the sign when necessary, either by replacing the sign or applying durable permanent adhesive decals, (c) in the event of a change to the emergency telephone number, update the signs before the displayed phone number becomes invalid, (d) in the event of a change to any other information as required by Schedule 1, update the signs within 180 days of the change of information, and (e) where a pipeline or part of a pipeline has been removed, remove any existing warning signs applicable to that area. Alternate signage 56 Despite section 54, a licensee may request, in exceptional circumstances, from the Regulator permission to install warning signs other than in accordance with Schedule 1. Temporary pipeline warning signs 57 (1) Despite section 54, a licensee may install temporary pipeline warning signs not in accordance with Schedule 1 during surface restoration activities. (2) The temporary signs installed under subsection (1) must be replaced with permanent signs in accordance with Schedule 1 as soon as restoration activities are completed. HVP product 58 Warning signs for a pipeline conveying HVP product must clearly indicate the name of the highest vapour pressure product that may be conveyed in accordance with Schedule 1. Group pipeline signs 59 (1) A licensee may install group pipeline warning signs for a group of pipelines in the same right of way or adjoining rights of way, rather than a separate sign for each pipeline, if (a) the licensee is the same for each pipeline in the group, (b) each pipeline in the group conveys the same product, (c) the warning sign, in accordance with Schedule 1, identifies that there are other pipelines close by, including at what sides of the sign the pipelines are located, and (d) none of the pipelines in the group convey HVP product or gas containing more than 10 moles of hydrogen sulphide gas per kilomole of natural gas. (2) The warning signs referred to in subsection (1) (a) must be placed at both sides of the right of way or adjoining rights of way containing the group of pipelines, (b) must not be more than 60 metres apart, and (c) must be placed at each side of the crossing. Identification of pipeline installations 60 (1) A licensee must install pipeline warning signs in accordance with Schedule 1 adjacent to all pipeline installations, including meter regulator stations and regulator stations, valve stations, field manifolds and line heaters. (2) A licensee must install an identification sign in accordance with Schedule 2 at the entrance to any gas compressor station or liquid pump station that is licensed as a pipeline installation showing the following as set out in Schedule 2: (a) the name of the installation; (b) the legal land location of the installation; (c) the name of the licensee; (d) an emergency telephone number and any warning symbols. (3) Warning symbols identifying the hazard at a pipeline installation referred to in subsection (2) must include, if applicable, (a) Category I: Flammable (gas or liquid), and (b) Category II: Poisonous Gas. Part 6 Changes to Pipeline Liner and internal protection installation 61 Unless otherwise authorized by the Regulator, an application to the Regulator for approval to install or remove a liner in a pipeline, whether expanded or freestanding or an in‑situ application of a thin‑film internal coating as internal protection, must be in accordance with the requirements of Directive 056. AR 125/2023 s61;243/2025 Liner and internal protection installation in sour service 62 If an expanded liner or an in‑situ‑applied thin‑film internal coating as internal protection is to be installed in a pipeline to be used in sour service, as defined in CSA Z662, and the hoop strength capability of the lined system depends on the strength of the exterior pipeline, the exterior pipeline must be in accordance with the sour service requirements of CSA Z662 and these Rules. Change in substance or pressure 63 Unless otherwise authorized by the Regulator, an application must be made to change the substance or the licensed maximum operating pressure of a pipeline in accordance with the requirements of Directive 056. Testing requirements for change in substance or pressure 64 The Regulator may establish any testing requirements it considers necessary for the approval of a change in substance conveyed or in licensed maximum operating pressure. Part 7 Relocation or Alteration of Pipeline or Other Regulator Direction Application for direction under section 33 of Act 65 (1) An application to the Regulator for a direction under section 33 of the Act must include (a) a sketch, map or drawing that identifies (i) the present location of the pipeline where the alteration, relocation or addition is proposed, (ii) the name of the licensee and the licence number of the pipeline, (iii) the proposed pipeline alteration, relocation or addition, and (iv) details of any surface work or improvement at the pipeline location if the alteration, relocation or addition is to accommodate the surface work or improvement, (b) the specifications of the pipeline and any associated casing, (c) a statement concerning (i) the purpose of the pipeline alteration, relocation or addition and the reason the applicant considers it to be