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Document Number: 19359
Do not copy – CONTROLLED DOCUMENT – Effective Date: June 10, 2020
YANGARRA RESOURCES LTD.
PIPELINE INTEGRITY AND OPERATIONS MANUAL
FOR
FERRIER
KELSEY LEWIS USB COPY
DISCLAIMER
This Pipeline Integrity and Operations Manual is designed to provide information, guidelines, schedules and
duties to assist operations personnel. The document provides procedures related to the operation,
inspection maintenance and repair of pipelines and the surrounding area. It is intended to be an important
component of the Integrity Management Program.
Verification of the information contained in this document is the sole responsibility of the client. DataSafe
does not accept any liability arising from the implementation or use of this manual.
This manual is copyrighted by:
DataSafe Recovery Services Ltd.
650, 703 – 6th
Avenue S.W.,
Calgary, Alberta T2P 0T9
Phone: (403) 269-9128
FAX: (403) 269-9140
Unauthorized reproduction is strictly prohibited.
Version 02.05
PIPELINE INTEGRITY MANAGEMENT PROGRAM
Table of Contents Pipeline Operations Manual
Table of Contents Page - 1
PIPELINE INTEGRITY MANAGEMENT POLICY
1. INTRODUCTION
1.1 Purpose and Scope
1.2 Document Control
2. GUIDING PRINCIPLES
2.1 Legislation
2.2 Standards
2.3 Recommended Practices
3. RECORDS
3.1 Record Keeping Requirements
4. OPERATIONS
4.1 General Operator Responsibilities
4.2 Safety
4.3 Fire Fighting Equipment
4.4 Warning Signs and Markers
4.5 Operating Pressures
4.6 Engineering Assessment
4.7 Leak and Break Detection
4.8 Spill Response
4.9 Pipeline Start-up
4.10 Change of Substance or Pressure
4.11 Line Suspension / Abandonment
4.12 Pigging Procedures
4.13 Preparation for Line Maintenance
4.14 Corrosion Management
4.15 Site Security
4.16 Hot Work
PIPELINE INTEGRITY MANAGEMENT PROGRAM
Table of Contents Pipeline Operations Manual
Table of Contents Page - 2
5. MAINTENANCE AND REPAIR
5.1 General
5.2 Pipeline Patrol and Surveillance
5.3 Ground Disturbance
5.4 Pipeline Repair
5.5 Pressure Testing
5.6 Inspection of Cathodic Protection System
5.7 Inspection of Pressure Control, Limiting and Relieving Devices
5.8 Valve Maintenance Program
5.9 Meter and Instrumentation Maintenance
5.10 Site Vegetation Control
5.11 Exposed Pipe Examination
5.12 In Line Inspection
6. FORMS
7. ORGANIZATION
8. VALVES AND CROSSINGS (behind Field Location tabs in Master documents)
9. EMERGENCY RESPONSE
8.1 General
Emergency Contact List (behind Field Location tabs in Master documents)
10. PIPELINE RISK ASSESSMENT
11. SYSTEM OVERVIEW (behind Field Location tabs in Master documents)
12. SYSTEM PIPELINE LIST (behind Field Location tabs in Master documents)
13. AREA OPERATORS (behind Field Location tabs in Master documents)
14. PIGGING SCHEDULE (behind Field Location tabs in Master documents)
15. REPAIR LOG (behind Field Location tabs in Master documents)
16. CORROSION CONTROL (behind Field Location tabs in Master documents)
17. CHEMICAL INHIBITOR PROGRAM (behind Field Location tabs in Master documents)
18. MAPS
PIPELINE INTEGRITY MANAGEMENT POLICY
The purpose of our Pipeline Integrity Management Program is to properly monitor and maintain our pipeline
systems to ensure that condition and dependability is appropriate for the intended service. Our Pipeline
Integrity and Operations Manual provides the documents and strategies to achieve and improve the safety
and reliability of our pipeline systems. We will allocate resources to:
• Identify and analyze actual and potential events that can result in pipeline incidents.
• Provide a comprehensive and integrated means for examining and comparing the risks and risk
mitigation procedures that are available.
• Provide a structured and comprehensive means for choosing and implementing risk reduction
activities.
• Ensure we employ appropriately trained and qualified company and third-party personnel for risk
management and pipeline integrity.
INTRODUCTION
PIPELINE INTEGRITY MANAGEMENT PROGRAM
Introduction Pipeline Operations Manual
Introduction Page - 1
1. INTRODUCTION AND CORRELATION
1.1 Purpose and Scope
Once a pipeline system is constructed and successfully tested for operation, it is the responsibility of
company field personnel to ensure that it is operated, tested, maintained and, if necessary, repaired to
meet requirements of provincial legislation, industry standards and codes of practice. This document
outlines the actions that will be taken to meet those requirements and provide the necessary information,
documentation and reporting to ensure the objectives of our Pipeline Integrity Management Program and
continuous improvement are met.
This manual provides a guide for the operation, testing, maintenance and repair of oil, gas and water
pipeline systems. It will assist in recognizing normal or emergency operating procedures. The user of the
document is expected to know when to refer to and/or implement other corporate documents such as the
Emergency Response Plan and Safety Manual.
The intent of the manual is to provide documented procedures for pipeline operations that will ensure safe
and efficient functioning and preserve the integrity of pipeline systems. Pipeline operations personnel are
expected to be familiar with this manual and know and understand their responsibilities.
1.2 Document Control
This Pipeline Integrity and Operations Manual will be reviewed and updated annually as a minimum. In
addition amendments will be made as required in response to changes in any of the following:
• Government regulatory requirements
• Industry standards
• Codes of practice
• Addition or change of maintenance, testing or operating procedures
• Responsibility of personnel identified in the document
• Company organization
• Site specific information
Please refer to the Document Distribution report at the back of this section for the location / owner of all
Emergency Response Plan (ERP) and Pipeline Integrity and Operations Manual (PIOM) documents.
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 2
1.3. Document Correlation to the Integrity Management Program
The Pipeline Integrity and Operations Manual is primarily an action and procedures based document to be
used by field operations personnel. The Pipeline Integrity Management Program (IMP) is a corporate initiative
that involves departments, procedures, documentation, responsibilities and personnel in many areas of the
company. This section has been included in the PIOM in order to assist the reader to better understand the
relevance of pipeline operation actions and procedures within the larger scope of the integrity management
program.
IMP correlation will provide the reader with an overview of each section of the manual. Specifically this
section details:
• Who has responsibilities related to each document section when applicable
• What interfaces within the company may be required
• What outputs are expected from operations activities
• Where the outputs are kept and for how long (record keeping)
• The purpose of the outputs as they relate to the company’s IMP
Guiding Principles – Section 2
Pipeline operations and integrity management are company activities that we perform in accordance with
legislated regulations, industry standards and best practices. By using these resources and adhering to these
requirements we can demonstrate compliance and achieve our IMP objectives using the most effective and
efficient methods. Section 2 – Guiding Principles lists the legislation, standards and practices that we follow to
manage our pipeline operations.
Records and Documents – Section 3
The records and documents section of the Pipeline Integrity and Operations Manual details the minimum set
of records and documents that must be retained to meet CSA standards and government regulations. The
section also provides the retention period for each type of record associated with the pipeline system.
For every pipeline segment record keeping begins with design information, engineering and materials
specifications, construction and government approvals and “as-built” attributes. Throughout the lifetime of
the pipeline records are continually created as a result of production, operations, maintenance, surveillance,
failure and repair activities. Personnel responsible for records and document creation and management are
the production and operations staff and management team and could require internal clerical and technical
personnel.
Records can be kept in digital or paper form and may be duplicated for multiple purposes. Head office should
be considered as the main repository for records and documents but this is not necessarily the most expedient
or efficient location and therefore exceptions are expected. The more important aspect of our pipeline
records is that they must be readily accessible, as needed, for internal purposes or as required by the
regulator.
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 3
Operations – Section 4
The Operations section of the Pipeline Integrity and Operations Manual contains sixteen distinct sections.
Each section provides guidelines related to the subject, the regulations, if any, that govern the operation,
whether specific outputs or results are expected, best practice or standards that should be followed and any
additional reference material that may require review prior to or during the activity.
The Operations Section contains the following subjects:
• 4.1 – General Operator Responsibilities
• 4.2 – Safety
• 4.3 – Fire Fighting Equipment
• 4.4 – Warning Signs and Markers
• 4.5 – Operating Pressure
• 4.6 – Engineering Assessment
• 4.7 – Leak and Break Detection
• 4 8 – Spill Response
• 4.9 – Pipeline Start-up
• 4.10 – Change of Substance or Pressure
• 4.11 – Line Suspension / Abandonment
• 4.12 – Pigging Procedures
• 4.13 – Preparation for Line Maintenance
• 4.14 – Corrosion Management
• 4.15 – Site Security
• 4.16 – Hot Work
If records are generated as a result of any of the activities listed above there will be a notation, including
retention requirement, in the section. If notifications to government agencies, the regulator, residents, land
owners or other stakeholders is required it will also be noted in the section.
Personnel with responsibilities for Operations are production and operations staff and management teams,
external services and contractors, engineers and possibly clerical staff for records management.
Maintenance and Repair – Section 5
The maintenance and repair section of the PIOM is broken into twelve parts that cover inspections, testing,
maintenance and repair methods. The IMP depends on these activities being performed following regulations,
and in accordance with standards and best practices. The goal by following these guidelines is to reduce
emergency situations, minimize hazardous conditions and help familiarize operations and maintenance
personnel with locations and installation of pipeline assets and equipment.
The Maintenance and Repair section covers the following subjects:
• 5.1 – General Information
• 5.2 – Pipeline Patrol and Surveillance
• 5.3 – Ground Disturbance
• 5.4 – Pipeline Repair
• 5.5 – Pressure Testing
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 4
• 5.6 – Inspection of Cathodic Protection System
• 5.7 – Inspection of Pressure Control, Limiting and Relieving Devices
• 5.8 – Valve Maintenance Program
• 5.9 – Meter and Instrument Maintenance
• 5.10 – Site Vegetation Control
• 5.11 – Exposed Pipe Examination
• 5.12 – In Line Inspection
Records will be created as a result of the activities found in the Maintenance and Repair section. If retention
periods are not noted that information can be found in the records section of the document. There are
several instances where notification to the regulator, land owner, pipeline co-owners, other industrial
operators and internal personnel is required. Follow all notification requirements as documented in the
section.
Maintenance and Repair activities will require involvement of production and operations and staff and
management. In many cases contracted services personnel and engineers will also be needed. There could
also be a need for internal resources from the land department to determine land owner contacts and clerical
personnel for records management.
Forms – Section 6
A set of forms is provided in the document. Please note that this may not be inclusive of all forms that are
required to be completed by operations personnel in the performance of their work. The Forms Table of
Contents page identifies forms that, when used, may require Emergency Response Plan (ERP) activation,
notification or reporting.
All forms that are completed must be reviewed by operations management and retained as detailed in the
records section or as required by the ERP.
Organization – Section 7
The organization section has specific purposes but can also be used by the company to keep any records that
are deemed relevant. An example would be ERP or PIOM training event logs. An organization chart that
defines specific responsibilities for Integrity Management Program expectations must be included in this
section.
Site Specific Information – Information Tabs
The sections that are found in the remainder of the document contain information specific to the location(s)
that this manual pertains to. The tabs in this section are a different colour than those found earlier and are
labelled descriptively relative to the contents of the section. The following is a typical list of the Site Specific
Information sections and a brief description of what each section contains. The information in these sections
tends to be more volatile and change followed by update is expected on a regular basis.
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 5
Valves and Crossings
This section should contain reports relative to the valves and crossings specific to each Unique
Pipeline Identifier (UPI). Valves must be listed by type, ESD or Check Valve for instance, and the
location by Legal Survey Description (LSD). Crossings are also listed by UPI and relevant crossings
are utility, roadway, railway and water.
This list should be cross-referenced by operations personnel when performing tasks such as
surveillance and maintenance to ensure that these activities are completed for all assets.
Emergency Response
A brief description and general information of the company ERP is at the beginning of this section.
If this section is referenced during day to day operations, as a result of conditions or hazards that
exist, then it is likely that the ERP should be invoked. To assist personnel to respond effectively and
as quickly as possible the Contact Information section from the company ERP is included here.
Pipeline Assessment
A major component of the company’s IMP is the process of pipeline assessment to determine
current, potential or future risk of failure. Pipeline assessments are performed routinely on a
rotating schedule as well as intermittently when changing conditions become evident.
In this section you will find a flowchart that details our risk assessment process by defining the
actions, decisions and criteria used in assessing risk. This is followed by guideline information for
hazard assessment which provides an overview of some of the factors that must be considered in
the assessment. There is a Risk Assessment Matrix to use when classifying risk severity once the
consequence and frequency factors of a specific situation are determined.
The latest pipeline assessment records are kept in this section. These records provide the current
status and are also used for review when the next assessment is performed. If risk increases then
more immediate mitigation activities are required.
If other types of assessments are performed or alternate methods are used for the assessment a
description of the process, tools and results should be added to the document in the Pipeline
Assessment section.
System Overview
This section is used to store the Site Overview reports for the location(s) covered by the PIOM
document. These reports are used to document detailed descriptions of the property under the
following headings:
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 6
- General Summary
- Property Description
- Detection
- Land Use
- Evacuation Summary
- Resident Summary
- Directions From Nearest Urban Centre
- Site Mutual Aid
See the System Overview section to familiarize yourself with the type of information that can be
documented in these reports.
System Pipeline List
An informational table style report listing all of the pipelines in the system with associated pipeline
attributes is contained behind this tab. If the system contains sour gas then the pipeline list is
grouped and includes information such as H2S content and the calculated Emergency Planning Zone
(EPZ).
Area Operators
The lists contained in this section are done by location and provide the main contact phone
numbers for other oil and gas operators within proximity of our operations. Like the emergency
contact list these numbers provide the document user with ready information to use if there is a
need to inform other companies of any situation that is occurring that could impact their operations
or personnel.
Pigging Schedule
There is a pigging frequency attribute that can be added to the Pipeline Assessment report.
However, pigging operations could be significant at certain locations or could require more detail.
In these circumstances any additional documentation can be added to this section of the PIOM. If
this information is kept in another location then a one page summary detailing the location of the
records will be added behind the Pigging Schedule tab.
Repair Log
When any repair is performed a documented record of the repair must be created by Operations or
Maintenance staff and added to this section of the manual. This information is reviewed and
analysed when pipeline assessments are performed. Increased numbers of repair records for
individual segments are an indication that more significant problems could exist. When this occurs
further investigation is required. If analysis indicates a higher risk exists then increased surveillance
and the priority of plans for mitigation activities must be escalated. Operations and Maintenance
management will be involved in these processes. A situation could also warrant the involvement of
engineering personnel.
PIPELINE INTEGRITY MANAGEMENT PROGRAM
IMP Correlation Pipeline Operations Manual
IMP Correlation Page - 7
Corrosion Control
Some corrosion control information such as whether there is cathodic protection on the pipeline
segment or whether the pipe is lined can be included in the Pipeline Assessment report. More
detailed information, if required, can be added to the Corrosion Control section. In a case where
there is significant additional information that is stored in another location a one page summary
detailing the location of the records will be added behind the Corrosion Control tab.
Chemical Inhibitor Program
This section includes specific information related to the Chemical Inhibitor Program and like the
Pigging Schedule and Corrosion Control section it could contain only a summary of the location of
pertinent records.
Maps
This section will contain all representations of the pipeline system(s), such as schematic diagrams,
and geographic maps showing the pipeline system including wells and facilities. These documents
are used for emergency response, surveillance and training purposes by operations and
maintenance staff. When changes occur to the pipeline system these maps and diagrams must be
updated to reflect those changes.
ERP DISTRIBUTION LIST
AB ICS CORPORATE MASTER (Non-Confidential)
FERRIER
Doc # AddressDescriptionLocation / Recipient Phone
DataSafe Recovery Services Ltd. DataSafe, Calgary 650, 703 - 6th Avenue SW, Calgary AB T2P 0T9 5148 (403) 269-9128
Doneff, Collin YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 16695 (403) 262-9558
Evaskevich, Jim YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 5144 (403) 262-9558
Evaskevich, Jim YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 10693 (403) 262-9558
Lewis, Kelsey USB Copy - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18217 (403) 262-9558
Operator, Area 02-04 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 16696 (403) 262-9558
Operator, Area 06-02 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18213 (403) 262-9558
Operator, Area 12-20 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18215 (403) 262-9558
Operator, Area 13-34 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18216 (403) 262-9558
Operator, Area 13-35 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18214 (403) 262-9558
Operator, Area 16-02 PLANT - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18212 (403) 262-9558
Operator, Area ADAM LATOS -
YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 19362 (403) 262-9558
Operator, Area FIELD OFFICE -
YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 18421 (403) 262-9558
Operator, Area RIG 1 - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 19357 (403) 262-9558
Operator, Area RIG 2 - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 19358 (403) 262-9558
Simpson, Lorne YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 19356 (403) 262-9558
Pipeline Integrity and Operations Manual (Site) (Non-Confidential)
FERRIER
Doc # AddressDescriptionLocation / Recipient Phone
Doneff, Collin YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 16670 (403) 262-9558
Evaskevich, Jim YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 14388 (403) 262-9558
Lewis, Kelsey USB COPY - YANGARRA
RESOURCES LTD., Head
Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 19359 (403) 262-9558
Page 1YANGARRA RESOURCES LTD.
ERP DISTRIBUTION LIST
Operator, Area FIELD OFFICE -
YANGARRA RESOURCES
LTD., Head Office
1530, 715 - 5th Avenue S.W., Calgary AB T2P 2X6 16706 (403) 262-9558
Page 2YANGARRA RESOURCES LTD.
GUIDING PRINCIPLES
GUIDING PRINCIPLES
Legislation / Standards / Best Practice Pipeline Operations Manual
Legislation / Standards / Best Practice Page - 1
2. GUIDING PRINCIPLES
Pipeline operations are regulated by the following legislation, industry standards and recommended
practices.
2.1 Legislation
• Alberta Oil and Gas Conservation Act
- Details requirements for oil and gas facilities
• Alberta Pipeline Act and Regulations
- Details requirements for the operation of pipeline systems
• British Columbia Oil and Gas Activities Act
- Details requirements for the operation of pipeline systems
• British Columbia Pipeline and Liquefied Natural Gas Facility Regulation
- Regulation component of the Oil and Gas Activities Act
• B.C. Oil and Gas Commission Emergency Response Plan Requirements
- Emergency preparedness and response requirements
• Alberta Environmental Protection and Enhancement Act (AEPEA)
- Details environmental requirements for operation of facilities, including chemical and
petroleum product spill reporting requirements
• Transport Canada – 621.19
- Requirements for marking and lighting aerial pipeline crossings
• Occupational Health and Safety Regulations
- Details workplace health and safety regulations
• Alberta Energy Regulator – Manuals, Requirements and Directives
- Ground Disturbance Requirements
- Safe Excavation Near Pipelines
- AER Directive 38 Noise Control
- AER Directive 55 Storage Requirements for the Upstream Petroleum Industry
- AER Directive 56 Energy Development Applications and Schedules
- AER Directive 58 Oilfield Waste Management Requirements for the Upstream
Petroleum Industry
- AER Directive 60 Upstream Petroleum Industry Flaring Guide
- AER Manual 001 Facility and Well Site Inspections
- AER Manual 005 Pipeline Inspections
- AER Directive 71 Emergency Preparedness and Response Requirements for the
Upstream Petroleum Industry
GUIDING PRINCIPLES
Legislation / Standards / Best Practice Pipeline Operations Manual
Legislation / Standards / Best Practice Page - 2
2.2 Standards
• CSA Z245.1 Steel Line Pipe Material Standards
• CSA Z245.11 Steel Fittings Material Standards
• CSA Z245.12 Steel Flanges Material Standards
• CSA Z245.15 Steel Valves Material Standards
• CSA Z245.20 External Fusion Bond Epoxy Coating for Steel Pipe
• CSA Z245.21 External Polyethylene Coating for Steel Pipe
• CSA Z662-15 Oil and Gas Pipeline Systems
2.3 Best Practices
• Canadian Petroleum Safety Council
- Industry Recommended Practices (IRP)
• Canadian Association of Petroleum Producers
- Recommended Practice for Liquid Petroleum Pipeline Leak Prevention and Detection in
Alberta
- Safety Guidelines for Ground Disturbance in the Vicinity of Underground Facilities
• Canadian Gas Association Recommended Practice OCC-1 (CGA OCC-1)
- Discusses the design, installation, operation and maintenance of corrosion control systems
RECORDS
RECORDS
Record and Document Requirements Pipeline Operations Manual
Record and Document Requirements Page - 1
3 Records and Documents
Various records and documentation related to our maintenance and operations activity are administered in
compliance with provincial regulations and CSA Z662 requirements. All personnel have responsibility to
ensure maintenance and operations reports, records and documentation are managed in a manner that
ensures compliance with government conventions.
In addition to meeting legislative requirements the company’s pipeline records initially establish a base line
of the reliability of our pipelines. Subsequent review mechanisms, assessments and performance indicators
will initiate a continuous improvement cycle that is essential to establish an effective Integrity Management
Program. Good records management is essential to change and integrity management processes.
3.1 Record Keeping Requirements
The list of required records includes, but is not limited to:
For the Life of the Pipeline
• Emergency Response Plan (updated at least once a year)
• Company approved drawings, documentation and procedures considered design information
such as:
- Stress calculations
- Soil support calculations
- Anchoring or expansion requirements and calculations
- Riser design
- Plot plans
- Bore details
- Crossing details
- Piping transitions
- Material specifications
- Welding procedures
- Backfill procedures
• Failure/repair records:
- Date and time of discovery
- Cause of leak
- Location
- Methods used to detect leak and concentrations observed
- Operating conditions at the time of discovery
- Response and actions, including persons and agencies notified
- Repair method
- Safety and environmental consequences
• All original and follow up pressure test data results:
- Time and date of test
- Test duration
- Pipe standards and specifications for the section tested
- Qualification pressure and its location and elevation
- Elevation profile
- Location of the test section and testing points
- Pressure test medium used
RECORDS
Record and Document Requirements Pipeline Operations Manual
Record and Document Requirements Page - 2
- Pressure and temperature recording charts and logs
- Pressure-volume charts
- Location and cause of any leak, rupture, or other failure and description of any repair action
taken
• Details of the design, installation and operation of corrosion control systems
• Crossing agreements and class locations
• License and technical specifications of pipelines (PL-100 for example)
• The standards/specifications of all pipe, components, bolting and coating materials used in
construction of the pipeline system
• Technical data concerning the following:
- Locations and lengths for each pipe diameter installed, noting wall thicknesses, grades and
standards or specifications, field test pressure, and where practical, burial depth
- Stations and other facilities – maximum operating limits, and the specifications and
nameplate data of major equipment
- Locations of valves designated as emergency valves, with complete information as to the
dates of inspection and maintenance, and the current intended operating position, whether
open or closed
- Component locations, types and pressure ratings
- Locations and details of any crossings of water, roads, railways, pipelines and other major
utilities
- Locations and details of appurtenances such as corrosion-control devices and weighted
sections
- Location and details of special design and construction methods
- Location and details of failures and repairs
• Details of the welding/joining procedure specification qualification test and the qualified
welding/joining procedure specification are kept at the nearest operating location
• Records of welder/joiner tests and a list of qualified welders/joiners including the procedure
specifications of welds/joins each is qualified to perform
• Records that detail the inspection and testing done, the conditions found and any corrective
action taken, if applicable, for the following:
- Underground tanks
- Pipe-type and bottle-type gas holders
- Pressure control, pressure limiting and pressure relieving systems or devices
- Pipelines that may be subject to changes in class location
- Control and safety devices and equipment
• Locations of equipment and major facilities, such as compressor or pump stations, measuring
stations, terminals, tank farms, block valves and cathodic protection rectifiers
• Design, performance, maintenance, inspection and repair records related to the cathodic
protection system
• Records of the interpretation of radiographs
• Ultrasonic evaluation records
• Measurements of unstable areas where differential settlement or heaving is occurring to enable
analysis of trends toward critical stress
• Internal and External corrosion control program records
RECORDS
Record and Document Requirements Pipeline Operations Manual
Record and Document Requirements Page - 3
Minimum of Five Years
• Audit records of incidents when detectable leaks were not detected by the leak detection
system or were not acted upon by the personnel responsible or when the leak detection system
was not operational for periods in excess on one hour due to equipment failure
• Meter and instrument maintenance and testing records
Minimum of Two Years
• Results of emergency exercises
• Records of observations, including visual inspection and patrols during the right of way
inspection and leakage surveys
• A written inspection report of the pipeline at the crossing locations
• In Line Inspection reports, Radiographs, ultrasonic inspection records, calibration records and
logbooks
• Records of inspection, testing, and assessments of pressure control, relieving and limiting
devices and systems
• Written inspection reports of facilities prior to backfilling
• As a minimum the following information must be included in the Inspection and Monitoring
records:
- Date(s) the activities were performed
- Methods and equipment used
- Results and observations
- Evaluation of the acceptability of the results and observations
- Recommendations
- Implementation of recommendations
Other Retention
• Daily, weekly, and monthly material balance results are kept for a minimum of six months
• Record of data recorded by the operator and by the supervisory control including actions taken
on field investigation alarms for a period of three months
OPERATIONS
OPERATIONS
Procedures and Guidelines Pipeline Operations Manual
Procedures and Guidelines Page - 1
4. OPERATIONS
4.1 General Operator Responsibilities
It is the responsibility of the employees or contract personnel that are involved in the operation of pipeline
facilities to:
• Operate, test and maintain the pipelines in accordance with this manual.
• Provide and maintain complete records as required by this manual; and
• Provide input when changes to this manual are required based on experience, system changes
or changes in technology, or other conditions. This ensures the integrity of our pipelines
systems and their continued safe and efficient operation.
Operation routines and system integrity management can be impacted by change. It is essential that a
change management process be used for all changes to ensure an opportunity for key operating,
maintenance, technical and management groups to assess the impact of change and address any measures
that need to be implemented or documented. Change management is an aspect of continuous
improvement of our operations and pipeline integrity.
4.2 Safety
We place a high value on protecting and maintaining the health and safety of employees and contractors
operating and maintaining our pipeline systems. The company requires that operations and maintenance
activities fully comply with all applicable occupational health and safety regulations and company safety and
loss management standards and practices to ensure a healthy and safe working environment.
Employees and contractors involved in the operation and maintenance of the pipeline system are required
to:
• Be fully trained and competent to do the work assigned to them
• To know and understand the hazards associated with operating, testing and maintaining the
pipeline
• To assess potential job related hazards before beginning a task and taking immediate steps to
control or eliminate all identified potential hazards
• To identify and report any unsafe conditions, unhealthy situations, or abnormal circumstances
associated with pipeline operations, testing or maintenance immediately to the responsible
supervisor
• To follow established operating, testing and maintenance practices and procedures as outlined
in this manual, and the Corporate Health and Safety Manual
• To follow all personal protective clothing and equipment requirements specified by regulations
and company health and safety standards
• Attend environmental and health and safety meetings held in the operating area and training
courses and programs as required by the company or the responsible supervisor
• Participate in emergency response training and exercises
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4.3 Firefighting Equipment
Firefighting equipment that is maintained at gas plants, batteries, satellites, gas compression and water
injection facilities or company vehicles is:
• Clearly identified
• Maintained in proper operating condition
• Checked at regular intervals with all checks performed being documented on an appropriate
form
• Regularly certified
This equipment is readily accessible and when used shall be positioned upwind of the fire if possible and
practical.
4.4 Warning Signs and Markers
Signs are posted in appropriate areas at the company’s facilities and along pipeline right of way (ROW) to
identify the presence of pipelines and facilities and provide important information. Warning signs will
conform to the design standards and requirements identified in the Pipeline Act and Regulations.
Facility Signs
Signs shall be posted at or near facilities to identify the operating company, the identity and location of the
facility, emergency notification information and other pertinent information to meet provincial
requirements. Signs indicating that smoking is not permitted shall be posted in hazardous areas at facilities,
as appropriate. Warning, caution and danger signs shall be posted at locations where hazards or toxic
substances may be present.
Pipeline Signs
We will post signs in appropriate locations to meet Pipeline Act and CSA Z662 requirements. Locations
include but are not limited to:
• Railway and road right of way
• Utility corridors
• Water crossings
• Fence lines
• In areas of:
- Subdivision development
- Construction activity
- Drainage systems
- Irrigation systems
- Any area of anticipated third party development
Service type, population density, land use, nature of terrain, fencing, potential for public access and need
for public awareness will be considered when locating and spacing signage for pipelines. Signs will be
installed where the pipeline enters and exits road and rail right of ways and, if practical, be visible from the
travelled road or track.
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Note: signage size, colour and information may vary depending on your location. Ensure that signage
meets local and provincial requirements.
The following example meets AER requirements for signs marking pipelines:
Information is printed on a background of sharply contrasting colour. “WARNING” is 25mm high, bold
lettering. Type of service “GAS PIPELINE” is 13mm high, bold lettering. The sign must include the name of
the operating company and emergency telephone number with area code. Consideration must also be
given to including the required information in a language appropriate to the region.
Material: Aluminum
Material Thickness: 2.057 mm
Dimensions: 17.71" x 11.81" (45.0 cm x 30.0 cm)
Alternative methods of identification must be considered in areas where the use of a sign is impractical or
would not serve the intended purpose.
If the crossing is a navigable waterway for commercial marine traffic, signs will include a “No Anchorage” or
“No Dredging” warning and the size of the sign will be determined by considering the width of the crossing
and the limitations of visibility.
Transport Canada 621.19 specifies the requirements for marking and lighting of aerial pipeline crossings
that could pose a hazard to air or water navigation.
When similarities in piping create the potential for improper operation, the piping will be identified by the
use of signs, stencil markings or colour coding.
Construction Signs
Warning signs will be placed at all company or contractor construction sites that are appropriate for the
nature of activity.
We will provide visual marking of the location of pipelines when requested by, or after becoming aware of,
a third party with construction activity in the vicinity of our pipelines.
Sign Maintenance
Facility and pipeline signage shall be inspected periodically. Any missing, damaged or illegible signs will be
promptly replaced.
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4.5 Operating Pressures
• The operating pressure of a pipeline shall not exceed the licensed maximum operating pressure
during the steady-state operation of the pipeline
• Pressure limiting devices will be installed to ensure that in abnormal conditions, including
transient pressure surges, the maximum operating pressure is not exceeded by more than 10
percent
Pipelines Connected to Artificial Lift Equipment
When artificial lift equipment is in use and is capable of supplying pressure in excess of the pipeline MOP
one of the following two options is required.
Option 1
• Two independently operating overpressure protection devices must be installed that are
designed to protect the pipeline from excess pressure.
• The overpressure protection devices must not allow the licensed MOP of the pipeline to be
exceeded by more than 10% or 35 kPa, whichever is greater.
• Conduct inspections, assessments and testing of the overpressure protection devices in
accordance with CSA Z662, clause 10.9.5.1
Option 2
• A single overpressure protection device must be installed that is designed to protect the
pipeline from excess pressure.
• The overpressure protection devices must not allow the licensed MOP of the pipeline to be
exceeded by more than 10% or 35 kPa, whichever is greater.
• Monthly inspections, assessments and testing of the single device must be performed by a
competent individual.
• A certified instrument technician must conduct annual inspections, assessments and testing.
The maximum interval between these activities must not exceed 18 months.
4.6 Engineering Assessment
An important component of integrity management is that appropriate personnel are contacted and
involved prior to undertaking new construction or when change is made to the operating condition of a
pipeline. The first step to new construction and significant changes is usually an Engineering Assessment.
Engineering Assessments are an integral component of the change management process. Examples of
changes to pipeline operating conditions that would warrant an Engineering Assessment includes:
• Increase in pipeline MOP
• Increase in pipeline operating temperature
• Reduction in pipeline minimum metal temperature
• Change in pipeline service
• Change in fluid properties (viscosity, density, etc.)
• Change in fluid components (i.e. HVP, H2S content, CO2 content, H2O content, etc.)
• Change in flow direction
• Change or failure of pipeline coating
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• Pipeline cover does not meet CSA Z662 requirements
• Construction of a new permanent lease road crossing
• Exposure of pipeline by water or wind erosion (loss of cover)
• Pipeline leaks (due to corrosion, erosion, unknown cause)
• Population density increase near pipeline ROW (review change in Class Location as per CSA
Z662)
• New construction along the pipeline ROW which may affect pipeline operation
• Any other condition not listed above which may significantly affect pipeline operation
An engineering assessment may also be required as the result of pipeline inspection and monitoring results.
The engineering assessment must take the following into consideration:
• Understanding of the performance capabilities and limitations of the inspection method
• Type of imperfection that might correspond to the reported indications
• Accuracy of reported dimensions and characteristics needed for evaluating imperfections
• Potential for unreported defects being associated with an imperfection indication
• Pipeline design, construction and material properties
• Service history and future service conditions
When any condition exists that can lead to failure of a pipeline system an engineering assessment must be
conducted to determine which portions can be susceptible to failures and whether such portions are
suitable for continued service. Failure condition includes but is not limited to:
• Mechanical damage that can develop into failures under sustained operation
• Mill defects not detected during the manufacturing process
• Corrosion
• Stress corrosion cracking
• Coating damage
• Coating deterioration
• Unstable slopes
• Compressive stress related to repetitive loading
Situations requiring an engineering assessment could also arise as a result of Pipeline Patrol and
Surveillance activities. More information related to these routine inspections can be found in the
Maintenance and Repair section.
Any time that operating personnel identify a required change the immediate supervisor should be notified.
Operations staff will work with their immediate supervisor and the Facility Engineer to determine the
engineering work that will be required. The resulting Engineering Assessment will detail the change that is
to be made. Operations personnel will execute the change. The performance of the pipeline will be closely
monitored after the change to ensure that operation is as expected. Stakeholders will monitor and evaluate
that the change meets the intended purpose.
The following diagram provides a graphic representation of our intent to continuously improve our pipeline
integrity by consistently employing an effective change management process.
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Assess
Design
Implement
Evaluate
Stakeholders
Company
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4.7 Leak and Break Detection
Right of way inspections are carried out at regular intervals as specified in the Pipeline Act and Regulations
and CSA Z662. In addition, unusual conditions such as construction or seismic activity, or any unexplained
loss of pressure or production will require additional investigation.
Special consideration will be given to the inspection and maintenance of pipeline crossings of major utilities,
other pipelines, railways, roads and water crossings.
Any of the following conditions could indicate a pipeline leak or break:
• Pooling of hydrocarbons or water on the right of way
• Unusual temperature changes
• Wilting or dead vegetation around right of way
• Soil slides, earth movement, soil erosion or settlement on or near the right of way
• Out of balance material measurement results
• H2S odours
• Gas indication on detector
• Indication by Gas volume analysis or mathematical modelling analysis
• Indication during bar-hole survey
Surveillance will also include:
• Inspection of above ground piping and pipeline appurtenances
• Pipeline identification markers (missing, damaged, obscured)
Internal audit records must be maintained that detail the action taken and results achieved with respect to
the following categories of incident:
• Detectable pipeline leaks that were not detected by the detection system or that were not
acted upon by personnel responsible for interpreting and responding to the material balance
• Occasions when the leak detection system was inoperative in excess of one hour because of
equipment or system failures
These audit records are to be kept on file for five years.
4.8 Spill Response
Regardless of seepage volume, a pipeline break or damage from contact must be reported to the Alberta
Energy Regulator immediately. Note that damage from contact may not cause a pipeline break and
subsequent leak. However, there is a significant increase in risk to a pipeline that has sustained damage by
contact. Thorough inspection and repair of damage from contact to ensure pipeline integrity is required.
In British Columbia immediate notification of a spill is made to PEP (see Contact Information in the
Emergency Response section). Reportable spill volumes are:
• 100 litres for flammable liquids
• 10 Kilograms of natural gas if there is a breakage in a pipeline or fitting operated above 100 psi
that results in a sudden and uncontrolled release
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See the Schedule contained in the Spill Reporting Regulation for reportable levels of other substances.
The following information must be provided:
- the reporting person's name and telephone number
- the name and telephone number of the person who caused the spill
- the location and time of the spill
- the type and quantity of the substance spilled
- the cause and effect of the spill
- details of action taken or proposed to stop, contain or minimize the effects of the spill
- a description of the spill location and of the area surrounding the spill
- the details of further action contemplated or required
- the names of agencies on the scene
- the names of other persons or agencies advised concerning the spill
References:
The Pipeline Act, Part 6, Section 35 (1) states: When a leak or break occurs in a pipeline, the licensee shall
immediately cause the AER to be informed of the location of the leak or break.
Pipeline Regulations Part 1, Section 2 (2) states: A licensee who is required to notify the AER of a pipeline
leak, break, test failure or contact damage shall immediately do so by telephoning the appropriate regional
field centre of the AER.
B.C. Environmental Management Act – Spill Reporting Regulation
The landowner must be notified and the spill area contained to prevent access by domestic stock or wildlife.
Spill Strategy
Operations personnel that discover a spill will initiate immediate action plans to control the situation and
decrease the impact of the spill. Although there could be exceptions under special circumstances, most
often the following general strategy will be used:
• Protect the public and safety of workers
• Shut in the source of the spill
• Assess the spill area
• Initiate containment, recovery and notification process
• Supervise site clean up
• Prepare internal and external reports
• Define the root cause to prevent similar incidents
• Reclaim the affected area
Containment and Recovery Options
The early deployment of temporary containment or diversion tactics can greatly reduce the cost of cleanup
and reclamation. There are a variety of accepted and proven options that can be used for spill containment.
Strategies specific to your location should be considered and prepared for in advance of a spill situation.
Commonly used spill containment and recovery options are:
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• Dikes and inverted weirs
• Bell holes and trenches
• Water flushing
• Sorbents
• Culvert blocks
• In-situ burning (specific conditions only)
Dikes
Dikes will provide an effective way to prevent fluids from continuing to migrate. Prior to constructing a dike
consideration should be given to the spill location, time of year, resources available to contain the spill and
the amount and material spilled. Dikes will be effective for smaller spills. Keep the height and width of a
dike to a minimum and use low areas and seams to reduce construction and disturbance. Existing roads and
other high spots can be used but must be monitored for erosion to prevent washout and subsequent loss of
contaminants. Straw bales can be used where possible and will reduce the use of heavy equipment. Note
that preparation of the ground area may be required and that the bales may need to be staked or
overlapped for significant flows and to prevent leaching under the dike. Snow and ice dikes can be used to
contain spills in the winter.
Dikes and Inverted Weirs
Dikes and inverted weirs are used when a significant amount of material has been spilled. A dike and
inverted weir can be installed to siphon off water from the bottom of the contained area into another
containment area. Culverts are commonly used in the construction of the inverted weir. An inverted weir
can be used to decrease the chance of liquid migrating to a less desirable location and will also substantially
reduce the amount of liquid that must be removed, treated or disposed of. A spill specialist must be
consulted before an inverted weir is put into practice.
Bell Holes and Trenches
Bell holes and trenches are used to contain and prevent further migration of the spill. They also provide an
effective means of collection by using a vacuum truck or pump suction hose. Use numerous shallow holes
or trenches to minimize the risk of fluid penetration in the soil and to reduce the risk of striking
underground hazards. Natural depressions and seams should be used to collect and direct fluid if possible.
Water Flushing
Flushing a spill area, with hot or cold water, is an effective fluid recovery method. A calcium product must
be added to water that is being used to flush an area where a salt water or produced water spill has
occurred. A spill specialist is required to advise on the calcium amendment that is required in each
situation. Note that toxic and flammable vapours can be produced and personal protective equipment and
procedural safety are essential when performing this operation.
Sorbents
Sorbents are used to recover residual oil or contaminants that mechanical equipment is unable to recover.
If sorbents are used ensure they will recover the product effectively, are readily available, easy to apply and
do not create a disposal problem. Consider the use of natural materials such as straw. Note that the cost
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for disposal of used sorbents is usually high; as a result they will not normally be used for cleanup of
significant amounts of fluid.
Culvert Blocks
Culvert blocks should be kept on site if it is foreseeable that a spill could readily migrate through a culvert.
Consider installing culvert gates in sensitive areas or in locations where the impact of a spill is considered
high. As a minimum precaution, store plywood or other culvert blocking material on site. When a culvert is
blocked liquid levels must be monitored to ensure a washout does not occur.
In-Situ Burning
Burning of a spill contaminant may be an option when:
• Regulatory approval has been granted and appropriate contacts are made
• It is unsafe to contain and recover the product with men and equipment
• Burning would prevent imminent contamination of a sensitive area
• Equipment usage would cause a greater overall impact
• Oil is located on ice that is not of an adequate thickness to allow recovery
• Further mechanical clean up is not feasible
• A controlled burn is possible
• Controls are in place to ensure a safe, effective burn and it is contained to the spill site
Regardless of the choice of control options, the following factors must be taken into consideration:
• Public and personnel safety is the number one priority
• Protect environmentally sensitive areas
• Determine spill boundaries
• Consult regulatory agencies, stakeholders and spill specialists
• Secure the site and control access
• Use of heavy equipment is expensive and can increase reclamation requirements. Minimize use
if possible.
• Never bury contaminated soil. Salvage for proper disposal.
• Remove as much free liquid as possible
• Prevent surface water from entering the spill site
• Avoid unnecessary damage to vegetation
• Remove contaminated soil following regulatory requirements
Fluid Disposal Options
The most cost effective way to deal with recovered fluid is to return it to a company facility for
reprocessing. In situations where the material cannot be reprocessed, for instance, insufficient volume or
too much debris, it may be necessary to involve a reclaiming company. This is a costly alternative directly
related to volume. Ensure as much material is reclaimed by other means as possible and attempt to remove
as much water as possible from emulsion spills.
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4.9 Pipeline Start-up
The main considerations when starting up and operating a pipeline system are personnel safety and
protection of equipment. High pressures are inherently dangerous and command respect and caution.
The following procedures will be used to safely start-up new, repaired or upgraded pipelines:
Clearance
Provincial regulator approval is required before any pipeline is placed in operation.
Consultation and subsequent clearance from the engineering representative, construction supervisor and
appropriate operating personnel must be obtained before proceeding with the commissioning of any
pipeline.
Pre-Commission Requirements
• Inspection performed and engineer clearance that all new manual valves have been inspected
and correctly set
• Ensure check valves are installed in the direction of flow
• Ensure all vents are closed and plugs are installed
• Ensure all drain valves are closed, locked and plugs and blinds installed as applicable
• Pig signals are installed and in correct direction of flow
• Pig trap closures are in place
• Pressure gauges are appropriate for use
• Cathodic insulating gaskets are installed as per drawings
• Inspect studs and nuts on flanges, ensure there is a minimum of two threads exposed beyond
the nuts on all studs
• Submit pipeline routings to the provincial One Call System
Pipeline Filling
Once clearance and pre-commissioning inspections are satisfied proceed with the following:
• Remove isolation equipment
• Inject corrosion inhibitor if it is to be applied
• Open valves slowly – use caution as the flow rate must be controlled on some systems to
ensure the system capacity is not exceeded
• Vent air if necessary
• Inspect system for leaks
• Perform a visual inspection of all fittings, flanges and valves when the pipeline reaches
operating pressure
4.10 Change of Substance or Pressure
In Alberta the substance shipped and/or the maximum operating pressure of a pipeline can only be changed
after obtaining an approval from the AER.
In all locations change of substance or pressure must comply with CSA Standards.
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4.11 Line Suspension / Abandonment
Line suspension or discontinuation is the temporary removal of a pipeline from the system. Line
abandonment is considered the permanent removal of a pipeline. In either case the pipeline must be
physically isolated from all operating facilities whether or not the pipeline is removed from the ground.
If the product in a pipeline can be proven non-corrosive using best practice test methods and the line will be
discontinued for less than 3 months, then the product may be left in the pipeline. Otherwise the product
must be considered corrosive. In this situation, or, if the pipeline will be shut-in for more than 3 months,
then the pipeline must be pigged out (refer to Section 4.12 of this manual) and left filled with an approved
medium. If the pipeline has been discontinued for more than 12 months an application must be submitted
to change status records to reflect that the line is discontinued. An integrity management plan for a
discontinued pipeline must be developed and maintained.
Note that under Directive 56 an application for abandonment or discontinuation is not submitted until after
the pipeline has been prepared for the change in status. There are regulatory requirements, including
public notification, that need to be met prior to abandoning a pipeline.
Hazards
A hazard assessment will be performed prior to commencing suspension or abandonment procedures to
determine protective measures that will be implemented. Typical hazards include fire, explosion, sour gas
exposure, excessive pressure and spills. All company and contract personnel will be briefed with respect to
the hazards and the protective measures to be implemented. Appropriate safety and personal protective
equipment such as LEL detectors, H2S monitors, SCBA, goggles/face shield, fire retardant work wear, and
firefighting equipment will be used.
General Discontinuation Procedure
1. Shutdown production, depressurize and isolate the line
2. Purge line with fresh water, followed by air, and where suitable use pigging
3. Block and isolate the line with blind flanges
4. Identify all isolation valves and blinds with line status and content
5. Leave cathodic protection in place
6. Leave line in safe condition
General Abandonment Procedure
1. Isolate line from all operating facilities
2. Clean the line appropriately and purge with air
- Salt water lines will be purged with fresh water followed by air
- Oil emulsion lines may require a mixture surfactant with fresh water, as appropriate,
followed by air
- Investigation followed by other appropriate cleaning procedures may be required for
significant deposits of sand or other materials
3. Use poly pigs between purging media
4. Cut risers and cap below ground at the horizontal position of the pipeline
5. All waste materials and deposits will be stored and disposed of to meet Directive 58 compliance
requirements
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6. Based on the potential for contamination at the site, investigation and testing will be
performed.
7. Reclamation procedures will be implemented
8. Compile abandonment log and secure regulatory release
9. Notify stakeholders of abandonment
Discontinuing Lines with Pig Traps
Determine any requirements for cathodic protection and consult with engineers whether to use an air or
nitrogen purge. If nitrogen is used, set up a purge program with the contractor.
1. Shutdown input facilities and close isolation valves
2. Insert a pig into the pig trap as per pigging procedures
3. Displace fluid in the normal flow direction
The pig signals must be reversed or removed if fluid is to be displaced in the reverse flow.
The truck operator must be informed of the MOP of the pipeline.
4. Launch the pig with the pressure truck loaded with fresh water
5. Displace a minimum of 30 metres length of the pipeline
6. Install a second pig
7. Launch the second pig using the compressed air or nitrogen truck
Monitor the operation closely to ensure system MOP and meter flow rates are not exceeded.
8. Do not let any significant volume of air or nitrogen into the downstream piping
9. Leave the truck connected to the line, even if it shuts down, until both pigs are received
10. Remove the pigs from the trap
11. Vent excess pressure leaving 200 – 500 kPa in the line
12. Close, lock and tag isolation valves
13. Install blinds where the pipeline connects to fluid sources
14. Notify the provincial regulator of the status
Discontinuing Lines without Pig Traps
Determine any requirements for cathodic protection and arrange for a vacuum truck and a pressure truck
with enough fresh, warm water to displace 110% of the line.
The truck operator must be informed of the MOP of the pipeline.
1. Connect the pressure truck to the inlet and the vacuum truck to the outlet
2. Ensure all valves in the path of flow are open
3. Pump the water from the pressure truck to the vacuum truck
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Monitor the operation closely to ensure system MOP and meter flow rates are not exceeded.
4. Once the line has been filled with water the vacuum truck can remove the water from every
available drain on the line
5. Close all valves and install blinds where the pipeline connects to fluid sources
6. Lock and tag the isolating valves
7. Notify the provincial regulator of the status
4.12 Pigging Procedures
Pigging is the process used to remove solid deposits such as wax and any trapped fluids from a line.
Procedures for pigging will vary from site to site based on age, configuration of the line, pig trap design and
any other system or operational differences.
Hazards
A hazard assessment will be performed prior to commencing pigging procedures to determine protective
measures that will be implemented. Typical hazards include fire, explosion, exposure to toxic gases,
arm/leg injury due to launcher or receiver caps releasing under pressure and spills. All company and
contract personnel will be briefed with respect to the hazards and the protective measures to be
implemented. Appropriate safety and personal protective equipment such as LEL detectors, H2S monitors,
SCBA, goggles/face shield, gloves, fire retardant work wear, and firefighting equipment will be used.
Procedure Guidelines
Piping modifications that are made prior to pigging operations must follow correct engineering procedures.
Operations personnel will review equipment involved. Particular attention will be given to the handling of
caps with respect to unexpected pressure when a cap is released.
As required by Directive 58, only approved handling and disposal methods will be used for pigging wax and
other solids and fluids as a result of the pigging operation.
A site-specific pigging procedure must be in place prior to commencing the operation. The following
considerations will be addressed:
• Personnel required for the job
• Characteristics of the substance to be pigged
• Requirements if sour products are expected to be encountered
• Inspection of cap, barrel and seals on launcher and trap prior to start of the operation
• Detailed isolation and depressurization procedures
• Detailed draining and ventilation procedures
• Specific review of hazards related to plugging of bleed-off lines
• Proper technique for launching and receiving for equipment involved and potential for hydraulic
shock
• Identification marking of pigs and launch and receive time logging
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Sour Substance Considerations
The maximum H2S content for each pipeline must be determined using records for pipeline grouping and/or
the analyses of producing sour well(s). Unless there are other risk exposures, pigging operations can be
performed without using the “buddy system” or breathing apparatus if the maximum H2S content is less
than 10 ppm. If H2S content is more than 10 ppm breathing apparatus must be worn by the operator
performing the pigging procedure and a second operator with breathing apparatus stationed 15 metres
upwind must be present.
Ensure pig launchers and receivers are bypassed and blocked when not in use.
4.13 Preparation for Line Maintenance
A hazard assessment will be performed prior to commencing purging procedures to determine protective
measures that will be implemented. Typical hazards include fire, explosion, sour gas exposure, excessive
pressure and spills. All company and contract personnel will be briefed with respect to the hazards and the
protective measures to be implemented. Appropriate safety and personal protective equipment such as LEL
detectors, H2S monitors, SCBA, goggles/face shield, fire retardant work wear, and firefighting equipment will
be used.
The procedure to prepare a line for modification, maintenance, or repair is similar to the procedure for
decommissioning a line with the following exceptions:
• The line is completely depressurized when turned over
• A copy of the list of blinds and locked valves is prepared and given to the
construction/maintenance supervisor
When work on the pipeline has been completed, use the procedure for Pipeline Filling in Section 4.9 of this
manual to reactivate the line.
4.14 Corrosion Management
External Protection
Primary external corrosion control is provided by the protective coating on the pipe that isolates the
external surface of the pipeline from the environment. Either the owner or the operator is responsible for
performing and documenting coating system evaluations and selections.
Coatings are applied in accordance with documented procedures that include quality control and address:
• Personnel qualification
• Material quality assurance (coating and abrasives)
• Environmental controls and monitoring (ambient temperature, steel temperature, humidity,
etc.)
• Surface preparation techniques and controls
• Application techniques and controls
• Curing
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• Finished coating inspection and testing
• Repair techniques
• Record keeping
Impressed current cathodic protection systems utilize an external power source that provides an electric
current to mitigate corrosion activity. We will apply cathodic protection systems to all metal pipelines,
metal underground piping and any other metal appurtenances in direct contact with the surrounding soils.
These systems provide a high level of protection but require regular monitoring and maintenance to ensure
long-term performance and continued integrity of the pipeline.
Within one year of completion of construction of pipeline facilities cathodic protection must be installed
and operational and must be maintained until the piping is abandoned. The design, operation, inspection
and maintenance of cathodic protection are to be in accordance with the appropriate Codes, Standards and
Regulations of the Canadian Electrical Code, CSA Z662 and CGA OCC-1.
Persons performing evaluations and selections of coatings and cathodic protection must be able to
demonstrate their understanding and have experience in the application of these corrosion control
techniques.
Riser Inspection
Risers must be inspected regularly for corrosion at the soil to air interface. Insulation must be removed for
visual inspection to determine if the coating is lacking or damaged. Coating can degrade as a result of
exposure to UV light and risers are more prone to mechanical damage. Damaged coating could allow water
to come in contact with piping. Lack of or damaged coating may also affect the reliability of cathodic
protection systems. Ensure that any insulation and taping is appropriately reapplied after the inspection.
Internal Protection
Pipelines will have the potential for corrosion if free water, bacteria, hydrogen sulphide, carbon dioxide or
suspended solids are carried in the fluids. Experience gained in your location and regular testing will
provide information to determine the prevention programs required to ensure the integrity and extend the
life expectancy of the pipeline. Prevention programs could include but are not limited to:
• Removal of water and foreign material by scraping or pigging
• Treatment of residual water or dehydration
• Injection of environmentally acceptable inhibitors, biocides or other chemical agents
• Removal of dissolved gases by chemical or mechanical means
• Gas blanketing
• Continuous internal coating or lining
CAPP 2003-0013 provides information on mitigation of internal corrosion in sweet gas gathering systems.
CAPP 2003-0023 provides information on mitigation of internal corrosion in sour service gas gathering
pipelines. Section 9 of CSA Z662 provides requirements that must be followed related to corrosion and
corrosion control.
Techniques to consider for monitoring internal corrosion control include but are not limited to:
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• Ongoing monitoring of operating conditions
• Deployment of corrosion-monitoring devices such as weight-loss coupons, corrosion probes,
hydrogen probes and removable spool pieces
• Non-destructive inspection such as ultrasonic or eddy current wall thickness measurement
• Visual inspection of the internal surface of cut-outs
• Use of internal electronic inspection equipment
Corrosion control records are retained for the life of the facility.
Safe Working Conditions
When metal pipe sections or fittings are separated electrical potential differences could be present across
the fittings or pipe sections creating the possibility of spark. The following procedure will be used to ensure
this hazard is eliminated:
• Shut off the cathodic protection rectifiers in the immediate vicinity
• Install a temporary bond cable between the sections before the fitting is broken or pipe section
is removed
• Remove the temporary bond cable when the break is reconnected and energize the rectifiers
4.15 Site Security
Operating staff are responsible for maintaining the security of valves and exposed company facilities to
prevent tampering or damage by outside parties.
Physical Barriers
The Alberta Oil and Gas Conservation Act sets a standard for physical barrier requirements for oil and gas
facilities. It states a security fence must be at least 2 metres high and made of small industrial type steel
mesh not greater than 130 square centimetres. This fence must completely enclose the facility and be
equipped with a gate that is locked when the facility is unattended. This type of fence must be erected:
• Around batteries where hydrogen sulphide concentrations in a representative sample of gas
from any well producing to the battery is found to exceed 10 moles/ kilomole and the battery is
located within 800 metres of an occupied dwelling, rural school, picnic ground or other
occupied area
• Around operating wells equipped with a pumping unit located within 800 metres of a city, town,
new town, village, summer village, hamlet or other incorporated centre, unrestricted
development, public facility, picnic area or campground
• As required in an order from the Regulator
The fences described above will be maintained in a proper manner at all times to prevent anyone from
easily climbing over. Large holes, washouts, frost heaves or other large openings under the fence will be
filled in as quickly as possible. Damage or deterioration in a way that would allow free entry by
unauthorized personnel will be repaired or replaced as soon as possible.
Where a battery is located elsewhere a four-strand barbwire fence equipped with either a gate or cattle
guard is required. Operating wells in low risk areas will have four-stand barbwire fencing with cattle guards
OPERATIONS
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or injection shelters for protection. Valves are required to be in an operable state, but chained and
padlocked.
An appropriate fence, maintained in a proper manner is required around any shut-in or suspended wells
with equipment remaining on-site.
Physical barriers, security fences, cattle guards and injection shelters that are damaged or deteriorated
should be repaired or replaced in a timely manner.
Signs
“Authorized Personnel Only” signs will be posted in appropriate locations at company facilities or lease
roads leading into a site.
Locks / Bull-Plugging
• Chains with padlocks are required on gates to high-risk facilities
• Valves that are in exposed locations or that may result in a spill or damage to equipment will be
chained and padlocked in the operating position
• If wells are shut-in or suspended, the valves will be bull-plugged wrench tight and chained and
padlocked in the proper position
• All lines that can release to the atmosphere and valves on all operating production field tanks
will be bull-plugged wrench tight
• Padlocks will be used at any appropriate company site to prevent tampering by unauthorized
personnel
• Padlock types and specifications will be appropriate for use and maintained to function at all
times
• Weathered, damaged or non-operable padlocks will be removed and replaced as quickly as
possible
Reporting
Vandalism and theft will be reported to the local RCMP and corporate head office.
4.16 Hot Work
Regulations require that open flames not be allowed within 25 metres of an area where flammable vapours
or gas could be present. When use of an open flame is necessary at such locations a Hot Work Permit must
be completed and the work must be performed in a designated area. Prior to any hot work the area must
be checked with a LEL monitor to ensure there are no flammable gases present. The area is to be
continuously monitored throughout the job.
Hot Work is not permitted if LEL readings are greater than zero.
If the LEL exceeds zero, work must be discontinued immediately. Work can resume when LEL readings
return to zero and remain at zero.
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5. MAINTENANCE AND REPAIR
5.1 General Information
Integrity management depends on regular inspections and testing combined with preventative and
scheduled maintenance routines. These activities reduce emergency repairs and minimize hazardous
conditions. Recurring maintenance, testing and inspections will ensure that operating and maintenance
personnel are familiar with the location and surface routes to installations such as valves, vents and
cathodic protection rectifiers. Changes that occur along right of ways will become readily noticeable. This
knowledge and familiarity is essential to ensure quick and effective emergency response and repair
activities.
In British Columbia it is a regulatory requirement that all pipeline incidents are reported to the Commission
directly or through the Provincial Emergency Program (PEP). A reportable pipeline incident is any incident
resulting in, or having potential to, damage a pipeline even if there is no spillage of products or substances
from the pipeline. Incident reporting is required regardless of the status of a pipeline or the type of product
released. Hits on deactivated or abandoned pipelines, leaks of freshwater from pipelines, or spills of any
substances within the right-of-way of pipelines must be reported.
Pipeline permit holders in British Columbia are required to investigate all pipeline incidents to determine
the cause and contributing factors, and to identify appropriate remedial actions and repairs to prevent a
recurrence. The root cause, repair methods and any changes in the operation or status of the pipeline must
be summarized on Form D – Permit Holder Post Incident Report, which must be submitted to the
Commission within 60 days of an incident. In addition, permit holders must inform the Commission of any
design or operational changes, as well as any change to the operating status of a pipeline, through
submission of a Notice of Intent (NOI) application.
The Post Incident Report must be submitted electronically to the BCOGC. A copy is included in the Forms
section of this document.
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5.2 Pipeline Patrol and Surveillance
Inspections of all pipeline right of ways (ROW) are to be performed as required by the Pipeline Act and
Regulations, CSA Z662 and the Pipeline and Liquefied Natural Gas Facility Regulation. The frequency of
inspections is determined by pipeline service and condition, pipeline size, operating pressure, terrain,
weather, population density (class location) and any other operating or unusual conditions. Special
consideration is given to the inspection and maintenance of pipeline crossings of major utilities, other
pipelines, railways, roads and water crossings. The purpose of the inspections is to monitor the conditions
and activities adjacent to the rights of way so quick remedial action can be taken when the system is
damaged or the integrity of the system is threatened.
Operations personnel will patrol and inspect giving particular attention to the following:
• Construction activity
• Dredging operations
• Seismic activity
• Erosion
• Ice effects
• Scour, abrasion
• Soil slides
• Subsidence, collapse
• Loss of cover
• Evidence of leaks, pooling, unhealthy or dead vegetation
Crossing Inspections
Additional consideration must be given to the inspection and maintenance of pipeline crossing of:
• Major utilities
• Other pipelines
• Railways
• Roads
• Water
- Adequacy of cover, erosion
- Accumulation of debris
- Water level
Operations staff in conjunction with the immediate supervisor will establish an inspection schedule with
intervals that could be daily, weekly, bi-monthly and monthly. The inspection interval is based on the risk
associated to each pipeline segment. Unscheduled, immediate inspections could be necessary as a result of
natural hazards such as flooding. Inspection intervals may have to be revised as a result of higher
associated risk such as population encroachment on the ROW (see Class Location, Section 4.3.2 of CSA
Z662).
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In addition to the above, the company is required to conduct:
• A daily inspection of any area of construction activity that is in close proximity to a pipeline right
of way
• A continuous inspection of any area of construction activity that:
- is occurring on a pipeline right of way
- may affect the safety of the pipeline
Right of Way Infringement
The following procedures outline our requirements for infringement of pipeline right of ways by outside
parties. The guidelines are based on sweet LVP service and the intent is to meet current AER requirements.
Note that pipeline operation in British Columbia is subject to the Oil and Gas Activities Act and associated
Regulations. A review of the BC Act and Regulations is recommended to ensure compliance to provincial
regulations.
Written approval or a Crossing Agreement is required anytime an external company performs activities in
any of our rights of way.
All activities by external companies on our right of ways will be performed following applicable standards,
regulations and best practices. Operating personnel will report non-conformance to the immediate
supervisor for investigation and follow-up.
Line Crossing
• A minimum of 30 cm clearance between pipelines is required and this depth will be maintained
for the entire width of the right of way
• The new line must go under the existing line (unless approved otherwise)
• Crossings will ideally be more than 25 degrees to minimize the length of exposed line (not
always possible)
• Proper support of exposed facilities must be provided
• No cathodic bonding between lines is allowed
• The crossing must meet requirements of CSA Z662
• The existing pipeline must be exposed by hand excavation (as per Ground Disturbance
procedures)
• A company field operator will witness / inspect exposing of line
• The field operator will check for line coating or insulation damage. The party requiring the ROW
infringement is responsible for the cost of any repairs.