in the public interest, (ii) any documented evidence relating to prior knowledge by the licensee, landowner or another licensee of the surface work or improvement affecting the pipeline, and (iii) the opinion of the applicant about allocation of costs necessary to complete the pipeline alteration, relocation or addition and the reasons for it, (d) an estimate of total costs for the alteration, relocation or addition, if known, (e) a list of landowners and occupants of property affected by the proposed pipeline alteration, relocation or addition, and (f) a list of the status of acquisition of right of way, working space and consents of owners and occupants for any proposed pipeline alteration, relocation or addition. (2) The Regulator may require the licensee to perform any testing that it considers necessary prior to making a direction under section 33 of the Act. Notice to Regulator 66 (1) A licensee must notify the Regulator when the work according to a direction under this Part has been completed. (2) After receiving a notice under subsection (1), the Regulator may amend the licence. Part 8 Release of Product and Contact Damage Report of leak, break or contact damage 67 (1) For the purpose of section 35 of the Act, if a leak, break or contact damage occurs in a pipeline or from the part of a pipeline or its isolation valves that differentiate the pipeline from any other equipment of a pipeline installation, the licensee must immediately report the leak, break or contact damage to the Regulator in accordance with section 5(2). (2) Subject to any other reporting obligations, if a release occurs on a facility surface lease or public lands disposition containing a pipeline installation but not from the pipeline or its isolation valves that differentiate the pipeline from any other equipment located on the lease or disposition, as the case may be, notification is required if the release (a) is of a volume of 2 cubic metres or more, or (b) may cause, is causing or has caused an adverse effect as defined in the Environmental Protection and Enhancement Act . (3) If a leak, break or contact damage has been reported to the Regulator in accordance with subsection (1), the licensee, on request, must submit to the Regulator a written report indicating (a) the time and location of the leak, break or contact damage, (b) the approximate quantity of substance lost, if any, (c) the method of repair, if applicable, (d) the conditions that caused or contributed to the leak, break or contact damage and any substantiating reports, (e) the steps to be taken to prevent similar occurrences in the future, (f) information regarding the spill containment and recovery techniques, and (g) any other information that the Regulator may request. (4) If a leak, break or contact damage has been reported to the Regulator in accordance with subsection (1), (a) the Regulator may require the licensee to conduct inspections, investigations, testing or an engineering assessment of an affected pipeline, and (b) the licensee must maintain a record of the leak, break or contact damage in accordance with the licensee’s Integrity Management Program and Safety and Loss Management System. AR 125/2023 s67;243/2025;8/2026 Containment of leak or break 68 If substances escape from a leak or break in a pipeline, the licensee, on detection of the leak or break, must take immediate steps to stop the source of release and contain and clean up the substances. Repair of leak, break or contact damage 69 If a leak, break or contact damage occurs in a pipeline, the Regulator may specify the method of repair. Intentional release of gas 70 (1) Unless otherwise authorized by the Regulator, and subject to subsection (2), no licensee shall intentionally release to the atmosphere any natural gas not meeting the definition of distribution specification gas in section 1(1)(r) either without combusting the gas in an approved manner or otherwise treating the gas to meet the distribution specifications. (2) Subsection (1) does not apply to gas released for short duration and intermittently from (a) corrosion coupon fittings and corrosion probe fittings, (b) composite pipe vents or the annulus vents of a pipeline with an expanded liner, (c) pigging traps and associated venting valves, once purged with clean gas, or (d) the blowdown of water traps or drains. (3) Gas vented from the equipment described in subsection (2) (a) does not require an approval under Directive 060, (b) must not be vented continuously, except as allowed under subsection (4), and (c) must not cause off‑lease or off‑right of way odours. (4) Annulus vents of a pipeline with an expanded liner must not be left open beyond the time recommended by the liner manufacturer or installer unless the vents are permanently connected to a gas treatment system designed for continuous operation and that treats any gas vented to meet the distribution specifications. (5) Any other gas vented from a pipeline must be vented in accordance with the requirements of Directive 060. Part 9 Discontinuance, Abandonment, Removal and Resumption General 71 (1) Unless otherwise authorized by the Regulator and subject to section 72, any pipeline that has not been in active flowing service for 