• No equipment is allowed on the ROW unless a minimum 1.5 metre build up cover is applied and
temporary access has been approved
• The field operator must submit a written inspection report for each exposed facility
(photographs are generally included) to Head Office for filing as per regulatory requirements
• External companies must provide a drawing for crossing approval which shows all of the above
details
• A company field operator will witness / inspect the back filling
• A copy of the Crossing Agreement will be kept in Operations files and a copy will be forwarded
to the operations personnel involved
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Road Crossing
• A temporary road crossing can be allowed to external companies. A minimum 1.5 metre cover
is required for a lease road and a minimum 1.8 metre cover is required for a road allowance.
• A permanent road crossing must meet requirements of CSA Z662
• If pipe thickness does not meet requirements of CSA Z662 - Table 4.9, the crossing must be
cased (with appropriate centralizers, vents, split casing) or thicker walled line pipe installed
• Road crossing should be 90 degrees to ROW
• All welds within the crossing must be radio graphed
• The extent of the crossing is a minimum of 15 metres on either side of the road centreline
If the line to be crossed meets CSA Z662 wall thickness requirements but operating stress levels are
considered high (>80%) then additional calculations will be necessary to determine if the external loading
will cause any wall deformation or failure.
Well Site Lease
• AER minimum allowable distance from a wellhead to the edge of a ROW is 30 metres
• The lease can border the ROW, however, future expansion must be considered prior to
approval
• Any distance less than 75 metres from a wellhead to the edge of a ROW must be reviewed for
location / interference of cathodic beds and rig anchor locations
Seismic Survey
• The seismic contractor will be required to contact operations personnel before commencing
work
• Operations will provide onsite field related coordination, including flow line location, for the
seismic contractor
• Seismic crews conducting operations in the vicinity of a ROW must maintain the following
minimum distances to the edge of the ROW:
- Vibrator 15 metres
- 2 kg charge 32 metres
- 4 kg charge 45 metres
- 40 kg charge 145 metres
• The seismic contractor is expected to report any non-conformance with our company policy or
procedure to the area operations supervisor for investigation and follow-up
• Any non-conformance noted by operations personnel will be reported to the area operations
supervisor for investigation and follow-up
25 KV Electrical Cable - Underground Crossing
• Cable must be shielded across the entire ROW
• Minimum 30 cm clearance
• The electrical system must be designed to allow the cable to be isolated from service for
extended periods of time without impact to other consumers
• Crossing to be under existing pipeline unless otherwise approved by the company
• Ground disturbance policies and procedures must be adhered to
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Underground crossings of electrical control cable or fibre optics will meet requirements similar to
transmission cable and will have adequate protection from mechanical damage for the entire width of the
ROW.
5.3 Ground Disturbance
For our purposes, ground disturbance shall be considered any activity that requires breaching the earth to a
depth of more than 30 cm. The disturbance also cannot reduce the cover over a pipeline to less than
permitted at installation. We require that Head Office approval or a Crossing Agreement is in place any
time we create a ground disturbance in the right of way of an underground facility or within 5 metres of any
underground facility where there is no right of way. Complete a Ground Disturbance Permit / Checklist (in
the Forms section) prior to commencing the work.
A company performing a ground disturbance is responsible for proving due diligence of all reasonable
precautions necessary to determine if underground facilities exist. All underground facilities within a 30
metre perimeter of the outside limits of the ground disturbance must be located.
A Ground Disturbance Supervisor must be assigned for any ground disturbance. This will be a company
employee, contractor or consultant authorized by the company. The supervisor must be deemed
competent by formal examination and/or certification to supervise a ground disturbance. The objectives for
ground disturbance supervision are:
• Successful completion of Ground Disturbance Orientation
• Clarify the sources when searching for buried facilities
• Providing notification to facility owners
• Receiving owner notification
• Approvals/crossing agreements
• Regulations
• Creating the plot/site drawing
• Line locating
• Exposure
• Backfill inspections
• Permits and pre-job meetings
• Emergency Response Plans
• Contacting a buried facility
Sources of information that must be available prior to work commencing are:
• AER Baseline maps / ACCUMAP within 30 days
• Certificate of title
• Site drawings (if available)
• Results of our internal or third party search
• Signed copy of the crossing agreement
• As built, facility, local survey plans etc.
• References to visual indicators
• Provincial One Call services if applicable
• Consultation with other area operators, including contractors
• Discussion with the land owner
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This search is carried out to determine the owners (permit holders and licensees) of facilities within the
search perimeter. The owners are notified of the:
• Nature and scope of the proposed ground disturbance
• Schedule for undertaking the work
It is the responsibility of the facility owner, at their own cost, to accurately locate and clearly indicate the
horizontal position and alignment of their facility on the surface of the ground.
• Locator services used by our company will be trained and competent at locating all types of
underground facility
• Operations personnel, thoroughly familiar with the area, will be present during locating
activities
• Operations personnel will understand line locator procedures and have a plot plan or site
drawing such as an as built map for reference
• The most effective method of detection is direct connection or clamping
• Blind search sweeping will be performed in four grid patterns (East/West, North/South and at
angles both ways) to ensure maximum detection potential
A ground disturbance cannot be performed within 5 metres of a pipeline where there is no right of way
unless there is written approval by the owner or by the provincial regulator if owner approval cannot be
obtained.
Facility owners must be notified a minimum of two working days, but not more than seven working days,
prior to commencement of the ground disturbance. This notification timeframe requirement may only
differ from regulations if agreed to by both parties.
Exposing Facilities
A site-specific pre-job safety meeting will be held when we perform a ground disturbance that encroaches
on the 5 metre safety zone for an underground facility. All personnel directly involved in the conduct of the
work will be in attendance. The meeting minutes and signed attendance list will be retained on file. New
crewmembers or replacements must be briefed prior to working on the site. As a minimum the meeting
will cover:
• All job safety and procedural considerations (safe work practices) and Crossing Agreement
requirements
• All hazards and risks on the site must be identified and communicated to all workers. Plans
must be developed and measures put in place to manage, eliminate or mitigate risks to an
acceptable level
• Identify all existing underground facilities in the ground disturbance area
• Identify the line size, operating pressure, substance carried (obtain MSDS for substances) and
the markings used for each facility
• Identify the exposure procedure for each facility
• Identify personal protective equipment to be used to conduct the work and in the event of an
emergency
• Identify firefighting equipment requirements and location
• Identify trenching and excavation requirements; OH&S regulations and Ground Disturbance
Safe Work Practices apply. Confined Space procedures may be necessary
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• Identify cathodic protection requirements
• Identify barricading and fencing requirements
• Establish escape routes, mustering location and evacuation procedures
• Ensure the site Emergency Response Plan is in place and reviewed
The owner representative and the excavation supervisor must have approved Ground Disturbance training.
All facilities are to be hand excavated using an approved method. A combination of hand and mechanical
excavation, as outlined in Schedule 4 of the Pipeline Regulations, can be used for facilities buried more than
1.5 metres deep.
Mechanical excavation equipment is not to be used within 60 cm of a pipeline without on-site supervision
by an owner representative. The facility must be exposed first by hand excavation methods.
If any contact occurs with a buried facility during ground disturbance that results in a crack or puncture to a
pipeline, scratch, gouge, flattening or dent on the outside surface of a pipe or damage to the external
protective coating the ground disturbance must be immediately halted. The facility owner must be advised
of the location and damage. The owner must immediately notify the provincial regulator and report the
location and type of damage. The particular ground disturbance that was halted as a result of contact must
not recommence without the approval of the owner.
Trenches and Excavations
Provincial regulations may vary with respect to trenches and excavations. In these situations, our personnel
will always employ Ground Disturbance Safe Work Practices.
All trenches and excavations that personnel will be required to work in will be created with appropriate
cutback or sloping or temporary protective structures will be installed prior to entry.
Spoil piles must be at least 1 metre from the side of the excavation and have a slope of less than 45 degrees.
Power poles must be protected from cave-in.
Equipment is not permitted closer to the edge than the distance from the same edge to the bottom of the
excavation. If equipment or heavy objects must closer, an engineer must approve additional support for the
walls of the excavation.
There is legal responsibility to guard an excavation in a manner that is adequate to prevent persons from
falling in. If the excavation is to be left unattended, barricades must be installed to warn people of the
danger and protect personnel, the public, livestock and wildlife from the hazard.
Backfilling Procedures
Notification to the owner of a facility that was exposed due to a ground disturbance must be given at least
24 hours prior to commencing the backfill. The owner must inspect the facility to ensure no damage has
occurred. The written inspection report is retained on file for 2 years.
Backfilling an exposed facility must be done to ensure no damage occurs, or will occur from subsequent
surface activities. Pipelines must be supported by undisturbed or compacted soil. Backfill material will
normally be the spoil removed from the excavation with appropriate care to remove objects that could
damage underground facilities. Clean fill or sand will be used as initial fill within 150 mm of the pipe wall in
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all directions. Care must be taken that the facility is not damaged as a result of subsequent backfill activities
and that these activities will be performed in a manner to prevent settling or erosion of the backfill and
support material. Complete a Backfill Inspection Form (in the Forms section) to be included in the records
of the work performed.
Single Penetration Points
Rig anchors, pile driving, auguring, and signposts are examples of single penetration points. All ground
disturbance guidelines apply, however it is likely that the exact location for a single point penetration can be
decided after the facility search. In this way it may be possible to remain more than 30 metres from a
foreign facility or beyond the 5 metre safety zone where a facility would require exposure by hand
excavation prior to the ground disturbance. Also be aware that if the penetration can be achieved by hand
techniques, then facilities within 5 metres need not be exposed. All notification and approval requirements
must still be met.
5.4 Pipeline Repair
All pipeline repairs will be performed in accordance with CSA Z662 and provincial authority requirements.
When it is not immediately practical to repair a pipeline permanently, a temporary repair can be made. It is
expected that a permanent repair will be performed within a year. Any temporary repair creates a risk
situation that will require sufficient periodic inspections to ensure the defective condition has not extended,
there are no leaks and the repair device has not deteriorated in any way.
Engineering review and acceptance of all proposed repairs will be done on an individual basis. Engineer
approval is required for repairs using steel or composite reinforcement sleeves or steel pressure
containment sleeves or if the repair requires hot tapping.
Hazards and Precautions
The potential hazards involved in pipeline repair include fire, explosion, exposure to toxic or irritating
substances and oxygen deficiency. As a result of any excavation, trench cave-in and exposure to broken
utility lines such as electricity are possible. Ground conditions such as mud will increase slip and fall
dangers.
A pre-job meeting will be held with all personnel involved to review the procedures that will be followed
and to ensure that all personnel understand the anticipated dangers and precautions to be taken. At this
meeting the hazards and potential seriousness of an incident will be evaluated and containment, mitigation
and recovery actions will be identified.
Company personnel will ensure that fire retardant work wear and appropriate respiratory protective
equipment is worn during pipeline repair activities. Air monitoring equipment, non-sparking tools and
electronic line location devices will be used. Positive air shutoff on diesel powered equipment and spark
arrestors on exhaust pipes or stacks of engines running in the area are required.
Site security measures must be taken. Danger and Caution signs and barricades will be placed appropriately
and access to the area will be restricted to essential personnel.
Employ ground disturbance, trenching and excavation safe practice procedures and isolate the pipe from
the potential of electrical hazard created by the cathodic protection system.
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During the pipe cutting operation all precautions must be taken to eliminate the possibility of sparks. The
pipe must be properly prepared before any hot work is performed. Personnel wearing respiratory
protective equipment will wipe the inside of the pipe on the cut ends a minimum of 1.5 metres. Use air
stopples or mud plugs that have been approved by the engineer. Air monitoring will be performed once the
plug is installed.
Before proceeding with any welding air monitoring will be performed. Consider the possibility of prior
hydrogen charging and the removal of hydrogen using a bake-out process. Fire extinguishers must be
manned when welders are in the excavation.
Welding procedures and practices will be in accordance with CSA Z662 Section 7. There are also welding
criteria that must be complied with in CSA Z662 Sections 10.13 and 10.14. Welders must be qualified to
perform the work as specified in the standards.
Notification
A company representative will notify the following when a repair is to be performed:
• Local and jurisdictional authority
• Pipeline co-owners
• Affected operating facility partners or owners
The notification will be in writing and will include the following information:
• Legal description and license number of the pipeline
• Description of the defect
• Detailed information regarding the repair:
- Permanent or temporary repair
- Repair method to be used
- Requirement for pipeline shutdown
- Actions that will be undertaken to ensure the integrity of the pipeline system
- Anticipated timing to perform permanent repair if original repair is temporary
Repair Methods
Pipeline repair methods take into account the type of damage and whether it is on the pipe body, on a mill
seam weld or on a circumferential joint weld. A dent that contains a stress concentrator (gouge, groove, arc
burn or surface crack) that is on a circumferential weld has significantly different repair requirements than a
dent with no other damage on a pipe body.
Table 10.1 of CSA Z662 details acceptable permanent repair methods and their limitations related to each
type of pipeline defect. The following information has been extracted from the table and shows the repair
methods for each type of defect that have no additional limitations beyond those specified in the associated
repair clause of the standards. Each defect type is also explained in further detail in the standards manual
and the first time a repair method or defect is referenced below the appropriate clause has been noted.
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Pipeline Replacement – CSA Z662 clause 10.11.3
This repair method is acceptable for all types of pipe defects.
NOTE: Pipeline replacement is the only acceptable repair method for internal corrosion defects on
sour service pipelines.
Steel Pressure Containment Repair Sleeve – CSA Z662 clause 10.11.4.2
This repair method is acceptable for all types of pipe defects except internal corrosion defects
NOTE: The above methods are the only two that are acceptable for repairing a leak (CSA Z662
clause 10.11.1.4).
NOTE: The above methods are the only two, without limitations, for repair of a dent defect (CSA
Z662 clause 10.10.4.2) with a stress concentrator on a circumferential weld.
Steel Compression Reinforcement Repair Sleeve – CSA Z662 clause 10.11.4.4
Acceptable for:
- External corrosion defects (CSA Z662 clause 10.10.2.7)
- Gouge, groove or arc burn (CSA Z662 clause 10.10.3) on a pipe body or mill seam weld and is not in
a dent
- Dent defect with a stress concentrator on a pipe body or a mill seam weld
- Dent defect without a stress concentrator
- Weld defect (CSA Z662 clauses 10.10.6 and 10.10.7) in a mill seam weld
- Grind defect (CSA Z662 clause 10.11.2.6)
Hot Tap – CSA Z662 clause 10.11.5 (damage must be completely contained in the metal removed)
Acceptable for:
- External corrosion defects
- Gouge, groove or arc burn on a pipe body or a mill seam and is not in a dent
- Dent defect with a stress concentrator on a pipe body or mill seam weld
- Dent defect without a stress concentrator on a pipe body or mill seam weld
- Pipe body surface crack (CSA Z662 clause 10.10.5) not in a dent
- Weld defect in a mill seam weld
- Grind defect
Steel Reinforcement Repair Sleeve – CSA Z662 clause 10.11.4.2
Acceptable for:
- External corrosion defect
- Dent defect without a stress concentrator on the pipe body
- Grind defect
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Grinding Repair – CSA Z662 clause 10.11.2
Acceptable for:
- Gouge Groove or arc burn on a pipe body or mill seam weld or circumferential weld and is not in a
dent
- Pipe body surface crack that is not in a dent
- Weld defect in a mill seam weld or circumferential weld
Direct Deposition Welding – CSA Z662 clause 10.11.6
This repair method is acceptable for external corrosion defect or grinding defect repairs.
Welding Repair – CSA Z662 clause 10.10.6
This is acceptable to repair a weld defect in a circumferential weld.
Composite Reinforcement Repair Sleeve – CSA Z662 clause 10.11.4.3
There are no defects that can be repaired by using a composite reinforcement repair sleeve by
itself. Information in Table 10.1 of CSA Z662 will provide details of the conditions that must be met
to use this as a permanent repair method. It may be an option worth considering at pipe bends or
when a welding truck cannot be brought to the location.
Refer to the following Flow Chart from CSA Z662 showing acceptable repair methods.
NOTE: The legend and limitations information is on the page following the flowchart.
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Legend
A – Grinding repair (CSA Z662 - Clause 10.11.2)
B – Pipe replacements (CSA Z662 - Clause 10.11.3)
C – Steel pressure-containing sleeve (CSA Z662 - Clause 10.11.4.2)
D – Steel reinforcement sleeve (CSA Z662 - Clause 10.11.4.2)
E – Steel compression reinforcement sleeve (CSA Z662 - Clause 10.11.4.4)
F – Composite reinforcement sleeve (CSA Z662 - Clause 10.11.4.3)
G – Hot tap (CSA Z662 - Clause 10.11.5)
H – Direct deposition welding (CSA Z662 - Clause 10.11.6)
I – Welding repair (CSA Z662 - Clause 10.10.6)
Limitations
These limitations are additional to any specified in the applicable repair clause.
1 This repair method is not acceptable for the defects with metal loss in excess of 80% of the
nominal wall thickness of the pipe.
2 The stress concentrator (gouge, groove, arc burn or crack) shall be removed by grinding as
specified in CSA Z662 Clauses 10.11.2.2 and 10.11.2.3 prior to the application of the sleeve.
3 The stress concentrator (gouge, groove, arc burn or crack) shall be removed by grinding as
specified in CSA Z662 Clauses 10.11.2.2 and 10.11.2.3 prior to the dent being assessed for
acceptability as specified in CSA Z662 Clause 10.10.4, with the depth of the ground area being
excluded from the dent depth. This repair method is not acceptable unless both of the
following apply:
a. The dent is no longer a defect as described in CSA Z662 Clause 10.10.4.2.
b. The pipe is considered to be acceptable based upon an engineering assessment as required
in CSA Z662 Clause 10.10.4.3 unless a steel reinforcement repair sleeve is applied.
4 This repair method is not acceptable unless all of the following apply:
a. The dent is on the pipe body or a mill seam weld.
b. The dent depth is 15% or less of the specified outside diameter of the pipe.
c. Any stress concentrators in the dent are removed by grinding as specified in CSA Z662
Clauses 10.11.2.2 and 10.11.2.3.
d. A suitable material is used to fill the dent prior to application of the sleeve in order to
prevent re-rounding of the pipe.
5 Any circumferential cracks shall be removed by grinding prior to application of the sleeve.
6 The stress concentrator (gouge, groove, arc burn or crack) shall be removed by grinding prior to
performing direct deposition weld repairs.
NOTES:
- Mill seam welds are longitudinal, helical or skelp end pipe seam welds.
- Permanent repairs may be preceded by temporary repairs. (See CSA Z662 Clause 10.12).
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If the repair requires shutdown, re-testing may be necessary to establish the integrity of the pipeline prior
to reactivation. This would usually be done by pressure testing. If appropriate, we can apply for approval to
establish the integrity of the pipe using alternate methods.
Regulatory approval is required to put the pipeline back in service.
5.5 Pressure Testing
In Alberta the AER must be notified at least 48 hours prior to the commencement of a pressure test. The
test will be performed in place, before being put into operation and under the same conditions as expected
during normal operations. Otherwise, the pipe should be pretested.
Pressure testing standards are found in Section 8 of CSA Z662. The Pipeline Act and Regulations also
provides requirements for performing tests. Evidence of satisfactory testing must be in place for all
pipelines we operate. The AER may require retesting if satisfactory records are not available.
Prior to the pressure test confirm that the test will not:
• Result in greater than allowable stress in the piping
• Adversely affect the soil surrounding the piping
• Damage valve seats
Consideration must be given to any adverse effects the liquid medium could have on the pipe. Adverse
effects can be caused by the presence of bacteria, oxygen, suspended solids or metals, high salinity, acidity
or industrial contaminants. Any of these conditions may necessitate a plan of treatment of the liquid or the
completed piping to protect against corrosion or other damage.
A pressure testing plan must be developed. The plan will address the safety of the public and the personnel
conducting the test. The plan must consider issues such as pressure, test medium, location, worker and
public access control and the consequences of uncontrolled or controlled depressurization. This list is not
comprehensive and other considerations may be necessary.
The minimum test pressure for any pipeline in Alberta will be 700 kPa unless the AER approves a lower test
pressure. If the pipeline has concentrations of H2S greater than 10 moles/ kilomole then the minimum test
pressure must be 1.4 times the maximum operating pressure.
Pressure testing pipelines within 20 metres of a test head assembly shall not exceed a hoop stress level of
90% SMYS (specified maximum yield strength).
There are specific requirements and/or approvals that must be in place to test a pipeline if the hoop stress
level will exceed 100% SMYS or if test durations will deviate from requirements.
Some pressure testing requirements do not apply for instrument and control piping that does not exceed 25
mm outside diameter.
MAINTENANCE AND REPAIR
Procedures and Guidelines Pipeline Operations Manual
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Liquid Test Medium Other Than Fresh Water
Approval from the AER is required to test a pipeline with any liquid test medium other that fresh water if:
• The volume of the test section exceeds 500 cubic metres
• The hoop stress level during the test is expected to exceed 100% SMYS, or
• The pipeline crosses or is within 100 metres of flowing water
In a situation where new welded steel pipe is to be tested within 100 metres of flowing water non-
destructive inspection of all welds, in accordance with CSA Z662, for the portion within 100 metres of the
flowing water must be performed. Unacceptable welds must be removed and repaired.
Prior to the start of pressure testing:
• Develop and document a contingency plan for immediate response in the event of a leak or spill
• Deploy equipment and resources to the site to ensure that implementation of the contingency
plan can be achieved without delay
• Complete all applicable sections of Form A6.1 – Non-Fresh Water Liquid Pressure Test for
Pipelines at least 48 hours prior to starting the pressure test
• Form A6.1 can be found here:
- http://www.aer.ca/documents/directives/Directive077_FormA61_122211.doc
• Maintain a copy of the completed Form A6.1 on site during the test
• Submit the completed Form A6.1 and the contingency plan to the AER upon request
• Maintain the original completed Form A6.1 for at least two years after the completion date of
the test
Written approval for any deviation from the above requirements must be obtained by request submitted to
pipelineoperations@aer.ca and must include the completed Form A6.1 along with justification for the
deviation.
Gaseous Test Media
Use of air or other gaseous medium to pressure test a pipeline section with an internal volume greater than
125 cubic metres will require approval from the AER. A detailed proposal of the test must be submitted
that includes a fully documented engineering evaluation that demonstrates the procedure is safe and
sufficiently sensitive to detect leaks.
If the pipeline section is known or suspected to have corrosion, or any other condition that could potentially
cause the pipeline to break, then the testing proposal must include a fully documented engineering
evaluation that demonstrates the testing procedure complies with CSA Z662 and the Pipeline Regulation.
Appropriate measures must be implemented to ensure the protection of people and property in the vicinity.
The Pipeline Regulation and CSA Z662 have specifications regarding the gases that can be used for gaseous
media pressure testing. No gas containing H2S may be used. After completion of the test the gas must be
vented or flared in accordance with Directive 038 and Directive 60.
MAINTENANCE AND REPAIR
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Recording Requirements
The following requirements apply for the recording of pressure test results:
• The record or chart of a pressure test shall be continuous and legible over the full test period.
The commencement and termination points must be clearly identified.
• Electronic pressure recording devices can be used provided:
- A permanent paper copy of the test data is retained
- The sample rate and instrument sensitivity will identify expected deviations from normal
test pressure
• The pressure during the test must fall between 25% and 90% of the full range of the recording
instrument. The range of the instrument must be recorded on the chart face or on the
permanent paper copy of the test data.
• The recording instrument must be accurate within 2% of its range. Verification that the
instrument is within specifications must be available.
Pre-Tested Pipe for Use in Emergency Repair
Pipe kept in storage can be used in emergency repairs. The pipe must be stored in a way that prevents
deterioration by excessive metal oxidation or UV damage to coatings. The pipe ends must be bagged or
capped.
All pre-tested pipe must conform to standards and be marked accordingly, complete with Heat Number.
Mill Test Certificates must be available as supporting documentation.
Pipe stored for emergency repair will pass testing in accordance with CSA Z662 Section 8. The test pressure
and date of testing will be painted along the length of the pipe. Test charts will be retained on file until the
pre-tested pipe is used.
Pipe not used within five years will be inspected for coating damage and re-tested as per CSA Z662.
When pipe is used from storage the pipe must be transported, handled, installed and buried using good
practices to avoid damage. Pipe documentation will be transferred to the project files and retained for the
life of the pipeline.
Note: The following testing and maintenance routines are essential to the integrity management of our
pipeline systems. By performing these activities we mitigate the risk associated with our pipeline
operations. The records that we produce from performing these tasks will establish the criteria for our
integrity management plan, a pro-active assessment of the repairs, improvements, modifications,
replacement or further testing that is foreseeable. The integrity management plan is executed based on
priority that is established by a risk assessment.
5.6 Inspection of Cathodic Protection System
Measurement of the rectifier voltage and current output levels will be recorded every two months, with no
interval longer than ten weeks. A technical assessment using the recorded information will be performed
annually, with no interval longer than fifteen months. The evaluation of the current required to provide
cathodic protection can give insight into the integrity of the external pipe coating.
MAINTENANCE AND REPAIR
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Interference bonds, whose failure would jeopardize pipeline protection, will be checked for proper
operation every two months, with no interval longer than ten weeks.
Annually, qualified personnel will perform the following:
• Check condition and efficiency of rectifier and ground bed installations
• Check condition and accuracy of meters and perform calibration if necessary
• Check condition of cased road crossings and measure to determine if contact between pipe and
casing is occurring
• Investigate any evidence of foreign interference
• Check condition of insulation fittings, continuity bonds and casing insulators
Repairs to components of the cathodic protection system are to be performed when inspections or
measurements indicate there are deficiencies.
A complete record of the repairs performed will be kept on file.
5.7 Inspection of Pressure Control, Limiting and Relieving Devices
Pressure control, pressure limiting and pressure relieving systems and devices can be left in place for
inspection, testing and assessment provided these activities can be performed safely and properly.
Annually, with no interval longer than 18 months, the following activities must be performed for pressure
control and pressure limiting systems and/or devices:
• Inspected to determine that they are properly installed and protected from dirt and other
conditions that can prevent their proper operation
• Tested to determine that they are in good operating condition and set to function at the correct
pressure
• An assessment must be performed to determine that they are adequate from the standpoint of
capacity and reliability for the service in which they are employed
A defective or non-functioning overpressure protection device must be repaired or replaced before the
operation of the pipeline resumes.
For all overpressure protection devices we must:
• Maintain adequate inspection, assessment and testing records for the device, and
• Submit the records to the AER upon request
Inspection, assessment and testing records must document the information used to perform effective
evaluation of the overpressure protection device; the results of the inspection, assessment and testing; and
the resolution of any issues regarding a defective or non-functioning device prior to the resumption of
pipeline operations by the licensee.
Rupture disks will be inspected, assessed and, if necessary, replaced in accordance with API 576.
As a minimum, once each calendar year emergency shutdown (ESD) valves and ancillary equipment will be
inspected and proper operation confirmed. Opportunities presented by other maintenance routines such
as compressor oil changes or turnarounds should be used to test ESD valves.
MAINTENANCE AND REPAIR
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The records of inspection, testing and assessment of these systems and/or devices will be kept on file for
two years.
5.8 Valve Maintenance Program
Wellhead and flow line valves will be maintained as recommended by the manufacturer. Valve
maintenance personnel will use safe work practices and procedures when performing maintenance
activities. The contractor will provide the company with status reports for each location listing the valves;
the maintenance performed and suggested repairs.
Our operating personnel must approve the closing and opening of valves during valve maintenance
procedures.
Other work to be performed on every wellhead includes:
• Tightening hand wheels where needed to prevent stem damage
• Check and tighten gland nuts as needed
• Check the ESD valves for leakage or faulty operation
• Service ball valves
- operator must approve valve operation
- damage to seals may occur if grease is forced into a closed valve
- close the valve after greasing and observe, a pressure increase would indicate the valve is
faulty
- add sealant if appropriate
- submit suggested repairs to the company
Pipeline valves that may be required in an emergency situation must be inspected and partially operated a
minimum of once per calendar year, with no interval longer than 18 months.
The open and closed position of major valves must be clearly marked.
5.9 Meter and Instrumentation Maintenance
As a general practice instruments and measuring equipment shall be calibrated at least annually, or as
required by regulations, standards or best practice. Malfunctions must be immediately corrected to
facilitate proper measurement and/or system security.
The performance of the leak detection system must be monitored regularly to ensure degradation in
performance is detected as soon as possible and remedial action taken. The leak detection system must be
tested annually. This should be done by removal of liquid from the pipeline.
The following information must be recorded:
MAINTENANCE AND REPAIR
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• Date, time and duration
• Method, location and description of leak
• Operating conditions at the time of the test
• Details of any alarms that were triggered by the test
• Analysis of the performance of the leak detection system and operating personnel during the
test
Maintenance and testing records must be retained on file for five years.
5.10 Site Vegetation Control
As a fire prevention measure, natural vegetation and vegetation used for erosion control or as a windbreak
at our facilities and right of ways will be maintained in an appropriate manner.
Approved methods of vegetation control are mowing and the use of short-term herbicides. Operating
personnel can perform spot spraying and maintenance of small areas. Operating personnel are not
permitted to use products requiring application by licensed personnel. Pipeline right of ways should be kept
clear of vegetation that obstructs visual inspection or impedes access for maintenance and repair or in the
event of an emergency. Where vegetation control may require larger machinery, licensed personnel or
involve large areas, consideration should be given to contracting a grounds keeper.
All vegetation control measures on company property will be performed using appropriate safety and
personal protective equipment and following all precautionary and procedural instructions.
Use of sterilants at our facilities is not recommended. Sterilants may persist in the soil for years and can
wash into agricultural fields resulting in crop damage. The company is liable for compensation claims and
reclamation of damaged areas. Use of long-term herbicide, on an exception basis, must satisfactorily pass
an environmental assessment and be approved by Operations management.
Use of herbicides must be documented and retained in the facility environmental files. Information should
include at least:
• The name of the facility
• The area at the facility where the herbicide was applied
• The name of the herbicide and application rate
5.11 Exposed Pipe Examination
Anytime that a pipe is exposed the coating of the pipe should be examined. This will provide a visual record
of the coating condition of the exposed portion and a reasonable estimation of the relative condition of the
entire pipe joint. Further investigation is warranted if problems with the coating or pipe are observed.
Removal of the old coating and application of new coating is appropriate for small areas. Cut out and
replacement of the existing pipe can be considered for more extensive failure.
Records of the observation, with photographs if warranted, and repair must be kept for the life of the
pipeline.
MAINTENANCE AND REPAIR
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Procedures and Guidelines Page - 20
5.12 In Line Inspection
This type of inspection will provide data to assess if deterioration of the steel pipe or coatings is occurring.
It is useful to establish current base line data for pipelines that have been in operation for many years. It is
also a practical testing method for pipelines with high corrosion rates.
This testing is typically provided by a third party and will require that the pipeline has no conditions that
could interfere with the passage of the tool. Build up of wax or other deposits must be cleared with
cleaning pigs prior to testing.
Further inspections using ultrasonic or radiographic techniques or mechanical measurement may be
scheduled as a result of the in line inspection to further investigate findings. Comparison of subsequent in
line inspection data will establish growth rate or change to any areas of concern.
FORMS
PIPELINE OPERATIONS MANUAL FORMS Table of Contents Pipeline Operations Manual
Table of Contents
6. FORMS
Note: Emergency Response Plan activation, notification or reporting may be required if any of the highlighted forms are used. Make copies as required or ensure that forms are replaced if original is used.
FIRST RESPONSE FORM 1
ACCIDENT / INCIDENT REPORT 3 FIRST CALL COMMUNICATION (ALBERTA) 5 INCIDENT LOG 7
ANIMAL HEALTH COMPLAINT FORM 9 BOMB THREAT FORM 11 RIGHT OF WAY INSPECTION REPORT 13 PIPELINE INSPECTION AND MONITORING REPORT 15 OUT OF SERVICE FORM 17
EVACUATION ZONE ACCESS CONTROL FORM 19 PLUME TRACKING AND AIR MONITORING FORM 21 SPILL REPORT 23 VALVE SUMMARY (insert in Valves and Crossings section when complete) 27 CROSSING SUMMARY (insert in Valves and Crossings section when complete) 29 GROUND DISTURBANCE PERMIT / CHECKLIST 31 BACKFILL INSPECTION FORM 33 THIRD PARTY INSPECTION 35 REPAIR LOG 37 PIPELINE CROSSING CHECKLIST 39 NEW WELL START UP FORM 41
PIPELINE OPERATIONS MANUAL FORMS Table of Contents Pipeline Operations Manual
Table of Contents
FIRST RESPONSE FORM Forms Pipeline Operations Manual
Forms Page - 1
CALLER INFORMATION
NAME: DATE/TIME:
PHONE: LOCATION:
EMERGENCY EVALUATION
CATEGORY: ALERT LEVEL 1 LEVEL 2 LEVEL 3
EMERGENCY DESCRIPTION:
ON-SCENE COMMANDER: PHONE:
INJURIES:
EVACUATION NEEDED: IMMEDIATE AREA ONLY TOTAL
EVACUATION COORDINATOR: NAME: PHONE:
NOTIFICATION
CHECKLIST
POLICE FIRE AMBULANCE LOCAL AUTHORITY LEAD AGENCY RESIDENTS CENTRE
OTHER: _________________________________________________________________
ROADBLOCKS REQUIRED/ ESTABLISHED
ASSIGNMENTS:
OPERATIONAL ATTRIBUTES
UPID OPERATING PRESSURE SUBSTANCE PROBLEM
DESIGN ATTRIBUTES
DIMENSION / MATERIAL M.O.P. COATING WELD ATTRIBUTES CORROSION SUPPRESSION
PRODUCT RECOVERY
SUBSTANCE VOLUME RELEASED VOLUME RECOVERED
FIRST RESPONSE FORM Forms Pipeline Operations Manual
Forms Page - 2
LOCATION INFORMATION
DESCRIPTION OF LAND:
PROXIMITY TO WATER:
PROXIMITY TO PUBLIC:
IMMEDIATE DANGER:
WEATHER CONDITIONS
WIND DIRECTION/SPEED:
ROAD CONDITIONS:
OTHER:
CONTACTS MADE BY CALLER
CONTACT PHONE CONTACT PHONE
INFORM THE CALLER OF ANY IMMEDIATE DANGER TO HIMSELF OR OTHERS INSTRUCT THE CALLER IN IMMEDIATE PRECAUTIONS TO BE TAKEN
ASSURE THE CALLER THAT IMMEDIATE ACTION WILL BE TAKEN NOTES:
ACCIDENT / INCIDENT REPORT Forms Pipeline Operations Manual
Forms Page - 3
ACCIDENT/INCIDENT DETAILS
EXACT LOCATION:
DATE AND TIME:
REPORTED TO: DATE AND TIME:
TYPE OF ACCIDENT/INCIDENT
LOST TIME INJURY OR ILLNESS PROPERTY DAMAGE
MEDICAL AID PRODUCTION LOSS OTHER
PERSONAL INJURY
NAME OF PERSON INJURED: OCCUPATION:
DESCRIPTION OF INJURY:
PROPERTY DAMAGE OR PRODUCTION LOSS
DESCRIPTION OF DAMAGE OR LOSS:
COST OR AMOUNT OF LOSS:
OBJECT/EQUIPMENT/SUBSTANCE INFLICTING DAMAGES:
DESCRIPTION
DESCRIBE CLEARLY HOW ACCIDENT/INCIDENT OCCURRED:
ACCIDENT / INCIDENT REPORT Forms Pipeline Operations Manual
Forms Page - 4
ANALYSIS
WHAT ACTS, FAILURES OR CONDITIONS CONTRIBUTED MOST DIRECTLY TO THIS ACCIDENT/INCIDENT:
PREVENTION
WHAT ACTION(S) WILL BE TAKEN OR RECOMMENDED TO PREVENT RECURRENCE:
POST-INCIDENT REVIEW
PERSON RESPONSIBLE FOR FOLLOW-UP:
INVESTIGATED BY: DATE AND TIME:
REVIEWED BY MANAGEMENT: DATE AND TIME:
COMMENTS
MANAGEMENT COMMENTS:
ADDITIONAL COMMENTS:
FIRST CALL COMMUNICATION - ALBERTA Forms Pipeline Operations Manual
Forms Page - 5
CO
NT
AC
T D
ET
AIL
S
AER Contact Field Centre
Media Contact
Caller*
Licensee
Phone*
Phone
date* time*
Notification*
start date* start time* end time*
Release* Ongoing
Location* Nearest Town
Nearest Resident Distance / Direction Phone
Media Involvement?*
Worker Injuries*Public
Health and Safety*
Regional
Local National
International
Operator Phone
PU
BL
IC IM
PA
CT
is jeopardized
could be jeopardized
Hospitalization
First aid Fatality
Emergency Assessment Matrix
Completed with licensee* ERP Activated?One
Alert Two
Three Field / Area
Site Specific Corporate
EPZ Size (2 km if unknown) Numbers and Types of Public in EPZ EOC / ICP Location
Public Protection Measure ImplementedNumber Evacuated
Shelter
Notification Roadblocks
Evacuation
RE
LE
AS
E T
YP
E
Release Impact*H2S Concentration*
Off Lease
Environment Affected*
Area Affected (m2)*
Land
Air Standing Water
Flowing Water
Water Body Name
Property Damage* Equipment Loss* Wildlife / Livestock Affected*
Gas ReleaseVolume / Rate
Liquid ReleaseVolume / Rate
Sweet Sour
Release Point Determined
Water Effluent
CO
NT
AIN
ME
NT
Third Party / Outside Assistance Required*Intermittent control possible
Incident contained or controlled Imminent control probable
Incident is uncontrolled
Company WCSS Co-op
First Call Communication
* These fields must be completed to generate an FIS number and/or to complete an Emergency Assessment Matrix.
Release Point Determined
Sensitive Environment*
On Lease
Oil
FIRST CALL COMMUNICATION - ALBERTA Forms Pipeline Operations Manual
Forms Page - 6
Type of IncidentWell Licence No.
OP
ER
AT
ION
TY
PE
Well Status
Blowout Loss of CirculationKick
Producing InjectionServicing
Sour CriticalSweet
Drilling
Standing
Suspended
Pipeline Licence No. Line No.Leak RuptureHit
Production Facility Licence No. AENV Approval No.Gas Plant CompressorGas
Battery OtherOil
AIR
MO
NIT
OR
ING
Estimated Time of ArrivalLicensee Air Monitoring Occuring HandheldMobile
DistanceInitial Readings / Location On SitePPB
Off SitePPM
Contractor Name Phone AMU Phone
Direction Speed
Wind
Meteorological Conditions AER AMU ETA
Communications competed by Licensee and/or AER
DFO First NationsAHW
Environment Canada Indian Oil and GasLocal Authority
AENV
WH&S
Other
CO
MM
UN
ICA
TIO
NS NEB TDGHealth RegionEMA WCSS
RCMP / Police
Ambulance
Fire
Contact Names and Phone Numbers
Incident Cause Natural Human-Induced Unintentional Human-Induced Intentional
OT
HE
R IN
FO
RM
AT
ION
Band / Settlement Name / Contact PhoneFirst Nations Band
Metis Settlement
ComplaintsLocal
Large Area
PhonePrivate Land Title Holder
Public Land Type Irrigation Forestry Grazing Other
PhonePublic Land Administrator Contact
Additional Information
INCIDENT LOG Forms Pipeline Operations Manual
Forms Page - 7
DATE/TIME ACTIONS RESULTS
INCIDENT LOG Forms Pipeline Operations Manual
Forms Page - 8
DATE/TIME ACTIONS RESULTS
ANIMAL HEALTH COMPLAINT FORM Forms Pipeline Operations Manual
Forms Page - 9
INITIAL CONTACT QUESTIONNAIRE
Name of person reporting incident: Date: Time:
Address:
Name of livestock owner (if not the same as above):
Address:
Legal Land Location: LSD SEC TWP RGE W Telephone: (work) (home)
Nature of animal health problem: ______ Distressed ______ Death ______ Other
Comments:
QUESTIONS FOR LIVESTOCK OWNER:
Have you consulted your veterinarian: ___ Yes ___ No
Name of veterinarian:
Have you had an animal health examination and documentation of problem? ___ Yes ___ No
Details:
Have you made any submissions to an animal health or veterinary diagnostic laboratory? ___ Yes ___ No
Details:
Have you contacted any government agency or others for assistance or direction regarding this matter? ___ Yes ___ No
Details:
Do you know the possible source of the problem? ___ Yes ___ No
Comments:
Is the source of the problem related to an oil or gas related activity? ___ Yes ___ No
If NO, this matter will be referred to (name & dept.):
LIVESTOCK OWNER DECLARATION:
I agree to an integrated government response in investigating this situation. To allow this integrated government response to occur, I agree to allow veterinary health data collected on my animals to be shared between the participating government agencies involved in this investigation.
__________________ _________________________________________
(Date) (Signature of livestock owner)
INVESTIGATOR QUESTIONS:
Have you or anyone else taken any samples? ___ Yes ___ No
Comments:
Possible source: ___ Oil & Gas Industry – Operator ______________________________________________________
___ Other ___________________________________________________________________________
Have you contacted the operator regarding this matter? ___ Yes ___ No
Describe the site: Is it a ___ well site? ___ pipeline? ___ battery? ___ plant site? ___ farmyard? ___
Is the total lease area ___ partially / ___ totally fenced? Have any photographs been taken? ___ Yes ___ No
Details:
Is there visual evidence of surface water migration off the site? ___ Yes ___ No
ANIMAL HEALTH COMPLAINT FORM Forms Pipeline Operations Manual
Forms Page - 10
Does this lead to a dugout or other drinking water source for livestock? ___ Yes ___ No
What have the livestock been grazing on?
Water conditions? Feed conditions? Soil conditions?
Actions taken by operator / complainant to minimize impact
DIAGRAM OF AREA:
Signature: __________________________________________________
Name (Print): __________________________________________________
Telephone: __________________________________________________
BOMB THREAT FORM Forms Pipeline Operations Manual
Forms Page - 11
If a threat is received by telephone, the receiver of this call should: REMAIN CALM AND LISTEN CAREFULLY PLEASE COMPLETE THIS FORM AS COMPLETELY AS POSSIBLE Time of call: Date of call:
Exact wording of call: (ASK TO REPEAT IF NECESSARY)
Type of Threat:
Expected time of detonation: Location of detonation:
DETERMINE IF YOU ARE ABLE (circle where applicable):
Voice: M F Unknown Familiar: Y N who? Approx. Age: 10-15 / 16-25 / 26-45 / 46-75
Is voice: Calm, Nervous, Young, Old, Middle-aged, Rough, Refined, Speech impediment
Accent of caller: Is caller intoxicated?
Background Noises: traffic, music, machinery, bells, horns, aircraft, tape recorder, motors, boats/ships,
trains, crowded areas (malls, schools, etc.), other:
PARTICULARS REGARDING THE EVENT What time will the bomb explode? Where is it located?
What does it look like? What kind of bomb?
Why are you doing this? Where are you calling from?
What will cause it to explode?
Did you place the bomb?
What is your name or group taking responsibility for this?
CONTINUED ON OTHER SIDE
BOMB THREAT FORM Forms Pipeline Operations Manual
Forms Page - 12
Did caller indicate knowledge of the facility: Y N If so how?
Receiver of call:
Telephone # of call: Ext. #:
Is this a listed or unlisted number?
Is this a night number? Y N If so whose #?
NOTIFICATION Notified immediate Supervisor: Title:
Supervisor contacted building management: Time:
Comments:
Supervisor contacted police: Time:
Comments:
FOLLOW INSTRUCTIONS FROM BUILDING MANAGEMENT OR POLICE
RIGHT OF WAY INSPECTION REPORT Forms Pipeline Operations Manual
Forms Page - 13
Pipeline System Description:
Pipeline Licence Number(s):
Date of Inspection:
Frequency of Inspection:
Block Valve and Pressure:
Control Equipment and Locations:
Inspection Remarks
Right-of-Way Vegetation
Soil Erosion or Differential Settlement
Heavy Equipment or Construction Activity
Seismic Activity
Pipeline Crossings - water - highway - railway - utilities - other pipelines
Aboveground piping and appurtenances condition
Condition of markers or signs - Right-of-Way - Pipeline, Crossings
RIGHT OF WAY INSPECTION REPORT Forms Pipeline Operations Manual
Forms Page - 14
RECOMMENDATIONS:
IMPLEMENTATION PLAN:
PIPELINE INSPECTION AND MONITORING REPORT Forms Pipeline Operations Manual
Forms Page - 15
Pipeline System Description:
Pipeline Licence Number(s):
Date of Inspection:
Frequency of Inspection:
Method / Equipment Used:
Results / Observations:
Engineering Evaluation:
PIPELINE INSPECTION AND MONITORING REPORT Forms Pipeline Operations Manual
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RECOMMENDATIONS:
IMPLEMENTATION PLAN:
OUT OF SERVICE FORM Forms Pipeline Operations Manual
Forms Page - 17
PIPELINE ABANDONMENT AND DISCONTINUATION STATUS FORM PIPELINE LICENCE: ____________________ LINE #: __________________ QC#: ______________
(Information can be obtained from the PL 100)
PIPE DIAMETER (OD): _____________________ WALL THICKNESS: ________________________ MATERIAL: _______________ COATED: _______________ PIPE LENGTH: ___________________ LOCATION: From: ______________________________ To: ______________________________ SUBSTANCE CODE: _________________ (what was line transporting prior to current work) DATE WORK COMPLETED: _________________________ STATUS: _______________________ (i.e. Abandoned or Discontinued) CATHODIC PROTECTION: No: _____ Yes: _____ (must be left in place if discontinuing line) VISUAL CONDITION OF PIPELINE: EXTERNAL: ______________________________________________________________________ INTERNAL: ______________________________________________________________________ PIGGED OUT: No: _____ Yes: _____ TYPE: Ribbed: _____ Foam: _____ PURGED WITH: Air: _____ Nitrogen Gas: _____ Water: _____ PHYSICALLY ISOLATED FROM ALL OPERATING FACILITIES: No: _____ Yes: _____ ENDCAPS: Steel Plates: _________ If other, describe: ___________________________________ HAS ALL FLUIDS BEEN REMOVED FROM LINE: No: _____ Yes: _____ HAS ANY PRESSURE BEEN LEFT ON THE LINE: No: _____ Yes: _____ REMARKS: ______________________________________________________________________
___________________________________________________________________
PERFORMED BY (PRINT): ____________________________________________ SIGNATURE: ______________________________________________________ (Enter Location Code or AFE and Item #'s): _____________________________________
OUT OF SERVICE FORM Forms Pipeline Operations Manual
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Notes:
EVACUATION ZONE ACCESS CONTROL FORM Forms Pipeline Operations Manual
Forms Page - 19
NOTE: Persons entering the Evacuation Zone must be equipped with Personnel Protective Equipment (PPE) and be updated regarding current conditions.
LOCATION OF ROADBLOCK: ______________________________________________ DATE: ________________
VEHICLE/LICENSE NAME OF DRIVER # OF PERSONS TIME IN TIME OUT
EVACUATION ZONE ACCESS CONTROL FORM Forms Pipeline Operations Manual
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VEHICLE/LICENSE NAME OF DRIVER # OF PERSONS TIME IN TIME OUT
PLUME TRACKING AND MONITORING Forms Pipeline Operations Manual
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LOG SHEET
No. Wind Speed
Wind Direction
Time Location H2S Level SO2 Level
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
PLUME TRACKING AND MONITORING Forms Pipeline Operations Manual
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Notes:
SPILL REPORT Forms Pipeline Operations Manual
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INITIAL REPORTING OF SPILL
Spill Detected By (Name and Phone #): ___________________________________________________________________________
Date: ___________________ Time: _______________ Area: ________________________________________________________
Spill Location Legal Description: LS ____ SC ____ TP ____ RG ____ W ____
Management Person Reported To: ______________________________________________________________________________
Date: ______________ Time: _______________
PIPELINE INFORMATION
From: ______________________________________________ To: __________________________________________________
Outside Diameter: ____________________________________ Wall Thickness: ________________________________________
M.O.P.: _____________________________________________ Material: _____________________________________________
Material Type: _______________________________________ Material Grade: ________________________________________
Line Installation Date: _________________________________ Number of Previous Leaks: _______________________________
Protection (e.g. Cathodic): _____________________________________________________________________________________
Type of Line: ___ Flowline ___ Transfer ___ Inj/Disp ___ Condensate ___ Pipeline ___ Fresh Water ___ Produced Water
EQUIPMENT FAILURE INFORMATION
___ Production Storage Tank ___ Pig Launcher/Receiver ___ Flow Line Break
___ Drilling/Servicing Storage Tank ___ Flange Gasket ___ Block Valve
___ Other (please specify): ______________________________________________________
Cause: ___ Corrosion ___ Mechanical Failure ___ Human Error ___ Vandalism ___ Test Failure
PRODUCT SPILLED/RECOVERED
___ Crude Oil Estimated Volume Spilled: ______________m3 Recovered: ______________m3
___ Salt Water Estimated Volume Spilled: ______________m3 Recovered: ______________m3
___ Chemical Estimated Volume Spilled: ______________m3 Recovered: ______________m3
___ Oil Effluent Estimated Volume Spilled: ______________m3 Recovered: ______________m3
___ Fresh Water Estimated Volume Spilled: ______________m3 Recovered: ______________m3
CONTAINMENT
___ Naturally ___ Booms ___ Dikes ___ No Containment ___ Other (Please Specify): __________________________________
AFFECTED LANDOWNERS/RESIDENTS
Name: __________________________________________ Date/Time: _____________________ Phone: _________________
Name: __________________________________________ Date/Time: _____________________ Phone: _________________
Name: __________________________________________ Date/Time: _____________________ Phone: _________________
Name: __________________________________________ Date/Time: _____________________ Phone: _________________
Name: __________________________________________ Date/Time: _____________________ Phone: _________________
SPILL REPORT Forms Pipeline Operations Manual
Forms Page - 24
PROVINCIAL OIL & GAS AUTHORITY REPORTED TO
AER Office Location: _________________________________________________ Date: __________________
Person Reported To: _________________________________________________
ECON Office Location: ________________________________________________ Date: __________________
Person Reported To: _________________________________________________
MIEDM Office Location: _______________________________________________ Date: __________________
Person Reported To: _________________________________________________
BCOGC Office Location: _______________________________________________ Date: __________________
Person Reported To: _________________________________________________
SPILL AREA SKETCH
Directions to spill site area: _____________________________________________________________________________________
____________________________________________________________________________________________________________
____________________________________________________________________________________________________________
____________________________________________________________________________________________________________
____________________________________________________________________________________________________________
Surface Feature Affected (choose up to 3): ___ Cultivated ___ Uncultivated ___ Bush ___ Surface Water ___ Groundwater ___ Access ___ Other ______________
Size of Area Affected (fill in one): _________________________ Square Meters ___________________________ Hectares
Total Area Affected: ____________________________________ % on lease ______________________________ % off lease
Soil Amendment: Type: ___________________________________________ Amount: ___________________
NORTH
SPILL REPORT Forms Pipeline Operations Manual
Forms Page - 25
Comments (include reason for failure):
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
REPAIRS AND RESTORATION
Oil & Gas Regulatory Authority Notified: ___ Yes ___ No Date: _________________ Time: ____________
Landowners/Residents Notified: ___ Yes ___ No Date: _________________ Time: ____________
Contaminated Material Disposed of: ___ Yes ___ No Date: _________________ Time: ____________
Environmental Consultant: _________________________________________
SITE DAMAGE SUMMARY
Damage incurred to environmentally sensitive areas such as lakes, streams, dugouts, etc. (include sketch and show details):
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
Describe other damages such as buildings, equipment, third party property, etc:
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
Describe any injury in connection with the event:
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
SPILL REPORT Forms Pipeline Operations Manual
Forms Page - 26
ACTION TAKEN
Remediation strategy and repair strategy. Include details on where material was taken (Facility Name, Landfill, etc.). Comment
regarding the action taken to repair damage (e.g. Dug up and repaired 2 metres of line then backfilled.)
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
___________________________________________________________________________________________________________
REMEDIAL WORK COMPLETION
Oil & Gas Regulatory Authority Office Notified: ___ Yes Date: ______________________
Landowner(s)/Resident(s) Notified: ___ Yes Date: ______________________
Sketch completed and attached to report: ___ Yes Date: ______________________
Cleanup Costs to Date: $ _________________. ____
Estimated Project Remediation Cost: $ _________________. ____
Report Prepared By: _______________________________________ Phone: ___________________ Date: ___________________
VALVE SUMMARY Forms Pipeline Operations Manual
Forms Page - 27
UPI LSD VALVE TYPE STATUS
VALVE SUMMARY Forms Pipeline Operations Manual
Forms Page - 28
UPI LSD VALVE TYPE STATUS
CROSSING SUMMARY Forms Pipeline Operations Manual
Forms Page - 29
UPI LSD CROSSING TYPE AGREEMENT REFERENCE
CROSSING SUMMARY Forms Pipeline Operations Manual
Forms Page - 30
UPI LSD CROSSING TYPE AGREEMENT REFERENCE
GROUND DISTURBANCE PERMIT / CHECKLIST
Forms Pipeline Operations Manual
Forms Page - 31
GROUND DISTURBANCE PERMIT / CHECKLIST
Forms Pipeline Operations Manual
Forms Page - 32
BACKFILL INSPECTION FORM
Forms Pipeline Operations Manual
Forms Page - 33
1. Indicate depth to existing line on above elevation. 2. Indicate depth to new line above or below existing line on above elevation. 3. Cathodic protection installed: Yes No
If yes, what type of protection? _____________________________________________________________________ 4. If pipe contacted, provide the following details:
Coating damage: Yangarra Other Coating repairs completed:_________________________________________________________________________ Pipe/cable damaged: Yangarra Other Regulatory Agency contacted? ______________________ Name: ________________________ Date: ____________
5. Wire color/Size existing line: _______________ / _______________ New line: _______________ / _______________ Owner of foreign or existing facility:
Size and condition of existing facility:
(New) oil, gas, water, etc.:
Contractor doing work:
Approval Print name:
Date completed: Yangarra Signature:
Print name:
Date completed: Foreign Signature:
Date: ________________________
Project: _________________________________________
Yangarra Line ID#: _________________________________
Size: __________________ (indicate unit of measurement)
Location:
LSD _____ Sec _____ Twp _____ Rge _____ W _____M
Other:
Type of New Facility Type of Crossing (check one) (check one) Pipeline Pipeline Road Road Railroad Railroad Watercourse Watercourse Data Cable Data Cable Other Other
BACKFILL INSPECTION FORM
Forms Pipeline Operations Manual
Forms Page - 34
THIRD PARTY PIPELINE INSPECTION REPORT
Forms Pipeline Operations Manual
Forms Page - 35
Pipeline System Description: ___________________________________________________________________ Pipeline Licence Number(s): ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ Date of Inspection: ___________________________________________________________________ Distance of Pipeline: ___________________________________________________________________ Method / Equipment Used: ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ Results / Observations: ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ Engineering Evaluation: ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________ ___________________________________________________________________
THIRD PARTY PIPELINE INSPECTION REPORT
Forms Pipeline Operations Manual
Forms Page - 36
RECOMMENDATIONS: IMPLEMENTATION PLAN:
REPAIR LOG
Forms Pipeline Operations Manual
Forms Page - 37
DATE/TIME ACTIONS RESULTS
REPAIR LOG
Forms Pipeline Operations Manual
Forms Page - 38
DATE/TIME ACTIONS RESULTS
PIPELINE CROSSING CHECKLIST Forms Pipeline Operations Manual
Forms Page - 39
Licence & Line#: ____________________ Date: ___________________________
By: ________________________________________________________________
Pipeline Owner: ______________________________________________________
Location: _________________________ Date: ___________________________ (Attach sketch if necessary)
Contractor: __________________________________________ Date: ___________________________
1. Is a copy of the Pipeline Crossing Agreement at the site? Yes No 2. Are construction drawings at the site? Yes No 3. Was 48 hours notice given to Yangarra? Yes No
If No, explain: _____________________________________________________________________
Date notice given: _____________________ Person notified: _________________________
4. Was the Yangarra pipeline hand exposed or hydro-vac for the 1 meter on either side of the crossing prior to machine excavation? Yes No
5. Was a Yangarra representative present during pipe exposure? Yes No
6. Yangarra pipeline located by (Name): ___________________________________________________
7. Foreign pipeline maintained at 30 cm below the Yangarra pipeline through right-of-way? Yes No Depth of separation (if other than 30 cm): Yes No 8. Backfill free of rocks, debris, etc.? Yes No 9. Backfill tamped properly? Yes No 10. Was the Yangarra pipeline and/or coating damaged? Yes No If Yes, were proper repairs completed? Yes No 11. If a cathodic test post was specified, was it installed? Yes No
Location: _________________________________________________________________________
12. Remarks: _________________________________________________________________________
Notes: Items 1,2,4,7,8, and 9 are MANDATORY
This certifies that this crossing was performed to Yangarra satisfaction.
Contractor: ____________________ _______________________ ____________________ (Signature) (Print) (Date)
Foreign
Pipe Owner: ____________________ _______________________ ____________________
(Signature) (Print) (Date)
Yangarra
Representative: ____________________ _______________________ ____________________
(Signature) (Print) (Date)
PIPELINE CROSSING CHECKLIST Forms Pipeline Operations Manual
Forms Page - 40
NEW WELL START UP FORM Forms Pipeline Operations Manual
Forms Page - 41
NEW WELL START UP FORM
SURFACE LOCATION_________________________ DATE______________________
DOWNHOLE LOCATION______________________
PIPELINE LICENCE/LINE #_____________________ MOP_______________________
VESSEL A#_________________________________ PSV SN#____________________
VESSEL MOP_______________________________ PSV SET PRESSURE___________
CALIBRATION DATE___________________
OVERPRESSURE DEVICE: YES / NO ESD SET PRESSURE___________
CALIBRATION DATE___________________ FUNCTION TESTED: YES / NO
ESD TAGGED PROPERLY: YES / NO
*****NOTE ***** PSV SET PRESSURE AND ESD SET PRESSURE CANNOT EXCEED THE MOP OF THE PIPELINE
COMMENTS:_______________________________________________________________________
__________________________________________________________________________________
__________________________________________________________________________________
__________________________________________________________________________________
PREFORMED BY:________________________________________________________(PRINT/SIGN)
NEW WELL START UP FORM Forms Pipeline Operations Manual
Forms Page - 42
ORGANIZATION
Pipeline Integrity, Operations, and Maintenance Organizational Structure
Role Responsibilities Assigned to Title
Pipeline Integrity and Operations Manual - Development and improvement
• Research and review government acts, regulations, directives as it applies to the manual. • Research and review industry standards and best practice.
DataSafe Recovery Services Account Manager
Pipeline Integrity and Operations Manual - Annual review (minimum)
• Continuous improvement to licensed materials to maintain compliance. • Verification of external contact information. • Update changes related to Client’s corporate information, personnel and contact numbers as provided by the Client. • Update changes related to field inventories, contractors/suppliers, safety equipment, and risk assessments as provided by the client.
DataSafe Recovery Services Account Manager
Pipeline Integrity and Operations Manual - Maps • Update changes related to field. DataSafe Recovery Services Account Manager
Integrity Management Program - Implementation of plans • Ensure company personnel have access to, and are implementing the Pipeline Integrity and Operations Manual.
Company Office Rep
VP Finance Trish Olynyk Senior Engineers Ryan MacKenzie Thomas Matthews
Daily operations and general maintenance of pipelines • It is the responsibility of company field personnel to ensure that pipelines are operated, and maintained to meet requirements of provincial legislation, industry standards and codes of practice.
Company Field Personnel Field Superintendent Collin Doneff
Role Responsibilities Assigned to Title
Integrity Management Program - Risk assessment and control planning
• Includes the steps of risk analysis (hazard identification, frequency analysis, consequence analysis, risk estimation) and risk evaluation (risk significance and options). • Risk assessment is applicable to the decision-making process in the design, construction, operation, inspection, monitoring, testing, maintenance, repair, modification, rehabilitation, and abandonment of pipelines. • The Pipeline Assessment process must be performed at least annually on every pipeline segment. When risks are identified more frequent assessment is required and the schedule must be documented.
Company Field Personnel Company Office Personnel
Field Superintendent Collin Doneff Senior Engineer Ryan MacKenzie
Integrity Management Program - Integrity performance indicators • Plan and develop method of monitoring to identify anticipated and actual changes that could affect the integrity of the pipeline system.
Company Field Personnel Company Office Personnel
Field Superintendent Collin Doneff Senior Engineer Ryan MacKenzie
Chemical inhibitor program for pipelines (if applicable) • Determine the chemical inhibitor programs required to ensure the integrity and extend the life expectancy of the pipeline.
Company Field Personnel Field Superintendent Collin Doneff
Cathodic maintenance of pipelines (if applicable)
• Will apply cathodic protection systems to all metal pipelines, metal underground piping and any other metal appurtenances in direct contact with the surrounding soils. • Ensuring the design, operation, inspection and maintenance of cathodic protection are handled appropriately.