24 months must be discontinued, abandoned or returned to active flowing service. (2) The licensee must manage a pipeline that is not in active flowing service in accordance with the licensee’s Integrity Management Program. (3) The licensee, on request of the Regulator, must provide records or documents that demonstrate that any pipeline not in active flowing service is being managed in accordance with the licensee’s Integrity Management Program. Duty to maintain and manage as operating 72 (1) Despite section 71, if a pipeline or part of a pipeline cannot be physically isolated or disconnected from an operating pipeline, it shall not be discontinued or abandoned but must be maintained as an operating pipeline under the licensee’s Integrity Management Program. (2) Dead legs that are continually exposed to operating pipeline conditions must be managed as an operating pipeline according to the licensee’s Integrity Management Program and are considered to be operating for the purposes of section 82. Application in case of discontinuance, abandonment or removal 73 (1) Unless otherwise authorized by the Regulator, a licensee discontinuing, abandoning or removing a pipeline or discontinuing or abandoning an entire pipeline system under this Part must apply to the Regulator for approval in accordance with the requirements of Directive 056 within 90 days of the completion of the discontinuance, abandonment or removal operation, as the case may be. (2) An application for discontinuance or abandonment of an entire pipeline system under subsection (1) must include a cover letter explaining the scope and circumstances of the system abandonment or discontinuation, as the case may be, and a listing of all line segments. Discontinuance or abandonment of entire pipeline system 74 Where a licensee intends to discontinue or abandon an entire pipeline system by isolating or disconnecting the pipelines within that system from every well, facility or pipeline that could provide a pressure source, the discontinuance or abandonment may take place without the removal of underground tie‑ins within the system subject to the following: (a) an application for approval for discontinuance or abandonment of the entire pipeline system is made under section 73; (b) all other requirements applicable to discontinuance or abandonment in this Part shall apply. Conducting discontinuance 75 Unless otherwise authorized by the Regulator, the licensee must ensure that the pipeline or the part of the pipeline that is discontinued is (a) pigged or cleaned to remove any free conveyed substances and debris as thoroughly as reasonably possible, (b) protected effectively against internal corrosion by purging with air or inert gas, or fresh water that is suitable for the pipeline materials, (c) protected effectively against external corrosion by maintaining effective cathodic protection, (d) physically isolated or disconnected from any pressure source, well, facility or other pipeline and plugged or capped by mechanical or welded means, except as allowed by section 74, (e) not isolated or disconnected in a manner that results in an adjoining operating pipeline being left with connection points that could be subject to internal corrosion due to stagnant fluid traps or dead legs, (f) left in a safe condition that does not pose a threat to the environment or to a person who may come into proximity with the pipeline, and (g) individually identified as discontinued, with its own line number, on the amended licence. AR 125/2023 s75;243/2025 Conducting abandonment 76 Unless otherwise authorized by the Regulator, the licensee must ensure that the pipeline or the part of the pipeline that is being abandoned is (a) pigged or cleaned to remove any free conveyed substances and debris as thoroughly as reasonably possible, (b) physically isolated or disconnected from any pressure source, well, facility or other pipeline, except as allowed by section 74, (c) completed by the removal of all associated surface equipment, including pig traps, risers, block valves, line heaters and support structures or pipe racks unless used by other equipment, (d) isolated by cutting off the riser at the pipeline level or as close to the pipeline level as practical, (e) plugged or capped by mechanical or welded means, (f) not isolated or disconnected in a manner that results in an adjoining operating pipeline being left with connection points that could be subject to internal corrosion due to stagnant fluid traps or dead legs, (g) left without corrosion inhibition and without cathodic protection, (h) not releasing gases from polymeric components that could result in flammable or toxic hazard, (i) left in a safe condition that does not pose a threat to the environment or to a person who may come into proximity with the pipeline, and (j) individually identified as abandoned, with its own line number, on the amended licence. Closure quotas 77 (1) The Regulator may establish closure quotas that are applicable to some or all licensees with respect to the required amount of work or the amount to be spent, or both, as directed by the Regulator and for the period determined by the Regulator, with respect to the closure of the licensee’s pipelines. (2) A