Company Field Personnel Field Superintendent Collin Doneff
Role Responsibilities Assigned to Title
Integrity Management Program - Inspections, testing, patrols, and monitoring
• Implement and document the methods and procedures used to conduct inspections, testing, patrols, and monitoring. Consideration shall be given to:(a) cathodic protection systems;(b) corrosion monitoring systems and devices;(c) leak detection methods and devices;(d) shutdown devices and systems;(e) pressure-control, pressure-limiting, and pressure-relieving systems;(f) size, location and operational position of pipeline system valves;(g) pipeline system patrolling; and(h) inspection of exposed piping for corrosion and other types of imperfections
Company Field Personnel Company Office Personnel
Field Superintendent Collin Doneff Senior Engineer Ryan MacKenzie
Integrity Management Program - Evaluation of inspection, testing, patrol, and monitoring results
• Assess inspection, testing, patrol, and monitoring results. • When inspection, testing, patrol, and monitoring results indicate the presence of conditions or imperfections that might lead to failure or damage incidents with significant consequences, operating companies shall perform an engineering assessment.
Company Field Personnel Company Office Personnel
Field Superintendent Collin Doneff Senior Engineer Ryan MacKenzie
Pipeline / Facility Engineer
• An important component of integrity management is that appropriate personnel are contacted and involved prior to undertaking new construction or when change is made to the operating condition of a pipeline. The first step to new construction and significant changes is usually an Engineering Assessment. Engineering Assessments are an integral component of the change management process. • An engineering assessment may also be required as the result of pipeline inspection and monitoring results.
Company Office Personnel Senior Engineers Ryan MacKenzie Thomas Matthews
Repair work for pipelines
• Maintenance and Repair activities will require involvement of production and operations and staff and management. In many cases contracted services personnel and engineers will also be needed.
Company Field Personnel Field Superintendent Collin Doneff
Role Responsibilities Assigned to Title
Land department • Determine land owner contacts if need be during the course of maintenance and repair, or any other applicable activities.
Company Office Personnel Surface Land Administrator Kelsey Lewis
Integrity Management Program - Audits, reviews, and evaluations
• Reviewing completed integrity activities in order to: (a) verify that the relevant methods and procedures for such activities were properly performed; (b) verify that changes in planned activities were reviewed and approved; (c) determine whether the intended objectives were achieved; (d) identify incomplete work and unresolved issues; (e) develop recommendations and plans for future work; and (f) verify that the relevant records were created or revised.
Company Office Personnel Senior Engineer Ryan MacKenzie
Integrity Management Program - Records management
• Manage the responsibilities and procedures for the creation, updating, retention, and deletion of records. • Develop methods of storage and retrieval of records related to a particular pipeline location or segment. • Track evidence of past activities, events, changes, analyses, and decisions. • Create an index describing the types, forms, and locations of records.
Company Office Personnel
Surface Land Administrator Kelsey Lewis Senior Engineer Ryan MacKenzie
VALVES AND CROSSINGS
EMERGENCY RESPONSE
EMERGENCY RESPONSE
General Information Pipeline Operations Manual
General Information Page - 1
EMERGENCY RESPONSE
General
The company’s Emergency Response Plan (ERP) must be invoked when an emergency occurs. The ERP
provides detailed response actions, notification procedures, reporting requirements and reference
information to appropriately respond to the incident.
Several forms in this document are from the Emergency Response Plan manual. They have been identified
in red bold italics in the Table of Contents of the forms section. Use of these forms must coincide with
reference to the ERP to ensure appropriate notification and reporting.
This document contains a copy of the Emergency Contact List created for the ERP. It is included to ensure
that initial immediate contact can be made with appropriate head office and field personnel. The ERP must
be invoked to ensure that subsequent activities are coordinated effectively.
You are the On-Scene Commander until the Incident Commander chooses an alternate.
Contact Information - Company Contacts FERRIER
Corporate Office Responsible for Field Operations
YANGARRA RESOURCES LTD.
Head OfficeOffice:
(403) 262-9558Phone Number:
(403) 262-8281Fax Number:
(403) 262-955824 hr Emergency Phone:
Site Office for Field Operations
YANGARRA RESOURCES LTD.
(403) 845-6877Phone Number:
Fax Number:
(403) 580-763824 hr Emergency Phone:
Incident/Corporate Commander
Seq Other Ph TypeTitle Office Phone Home Phone Cell Phone Other PhoneName
1 President (403) 262-9558 (403) 697-4911 (403) 803-5161Jim Evaskevich
2 VP Operations (403) 262-9558 (403) 771-2474Lorne Simpson
Operations Section Chief
Seq Other Ph TypeTitle Office Phone Home Phone Cell Phone Other PhoneName
1 Field Superintendent (403) 580-7638Collin Doneff
2 Production Foreman (403) 895-3797Mitch Hetu
3 Operator (403) 844-3316Brad Dukart
4 Operator (403) 826-8340Ryan Fancie
5 Operator (403) 844-7042Jeff Gramlich
6 Operator (403) 844-0464Mike Rainer
7 Operator (403) 895-7113Logan Lawton
8 Operator (403) 845-9753Brady Poulsen
9 Operator (403) 895-8489Myles McGinnis
10 Fluid Manager (403) 895-2501Chris Carlson
11 Crew Supervisor (403) 845-8968Billy Normile
Media Relations
Seq Other Ph TypeTitle Office Phone Home Phone Cell Phone Other PhoneName
President (403) 262-9558 (403) 697-4911 (403) 803-5161Jim Evaskevich
1530, 715 - 5th Avenue S.W.
Calgary, AB
T2P 2X6
Office Address:
Ferrier Field OfficeOffice:
Rocky Mountain House, AB
Office Address:
Monday, June 15, 2020
YANGARRA RESOURCES LTD. Page 1 of 2
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Monday, June 15, 2020
YANGARRA RESOURCES LTD. Page 2 of 2
FERRIERContact Information - Emergency Contacts
Local Authorities Contact Information
CountyCLEARWATER
Christine Heggart
(DEM)
Cell
Manager On-call Cell
Name Business
Phone
Area Authority: þ911 Avail
(403) 845-4444Area Office Phone: (403) 845-7330Area Office Fax:
24 hour Number (403) 844-8500
(403) 845-4444 (403) 844-8500
(403) 844-8500
Area Office Alternate Phone:
Area Emergency Liaison Officers:
Alternate
Phone
Alternate Contact:
CountyMOUNTAIN VIEW
Ryan Morrison Cell
Kevin Heppler Cell
Name Business
Phone
Area Authority: þ911 Avail
(403) 335-3311Area Office Phone: (403) 335-9207Area Office Fax:
(403) 335-3311
(403) 335-3311
(403) 586-0040
(403) 994-0834
Area Office Alternate Phone:
Area Emergency Liaison Officers:
Alternate
Phone
Alternate Contact:
CountyPONOKA
Dennis Jones (DEM &
Regional Fire Chief)
Cell
Charlie Cutforth (Deputy
DEM)
Cell
Name Business
Phone
Area Authority: þ911 Avail
(403) 783-3333Area Office Phone: Area Office Fax:
(403) 783-3333
(403) 783-3333
(403) 913-5105
(403) 783-0995
Area Office Alternate Phone:
Area Emergency Liaison Officers:
Alternate
Phone
Alternate Contact:
Nearest Municipalities with Services
ROCKY MOUNTAIN HOUSE
ROCKY MOUNTAIN HOUSE
ROCKY MOUNTAIN HOUSE
ROCKY MOUNTAIN HOUSE
ROCKY MOUNTAIN HOUSE
Emergency Tel Dispatch Location
(403) 845-2866Office Phone:
(403) 845-3230Fax:
- 911 -Fire
- 911 -Ambulance
(403) 845-2881
(403) 845-3347Hospital
(403) 347-3373
(403) 845-2882Police
(780) 786-2223
Admin Tel
(403) 845-3347
First contact to emergency services will be to call 911. The nearest Urban
Centre with all emergency services is Rocky Mountain House.
Primary Emergency Services
Responding Centre:
Monday, June 15, 2020
YANGARRA RESOURCES LTD. Page 1 of 2
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Monday, June 15, 2020
YANGARRA RESOURCES LTD. Page 2 of 2
Company Type of Service City Phone
FERRIERSupport Services
Trojan Safety Services Air Monitoring Sylvan Lake (403) 309-3025
Summit Safety Air Monitoring and H2S Safety Drayton Valley (780) 542-9191
Nelson Bros Oilfield Services
(1997) Ltd
Water Hauling Drayton Valley (780) 542-5777
Wrangler Rentals Water Trucks Leduc (780) 980-1331
Hellfire Suppression Services Well Control Rocky Mountain House (403) 846-4499
YANGARRA RESOURCES LTD. Page 1 of 2
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YANGARRA RESOURCES LTD. Page 2 of 2
PIPELINE ASSESSMENT
Oil Gas Water
3 90 0
3 10 0
0 1 0
1 47 0
155
Oil Gas Water
146 6 1
4 3 0
7 0 0
3 0 0
170
71
1
36
119
0
66
2020
2020
Operator: Brad Dukart (403) 844-3316
Field: Willesden GreenOperator:
Head Office: Colin Doneff (403) 580-7638
Account Manager:
District Manager: Trent Elgert (780) 312-4896
Prepared by: Wally Hartung (780) 352-2436
within LSD area: 042-07W5Main Facility: 02-04-042-07W5
# of wells found:
Pipelines
# of lines Operational:
# of lines disc.:
# of lines abandoned:
# of planned lines:
# of lines found:
Wells
# of operating wells:
# of susp. wells:
# of shut in wells:
# of abandoned wells:
Supplied gas analysis were performed on:
Water analysis was performed on:
This document contains CONFIDENTIAL information of Contact Chemicals and is revealed for limited purposes only. It may not be reproduced, used or disclosed to persons not having a need to know consistent with the purpose of the document without the written consent of
Contact Chemicals. Contact Chemicals disclaims all warranties or representations express or implied, including any implied warranties of merchantability or fitness for particular purpose or the accuracy, correctness or completeness of such information herein or that reliance on
such information will accomplish any particular result. All such information is furnished “as is” and by using such information the user is assuming all liabilities for the use or reliance on such information.
This assessment is based on information given by the client and ABADATA 2.0 . Contact Chemicals takes no responsibility on the accuracy of the data. The assessment of the above stated field's assets are based on internal, proprietary risk factors, it should NOT be used as a
replacement for engineering assessments, a client's PIMP and/or KPI.
CONTACT CHEMICALS SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES OR LOSSES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO NEGLIGENCE.
# of Batteries found:
# of satellites found:
lines with low risk:
lines with medium risk:
lines with high risk:
lines requiring treatment:
General comments and concerns: The Willesden Green field has a medium potential corrosion risk divided into 36 low and 119 medium risk line segments. 75 line segments are recommended to be treated due to various risks, such as environmental and/or operating factors.No lines were identified as deadlegs.The gas and water analysis showed that this field's production has low corrosivity however, due to the high production and velocities corrosion may yet still occurr. In addition to the low corrosivity of the gas and fluids, most of this field's steel linesare being pigged monthly.
This field is currently monitored via 4 corrosion coupon located at the inlets of the main facilities: 02-04, 16-02 and 06-02
02-04
AER
License
from
location
to
location
Physical
Risk
Operational
Risk
Chemical
Risk
Theoratical
Corr. Rate
(mpy)
Overall
Risk
Treat
Pipe(yes/no)
Treatment
ReconciliationComments
19415 - 2 8-23-40-6W5 B 6-19-40-5W5 PL 2.5 1.6 2.3 4.82 2.1 no review risks annually
42289 - 7 2-4-42-7W5 CS 10-33-41-7W5 PL 2.6 1.9 2.3 10.03 2.2 no review risks annually sales gas from 02-04
42289 - 8 10-4-42-7W5 BE 11-4-42-7W5 BE 2.3 1.7 1.7 10.03 1.9 no review risks annually
42289 - 10 5-11-42-7W5 WE 4-10-42-7W5 PL 2.6 1.9 2.3 no fluid 2.3 no review risks annually
43702 - 2 11-4-42-7W5 WE 2-4-42-7W5 CS 2.5 1.9 2.3 no fluid 2.2 no Line is not operated
43702 - 3 6-3-42-7W5 WE 2-4-42-7W5 CS 2.6 1.9 2.3 no fluid 2.3 no Environmental risk
43702 - 4 12-29-41-7W5 WE 7-29-41-7W5 PL 2.6 1.7 2.4 Deadleg 2.2 yes Environmental risk
43702 - 8 1-33-41-7W5 WE 10-33-41-7W5 PL 2.6 2.4 2.3 14.67 2.4 no review risks annually
44436 - 1 14-22-41-7W5 BE 11-21-41-7W5 BE 2.2 1.7 1.7 no fluid 1.9 no review risks annually
46735 - 1 13-17-41-7W5 BE 8-19-41-7W5 BE 2.3 1.7 1.7 no fluid 1.9 no review risks annually
47376 - 3 4-4-40-8W5 PL 11-33-39-8W5 PL 2.1 1.8 2.0 8.23 2.0 no review risks annually
47376 - 4 4-33-39-8W5 PL 11-33-39-8W5 PL 2.0 1.4 2.0 14.67 1.8 no Environmental risk
48014 - 1 16-25-39-7W5 BE 13-30-39-6W5 BE 2.3 1.7 1.7 14.67 1.9 no review risks annually
48160 - 1 13-20-41-7W5 WE 15-20-41-7W5 PL 2.6 1.8 2.3 14.67 2.2 no Environmental risk
48695 - 1 13-19-40-6W5 BE 2-30-40-6W5 BE 2.3 1.7 1.7 Deadleg 1.9 no Environmental risk
53228 - 1 13-31-37-7W5 BE 12-31-37-7W5 BE 2.2 1.7 1.7 no fluid 1.9 no Line is not operated
53316 - 1 4-28-41-7W5 WE 4-28-41-7W5 PL 2.4 1.8 2.3 no fluid 2.1 yes Line is not operated
53368 - 1 2-29-41-7W5 WE 2-29-41-7W5 PL 2.5 1.9 2.3 14.67 2.2 no review risks annually
53453 - 2 12-16-41-7W5 WE 13-16-41-7W5 PL 2.4 1.8 2.3 no fluid 2.1 yes Multiple risks
53932 - 1 1-35-37-8W5 WE 3-34-37-8W5 PL 2.5 1.6 2.3 no fluid 2.1 no review risks annually sales gas from 16-02
55029 - 2 16-2-38-8W5 B 16-35-37-8W5 PL 2.5 1.8 2.3 10.03 1.6 no Not a bare steel pipeline proximity to Cow Lake; sales gas from 16-02
55029 - 3 15-35-37-8W5 WE 16-35-37-8W5 PL 2.3 2.3 2.3 no fluid 1.7 yes Not a bare steel pipeline
55029 - 4 2-2-38-8W5 WE 15-35-37-8W5 PL 1.9 1.8 2.3 no fluid 2.0 no Line is not operated
55030 - 1 3-34-37-8W5 PL 1-33-37-8W5 PL 2.4 1.9 2.3 14.67 2.2 no review risks annually sales gas from 16-02
55063 - 1 16-35-37-8W5 PL 1-35-37-8W5 PL 2.5 1.9 2.3 no fluid 2.2 no Line is not operated sales gas from 16-02
55063 - 2 1-35-37-8W5 PL 16-35-37-8W5 PL 2.5 1.9 2.3 9.20 2.2 no Environmental risk
55652 - 1 1-15-41-6W5 BE 3-15-41-6W5 BE 2.2 1.6 1.7 9.20 1.8 no review risks annually
55895 - 1 4-7-39-5W5 WE 13-6-39-5W5 PL 2.3 1.7 2.3 no fluid 2.1 yes Identified parameter risk
56048 - 1 16-8-39-5W5 WE 7-8-39-5W5 PL 2.3 1.7 2.3 no fluid 2.1 yes Line is not operated
56068 - 1 4-2-38-8W5 WE 16-35-37-8W5 PL 2.4 1.8 2.3 14.67 2.1 no review risks annually
56261 - 1 3-28-41-7W5 WE 4-28-41-7W5 PL 2.3 1.8 2.3 no fluid 2.1 yes Multiple risks
56302 - 1 11-11-39-5W5 WE 12-11-39-5W5 PL 1.9 1.7 2.3 14.67 1.9 no review risks annually
57466 - 1 10-35-41-8W5 WE 10-2-42-8W5 PL 2.0 1.7 2.3 14.67 2.0 no review risks annually
57873 - 1 2-31-41-7W5 WE 8-32-41-7W5 PL 2.7 1.8 2.3 14.67 2.2 no review risks annually
57873 - 2 4-10-42-7W5 WE 6-3-42-7W5 PL 2.6 1.9 2.3 no fluid 2.2 no review risks annually
58418 - 1 8-16-41-6W5 BE 15-9-41-6W5 BE 1.7 1.7 2.3 no fluid 1.9 no review risks annually
58419 - 1 6-18-41-5W5 WE 14-18-41-5W5 PL 2.1 1.8 2.3 14.67 2.0 no review risks annually
58419 - 2 14-18-41-5W5 WE 2-19-41-5W5 PL 2.0 1.8 1.7 no fluid 1.9 no Environmental risk treated via injection at 14-18
58739 - 1 1-2-40-9W5 BE 13-2-40-9W5 BE 1.8 1.7 2.3 14.67 1.9 no review risks annually
58743 - 1 3-21-41-7W5 WE 13-16-41-7W5 B 2.1 2.3 2.3 14.67 2.2 no review risks annually
58932 - 1 8-10-40-8W5 WE 1-15-40-8W5 PL 2.1 1.9 1.7 14.67 1.9 no review risks annually
59026 - 1 13-13-40-6W5 WE 8-23-40-6W5 PL 1.9 1.6 2.3 14.67 1.9 no review risks annually
59260 - 1 6-2-40-9W5 BE 1-2-40-9W5 BE 1.7 1.7 2.3 14.67 1.3 no Not a bare steel pipeline
59263 - 1 7-26-37-8W5 WE 15-26-37-8W5 PL 1.9 1.8 2.3 no fluid 2.0 no review risks annually
59530 - 1 14-8-41-6W5 WE 15-8-41-6W5 PL 1.8 1.7 1.7 14.67 1.7 no review risks annually
59541 - 1 14-7-38-6W5 WE 3-18-38-6W5 PL 1.7 1.8 2.3 no fluid 1.9 no review risks annually
59552 - 1 4-4-40-8W5 WE 4-4-40-8W5 PL 1.9 2.2 2.0 14.67 2.0 no review risks annually lines has been discontinued
59556 - 1 15-36-39-6W5 WE 10-36-39-6W5 PL 2.0 1.9 2.3 no fluid 2.0 no review risks annually
59787 - 1 3-2-42-8W5 WE 6-2-42-8W5 PL 1.5 1.7 2.3 14.67 1.8 no Environmental risk
59806 - 1 8-34-37-8W5 WE 2-35-37-8W5 PL 1.9 1.9 2.3 no fluid 2.0 no Line is not operated
59892 - 1 10-30-39-8W5 WE 1-36-39-9W5 PL 2.0 1.8 2.0 9.34 2.0 no review risks annually
59918 - 1 14-33-39-8W5 WE 14-33-39-8W5 PL 2.1 1.8 2.0 9.34 2.0 no review risks annually
59924 - 1 12-28-37-8W5 WE 1-34-37-8W5 PL 2.1 1.7 2.3 14.67 2.0 no review risks annually
59941 - 1 1-19-42-7W5 WE 14-17-42-7W5 PL 1.9 2.1 2.3 14.67 2.1 no review risks annually
59943 - 1 11-5-40-8W5 PL 4-4-40-8W5 PL 2.0 1.7 2.0 9.34 1.9 no review risks annually
59943 - 2 4-4-40-8W5 PL 4-4-40-8W5 PL 2.0 1.7 2.0 14.67 1.9 no review risks annually
59959 - 2 15-7-41-6W5 WE 15-7-41-6W5 PL 2.0 2.1 2.3 9.32 1.5 no Not a bare steel pipeline
59959 - 4 15-8-41-6W5 PL 2-17-41-6W5 PL 1.9 1.7 2.3 14.67 2.0 no review risks annually
59959 - 5 2-15-41-6W5 WE 11-15-41-6W5 PL 2.0 1.7 2.3 no fluid 2.0 no review risks annually
59971 - 1 1-36-39-9W5 WE 3-36-39-9W5 PL 1.9 1.7 2.0 14.67 1.9 no review risks annually
59986 - 2 5-23-38-7W5 BE 3-23-38-7W5 BE 2.1 1.7 2.3 14.67 2.0 no review risks annually
59986 - 10 13-10-38-7W5 BE 15-9-38-7W5 BE 2.1 1.7 1.7 no fluid 1.8 no review risks annually
59986 - 11 5-10-38-7W5 WE 6-10-38-7W5 PL 2.2 1.7 2.3 9.32 2.1 no review risks annually
60003 - 1 14-5-40-8W5 WE 11-5-40-8W5 PL 2.0 1.7 1.7 9.32 1.8 no review risks annually
60006 - 1 6-2-40-9W5 B 3-2-40-9W5 PL 2.1 1.8 2.0 9.32 2.0 no Environmental risk sales gas from 06-02
60041 - 1 3-3-39-5W5 WE 8-4-39-5W5 PL 1.9 1.6 2.3 9.32 1.9 no review risks annually
60151 - 1 10-28-39-8W5 WE 4-33-39-8W5 PL 2.0 1.4 2.0 9.32 1.8 no review risks annually
60151 - 2 10-28-39-8W5 WE 4-33-39-8W5 PL 2.0 1.4 2.0 no fluid 1.2 no Line is not operated
60221 - 1 1-26-41-7W5 WE 8-27-41-7W5 PL 2.1 1.4 2.3 14.67 1.3 no Not a bare steel pipeline
60221 - 2 7-27-41-7W5 PL 3-27-41-7W5 PL 1.6 1.4 2.3 1.2 no Not a bare steel pipeline
60221 - 3 8-27-41-7W5 PL 7-27-41-7W5 PL 1.6 1.4 2.3 14.67 1.8 no review risks annually
60222 - 2 2-19-41-5W5 PL 11-19-41-5W5 PL 2.1 1.7 2.3 14.67 2.0 no Environmental risk
60222 - 3 15-31-41-5W5 WE 11-19-41-5W5 PL 2.2 1.8 2.3 14.67 2.1 no review risks annually
60222 - 4 11-31-41-5W5 WE 15-31-41-5W5 PL 2.0 1.3 2.3 no fluid 1.2 no Line is not operated
60311 - 1 7-30-37-7W5 PL 6-25-37-8W5 PL 2.1 2.0 2.3 14.67 1.5 no Not a bare steel pipeline
60311 - 2 16-8-37-7W5 WE 10-18-37-7W5 PL 2.2 1.4 2.3 1.3 no Not a bare steel pipeline
60311 - 3 14-6-37-7W5 WE 10-18-37-7W5 PL 2.0 2.0 2.3 4.82 1.5 no Not a bare steel pipeline
60520 - 1 9-31-37-7W5 PL 16-35-37-8W5 PL 2.6 1.7 2.3 14.67 2.2 no review risks annually treated via injection at 03-23
60544 - 1 7-26-37-8W5 WE 15-26-37-8W5 PL 2.0 2.0 2.3 no fluid 2.1 no review risks annually
57718 - 1 1-29-43-9W5 WE 4-32-43-9W5 PL 1.8 1.8 2.3 no fluid 1.4 yes Line is not operated
57718 - 2 13-29-43-9W5 WE 13-29-43-9W5 PL 1.8 1.8 2.3 14.67 1.3 no Not a bare steel pipeline
59996 - 1 1-29-43-9W5 WE 6-21-43-9W5 B 1.5 1.7 2.3 1.2 no Not a bare steel pipeline
45437 - 1 7-14-43-3W5 BE 6-23-43-3W5 BE 1.8 1.7 2.3 14.67 1.3 no Not a bare steel pipeline
53737 - 1 2-14-43-3W5 BE 7-14-43-3W5 BE 1.7 1.7 2.3 Deadleg 1.3 no Not a bare steel pipeline
58048 - 1 2-14-43-3W5 WE 10-11-43-3W5 PL 1.5 1.8 2.3 14.67 1.3 no Not a bare steel pipeline
60062 - 4 12-20-37-7W5 B 16-19-37-7W5 PL 1.8 2.1 2.3 10.03 2.1 no review risks annually
60062 - 5 16-19-37-7W5 PL 6-30-37-7W5 PL 1.9 2.1 2.3 9.32 1.5 no Not a bare steel pipeline
60311 - 4 6-30-37-7W5 PL 6-30-37-7W5 PL 2.1 2.1 2.3 14.67 1.6 no Not a bare steel pipeline
31390 - 2 11-33-39-8W5 PL 9-36-39-9W5 PL 2.8 1.9 2.0 14.67 2.2 yes main gathering line treated via injection at 04-04
31390 - 3 3-36-39-9W5 PL 9-36-39-9W5 PL 2.7 1.8 2.0 10.03 1.6 yes Not a bare steel pipeline proximity to North Sakatchewan River
42289 - 9 2-15-42-7W5 WE 4-10-42-7W5 PL 2.6 1.9 2.3 10.03 2.2 yes Multiple risks
43702 - 1 11-21-41-7W5 WE 7-29-41-7W5 PL 2.6 1.9 1.8 10.03 1.5 yes main gathering line treated via injection at 11-15 & 16-25
43702 - 5 7-29-41-7W5 PL 12-33-41-7W5 PL 2.7 1.9 1.9 14.67 1.5 yes Not a bare steel pipeline treated via injection at 11-15 & 16-25; Big Beaver Crossing
43702 - 6 12-33-41-7W5 PL 2-4-42-7W5 CS 2.6 1.9 1.8 9.34 1.5 yes main gathering line treated via injection at 11-15 & 16-25
43702 - 7 8-19-41-7W5 WE 7-29-41-7W5 PL 2.7 1.8 2.3 10.03 1.7 yes Not a bare steel pipeline proximity to North Saskatewan River
46735 - 2 5-20-41-7W5 WE 8-19-41-7W5 PL 2.4 1.8 2.3 10.03 1.6 yes Not a bare steel pipeline proximity to North Saskatewan River
47376 - 1 4-4-40-8W5 WE 11-33-39-8W5 PL 2.6 1.8 2.0 14.67 2.2 no main gathering line treated via injection at 04-04 (inj based on surface)
47376 - 2 4-33-39-8W5 WE 11-33-39-8W5 PL 2.5 1.9 2.0 14.67 1.5 no Not a bare steel pipeline
52347 - 1 8-3-41-7W5 WE 11-21-41-7W5 PL 2.7 2.1 2.4 14.67 2.4 yes Identified parameter risk partially treated via injection at 11-15 & 16-25 (1km will be batched)
52347 - 2 13-35-40-7W5 WE 8-3-41-7W5 PL 2.5 2.0 2.4 14.67 1.7 yes part of pig run batch volume includes appr. 1km of the 52347-1 segment
52744 - 2 5-31-37-7W5 WE 12-31-37-7W5 PL 2.4 1.9 2.3 14.67 1.6 no part of pig run Combined with 60520-2
53385 - 1 8-30-41-7W5 WE 12-29-41-7W5 PL 2.5 1.8 2.3 14.67 2.2 yes Multiple risks proximity to North Saskatewan River
53453 - 1 13-16-41-7W5 WE 4-28-41-7W5 PL 2.5 1.8 2.3 14.67 2.2 yes Environmental risk proximity to Little Beaver Creek
53453 - 3 15-20-41-7W5 WE 15-20-41-7W5 PL 2.4 1.9 2.3 10.03 2.2 no part of pig run
54016 - 1 3-11-38-8W5 WE 3-11-38-8W5 PL 2.4 1.8 2.3 10.03 1.6 yes Not a bare steel pipeline proximity to Cow Lake; combined with 54970
54571 - 1 1-9-41-7W5 WE 16-9-41-7W5 PL 2.5 1.8 1.7 10.03 2.0 yes Identified parameter risk
54970 - 1 3-11-38-8W5 PL 16-2-38-8W5 B 2.5 1.8 2.3 14.67 2.2 yes Multiple risks proximity to Cow Lake; combined with 54016
55029 - 1 16-35-37-8W5 PL 16-2-38-8W5 B 2.5 1.8 1.8 no fluid 2.1 yes Line is not operated proximity to Cow Lake
55033 - 1 15-26-37-8W5 WE 1-35-37-8W5 PL 2.3 2.4 2.3 14.67 2.3 yes main gathering line
55270 - 1 4-12-41-7W5 WE 1-11-41-7W5 PL 2.3 1.9 2.3 2.1 yes main gathering line
55273 - 1 1-11-41-7W5 WE 1-10-41-7W5 PL 2.4 1.8 2.3 14.67 2.1 yes Multiple risks
56545 - 1 13-31-41-7W5 WE 2-31-41-7W5 PL 2.5 1.8 2.3 9.34 2.2 yes Multiple risks proximity to Big Beaver Creek
57486 - 1 13-11-41-7W5 WE 8-10-41-7W5 PL 2.0 1.8 2.3 9.34 2.0 yes part of pig run
57591 - 1 1-35-37-8W5 WE 1-35-37-8W5 PL 2.3 2.1 2.3 14.67 1.6 no part of pig run
57601 - 1 2-35-37-8W5 WE 1-35-37-8W5 PL 2.3 1.9 2.3 no fluid 2.1 yes combines prod. from multple wells
58050 - 1 4-14-42-8W5 WE 10-15-42-8W5 S 2.5 1.8 2.3 9.34 2.2 yes Identified parameter risk Proximity to North Saskatchewan River; Combined with 58050-2,3,4,5
58050 - 2 10-2-42-8W5 WE 14-2-42-8W5 PL 2.2 1.8 2.3 1.5 yes Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-1,3,4,5
58050 - 3 14-2-42-8W5 PL 14-2-42-8W5 PL 2.2 1.8 2.3 no fluid 1.5 yes Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-2,1,4,5
58050 - 4 14-2-42-8W5 PL 4-11-42-8W5 PL 2.2 1.8 2.3 10.03 2.1 yes Identified parameter risk Proximity to North Saskatchewan River; Combined with 58050-2,3,1,5
58050 - 5 4-11-42-8W5 PL 4-14-42-8W5 PL 2.5 1.8 2.3 9.34 1.6 yes Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-2,3,4,1
58515 - 1 16-25-39-7W5 WE 6-12-40-7W5 PL 2.5 1.8 2.3 10.03 2.2 yes Multiple risks combined with 58515-2,3; treated via injection at 16-25
58515 - 2 14-13-40-7W5 PL 4-12-41-7W5 PL 2.6 1.8 2.3 14.67 2.2 yes Environmental risk combined with 58515-1,3; treated via injection at 16-25
58515 - 3 11-12-40-7W5 PL 14-13-40-7W5 PL 2.3 1.8 2.3 no fluid 1.5 yes Not a bare steel pipeline combined with 58515-2,1; treated via injection at 16-25
59079 - 1 6-25-37-8W5 PL 7-26-37-8W5 PL 2.4 2.1 2.3 no fluid 1.6 yes part of pig run
59259 - 1 15-31-41-5W5 WE 16-31-41-5W5 PL 2.2 2.1 2.3 no fluid 1.6 yes deadleg? confirm operating status
59587 - 1 4-1-40-9W5 WE 1-2-40-9W5 PL 2.4 1.9 2.0 no fluid 1.5 yes main gathering line treated via injection at 04-04
59891 - 1 4-12-41-7W5 WE 1-10-41-7W5 PL 2.3 1.9 2.3 no fluid 1.5 yes main gathering line treated via injection at 11-15 & 16-25
59916 - 1 14-6-40-8W5 PL 9-2-40-9W5 PL 2.4 1.7 2.0 14.67 2.1 yes main gathering line Combined with 59970 & 60045
59959 - 1 14-7-41-6W5 PL 4-12-41-7W5 PL 2.4 1.8 2.3 14.67 1.5 yes main gathering line treated via injection at 11-15
59959 - 3 1-17-41-6W5 PL 15-7-41-6W5 PL 2.4 1.8 2.3 14.67 1.6 yes main gathering line treated via injection at 11-15
59959 - 6 11-15-41-6W5 WE 8-16-41-6W5 PL 2.4 1.8 2.3 no fluid 1.5 yes main gathering line treated via injection at 11-15
59959 - 7 8-16-41-6W5 WE 4-16-41-6W5 PL 2.4 1.8 2.3 14.67 1.5 yes Not a bare steel pipeline treated via injection at 11-15
59970 - 1 11-6-40-8W5 WE 14-6-40-8W5 PL 2.2 1.7 2.0 no fluid 1.4 yes main gathering line Combined with 59916 & 60045
59976 - 1 1-2-40-9W5 WE 6-2-40-9W5 B 2.2 1.8 2.0 14.67 1.4 yes main gathering line treated via injection at 04-04
59986 - 1 3-23-38-7W5 WE 12-14-38-7W5 PL 2.5 1.8 2.3 14.67 2.2 yes main gathering line proximity to Clearwater Creek; treated via injection at 03-23
59986 - 3 12-14-38-7W5 PL 13-10-38-7W5 PL 2.4 1.8 2.3 no fluid 2.2 yes Multiple risks crosses Clearwater Creek; treated via injection at 03-23
59986 - 4 9-15-38-7W5 B 12-14-38-7W5 PL 2.4 1.8 1.7 14.67 2.0 no main gathering line proximity to Clearwater Creek; treated via injection at 03-23
59986 - 5 12-14-38-7W5 PL 9-15-38-7W5 B 2.4 1.8 2.3 14.67 2.1 yes main gathering line proximity to Clearwater Creek; treated via injection at 03-23
59986 - 7 1-9-38-7W5 WE 5-10-38-7W5 PL 2.3 1.7 2.3 14.67 2.1 yes main gathering line treated via injection at 03-23
59986 - 8 5-3-38-7W5 WE 4-10-38-7W5 PL 2.3 1.7 2.3 14.67 1.5 yes part of pig run
59986 - 9 13-10-38-7W5 PL 5-10-38-7W5 PL 1.9 1.7 2.3 14.67 2.0 yes Identified parameter risk treated via injection at 03-23
60020 - 1 9-36-39-9W5 PL 4-1-40-9W5 PL 2.4 1.8 2.0 14.67 2.1 yes main gathering line treated via injection at 04-04
60045 - 1 9-2-40-9W5 PL 8-2-40-9W5 PL 2.3 1.7 2.0 14.67 1.4 yes main gathering line Combined with 59916 & 59970
60062 - 1 7-18-37-7W5 PL 7-30-37-7W5 PL 2.8 2.0 2.3 no fluid 2.4 yes Line is not operated crosses Prairie Creek
60222 - 1 11-19-41-5W5 PL 15-15-41-6W5 PL 2.5 1.8 2.3 no fluid 2.2 yes main gathering line
60520 - 2 12-31-37-7W5 PL 12-31-37-7W5 PL 2.2 1.4 2.3 no fluid 2.0 yes main gathering line combined with 52744-2
60520 - 3 14-32-37-7W5 PL 9-31-37-7W5 PL 2.4 1.7 2.3 13.01 1.5 yes main gathering line treated via injection at 03-23
60520 - 4 3-5-38-7W5 PL 14-32-37-7W5 PL 2.0 1.7 2.3 15.40 2.0 yes main gathering line treated via injection at 03-23
60520 - 5 1-9-38-7W5 WE 3-5-38-7W5 PL 2.4 1.7 2.3 16.17 2.1 yes main gathering line crosses Prairie Creek; treated via injection at 03-23
54958 - 1 14-11-43-3W5 WE 2-14-43-3W5 B 1.9 2.1 2.3 16.97 1.5 yes deadleg?
60062 - 2 12-20-37-7W5 B 16-19-37-7W5 PL 2.0 1.8 2.3 17.80 1.4 yes new line cant find on ABADATA
60062 - 3 16-19-37-7W5 PL 12-20-37-7W5 B 2.1 1.8 2.3 18.67 1.4 yes new line
60311 - 8 13-10-037-07W5 13-01-037-07W5 3.3 1.5 2.3 no fluid 2.1 yes Environmental risk crosses the Prairie creek
60311 - 5 13-01-037-07W5 14-06-037-07W5 2.8 1.5 2.3 no fluid 2.0 yes new line
10-18-037-07W5 12-20-037-07W5 3.0 1.5 2.3 no fluid 2.0 yes new line
*Theoretical corrosion rates are calculated based on the DeWaard-Lotz model, marked lines are either coated or made out of none-steel components.
Risk Ranking: < 1.5 = low risk - no treatment required
1.5 to 2 = medium risk - treatment depending on client
2 to 2.5 = elevated risk - treatment recommended
2.5 to 5 = high risk - treatment is recommended
3 to 4 = severe risk -treatment is strongly recommended
4 to 5 = extreme risk - aggressive treatment is strongly recommended
Risk assessment and recommendation for the Willesden Green field
It is recommended to treat all line segments with an overall risk of 2.5 or greater. In circumstances such as environmental risk and/or high theoretical corrosion rates (>100 mpy) should be treated regardless of risk ranking.
oil emulsion or crude oil line on lease oil emulsion (no AER license) foreign 3rd party owned line
= Gas well = Water well natural gas line on lease gas line (no AER license) LVP line
Water line on lease water line (no AER license)
= Oil well = Misc. well
lease 42289-9 (4")
lease
42289-10 (4") discontinued 57873-2 (4") 06-03
04-10
lease
lease
lease 43702-2 (4")
42289-8 (4")
discontinued lease
43702-8 (3") 10-33 42289-7 (6") Sales Gas 53385-1 (3") lease
discontinued
lease
53316-1 (3")
lease 44436-1 (2") discontinued
lease 12-33 43702-6 (6") 12-29
43702-4 (4")
lease
lease 02-31 57873-1 (4") 08-32 43702-5 (6") 07-29 43702-1 (6") 43702-1 (6") 11-21 lease
04-28
60221-3 (3") M:Composite lease
07-27
lease 02-29 53368-1 (3") lease
lease
lease
lease 53453-3 (3") lease
lease 14-22 50315-37 (4")
15-20 InPlay Gas lease
lease
lease 08-19 43702-7 (4") 48160-1 (4") lease
50315-36 (4") 14-15
lease 58743-1 (3") InPlay Gas
lease M: Composite
lease
lease 46735-2 (3") lease
lease 54571-1 (4") 50315-35 (4") 11-15
46735-1 (3") discontinued InPlay Gas
lease
lease
48014-1 (4") 13-30 lease
lease discontinued lease 57486-1 (3") 08-10
C1218 @ 4L/d
lease 58515-1 (4") 11-12 58515-3 (4") 14-13 58515-2 (4")
59891-1 (4")
lease 59959-2 (3") M: Composite 15-07 59959-1 (6") 55270-1 (4") 55273-1 (4") 52347-1 (6") lease
01-10
lease leaes
53749-1 (3") 52347-2 (6")
Obsidian Gas lease
lease
lease 59530-1 (3") M: Composite 59959-4 (3") 02-17 58418-1 (3") 15-09 lease
15-08 M: Composite discontinued M: Composite
lease 59959-7 (6") lease 14-17 59941-1 (3")
M: Composite
lease lease lease
lease 59026-1 (3")
M: Composite
lease C1218 @ 9L/d
57466-1 (3") M: Composite
lease 58419-2 (3") 12-19 60222-2 (5") 11-19 60222-1 (6") lease 48436-1 (3")
M: Composite M: Composite 15-15 Baytex Gas
lease lease
lease 19415-2 (3") 06-19 06-02 59787-1 (3") M: Composite
lease 58419-1 (3") lease 08-23
M: Composite
lease 10-15 58050-1 (2") 04-14 58050-5 (2") 04-11 58050-4 (2") 14-02 58050-3 (2") 14-02 58050-2 (2")
10-02 lease
lease lease
lease 59556-1 (3") 10-36 13-06 55895-1 (3")
lease 60222-3 (5") M: Composite
M: Composite lease
59959-5 (3") M: Composite leaes
59259-1 (3") 16-31
lease 60222-4 (5") discontinued lease lease 56302-1 (3") 12-11 07-08 56048-1 (3")
M: Composite M: Composite
lease
06-23 55652-1 (3") discontinued 03-15
lease
54958-1 (3") leaes 59541-1 (3") 03-18 08-04 60041-1 (3")
lease 57718-2 (3") 57718-1 (3") 04-23 M: Composite M: Composite
13-29
07-14 53737-1 (3")
discontinued lease
lease lease
10-11 58048-1 (3") M: Composite lease 46507-5 (4") Timberrock Gas
59996-1 (5") 06-21
M: Composite 59986-2 (4") discontinued
C1218 @ 7L/d
06-10
15-09 lease
lease
lease 59986-8 (4")
lease
lease 59986-7 (4") 59986-9 (5") Composite 13-10
04-10 05-10
lease
lease 56068-1 (3")
53228-1 (3")
discontinued lease
60520-4 (6") 14-32 60520-3 (6") 09-31 60520-1 (6") 12-31 60520-1 (6")
03-05 lease 55029-3 (3") 15-35 lease
lease
lease 58932-1 (3") M:Composite 01-15 12-31 55029-4 (3") M: Composite
16-35 55063-1 (6") 01-35 53932-1 (6")
Sales Gas Sales Gas lease
03-34
lease
lease 60003-1 (5") 11-05 59943-1 (5") 04-04
M: Composite M: Composite lease
lease lease lease
59552-1 (3") discontinued 01-33
M: Composite lease Keyera lease
C1218 @ 6L/d
lease 47376-1 (3") lease lease
47376-3 (5") M: Composite lease lease 54016-1 (6") 57601-1 (3") lease
03-11
lease lease lease
lease 59918-1 (3") M: Composite 14-33 lease
59806-1 (5") M: Composite 01-34 59806-1 (5")
lease M: Composite
lease lease
lease lease
lease
lease 60151-2 (5") 04-33 47376-4 (5") lease
M: Composite M: Composite lease lease
lease 60151-1 (3") 04-33 47376-2 (3") lease
M: Composite lease 59924-1 (5")
lease M: Composite
lease
lease
lease 60062-1 (6") 07-30 60311-1 (5") M: Composite 06-25 59079-1 (4") 07-26 59263-1 (3") M: Composite
10-18
59971-1 (5") 03-36 31390-3 (8") lease
lease M: Composite 09-36
lease
lease
lease
lease 13-02 lease
16-19
lease 59892-1 (5") lease
M: Composite
lease lease
lease 59587-1 (6") 60045-1 (6") 09-02 lease (6") 14-06 60311-5 (6") 13-01 60311-8 (6")
08-02
lease
14-06 lease
lease
lease lease
lease 60006-1 (5") 03-02 lease
M: Composite
lease
= no information available = header = Corr. Coupon = recommended Injection Point = Demulsifier
= piggable section = blind ended = Riser = Corrosion Inhibitor = Scale Inhibitor
= underground tie-in = recommended Corr. Coupon = Wax Inhibitor/Dispersant = Scale/Corrosion Inhibitor
= Other March, 2018
This schematic does not represent geographical relationships; it is for connectivity purposes only
Comments
04-04-40-08W547376-1, 31390-2,
60020-1, 59587-1,
59976-13, 6 & 8 C1218 Corrosion Inhibitor 6
Willesden Green
Injection Points
LocationProtected
LinesLine size Product Type
Inj rate
(L/day)
02-15-042-07W502-15
Sing. Batt. 02/06-03-042-07W5
Suspended14-18-041-05W5
60222-1, 59959-
6,7,3,1
+ others6 C1218 Corrosion Inhibitor 9
03-23-038-07W559986-1,5,4,3,9,7,
60520-5,4,3,1, 55029-
16 C1218 Corrosion Inhibitor 7
is supplemented by
additional injection points05-11-042-07W5
Supended16-25-039-07W5
58515-1,3,2, 59891-
1, 55270-1, 52347-1,
43702-1,5,66 C1218 Corrosion Inhibitor 4
02/11-04-042-07W5
Shut in
04-10-042-07W5
Suspended 43
70
2-3
(6")
11-04-042-07W511-04
Sing. Batt.
10-04-042-07W5
Disposal 02-04-042-07W5
Battery/ Compressor
03-28-041-07W5
(DH: 02/03-21)01-33-041-07W5
Supended
08-30
Sing. Batt.
08-30-041-07W5
(DH: 02/07-29)
03-28-041-07W5
(DH: 03-21)
03-28
Sing. Batt.
56
26
1-1
(3")
11-21-041-07W5
04-28-041-07W5
(DH: 04-21)
04-28
Sing. Batt.12-29-041-07W5
14-22-041-07W5
Suspended12-33-041-07W5
08-27-041-07W5
(DH: 08-26)
02-31-041-07W508-27-041-07W5
(DH: 02/01-26)
56
54
5-1
(3")
08-27
Sing. Batt.
07-27-041-07W5
(DH: 01-26)43
70
2-7
(4")
53
45
3-1
(4")
52
34
7-1
(6")
01-26-041-07W5
(DH: 01-23)13-16-041-07W5
(DH: 14-17)
13-16
Battery13-31-041-07W5
(DH: 02/14-06)
01-26
Sing. Batt.
01-26-041-07W5
(DH: 02/01-23)
13-31-041-07W5
(DH: 03/14-06)
13-31
Battery M: C
om
po
site
60
22
1-2
(3")
M: C
om
po
site
60
22
1-1
(3")
13-31-041-07W5
(DH: 13-07)
02-29
Sing. Batt.
02-29-041-07W5
(DH: 09-20)
01-26-041-07W5
(DH: 03/02-23)16-15
Inplay13-20-041-07W5
(DH: 12-19)
03-21-041-07W5
(DH: 05-19)05-20-041-07W5
(DH: 07-20)5
23
47
-1 (6
")
13-20-041-07W5
13-31-041-07W5
(DH: 02/13-06)
15-20
Sing. Batt.
15-20-041-07W5
(DH: 12-20)
53
45
3-2
(3")
03-27
Battery
InPlay
01-26-041-07W5
(DH: 02-23)12-16-041-07W5
(DH: 02/12-17) 01-26-041-07W5
(DH: 02/02-23)12-16-041-07W5
(DH: 05-17)
12-16
Sing. Batt.
05-20-041-07W5
(DH: 01-20)
05-20
Sing. Batt.
01-09-041-07W5
(DH: 04-09)01-09-041-07W5
(DH: 02/16-09)
01-09
Sing. Batt.
16-09
Inplay13-17-041-07W5
(DH: 02/13-17) Susp. 01-09-041-07W5
(DH: 13-04)
08-19-041-07W513-20
Sing. Batt.
13-20-041-07W5
(DH: 13-19)
13-11-041-07W5
(DH: 04/13-09) 07-10
Sing. Batt.
07-10-041-07W5
(DH: 11-10) Shut in16-25-039-07W5
(DH: 15-19)
13-11-041-07W5
(DH: 02/13-09)
13-11
Sing. Batt.
52
34
7-1
(6")
16-25-039-07W5
Suspended
16-25
Sing. Batt.
59
95
9-3
(6")
04-12-041-07W5
(DH: 04-11)
01-11-041-07W5
(DH: 01-02)15-08
Obsidian
13-35
Sing. Batt.
13-35-041-07W5
(DH: 14-02)01-11-041-07W5
(DH: 02-02) 13-35-041-07W5
(DH:13-02)
15-07-041-06W515-07
Sing. Batt.
04-12
Sing. Batt.
08-03
Sing. Batt.
08-03-041-07W5
(DH: 06-03)01-11
Sing. Batt.
14-08-041-06W514-08
Sing. Batt.13-35-041-07W5
01-17-041-06W501-17
Sing. Batt.
08-16
Sing. Batt.
08-16-041-06W5
(DH: 02/08-14)
01-19
Battery
01-19-042-07W5
(DH: 02-18)
01-17-041-06W508-16-041-06W5
(DH: 02/08-14)
01-19-042-07W5
(DH: 02/02-18)
59
95
9-6
(6")
13-13-040-06W5
(DH: 12-15)
13-13
Sing. Batt.
14-18-041-05W5
(DH: 14-18) 10-35
Sing. Batt.
10-35-041-08W5
(DH: 02/01-26)14-18-041-05W5
(DH: 03/04-07)
14-18
Sing. Batt.
11-15-041-06W5
(DH: 16-14)
07-24
Baytex
06-18-041-05W5
(DH: 04/14-19)
11-15-041-06W5
(DH: 02/16-14)
M: C
om
po
site
60
22
2-3
(5")
11-15
Sing. Batt.
01-23-040-06W5
Abandoned
03-02
Sing. Batt.
03-02-042-08W5
(DH: 03-26)06-18-041-05W5
Shut in
06-18
Sing. Batt.
11-15-041-06W5
(DH: 03/16-14)11-15-041-06W5
(DH: 09-14) 04-07-039-05W5
(DH: 05-12)15-31-041-05W5
(DH: 15-07)
11-15-041-06W5
(DH: 02/09-14) 15-36-039-06W5
(DH: 02/15-01)
15-36
Sing. Batt.
04-07
Battery
04-07-039-05W5
(DH: 05-13)15-31-041-05W5
(DH: 02/16-07)
15-31
Sing. Batt. 04-07-039-05W5
(DH: 04-12)02-15
Sing. Batt.
02-15-041-06W5
(DH: 01-10)
11-11-039-05W5
(DH: 11-02)16-08-039-05W5
(DH: 15-17)16-08-039-05W5
(DH: 16-17)13-29-043-09W5
(DH: 05-05) dis
co
ntin
ue
d
45
43
7-1
(3")
14-11-043-03W5
(DH: 14-14) Shut in
14-07-038-06W5
(DH: 14-19)
14-07
Sing. Batt.
03-03
Sing. Batt.
03-03-039-05W5
(DH: 04-27)
11-31-041-05W5
(DH: 13-07)
11-31
Sing. Batt.
02-15-041-06W5
(DH: 02-10)
01-11-039-05W5
(DH: 12-02)
11-11
Sing. Batt.
16-08
Battery
05-23-038-07W5
(DH: 13-23) Susp.
03-23
Sing. Batt. 03-23-038-07W5
(DH: 01-23) ABD
59
98
6-1
1 (4
")
59
98
6-1
& 5
(6")
ab
an
do
ne
d
59
98
6-1
0 (6
")
02/03-23-038-07W5
Shut in
13-29-043-09W5
(DH: 13-29) ABD
13-29
Sing. Batt.
02-14
Sing. Batt.
02-14-043-03W5
(DH: 15-14) 03-18-038-06W5
Timberrock01-29-043-09W5
(DH: 02-20)
01-29
Sing. Batt.
02-14-043-03W5
(DH: 02/16-14) 05-18-038-06W5
Timberrock
60
52
0-5
(6")
16-35-037-08W5
(DH: 16-02)16-35-037-08W5
(DH: 09-36)
04-02
Battery
04-02-038-08W5
(DH: 04-35)13-31-037-07W5
(DH: 14-36) Susp. 04-02-038-08W5
(DH: 02/04-35)
05-03-038-07W5
(DH: 08-03)
05-03
Sing. Batt. 03-23-038-07W5
Shut in
01-09-038-07W5
(DH: 07-04) Shut in
01-09
Sing. Batt.
59986-4 & 3 (6") 09-15
Satellite
16-35
Battery
15-35-037-08W5
(DH: 15-02)
60
52
0-2
(6")
16-35-037-08W5
(DH: 02/16-36)08-10-040-08W5
(DH: 02/01-34) 55
02
9-1
(6")
55
06
3-2
(6")
08-10-040-08W5
(DH: 01-34)
08-10
Sing. Batt.
02-02
Battery
14-05-040-08W5
(DH: 13-08)
14-05
Sing. Batt.16-02-037-08W5
Battery/CompressorM
:Co
mp
osite
59
94
3-2
(5")
16-02-038-08W5
(DH: 15-11)14-06-037-07W5
(DH: 13-18)
16-02-038-08W5
(DH: 02/16-11)
02-02-038-08W5
(DH: 02/02-35)
52
74
4-2
(4")
02-02-038-08W5
(DH: 01-26)Sa
les
Ga
s
55
02
9-2
(6")
14-05-040-08W5
(DH: 14-08)
05-31
Sing. Batt.
05-31-037-07W5
(DH: 06-36) Sa
les
Ga
s
55
03
0-1
(6")
01-35-037-08W5
(DH: 16-35)04-04
CNRL 14-06-037-07W5
(DH: 15-18)
54
97
0-1
(6")
01-35
Battery
01-35-037-08W5
(DH: 01-36)14-06
Sing. Batt.
03-11
Battery
55
03
3-1
(4")
02-35
Battery
04-04-40-08W5
Shut in
04-04
Sing. Batt.
14-06-037-07W5
(DH: 02/14-18)
03-11-038-08W5
(DH: 13-11)
60
31
1-3
(5") M
: Co
mp
osite
14-06-037-07W5
(DH: 04/14-18)
03-11-038-08W5
(DH: 14-11)
15-26-037-08W5
(DH: 03/14-35)
10-28-039-08W5
(DH: 16-27)
02-35-037-08W5
(DH: 03-23)14-33-040-08W5
(DH: 02/14-09)
03-11-038-08W5
(DH: 04-02)
02-35-037-08W5
(DH: 03-26)14-33-040-08W5
(DH: 15-09)
14-33
Sing. Batt.
03-11-038-08W5
(DH: 02/03-02) 08-34
Battery
08-34-037-08W5
(DH: 02/04-23)16-08-037-07W5
(DH: 08-20) 08-34-037-08W5
(DH: 04-23)10-28-039-08W5
(DH: 02/16-33)
16-08-037-07W5
(DH: 13-21)
15-26
Battery15-26-037-08W5
(DH: 15-35) ABD10-28-039-08W5
(DH: 16-33)
11-33
Header
16-08
Sing. Batt.
16-08-037-07W5
(DH: 08-20) 15-26-037-08W5
(DH: 11-35)
12-28-037-08W5
(DH: 11-16)10-28-039-08W5
(DH: 09-27)
10-28
Sing. Batt.
31
39
0-2
(8")
60
31
1-2
(5") M
:Co
mp
osite
16-08-037-07W5
(DH: 08-20)
60
54
4-1
(5") M
:Co
mp
osite
15-26-037-08W5
(DH: 02/15-35)
12-28
Battery
12-28-037-08W5
(DH: 03-21)12-28-037-08W5
(DH: 04-21)10-28-039-08W5
(DH: 02/1627)10-28-039-08W5
(DH: 02/09-27)
07-26
Battery
07-26-037-08W5
(DH: 03-14)
60
06
2-5
(5") M
: Co
mp
osite
07-26-037-08W5
(DH: 01-23)01-36-039-09W5
(DH: 04-30) 60
02
0-1
(6")
04-01-040-09W5
(DH: 03/04-36)
04-01-040-09W5
(DH: 01-26)
59
58
7-1
(6")
60
06
2-3
(6")
60
06
2-4
(5") M
:Co
mp
osite
01-02-040-09W5
RESPONSE
12-20-037-07W5
(DH: 02/04-17)
01-36-039-09W5
(DH: 02/04-30)
01-36
Sing. Batt. 04-01-040-09W5
(DH: 02/04-36)10-30-039-08W5
(DH: 02-19)
04-01
Battery
04-01-040-09W5
(DH: 04-36)
58
73
9-1
(3") M
: Co
mp
osite
10-30-039-08W5
(DH: 01-19)
10-30
Sing. Batt.
dis
co
ntin
ue
d
01-02-040-09W5
(DH: 02-26)
01-02
Sing. Batt.
12-20-037-07W5
(DH: 02/03-17)
12-20
Battery
13-10
Battery59
91
6-1
(6")5
99
76
-1 (6
")
12-20-037-07W5
(DH: 03-17)
dis
co
ntin
ue
d
06-02-040-9W5
(DH: 02/03-26)
= non-piggable section= segements covered
by injection
= segements covered
by batch
59
26
0-1
(3") M
: Co
mp
osite
12-20-037-07W5
(DH: 04-17)
59
97
0-1
(6") 11-06-040-08W5
(DH: 13-07)11-06
Battery06-02-040-9W5
(DH: 02/03-26) 06-02-040-09W5
Battery/ Compressor
11-06-040-08W5
(DH: 13-07)06-02-040-9W5
(DH: 02/03-26)
11-06-040-08W5
(DH: 13-07)
*note: information stated below based on AER license information obtained from ABADATA 2.0. Contact Chemicals Inc. takes no resposibility for accuracy of this data.