licensee must comply with any closure quota applicable to it, unless otherwise directed by the Regulator. Closure plans 78 (1) When requested by the Regulator, a licensee must submit a closure plan regarding some or all of its pipelines, in accordance with any direction of the Regulator given under subsection (3). (2) A closure plan must contain the information required by the Regulator and the plan must be approved by the Regulator subject to any terms and conditions imposed by the Regulator. (3) The Regulator may direct the timing and priority for performing work with respect to the closure of the licensee’s pipelines. (4) A licensee must comply with any terms and conditions of its approved closure plan. Mandatory abandonment 79 Despite section 76, a licensee must abandon a pipeline if (a) the Regulator suspends or cancels the licensee’s licence because the licensee has contravened the Act, these Rules or an order or direction of the Regulator, (b) the Regulator notifies the licensee that in the opinion of the Regulator the pipeline may constitute an environmental or safety hazard, (c) the licensee (i) is not or ceases to be resident in Alberta, (ii) has not appointed an agent in accordance with section 19 of the Act, and (iii) does not hold a subsisting exemption under section 3 from the requirement to appoint an agent, (d) the licensee is deceased, (e) the licensee is a corporation registered, incorporated or continued under the Business Corporations Act that is not active or has been dissolved, or if the corporate registry status of the licensee is struck or rendered liable to be struck under any legislation governing corporations, (f) the licensee has not discontinued the pipeline in accordance with the Act, these Rules or an order or direction of the Regulator, (g) the pipeline is associated with a well or facility that has been abandoned or has been ordered to be abandoned by the Regulator and the pipeline is not used for any other well or facility, (h) the licensee has sold or disposed of the licensee’s interest in the pipeline and has not transferred it to a person who is eligible to hold a licence for the pipeline, or (i) the licensee is otherwise ordered to do so by the Regulator. Responsibility for discontinued or abandoned pipeline 80 An approval by the Regulator for discontinuance or abandonment operations does not relieve the licensee from the responsibility for further discontinuance or abandonment or other operations with respect to the same pipeline or part of a pipeline that may become necessary. Conducting removal 81 (1) Unless otherwise authorized by the Regulator, the licensee must ensure that any pipeline or part of a pipeline that is removed (a) is first pigged or cleaned to remove any free conveyed substances and debris as thoroughly as reasonably possible, (b) is not disconnected in a manner that results in an adjoining operating pipeline being left with connection points that could be subject to internal corrosion due to stagnant fluid traps or dead legs, and (c) is individually identified as removed, with its own line number on the amended licence. (2) Unless otherwise authorized by the Regulator, any associated surface equipment, including pig traps, risers, block valves, line heaters, support structures and pipe racks must be removed unless used by other equipment. (3) Any remaining pipeline, if discontinued or abandoned, must be capped or plugged by mechanical or welded means at the terminated end. (4) Removed pipe and equipment must be transported from the right of way of the removed pipeline in a timely manner and must not be allowed to remain on the right of way longer than 60 days after removal of the pipeline, unless otherwise authorized by the Regulator. Resumption of pipeline operation 82 Unless otherwise authorized by the Regulator, a licensee intending to resume the operation of a pipeline or part of a pipeline (a) that was discontinued or abandoned, (b) that has not been in active flowing service for a period longer than 24 months, or (c) the licence of which has been transferred by the direction of the Regulator under section 18(7) of the Act must make an application to the Regulator for approval of resumption in accordance with the requirements of Directive 056. Part 10 Transitional Provisions, Repeal, Expiry and Coming into Force Transitional 83 (1) In this section, “former Rules” means the Pipeline Rules (AR 91/2005) as they read immediately before the coming into force of these Rules. (2) A licence or approval granted by the Regulator under the former Rules remains in force according to its terms until it expires or is amended, suspended or cancelled or a subsequent licence or approval is granted under the Act or these Rules. Repeal 84 The Pipeline Rules (AR 91/2005) are repealed. Expiry 85 For the purpose of ensuring that these Rules are reviewed for ongoing relevancy and necessity, with the option that they may be repassed in their present or an amended form following a review, these Rules expire on January 31, 2031. Coming into force 86 These Rules come into force on November 15, 2023. Schedule 1 Pipeline Warning Signs (sections 53 – 60(1)) Schedule 2 Pipeline Installation Identification Signs (section 60(2))