AER
License
from
location
to
location
Length(km) Status Substance
H2S(mol/kmol)
OD(mm)
WT(mm) Material TYPE GRADE
MOP(kPa) Joints
Internal
Coating
Elevation
Profile
Pipeline
Age (yrs) Enviro. Physical Risk
19415 - 2 8-23-40-6W5 B 6-19-40-5W5 PL 2.4 O NG 0 88.9 3.18 S 5LX X42 1720 W U 38 2.5
31390 - 2 11-33-39-8W5 PL 9-36-39-9W5 PL 4.23 O NG 0 219.1 5.6 S Z245.1 3592 9930 W U 22 2.8
31390 - 3 3-36-39-9W5 PL 9-36-39-9W5 PL 1.24 O NG 0 219.1 5.6 S Z245.1 3592 9930 W U 22 2.7
42289 - 7 2-4-42-7W5 CS 10-33-41-7W5 PL 0.65 O NG 0 168.3 4 S Z245.1 3591 9850 W U 15 2.6
42289 - 8 10-4-42-7W5 BE 11-4-42-7W5 BE 0.42 D NG 0 114.3 4.8 S Z245.1 3592 0 W U 14 2.3
42289 - 9 2-15-42-7W5 WE 4-10-42-7W5 PL 2.78 O NG 0 114.3 4.8 S Z245.1 3592 9930 W U not available 14 CC 2.6
42289 - 10 5-11-42-7W5 WE 4-10-42-7W5 PL 2.5 O NG 0 114.3 4 S Z245.1 3592 9930 W U 10 CC 2.6
43702 - 1 11-21-41-7W5 WE 7-29-41-7W5 PL 2.38 O NG 2 168.3 4 S Z245.1 3591 9930 W U 15 2.6
43702 - 2 11-4-42-7W5 WE 2-4-42-7W5 CS 1.1 O NG 2 114.3 4.8 S Z245.1 3591 9930 W U 15 2.5
43702 - 3 6-3-42-7W5 WE 2-4-42-7W5 CS 1.8 O NG 2 168.3 4 S Z245.1 3591 9930 W U 15 2.6
43702 - 4 12-29-41-7W5 WE 7-29-41-7W5 PL 0.81 O NG 2 114.3 4.8 S Z245.1 3591 9930 W U 15 2.6
43702 - 5 7-29-41-7W5 PL 12-33-41-7W5 PL 2.25 O NG 2 168.3 4 S Z245.1 3591 9930 W U 15 CC 2.7
43702 - 6 12-33-41-7W5 PL 2-4-42-7W5 CS 1.42 O NG 2 168.3 4 S Z245.1 3591 9930 W U 15 2.6
43702 - 7 8-19-41-7W5 WE 7-29-41-7W5 PL 2.8 O NG 2 114.3 4.8 S Z245.1 3592 9930 W U 14 CC 2.7
43702 - 8 1-33-41-7W5 WE 10-33-41-7W5 PL 0.91 O NG 2 88.9 4 S Z245.1 3591 9930 W U 12 CC 2.6
44436 - 1 14-22-41-7W5 BE 11-21-41-7W5 BE 1.52 D NG 0 60.3 3.2 S Z245.1 2901 0 W U 14 2.2
46735 - 1 13-17-41-7W5 BE 8-19-41-7W5 BE 0.7 D NG 2 88.9 4 S Z245.1 3592 0 W U 13 2.3
46735 - 2 5-20-41-7W5 WE 8-19-41-7W5 PL 0.22 O NG 2 88.9 4.8 S Z245.1 3592 9930 W U 9 2.4
47376 - 1 4-4-40-8W5 WE 11-33-39-8W5 PL 1.7 O NG 0 88.9 3.2 S Z245.1 3591 9520 W U 13 2.6
47376 - 2 4-33-39-8W5 WE 11-33-39-8W5 PL 0.6 O NG 0 88.9 3.2 S Z245.1 3591 9520 W U 13 2.5
47376 - 3 4-4-40-8W5 PL 11-33-39-8W5 PL 1.14 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2.1
47376 - 4 4-33-39-8W5 PL 11-33-39-8W5 PL 0.49 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
48014 - 1 16-25-39-7W5 BE 13-30-39-6W5 BE 0.34 D NG 0 114.3 4 S Z245.1 3592 0 W U 13 2.3
48160 - 1 13-20-41-7W5 WE 15-20-41-7W5 PL 0.54 O NG 0 114.3 4.8 S Z245.1 3592 9930 W U 13 2.6
48695 - 1 13-19-40-6W5 BE 2-30-40-6W5 BE 1.38 D NG 0 88.9 3.2 S Z245.1 3592 0 W U 12 2.3
52347 - 1 8-3-41-7W5 WE 11-21-41-7W5 PL 8.1 O NG 0 168.3 4 S Z245.1 3592 9930 W U 9 CC 2.7
52347 - 2 13-35-40-7W5 WE 8-3-41-7W5 PL 1.36 O NG 0 168.3 4 S Z245.1 3592 9930 W U 8 2.5
52744 - 2 5-31-37-7W5 WE 12-31-37-7W5 PL 0.35 O OE 0 114.3 4 S Z245.1 3592 9930 W U 8 2.4
53228 - 1 13-31-37-7W5 BE 12-31-37-7W5 BE 0.73 D OE 0 88.9 4 S Z245.1 3592 0 W U 8 2.2
53316 - 1 4-28-41-7W5 WE 4-28-41-7W5 PL 0.19 O NG 0 88.9 3.2 S Z245.1 3592 9930 W U 8 2.4
53368 - 1 2-29-41-7W5 WE 2-29-41-7W5 PL 0.12 O NG 2 88.9 4 S Z245.1 3592 9930 W U 9 2.5
53385 - 1 8-30-41-7W5 WE 12-29-41-7W5 PL 1.11 O NG 2 88.9 4.8 S Z245.1 3592 9930 W U 8 2.5
53453 - 1 13-16-41-7W5 WE 4-28-41-7W5 PL 2.05 O NG 0 114.3 4.8 S Z245.1 3592 9930 W U 8 2.5
53453 - 2 12-16-41-7W5 WE 13-16-41-7W5 PL 0.71 O NG 0 88.9 3.2 S Z245.1 3592 9930 W U 4 2.4
53453 - 3 15-20-41-7W5 WE 15-20-41-7W5 PL 0.37 O NG 0 88.9 4.8 S Z245.1 3592 9930 W U 8 2.4
53932 - 1 1-35-37-8W5 WE 3-34-37-8W5 PL 2.94 O NG 0 168.3 4 S Z245.1 3592 9930 W U 7 2.5
54016 - 1 3-11-38-8W5 WE 3-11-38-8W5 PL 0.19 O NG 0 168.3 4.8 S Z245.1 3592 9930 W U 7 2.4
54571 - 1 1-9-41-7W5 WE 16-9-41-7W5 PL 1.47 O NG 0 114.3 4 S Z245.1 3592 9930 W U 6 CC 2.5
54970 - 1 3-11-38-8W5 PL 16-2-38-8W5 B 0.82 O NG 0 168.3 4.8 S Z245.1 3592 9930 W U 6 2.5
55029 - 1 16-35-37-8W5 PL 16-2-38-8W5 B 2.7 O NG 0 168.3 4 S Z245.1 2901 9930 W U 6 2.5
55029 - 2 16-2-38-8W5 B 16-35-37-8W5 PL 2.7 O NG 0 168.3 4 S Z245.1 2901 9930 W U 6 2.5
55029 - 3 15-35-37-8W5 WE 16-35-37-8W5 PL 0.27 O NG 0 88.9 3.2 S Z245.1 3592 9930 W U 4 2.3
55029 - 4 2-2-38-8W5 WE 15-35-37-8W5 PL 0.32 O NG 0 101 12 G FPLP 601 9930 M U 2 1.9
55030 - 1 3-34-37-8W5 PL 1-33-37-8W5 PL 0.59 O NG 0 168.3 4 S Z245.1 3592 9930 W U 6 2.4
55033 - 1 15-26-37-8W5 WE 1-35-37-8W5 PL 0.77 O NG 0 114.3 4 S Z245.1 3592 9930 W U 6 2.3
55063 - 1 16-35-37-8W5 PL 1-35-37-8W5 PL 1.53 O NG 0 168.3 4 S Z245.1 2901 9930 W U 6 2.5
55063 - 2 1-35-37-8W5 PL 16-35-37-8W5 PL 1.53 O NG 0 168.3 4 S Z245.1 2901 9930 W U 6 2.5
55270 - 1 4-12-41-7W5 WE 1-11-41-7W5 PL 0.61 O NG 0 114.3 4 S Z245.1 3592 9930 W U 6 2.3
55273 - 1 1-11-41-7W5 WE 1-10-41-7W5 PL 1.63 O NG 0 114.3 4 S Z245.1 3592 9930 W U 6 CC 2.4
55652 - 1 1-15-41-6W5 BE 3-15-41-6W5 BE 0.63 D NG 0 88.9 4 S Z245.1 3592 0 W U 5 2.2
55895 - 1 4-7-39-5W5 WE 13-6-39-5W5 PL 0.49 O NG 0 88.9 4 S Z245.1 3592 4960 W U 5 2.3
56048 - 1 16-8-39-5W5 WE 7-8-39-5W5 PL 1.03 O NG 0 88.9 4 S Z245.1 3592 4960 W U 5 2.3
56068 - 1 4-2-38-8W5 WE 16-35-37-8W5 PL 1.4 O NG 0 88.9 4 S Z245.1 3592 9930 W U 5 2.4
56261 - 1 3-28-41-7W5 WE 4-28-41-7W5 PL 0.61 O NG 0 88.9 4 S Z245.1 3592 9930 W U 5 2.3
56302 - 1 11-11-39-5W5 WE 12-11-39-5W5 PL 0.27 O NG 0 88.9 4 S Z245.1 3592 4960 W U 5 1.9
56545 - 1 13-31-41-7W5 WE 2-31-41-7W5 PL 1.63 O NG 0 88.9 3.2 S Z245.1 3592 9930 W U 5 2.5
57466 - 1 10-35-41-8W5 WE 10-2-42-8W5 PL 2.44 O NG 0 91 8 G FSLP 750 4950 M U 4 2
57486 - 1 13-11-41-7W5 WE 8-10-41-7W5 PL 1.23 O NG 0 88.9 4 S Z245.1 3592 9930 W U 4 2
57591 - 1 1-35-37-8W5 WE 1-35-37-8W5 PL 0.07 O NG 0 88.9 4 S Z245.1 2901 9930 W U 3 2.3
57601 - 1 2-35-37-8W5 WE 1-35-37-8W5 PL 0.19 O NG 0 88.9 4 S Z245.1 2901 9930 W U 3 2.3
57873 - 1 2-31-41-7W5 WE 8-32-41-7W5 PL 2.3 O NG 2 114.3 4.8 S Z245.1 3592 9930 W U 15 2.7
57873 - 2 4-10-42-7W5 WE 6-3-42-7W5 PL 1.41 O NG 2 114.3 4.8 S Z245.1 3592 9930 W U 14 2.6
58050 - 1 4-14-42-8W5 WE 10-15-42-8W5 S 1.14 O NG 0 60.3 3.18 S 5L B 4950 W U 38 2.5
58050 - 2 10-2-42-8W5 WE 14-2-42-8W5 PL 0.28 O NG 0 60.3 3.9 S Z245.1 2901 4950 W U 19 2.2
58050 - 3 14-2-42-8W5 PL 14-2-42-8W5 PL 0.1 O NG 0 60.3 3.9 S Z245.1 2901 4950 W U 19 CC 2.2
58050 - 4 14-2-42-8W5 PL 4-11-42-8W5 PL 0.6 O NG 0 60.3 3.9 S Z245.1 2901 4950 W U 19 2.2
58050 - 5 4-11-42-8W5 PL 4-14-42-8W5 PL 1.7 O NG 0 60.3 3.91 S Z245.1 2901 4950 W U 35 2.5
58418 - 1 8-16-41-6W5 BE 15-9-41-6W5 BE 1.1 D NG 0 101 12 G FPLP 601 0 M U 2 1.7
58419 - 1 6-18-41-5W5 WE 14-18-41-5W5 PL 0.75 O NG 0 101 12 G FPLP 601 9930 M U 2 2.1
58419 - 2 14-18-41-5W5 WE 2-19-41-5W5 PL 0.98 O NG 0 101 12 G FPLP 601 9930 M U 2 2
58515 - 1 16-25-39-7W5 WE 6-12-40-7W5 PL 5.1 O NG 0 114.3 4 S Z245.1 3592 9930 W U 2 2.5
58515 - 2 14-13-40-7W5 PL 4-12-41-7W5 PL 8.15 O NG 0 114.3 4 S Z245.1 3592 9930 W U 2 CC 2.6
58515 - 3 11-12-40-7W5 PL 14-13-40-7W5 PL 2.19 O NG 0 114.3 4 S Z245.1 3592 9930 W U 2 2.3
58739 - 1 1-2-40-9W5 BE 13-2-40-9W5 BE 1.72 D NG 0 101 12 G FPLP 601 0 M U 2 1.8
58743 - 1 3-21-41-7W5 WE 13-16-41-7W5 B 0.53 O OE 0 101 12 G FPLP 601 9930 M U 2 2.1
58932 - 1 8-10-40-8W5 WE 1-15-40-8W5 PL 1.85 O NG 0 101 12 G FPLP 601 8960 M U 2 2.1
59026 - 1 13-13-40-6W5 WE 8-23-40-6W5 PL 1.1 O NG 0 101 12 G FPLP 601 1720 M U 2 1.9
59079 - 1 6-25-37-8W5 PL 7-26-37-8W5 PL 1.1 O NG 0 114.3 4 S Z245.1 3592 9930 W U 6 2.4
59259 - 1 15-31-41-5W5 WE 16-31-41-5W5 PL 0.28 O NG 0 88.9 3.2 S Z245.1 2901 9930 W U 2 2.2
59260 - 1 6-2-40-9W5 BE 1-2-40-9W5 BE 1.01 D NG 0 101 12 G FPLP 601 0 M U 2 1.7
59263 - 1 7-26-37-8W5 WE 15-26-37-8W5 PL 1.14 O NG 0 101 12 G FPLP 601 9930 M U 2 1.9
59530 - 1 14-8-41-6W5 WE 15-8-41-6W5 PL 0.28 O NG 0 101 12 G FPLP 601 4960 M U 1 1.8
59541 - 1 14-7-38-6W5 WE 3-18-38-6W5 PL 0.67 O NG 0 101 12 G FPLP 601 9930 M U 1 1.7
59552 - 1 4-4-40-8W5 WE 4-4-40-8W5 PL 0.17 O NG 0 101 12 G FPLP 601 8040 M U 1 1.9
59556 - 1 15-36-39-6W5 WE 10-36-39-6W5 PL 0.41 O NG 0 101 12 G FPLP 601 9930 M U 1 2
59587 - 1 4-1-40-9W5 WE 1-2-40-9W5 PL 1.06 O NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.4
59787 - 1 3-2-42-8W5 WE 6-2-42-8W5 PL 0.51 O NG 0 97 10 G FPLP 301 4950 M U 1 1.5
59806 - 1 8-34-37-8W5 WE 2-35-37-8W5 PL 1.49 O NG 0 130 15.5 G FPLP 601 9930 M U 1 1.9
59891 - 1 4-12-41-7W5 WE 1-10-41-7W5 PL 2.23 O NG 0 114.3 4 S Z245.1 3592 9930 W U 1 2.3
59892 - 1 10-30-39-8W5 WE 1-36-39-9W5 PL 1.77 O NG 0 130 15.5 G FPLP 601 9930 M U 1 2
59916 - 1 14-6-40-8W5 PL 9-2-40-9W5 PL 2.55 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.4
59918 - 1 14-33-39-8W5 WE 14-33-39-8W5 PL 0.37 P NG 0 101 12 G FPLP 601 9930 M U 2 2.1
59924 - 1 12-28-37-8W5 WE 1-34-37-8W5 PL 3.75 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.1
59941 - 1 1-19-42-7W5 WE 14-17-42-7W5 PL 1.14 P OE 0 101 12 G FPLP 601 4960 M U 1 1.9
59943 - 1 11-5-40-8W5 PL 4-4-40-8W5 PL 1.64 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
59943 - 2 4-4-40-8W5 PL 4-4-40-8W5 PL 0.15 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
59959 - 1 14-7-41-6W5 PL 4-12-41-7W5 PL 3.17 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.4
59959 - 2 15-7-41-6W5 WE 15-7-41-6W5 PL 0.44 P NG 0 101 12 G FPLP 601 9930 M U 2 2
59959 - 3 1-17-41-6W5 PL 15-7-41-6W5 PL 2.86 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.4
59959 - 4 15-8-41-6W5 PL 2-17-41-6W5 PL 0.31 P NG 0 101 12 G FPLP 601 9930 M U 2 1.9
59959 - 5 2-15-41-6W5 WE 11-15-41-6W5 PL 1.12 P NG 0 101 12 G FPLP 601 9930 M U 2 2
59959 - 6 11-15-41-6W5 WE 8-16-41-6W5 PL 2.12 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.4
59959 - 7 8-16-41-6W5 WE 4-16-41-6W5 PL 2.07 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 CC 2.4
59970 - 1 11-6-40-8W5 WE 14-6-40-8W5 PL 0.14 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.2
59971 - 1 1-36-39-9W5 WE 3-36-39-9W5 PL 1 P NG 0 130 15.5 G FPLP 601 9930 M U 2 1.9
59976 - 1 1-2-40-9W5 WE 6-2-40-9W5 B 1.03 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.2
59986 - 1 3-23-38-7W5 WE 12-14-38-7W5 PL 1.33 O NG 0 168.3 4 S Z245.1 3592 9930 W U 10 2.5
59986 - 2 5-23-38-7W5 BE 3-23-38-7W5 BE 0.84 D NG 0 114.3 3.2 S Z245.1 3592 0 W U 9 CC 2.1
59986 - 3 12-14-38-7W5 PL 13-10-38-7W5 PL 2.52 O NG 0 168.3 4 S Z245.1 3592 9930 W U 1 RC 2.4
59986 - 4 9-15-38-7W5 B 12-14-38-7W5 PL 0.09 O NG 0 168.3 4.8 S Z245.1 3592 9930 W U 9 2.4
59986 - 5 12-14-38-7W5 PL 9-15-38-7W5 B 0.09 O NG 0 168.3 4.8 S Z245.1 3592 9930 W U 9 2.4
59986 - 7 1-9-38-7W5 WE 5-10-38-7W5 PL 1.1 O NG 0 114.3 4 S Z245.1 3592 4960 W U 8 2.3
59986 - 8 5-3-38-7W5 WE 4-10-38-7W5 PL 1.89 O NG 0 114.3 4 S Z245.1 3592 4960 W U 8 2.3
59986 - 9 13-10-38-7W5 PL 5-10-38-7W5 PL 1.02 P NG 0 130 15.5 G FPLP 601 9930 M U 1 1.9
59986 - 10 13-10-38-7W5 BE 15-9-38-7W5 BE 1.02 A NG 0 168.3 4 S Z245.1 3592 0 W U 1 RC 2.1
59986 - 11 5-10-38-7W5 WE 6-10-38-7W5 PL 0.53 O NG 0 114.3 4 S Z245.1 3592 4960 W U 8 2.2
60003 - 1 14-5-40-8W5 WE 11-5-40-8W5 PL 0.31 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2
60006 - 1 6-2-40-9W5 B 3-2-40-9W5 PL 0.54 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.1
60020 - 1 9-36-39-9W5 PL 4-1-40-9W5 PL 1.51 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.4
60041 - 1 3-3-39-5W5 WE 8-4-39-5W5 PL 1.48 P NG 0 97 10 G FPLP 301 4960 M U 2 1.9
60045 - 1 9-2-40-9W5 PL 8-2-40-9W5 PL 0.5 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.3
60062 - 1 7-18-37-7W5 PL 7-30-37-7W5 PL 3.62 O NG 0 168.3 4 S Z245.1 2901 9930 W U 24 CC 2.8
60151 - 1 10-28-39-8W5 WE 4-33-39-8W5 PL 1.23 P NG 0 101 12 G FPLP 601 9930 M U 2 2
60151 - 2 10-28-39-8W5 WE 4-33-39-8W5 PL 1.23 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
60221 - 1 1-26-41-7W5 WE 8-27-41-7W5 PL 2.28 P NG 0 101 12 G FPLP 601 9930 M U 2 2.1
60221 - 2 7-27-41-7W5 PL 3-27-41-7W5 PL 0.77 P NG 0 101 12 G FPLP 601 9930 M U 2 1.6
60221 - 3 8-27-41-7W5 PL 7-27-41-7W5 PL 0.11 P NG 0 101 12 G FPLP 601 9930 M U 1 1.6
60222 - 1 11-19-41-5W5 PL 15-15-41-6W5 PL 5.5 P NG 0 168.3 4 S Z245.1 3592 9930 W U 2 2.5
60222 - 2 2-19-41-5W5 PL 11-19-41-5W5 PL 1.03 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.1
60222 - 3 15-31-41-5W5 WE 11-19-41-5W5 PL 4.65 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.2
60222 - 4 11-31-41-5W5 WE 15-31-41-5W5 PL 0.72 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
60311 - 1 7-30-37-7W5 PL 6-25-37-8W5 PL 2.46 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.1
60311 - 2 16-8-37-7W5 WE 10-18-37-7W5 PL 3.26 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2.2
60311 - 3 14-6-37-7W5 WE 10-18-37-7W5 PL 2.97 P NG 0 130 15.5 G FPLP 601 9930 M U 2 2
60520 - 1 9-31-37-7W5 PL 16-35-37-8W5 PL 3.94 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.6
60520 - 2 12-31-37-7W5 PL 12-31-37-7W5 PL 0.04 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.2
60520 - 3 14-32-37-7W5 PL 9-31-37-7W5 PL 1.67 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.4
60520 - 4 3-5-38-7W5 PL 14-32-37-7W5 PL 0.12 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2
60520 - 5 1-9-38-7W5 WE 3-5-38-7W5 PL 4.33 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.4
60544 - 1 7-26-37-8W5 WE 15-26-37-8W5 PL 1.14 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2
57718 - 1 1-29-43-9W5 WE 4-32-43-9W5 PL 2.28 O NG 0 88.9 4 S Z245.1 2901 9930 W U 3 1.8
57718 - 2 13-29-43-9W5 WE 13-29-43-9W5 PL 0.09 O NG 0 88.9 4 S Z245.1 2901 9930 W U 3 1.8
59996 - 1 1-29-43-9W5 WE 6-21-43-9W5 B 1.72 P NG 0 130 15.5 G FPLP 601 9930 M U 2 1.5
45437 - 1 7-14-43-3W5 BE 6-23-43-3W5 BE 2.47 D OE 0 88.9 4 S Z245.1 2901 0 W U 14 1.8
53737 - 1 2-14-43-3W5 BE 7-14-43-3W5 BE 0.46 D OE 0 88.9 4.8 S Z245.1 3592 0 W U 7 1.7
54958 - 1 14-11-43-3W5 WE 2-14-43-3W5 B 0.74 O OE 0 88.9 4 S Z245.1 3592 9920 W U 6 1.9
58048 - 1 2-14-43-3W5 WE 10-11-43-3W5 PL 0.63 O NG 0 101 12 G FPLP 601 8270 M U 3 1.5
60062 - 2 12-20-37-7W5 B 16-19-37-7W5 PL 0.66 P NG 0 168.3 4 S Z245.1 3592 9930 W U not available 1 2
60062 - 3 16-19-37-7W5 PL 12-20-37-7W5 B 0.66 P NG 0 168.3 4 S Z245.1 3592 9930 W U 1 2.1
60062 - 4 12-20-37-7W5 B 16-19-37-7W5 PL 0.66 P NG 0 130 15.5 G FPLP 601 9930 M U 1 1.8
60062 - 5 16-19-37-7W5 PL 6-30-37-7W5 PL 1.1 P NG 0 130 15.5 G FPLP 601 9930 M U 1 1.9
60311 - 4 6-30-37-7W5 PL 6-30-37-7W5 PL 0.05 P NG 0 130 15.5 G FPLP 601 9930 M U 1 2.1
60311 - 8 13-10-037-07W5 13-01-037-07W5 4.03 O NG 0 168.3 S not available 0 CC 3.3
60311 - 5 13-01-037-07W5 14-06-037-07W5 2.13 O NG 0 168.3 S not available 0 2.8
10-18-037-07W5 12-20-037-07W5 3.62 O NG 0 168.3 S not available 0 3
Legend:
Length and size
Operating status
Material and coating
MOP
Elevation Profile
Age
Enviromental
Pipeline risk based on physical properties for Willesden Green
Status Substance Pipe Mat. Internal Coating Risks rating based on:
O = Operating OE = oil emulsion S = Steel U = uncoated
D = Discontinued NG = natural gas G = Composite L = Free Standing
C = Cement
R = Removed SG = sour natural gas V = Polyvinyl Chloride
A = Abandoned FW = fresh water A = Aluminium E = Expanded Polythylene
P = in construction SW = salt water P = Polythylene Y = (unexplained)
LV = LVP C = Cellulose Acetate Butyrate
H = Asbestos Cement
N = Not constructed FG = fuel gas F = Fibreglass
AER
License
segment
status
Total gas
prod.
(e3m
3/day)
Total oil
prod.
(m3/day)
Total water
prod.
(m3/day)
Total fluid
prod.
(m3/day)
Watercut(%)
Gas
Velocity(m/s)
Fluid
Velocity(m/s)
Mixed
Velocity(m/s)
Gas flow
regime
Fluid flow
regime
Operating
temp.(°C)
Operating
pressure(kPa)
Pigging(#/year)
Operational
Risk
19415 - 2 Active 2.9 0 6.9 6.9 100.0 0.25008 0.01493 0.26501 mist laminar 10 860 4 1.6
31390 - 2 Active 316.1 0 65.4 65.4 100.0 0.00683 0.0223 0.02913 mist turbulent 10 4965 4 1.9
31390 - 3 Active 94.2 0 20.7 20.7 100.0 0.00683 0.00706 0.01389 mist laminar 10 4965 4 1.8
42289 - 7 Active 136.8 0 0 0 0.0 0.01158 0 0.01158 mist no fluid 10 4925 4 1.9
42289 - 8 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
42289 - 9 Active 0.2 0 0 0 0.0 0.02692 0 0.02692 mist no fluid 10 4965 4 1.9
42289 - 10 Active 0.1 0 0 0 0.0 0.02612 0 0.02612 mist no fluid 10 4965 4 1.9
43702 - 1 Active 122.1 0 128.5 128.5 100.0 0.01149 0.07369 0.08518 mist turbulent 10 4965 4 1.9
43702 - 2 Active 0.1 0 0 0 0.0 0.02692 0 0.02692 mist no fluid 10 4965 4 1.9
43702 - 3 Active 0.3 0 0 0 0.0 0.01148 0 0.01148 mist no fluid 10 4965 4 1.9
43702 - 4 Active 5.3 0 0.2 0.2 100.0 0.1782 0.00027 0.17847 mist laminar 13 758 4 1.7
43702 - 5 Active 134.8 0 134.5 134.5 100.0 0.01149 0.07714 0.08862 mist turbulent 10 4965 4 1.9
43702 - 6 Active 136.4 0 134.5 134.5 100.0 0.01149 0.07714 0.08862 mist turbulent 10 4965 4 1.9
43702 - 7 Active 3.2 0 5.2 5.2 100.0 0.02692 0.00699 0.03391 mist laminar 10 4965 4 1.8
43702 - 8 Active 0 0.1 0 0.1 0.0 0 0.00023 0.00023 N/A laminar 10 4965 4 2.4
44436 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
46735 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
46735 - 2 Active 0.3 0 4.8 4.8 100.0 0.04693 0.01125 0.05818 mist laminar 10 4965 4 1.8
47376 - 1 Active 0.6 0 0 0 0.0 0.04523 0 0.04523 mist no fluid 10 4760 4 1.8
47376 - 2 Active 106.6 0 0 0 0.0 0.04523 0 0.04523 mist no fluid 10 4760 4 1.9
47376 - 3 Planned 102.3 0 65.4 65.4 100.0 0.03011 0.09833 0.12845 mist turbulent 10 4965 4 1.8
47376 - 4 Planned 106.6 0 0 0 0.0 0.03011 0 0.03011 mist no fluid 10 4965 4 1.4
48014 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
48160 - 1 Active 1.2 0 0.4 0.4 100.0 0.02692 0.00054 0.02746 mist laminar 10 4965 4 1.8
48695 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
52347 - 1 Active 123.8 0 128.2 128.2 100.0 0.10252 0.07352 0.17604 mist turbulent 17 570 4 2.1
52347 - 2 Active 3.5 0 0.1 0.1 100.0 0.10251 5.7E-05 0.10257 mist laminar 17 570 4 2
52744 - 2 Active 7.8 0 0 0 0.0 0.02612 0 0.02612 mist no fluid 10 4965 4 1.9
53228 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
53316 - 1 Active 0.2 0 0.2 0.2 100.0 0.04336 0.00043 0.04379 mist laminar 10 4965 4 1.8
53368 - 1 Active 0.3 0 0 0 0.0 0.04509 0 0.04509 mist no fluid 10 4965 4 1.9
53385 - 1 Active 0.6 0 0.2 0.2 100.0 0.04693 0.00047 0.0474 mist laminar 10 4965 4 1.8
53453 - 1 Active 2.3 0 4.8 4.8 100.0 0.02692 0.00645 0.03337 mist laminar 10 4965 4 1.8
53453 - 2 Active 0.6 0 0.1 0.1 100.0 0.04336 0.00022 0.04358 mist laminar 10 4965 4 1.8
53453 - 3 Active 0.3 0 0 0 0.0 0.04693 0 0.04693 mist no fluid 10 4965 4 1.9
53932 - 1 Active 109.3 0 0 0 0.0 0.01149 0 0.01149 mist no fluid 10 4965 14 1.6
54016 - 1 Active 6.7 0 7.6 7.6 100.0 0.01172 0.00445 0.01616 mist laminar 10 4965 4 1.8
54571 - 1 Active 0.7 0 0 0 0.0 0.02612 0 0.02612 mist no fluid 10 4965 4 1.8
54970 - 1 Active 6.7 0 7.6 7.6 100.0 0.01172 0.00445 0.01616 mist laminar 10 4965 4 1.8
55029 - 1 Active 16.2 0 8.4 8.4 100.0 0.01148 0.00482 0.0163 mist laminar 10 4965 4 1.8
55029 - 2 Active 16.2 0 8.4 8.4 100.0 0.01148 0.00482 0.0163 mist laminar 10 4965 4 1.8
55029 - 3 Active 31.9 0.3 9.3 9.6 96.9 0.04336 0.02079 0.06415 mist laminar 10 4965 4 2.3
55029 - 4 Active 28.8 0 6 6 100.0 0.04978 0.01491 0.06469 mist laminar 10 4965 4 1.8
55030 - 1 Active 109.3 0 0 0 0.0 0.01149 0 0.01149 mist no fluid 10 4965 4 1.9
55033 - 1 Active 236.5 34 19.4 53.4 36.3 0.02612 0.06964 0.09576 mist turbulent 10 4965 4 2.4
55063 - 1 Active 109.3 0 0 0 0.0 0.01149 0 0.01149 mist no fluid 10 4965 4 1.9
55063 - 2 Active 40.1 0 95.5 95.5 100.0 0.01149 0.05477 0.06625 mist turbulent 10 4965 4 1.9
55270 - 1 Active 1.3 0 0 0 0.0 0.02612 0 0.02612 mist no fluid 10 4965 4 1.9
55273 - 1 Active 6 0 0.1 0.1 100.0 0.02612 0.00013 0.02625 mist laminar 10 4965 4 1.8
55652 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 0 no 1.6
55895 - 1 Active 7.2 0 0.8 0.8 100.0 0.09027 0.0018 0.09207 mist laminar 10 2480 4 1.7
56048 - 1 Active 3.1 0 0.1 0.1 100.0 0.09027 0.00023 0.0905 mist laminar 10 2480 4 1.7
56068 - 1 Active 1.7 0 4.2 4.2 100.0 0.04509 0.00946 0.05455 mist laminar 10 4965 4 1.8
56261 - 1 Active 0.3 0 0.1 0.1 100.0 0.04509 0.00023 0.04532 mist laminar 10 4965 4 1.8
56302 - 1 Active 0.9 0 0.3 0.3 100.0 0.09027 0.00068 0.09095 mist laminar 10 2480 4 1.7
56545 - 1 Active 4 0 0.5 0.5 100.0 0.04336 0.00108 0.04444 mist laminar 10 4965 4 1.8
57466 - 1 Active 12.8 0 58.5 58.5 100.0 0.10525 0.15326 0.25851 mist turbulent 10 2475 4 1.7
57486 - 1 Active 2 0 0.7 0.7 100.0 0.04509 0.00158 0.04667 mist laminar 10 4965 4 1.8
57591 - 1 Active 0 0 0 0 0.0 0 0 0 N/A no fluid 10 4965 4 2.1
57601 - 1 Active 34.8 0 94 94 100.0 0.04509 0.21165 0.25675 mist turbulent 10 4965 4 1.9
57873 - 1 Active 4.2 0 0.5 0.5 100.0 0.02692 0.00067 0.02759 mist laminar 10 4965 4 1.8
57873 - 2 Active 0.3 0 0 0 0.0 0.02692 0 0.02692 mist no fluid 10 4965 4 1.9
58050 - 1 Active 12.8 0 58.5 58.5 100.0 0.20348 0.2963 0.49977 mist turbulent 10 2475 4 1.8
58050 - 2 Active 12.8 0 58.5 58.5 100.0 0.21479 0.31278 0.52757 mist turbulent 10 2475 4 1.8
58050 - 3 Active 12.8 0 58.5 58.5 100.0 0.21479 0.31278 0.52757 mist turbulent 10 2475 4 1.8
58050 - 4 Active 12.8 0 58.5 58.5 100.0 0.21479 0.31278 0.52757 mist turbulent 10 2475 4 1.8
58050 - 5 Active 12.8 0 58.5 58.5 100.0 0.21495 0.31301 0.52797 mist turbulent 10 2475 4 1.8
58418 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
58419 - 1 Active 7.2 0 3.5 3.5 100.0 0.04977 0.0087 0.05847 mist laminar 10 4965 4 1.8
58419 - 2 Active 11.4 0 10.1 10.1 100.0 0.04977 0.0251 0.07488 mist laminar 10 4965 4 1.8
58515 - 1 Active 10.6 0 8.4 8.4 100.0 0.02612 0.01095 0.03707 mist laminar 10 4965 4 1.8
58515 - 2 Active 10.6 0 8.4 8.4 100.0 0.02612 0.01095 0.03707 mist laminar 10 4965 4 1.8
58515 - 3 Active 10.6 0 8.4 8.4 100.0 0.02612 0.01095 0.03707 mist laminar 10 4965 4 1.8
58739 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
58743 - 1 Active 1.6 5.6 4.7 10.3 45.6 0.04977 0.0256 0.07538 mist laminar 10 4965 4 2.3
58932 - 1 Active 44.4 0 263.8 263.8 100.0 0.05516 0.65568 0.71084 mist turbulent 10 4480 4 1.9
59026 - 1 Active 2.9 0 6.9 6.9 100.0 0.28736 0.01715 0.30451 mist laminar 10 860 4 1.6
59079 - 1 Active 213.1 34 0 34 0.0 0.02612 0.04434 0.07046 mist turbulent 10 4965 4 2.1
59259 - 1 Active 0 0 0 0 0.0 0 0 0 N/A no fluid 10 4965 4 2.1
59260 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
59263 - 1 Active 17.8 0 19.4 19.4 100.0 0.04977 0.04822 0.09799 mist transitional 10 4965 4 1.8
59530 - 1 Active 4.5 0 5.4 5.4 100.0 0.09965 0.01342 0.11307 mist laminar 10 2480 4 1.7
59541 - 1 Active 6.7 0 3.5 3.5 100.0 0.04977 0.0087 0.05847 mist laminar 10 4965 4 1.8
59552 - 1 Active 0.6 0 0 0 0.0 0.06147 0 0.06147 mist no fluid 10 4020 no 2.2
59556 - 1 Active 1 0 27.7 27.7 100.0 0.04977 0.06885 0.11862 mist turbulent 10 4965 4 1.9
59587 - 1 Active 526.7 0 201.8 201.8 100.0 0.01149 0.11573 0.12722 mist turbulent 10 4965 4 1.9
59787 - 1 Active 10 0 58.4 58.4 100.0 0.09985 0.14515 0.245 mist turbulent 10 2475 4 1.7
59806 - 1 Active 26.5 0 84.9 84.9 100.0 0.03011 0.12765 0.15776 mist turbulent 10 4965 4 1.9
59891 - 1 Active 99.1 0 127.3 127.3 100.0 0.02612 0.16602 0.19214 mist turbulent 10 4965 4 1.9
59892 - 1 Active 45.5 0 14.2 14.2 100.0 0.03011 0.02135 0.05146 mist laminar 10 4965 4 1.8
59916 - 1 Planned 34.9 0 26.6 26.6 100.0 0.01148 0.01525 0.02674 mist laminar 10 4965 4 1.7
59918 - 1 Planned 80.1 0 53.2 53.2 100.0 0.04978 0.13223 0.18201 mist turbulent 10 4965 4 1.8
59924 - 1 Planned 4.1 0 25.2 25.2 100.0 0.03011 0.03789 0.068 mist transitional 10 4965 4 1.7
59941 - 1 Planned 3.3 6.8 2.3 9.1 25.3 0.09965 0.02262 0.12227 mist laminar 10 2480 4 2.1
59943 - 1 Planned 22.2 0 12.2 12.2 100.0 0.03011 0.01834 0.04845 mist laminar 10 4965 4 1.7
59943 - 2 Planned 22.2 0 12.2 12.2 100.0 0.03011 0.01834 0.04845 mist laminar 10 4965 4 1.7
59959 - 1 Planned 88.5 0 118.9 118.9 100.0 0.01149 0.06819 0.07967 mist turbulent 10 4965 4 1.8
59959 - 2 Planned 2.8 0 53.5 53.5 100.0 0.04977 0.13297 0.18275 mist turbulent 10 4965 no 2.1
59959 - 3 Planned 85.7 0 65.4 65.4 100.0 0.01149 0.03751 0.04899 mist turbulent 10 4965 4 1.8
59959 - 4 Planned 10.7 0 5.6 5.6 100.0 0.04977 0.01392 0.06369 mist laminar 10 4965 4 1.7
59959 - 5 Planned 0.7 0 0.2 0.2 100.0 0.04977 0.0005 0.05027 mist laminar 10 4965 4 1.7
59959 - 6 Planned 67.9 0 57.3 57.3 100.0 0.01149 0.03286 0.04435 mist turbulent 10 4965 4 1.8
59959 - 7 Planned 74.6 0 59.7 59.7 100.0 0.01149 0.03424 0.04572 mist turbulent 10 4965 4 1.8
59970 - 1 Planned 34.9 0 26.6 26.6 100.0 0.01148 0.01525 0.02674 mist laminar 10 4965 4 1.7
59971 - 1 Planned 94.2 0 20.7 20.7 100.0 0.03011 0.03112 0.06124 mist transitional 10 4965 4 1.7
59976 - 1 Planned 563.6 0 213.6 213.6 100.0 0.01149 0.1225 0.13399 mist turbulent 10 4965 4 1.8
59986 - 1 Active 10.7 0 3.6 3.6 100.0 0.01148 0.00206 0.01355 mist laminar 10 4965 4 1.8
59986 - 2 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
59986 - 3 Active 10.7 0 3.6 3.6 100.0 0.01148 0.00206 0.01355 mist laminar 10 4965 4 1.8
59986 - 4 Active 10.7 0 3.6 3.6 100.0 0.01172 0.00211 0.01382 mist laminar 10 4965 4 1.8
59986 - 5 Active 10.7 0 3.6 3.6 100.0 0.01172 0.00211 0.01382 mist laminar 10 4965 4 1.8
59986 - 7 Active 8.5 0 0.1 0.1 100.0 0.05229 0.00013 0.05242 mist laminar 10 2480 4 1.7
59986 - 8 Active 8.5 0 0.1 0.1 100.0 0.05229 0.00013 0.05242 mist laminar 10 2480 4 1.7
59986 - 9 Planned 10.7 0 3.6 3.6 100.0 0.03011 0.00541 0.03552 mist laminar 10 4965 4 1.7
59986 - 10 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
59986 - 11 Active 19.2 0 3.7 3.7 100.0 0.05229 0.00483 0.05711 mist laminar 10 2480 4 1.7
60003 - 1 Planned 22.2 0 12.2 12.2 100.0 0.03011 0.01834 0.04845 mist laminar 10 4965 4 1.7
60006 - 1 Planned 675.3 0 0 0 0.0 0.03469 0 0.03469 mist no fluid 53 4965 4 1.8
60020 - 1 Planned 410.2 0 86.1 86.1 100.0 0.01149 0.04938 0.06087 mist turbulent 10 4965 4 1.8
60041 - 1 Planned 41.5 0 5.1 5.1 100.0 0.09965 0.01268 0.11233 mist laminar 10 2480 4 1.6
60045 - 1 Planned 34.9 0 26.6 26.6 100.0 0.01148 0.01525 0.02674 mist laminar 10 4965 4 1.7
60062 - 1 Active 213.1 34 0 34 0.0 0.01149 0.0195 0.03099 mist transitional 10 4965 4 2
60151 - 1 Planned 106.6 0 0 0 0.0 0.04978 0 0.04978 mist no fluid 10 4965 4 1.4
60151 - 2 Planned 106.6 0 0 0 0.0 0.03011 0 0.03011 mist no fluid 10 4965 4 1.4
60221 - 1 Planned 5.3 0 0 0 0.0 0.04977 0 0.04977 mist no fluid 10 4965 4 1.4
60221 - 2 Planned 5.3 0 0 0 0.0 0.04977 0 0.04977 mist no fluid 10 4965 4 1.4
60221 - 3 Planned 5.3 0 0 0 0.0 0.04977 0 0.04977 mist no fluid 10 4965 4 1.4
60222 - 1 Planned 55.4 0 57.1 57.1 100.0 0.01149 0.03275 0.04423 mist turbulent 10 4965 4 1.8
60222 - 2 Planned 11.4 0 10.1 10.1 100.0 0.03011 0.01519 0.0453 mist laminar 10 4965 4 1.7
60222 - 3 Planned 44 0 47 47 100.0 0.03011 0.07067 0.10078 mist turbulent 10 4965 4 1.8
60222 - 4 Planned 0 0 0 0 0.0 0 0 0 N/A no fluid 10 4965 4 1.3
60311 - 1 Planned 213.1 34 0 34 0.0 0.03011 0.05112 0.08124 mist turbulent 10 4965 4 2
60311 - 2 Planned 103 0 0 0 0.0 0.03011 0 0.03011 mist no fluid 10 4965 4 1.4
60311 - 3 Planned 110.1 34 0 34 0.0 0.03011 0.05112 0.08123 mist turbulent 10 4965 4 2
60520 - 1 Planned 16.3 0 0.1 0.1 100.0 0.01148 5.7E-05 0.01154 mist laminar 10 4965 4 1.7
60520 - 2 Planned 7.8 0 0 0 0.0 0.01148 0 0.01148 mist no fluid 10 4965 4 1.4
60520 - 3 Planned 8.5 0 0.1 0.1 100.0 0.01148 5.7E-05 0.01154 mist laminar 10 4965 4 1.7
60520 - 4 Planned 8.5 0 0.1 0.1 100.0 0.01148 5.7E-05 0.01154 mist laminar 10 4965 4 1.7
60520 - 5 Planned 8.5 0 0.1 0.1 100.0 0.01148 5.7E-05 0.01154 mist laminar 10 4965 4 1.7
60544 - 1 Planned 213.1 34 0 34 0.0 0.03011 0.05112 0.08124 mist turbulent 10 4965 4 2
57718 - 1 Active 46.2 0 0.8 0.8 100.0 0.04509 0.0018 0.04689 mist laminar 10 4965 4 1.8
57718 - 2 Active 33.5 0 0.7 0.7 100.0 0.04509 0.00158 0.04667 mist laminar 10 4965 4 1.8
59996 - 1 Planned 12.7 0 0.1 0.1 100.0 0.03011 0.00015 0.03026 mist laminar 10 4965 4 1.7
45437 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
53737 - 1 Inactive 0 0 0 0 0.0 0 0 0 N/A no fluid 10 0 no 1.7
54958 - 1 Active 0 0 0 0 0.0 0 0 0 N/A no fluid 10 4960 4 2.1
58048 - 1 Active 2.1 0 1 1 100.0 0.05977 0.00249 0.06225 mist laminar 10 4135 4 1.8
60062 - 2 Planned 55 0 0.1 0.1 100.0 0.01153 5.7E-05 0.01158 mist laminar 11 4965 4 1.8
60062 - 3 Planned 55 0 0.1 0.1 100.0 0.01157 5.7E-05 0.01162 mist laminar 12 4965 4 1.8
60062 - 4 Planned 55 0 0.1 0.1 100.0 0.03043 0.00015 0.03058 mist laminar 13 4965 no 2.1
60062 - 5 Planned 55 0 0.1 0.1 100.0 0.03054 0.00015 0.03069 mist laminar 14 4965 no 2.1
60311 - 4 Planned 55 0 0.1 0.1 100.0 0.03064 0.00015 0.03079 mist laminar 15 4965 no 2.1
60311 - 8 Active 0 0 0 0 0.0 0 0 0 N/A no fluid 16 4965 4 1.5
60311 - 5 Active 0 0 0 0 0.0 0 0 0 N/A no fluid 17 4965 4 1.5
Active 0 0 0 0 0.0 0 0 0 N/A no fluid 18 4965 4 1.5
Production and % of total production Production issues (ie Deadlegs) Flow regimes pigging schedule
Water Cut Production Velocities Operating temp and pressures
Pipeline risk based on operation of the Willesden Green field
Risks rating based on:
AER
License
from
locationpH
(@ 25°C)
Chlorides(ppm)
TDS(ppm)
Iron(ppm)
Manganese(ppm)
Bacteria
ATP(pg/mL)
Bacteria
Dilution(cfu/mL)
H2S
(%)
CO2
(mol frac.)
deWaard
Milliams
Corr.
Coupon(mpy)
Chemical
Corrosion
Risk19415 - 2 8-23-40-6W5 B 7.5 10,000 18,500 30 0.5 3,000 0 0.0104 0.697 2.3
31390 - 2 11-33-39-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
31390 - 3 3-36-39-9W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
42289 - 7 2-4-42-7W5 CS 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
42289 - 8 10-4-42-7W5 BE 0 1.7
42289 - 9 2-15-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
42289 - 10 5-11-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.500 2.3
43702 - 1 11-21-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 0.045 1.8
43702 - 2 11-4-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
43702 - 3 6-3-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
43702 - 4 12-29-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0208 0.741 2.4
43702 - 5 7-29-41-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 0.172 1.9
43702 - 6 12-33-41-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 0.101 1.8
43702 - 7 8-19-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
43702 - 8 1-33-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.500 2.3
44436 - 1 14-22-41-7W5 BE 0 1.7
46735 - 1 13-17-41-7W5 BE 0 1.7
46735 - 2 5-20-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
47376 - 1 4-4-40-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
47376 - 2 4-33-39-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
47376 - 3 4-4-40-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
47376 - 4 4-33-39-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
48014 - 1 16-25-39-7W5 BE 0 1.7
48160 - 1 13-20-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
48695 - 1 13-19-40-6W5 BE 0 1.7
52347 - 1 8-3-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0237 0.762 2.4
52347 - 2 13-35-40-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0237 0.762 2.4
52744 - 2 5-31-37-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53228 - 1 13-31-37-7W5 BE 0 1.7
53316 - 1 4-28-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53368 - 1 2-29-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53385 - 1 8-30-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53453 - 1 13-16-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53453 - 2 12-16-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53453 - 3 15-20-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53932 - 1 1-35-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
54016 - 1 3-11-38-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
54571 - 1 1-9-41-7W5 WE 0 1.7
54970 - 1 3-11-38-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55029 - 1 16-35-37-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 0.046 1.8
55029 - 2 16-2-38-8W5 B 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55029 - 3 15-35-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55029 - 4 2-2-38-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55030 - 1 3-34-37-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55033 - 1 15-26-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55063 - 1 16-35-37-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55063 - 2 1-35-37-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55270 - 1 4-12-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55273 - 1 1-11-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
55652 - 1 1-15-41-6W5 BE 0 1.7
55895 - 1 4-7-39-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
56048 - 1 16-8-39-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
56068 - 1 4-2-38-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
56261 - 1 3-28-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
56302 - 1 11-11-39-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
56545 - 1 13-31-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57466 - 1 10-35-41-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57486 - 1 13-11-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57591 - 1 1-35-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57601 - 1 2-35-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57873 - 1 2-31-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57873 - 2 4-10-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58050 - 1 4-14-42-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58050 - 2 10-2-42-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58050 - 3 14-2-42-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58050 - 4 14-2-42-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58050 - 5 4-11-42-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58418 - 1 8-16-41-6W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58419 - 1 6-18-41-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58419 - 2 14-18-41-5W5 WE 0 1.7
58515 - 1 16-25-39-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58515 - 2 14-13-40-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58515 - 3 11-12-40-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58739 - 1 1-2-40-9W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58743 - 1 3-21-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58932 - 1 8-10-40-8W5 WE 0 1.7
59026 - 1 13-13-40-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59079 - 1 6-25-37-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59259 - 1 15-31-41-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59260 - 1 6-2-40-9W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59263 - 1 7-26-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59530 - 1 14-8-41-6W5 WE 0 1.7
59541 - 1 14-7-38-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59552 - 1 4-4-40-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.500 2
59556 - 1 15-36-39-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59587 - 1 4-1-40-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59787 - 1 3-2-42-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59806 - 1 8-34-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59891 - 1 4-12-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59892 - 1 10-30-39-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59916 - 1 14-6-40-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59918 - 1 14-33-39-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59924 - 1 12-28-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59941 - 1 1-19-42-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59943 - 1 11-5-40-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59943 - 2 4-4-40-8W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59959 - 1 14-7-41-6W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 2 15-7-41-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 3 1-17-41-6W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 4 15-8-41-6W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 5 2-15-41-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 6 11-15-41-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59959 - 7 8-16-41-6W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59970 - 1 11-6-40-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59971 - 1 1-36-39-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59976 - 1 1-2-40-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
59986 - 1 3-23-38-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 2 5-23-38-7W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 3 12-14-38-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 4 9-15-38-7W5 B 0 1.7
59986 - 5 12-14-38-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 7 1-9-38-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 8 5-3-38-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 9 13-10-38-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59986 - 10 13-10-38-7W5 BE 0 1.7
59986 - 11 5-10-38-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60003 - 1 14-5-40-8W5 WE 0 1.7
60006 - 1 6-2-40-9W5 B 7.5 10000 18500 30 0.5 3000 0 0.0059 0.806 2
60020 - 1 9-36-39-9W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
60041 - 1 3-3-39-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60045 - 1 9-2-40-9W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
60062 - 1 7-18-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60151 - 1 10-28-39-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
60151 - 2 10-28-39-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0059 0.671 2
60221 - 1 1-26-41-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60221 - 2 7-27-41-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60221 - 3 8-27-41-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60222 - 1 11-19-41-5W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60222 - 2 2-19-41-5W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60222 - 3 15-31-41-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60222 - 4 11-31-41-5W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60311 - 1 7-30-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60311 - 2 16-8-37-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60311 - 3 14-6-37-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60520 - 1 9-31-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60520 - 2 12-31-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60520 - 3 14-32-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60520 - 4 3-5-38-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60520 - 5 1-9-38-7W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60544 - 1 7-26-37-8W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57718 - 1 1-29-43-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
57718 - 2 13-29-43-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
59996 - 1 1-29-43-9W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
45437 - 1 7-14-43-3W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
53737 - 1 2-14-43-3W5 BE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
54958 - 1 14-11-43-3W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
58048 - 1 2-14-43-3W5 WE 7.5 10000 18500 30 0.5 3000 0 0.0104 0.697 2.3
60062 - 2 12-20-37-7W5 B 7.5 10000 18500 30 0.5 3000 0 0.0104 0.700 2.3
60062 - 3 16-19-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.704 2.3
60062 - 4 12-20-37-7W5 B 7.5 10000 18500 30 0.5 3000 0 0.0104 0.707 2.3
60062 - 5 16-19-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.711 2.3
60311 - 4 6-30-37-7W5 PL 7.5 10000 18500 30 0.5 3000 0 0.0104 0.714 2.3
60311 - 8 13-10-037-07W5 7.5 10000 18500 30 0.5 3000 0 0.0104 0.717 2.3
60311 - 5 13-01-037-07W5 7.5 10000 18500 30 0.5 3000 0 0.0104 0.721 2.3
10-18-037-07W5 7.5 10000 18500 30 0.5 3000 0 0.0104 0.724 2.3
low pH Iron concentration H2S concentration Corrosion coupon data
chlorides concentration Manganese concentration CO2 Concentration
TDS concentration Bacteria levels (Serial or ATP) DeWaard
Pipeline risk based on analysis results of the Willesden Green field
Risks rating based on:
Send Location Receive LocationPipelines
Covered
Line
Length
(km)
Line
OD
(mm)
Wall
Thickness
(mm)
Treat.
Type
Batch
Chemical
Film
Thickness
(MIL)
Chem.
Vol
(L)
Diluent
(L)
Inj. Rate
(L/day)
Treatment
Frequency
Treatment
ReconciliationComments
11-33-39-8W5 PL 9-36-39-9W5 PL 31390 - 2 4.23 219.1 5.6 inj C1218 continous review risks annually sales gas from 02-04
3-36-39-9W5 PL 9-36-39-9W5 PL 31390 - 3 1.24 219.1 5.6 film C1210 3 93 85 quarterly review risks annually
4-4-40-8W5 WE 11-33-39-8W5 PL 47376 - 1 1.7 88.9 3.2 inj C1218 6 continous Identified parameter risk
4-33-39-8W5 WE 11-33-39-8W5 PL 47376 - 2 0.6 88.9 3.2 film C1210 3 75 69 quarterly review risks annually sales gas from 16-02
4-4-40-8W5 PL 11-33-39-8W5 PL 47376 - 3 1.14 130 15.5 Not a bare steel pipeline proximity to Cow Lake; sales gas from 16-02
4-33-39-8W5 PL 11-33-39-8W5 PL 47376 - 4 0.49 130 15.5 Not a bare steel pipeline
1-2-40-9W5 BE 13-2-40-9W5 BE 58739 - 1 1.72 101 12 Line is not operated
8-10-40-8W5 WE 1-15-40-8W5 PL 58932 - 1 1.85 101 12 Not a bare steel pipeline
6-2-40-9W5 BE 1-2-40-9W5 BE 59260 - 1 1.01 101 12 Line is not operated
4-4-40-8W5 WE 4-4-40-8W5 PL 59552 - 1 0.17 101 12 Not a bare steel pipeline
4-1-40-9W5 WE 1-2-40-9W5 PL 59587 - 1 1.06 168.3 4 inj C1218 continous review risks annually
10-30-39-8W5 WE 1-36-39-9W5 PL 59892 - 1 1.77 130 15.5 Not a bare steel pipeline proximity to North Sakatchewan River
14-33-39-8W5 WE 14-33-39-8W5 PL 59918 - 1 0.37 101 12 Not a bare steel pipeline treated via injection at 11-15 & 16-25
11-6-40-8W5 WE 8-2-40-9W5 PL59970-1; 59916-
1; 60045-13.19 168.3 4 film C1210 3 90 82 quarterly review risks annually
1-36-39-9W5 WE 3-36-39-9W5 PL 59971 - 1 1 130 15.5 Not a bare steel pipeline proximity to Cow Lake; combined with 54970
1-2-40-9W5 WE 6-2-40-9W5 B 59976 - 1 1.03 168.3 4 inj C1218 continous Identified parameter risk
14-5-40-8W5 WE 4-4-40-8W5 PL60003-1;
59943-1&22.1 130 15.5 Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-1,3,4,5
6-2-40-9W5 B 3-2-40-9W5 PL 60006 - 1 0.54 130 15.5 Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-2,1,4,5
9-36-39-9W5 PL 4-1-40-9W5 PL 60020 - 1 1.51 168.3 4 inj C1218 continous Identified chemical risks Proximity to North Saskatchewan River; Combined with 58050-2,3,1,5
10-28-39-8W5 WE 4-33-39-8W5 PL 60151 - 1 1.23 101 12 Not a bare steel pipeline combined with 58515-2,1; treated via injection at 16-25
10-28-39-8W5 WE 4-33-39-8W5 PL 60151 - 2 1.23 130 15.5 Not a bare steel pipeline
WEST Batch Table (2020)
Send Location Receive LocationPipelines
Covered
Line
Length
(km)
Line
OD
(mm)
Wall
Thickness
(mm)
Treat.
Type
Batch
Chemical
Film
Thickness
(MIL)
Chem.
Vol
(L)
Diluent
(L)
Inj. Rate
(L/day)
Treatment
Frequency
Treatment
ReconciliationComments
8-23-40-6W5 B 6-19-40-5W5 PL 19415 - 2 2.4 88.9 3.18 review risks annually
5-31-37-7W5 WE 12-31-37-7W5 PL 52744-2; 60520-2 0.39 114.3 4 film C1210 3 20 20 quarterly Multiple risks
13-31-37-7W5 BE 12-31-37-7W5 BE 53228 - 1 0.73 88.9 4 Line is not operated
1-35-37-8W5 WE 3-34-37-8W5 PL 53932 - 1 2.94 168.3 4 review risks annually
3-11-38-8W5 WE 16-2-38-8W5 B 54016-1; 54970-1 1.01 168.3 4.8 film C1210 3 25 23 quarterly review risks annually
16-35-37-8W5 PL 16-2-38-8W5 B 55029 - 1 2.7 168.3 4 film C1210 3 67 61 quarterly review risks annually
16-2-38-8W5 B 16-35-37-8W5 PL 55029 - 2 2.7 168.3 4 review risks annually
15-35-37-8W5 WE 16-35-37-8W5 PL 55029 - 3 0.27 88.9 3.2 review risks annually
2-2-38-8W5 WE 15-35-37-8W5 PL 55029 - 4 0.32 101 12 Not a bare steel pipeline
3-34-37-8W5 PL 1-33-37-8W5 PL 55030 - 1 0.59 168.3 4 review risks annually
16-35-37-8W5 PL 1-35-37-8W5 PL 55063 - 1 1.53 168.3 4 review risks annually
1-35-37-8W5 PL 16-35-37-8W5 PL 55063 - 2 1.53 168.3 4 review risks annually lines has been discontinued
4-7-39-5W5 WE 13-6-39-5W5 PL 55895 - 1 0.49 88.9 4 review risks annually
16-8-39-5W5 WE 7-8-39-5W5 PL 56048 - 1 1.03 88.9 4 review risks annually
4-2-38-8W5 WE 16-35-37-8W5 PL 56068 - 1 1.4 88.9 4 review risks annually
11-11-39-5W5 WE 12-11-39-5W5 PL 56302 - 1 0.27 88.9 4 review risks annually
10-35-41-8W5 WE 10-2-42-8W5 PL 57466 - 1 2.44 91 8 Not a bare steel pipeline
2-35-37-8W5 WE 1-35-37-8W5 PL 57601 - 1 0.19 88.9 4 film C1210 3 26 24 quarterly review risks annually
10-2-42-8W5 WE 10-15-42-8W5 S 58050-2,3,4,5,1 3.82 60.3 3.9 film C1210 3 44 40 quarterly review risks annually
13-13-40-6W5 WE 8-23-40-6W5 PL 59026 - 1 1.1 101 12 Not a bare steel pipeline
6-25-37-8W5 PL 7-26-37-8W5 PL 59079 - 1 1.1 114.3 4 film C1210 3 149 135 quarterly review risks annually treated via injection at 03-23
7-26-37-8W5 WE 15-26-37-8W5 PL 59263 - 1 1.14 101 12 Not a bare steel pipeline
14-7-38-6W5 WE 3-18-38-6W5 PL 59541 - 1 0.67 101 12 Not a bare steel pipeline
15-36-39-6W5 WE 10-36-39-6W5 PL 59556 - 1 0.41 101 12 Not a bare steel pipeline
3-2-42-8W5 WE 6-2-42-8W5 PL 59787 - 1 0.51 97 10 Not a bare steel pipeline
8-34-37-8W5 WE 2-35-37-8W5 PL 59806 - 1 1.49 130 15.5 Not a bare steel pipeline
12-28-37-8W5 WE 1-34-37-8W5 PL 59924 - 1 3.75 130 15.5 Not a bare steel pipeline treated via injection at 11-15 & 16-25; Big Beaver Crossing
1-19-42-7W5 WE 14-17-42-7W5 PL 59941 - 1 1.14 101 12 Not a bare steel pipeline treated via injection at 11-15 & 16-25
3-23-38-7W5 WE 12-14-38-7W5 PL 59986 - 1 1.33 168.3 4 inj C1218 7 continous Identified parameter risk proximity to Cow Lake; combined with 54016
5-23-38-7W5 BE 3-23-38-7W5 BE 59986 - 2 0.84 114.3 3.2 Line is not operated proximity to Cow Lake
12-14-38-7W5 PL 13-10-38-7W5 PL 59986 - 3 2.52 168.3 4 inj C1218 continous Environmental risk
9-15-38-7W5 B 12-14-38-7W5 PL 59986 - 4 0.09 168.3 4.8 inj C1218 continous Multiple risks
12-14-38-7W5 PL 9-15-38-7W5 B 59986 - 5 0.09 168.3 4.8 inj C1218 continous Identified parameter risk
1-9-38-7W5 WE 5-10-38-7W5 PL 59986 - 7 1.1 114.3 4 inj C1218 continous Identified parameter risk proximity to Big Beaver Creek
5-3-38-7W5 WE 4-10-38-7W5 PL 59986 - 8 1.89 114.3 4 film C1210 3 37 34 quarterly Identified chemical risks
13-10-38-7W5 PL 5-10-38-7W5 PL 59986 - 9 1.02 130 15.5 inj C1218 continous Not a bare steel pipeline
13-10-38-7W5 BE 15-9-38-7W5 BE 59986 - 10 1.02 168.3 4 Line is not operated
5-10-38-7W5 WE 6-10-38-7W5 PL 59986 - 11 0.53 114.3 4 Identified parameter risk Proximity to North Saskatchewan River; Combined with 58050-2,3,4,5
3-3-39-5W5 WE 8-4-39-5W5 PL 60041 - 1 1.48 97 10 Not a bare steel pipeline Proximity to North Saskatchewan River; Combined with 58050-2,3,4,1
7-18-37-7W5 PL 7-30-37-7W5 PL 60062 - 1 3.62 168.3 4 film C1210 3 210 191 quarterly Environmental risk combined with 58515-1,3; treated via injection at 16-25
7-30-37-7W5 PL 6-25-37-8W5 PL 60311 - 1 2.46 130 15.5 Not a bare steel pipeline treated via injection at 11-15
16-8-37-7W5 WE 10-18-37-7W5 PL 60311 - 2 3.26 130 15.5 Not a bare steel pipeline Combined with 59916 & 60045
14-6-37-7W5 WE 10-18-37-7W5 PL 60311 - 3 2.97 130 15.5 Not a bare steel pipeline treated via injection at 04-04
9-31-37-7W5 PL 16-35-37-8W5 PL 60520 - 1 3.94 168.3 4 inj C1218 continous Identified parameter risk proximity to Clearwater Creek; treated via injection at 03-23
14-32-37-7W5 PL 9-31-37-7W5 PL 60520 - 3 1.67 168.3 4 inj C1218 continous review risks annually proximity to Clearwater Creek; treated via injection at 03-23
3-5-38-7W5 PL 14-32-37-7W5 PL 60520 - 4 0.12 168.3 4 inj C1218 continous Identified parameter risk proximity to Clearwater Creek; treated via injection at 03-23
1-9-38-7W5 WE 3-5-38-7W5 PL 60520 - 5 4.33 168.3 4 inj C1218 continous Multiple risks treated via injection at 03-23
7-26-37-8W5 WE 15-26-37-8W5 PL 60544 - 1 1.14 130 15.5 Not a bare steel pipeline
12-20-37-7W5 B 16-19-37-7W5 PL 60062 - 2 0.66 168.3 4 film C1210 20 20 quarterly Identified parameter risk cant find on ABADATA
16-19-37-7W5 PL 12-20-37-7W5 B 60062 - 3 0.66 168.3 4 film C1210 20 20 quarterly Identified parameter risk
12-20-37-7W5 B 16-19-37-7W5 PL 60062 - 4 0.66 130 15.5 Not a bare steel pipeline
16-19-37-7W5 PL 6-30-37-7W5 PL 60062 - 5 1.1 130 15.5 Not a bare steel pipeline
6-30-37-7W5 PL 6-30-37-7W5 PL 60311 - 4 0.05 130 15.5 Not a bare steel pipeline
13-10-037-07W5 13-01-037-07W5 4.03 168.3 film C1210 85 85 quarterly new line
13-01-037-07W5 14-06-037-07W5 2.13 168.3 film C1210 45 45 quarterly new line
10-18-037-07W5 12-20-037-07W5 3.62 168.3 film C1210 76 76 quarterly new line
SOUTH Batch Table (2020)
Send Location Receive LocationPipelines
Covered
Line
Length
(km)
Line
OD
(mm)
Wall
Thickness
(mm)
Treat.
Type
Batch
Chemical
Film
Thickness
(MIL)
Chem.
Vol
(L)
Diluent
(L)
Inj. Rate
(L/day)
Treatment
Frequency
Treatment
ReconciliationComments
2-4-42-7W5 CS 10-33-41-7W5 PL 42289 - 7 0.65 168.3 4 review risks annually
2-15-42-7W5 WE 4-10-42-7W5 PL 42289 - 9 2.78 114.3 4.8 film C1210 3 39 35 quarterly Environmental risk
5-11-42-7W5 WE 4-10-42-7W5 PL 42289 - 10 2.5 114.3 4 Environmental risk
11-21-41-7W5 WE 7-29-41-7W5 PL 43702 - 1 2.38 168.3 4 inj C1218 continous review risks annually
11-4-42-7W5 WE 2-4-42-7W5 CS 43702 - 2 1.1 114.3 4.8 review risks annually
6-3-42-7W5 WE 2-4-42-7W5 CS 43702 - 3 1.8 168.3 4 review risks annually
12-29-41-7W5 WE 7-29-41-7W5 PL 43702 - 4 0.81 114.3 4.8 review risks annually
7-29-41-7W5 PL 12-33-41-7W5 PL 43702 - 5 2.25 168.3 4 inj C1218 continous Environmental risk
12-33-41-7W5 PL 2-4-42-7W5 CS 43702 - 6 1.42 168.3 4 inj C1218 continous review risks annually
8-19-41-7W5 WE 7-29-41-7W5 PL 43702 - 7 2.8 114.3 4.8 film C1210 3 41 37 quarterly Environmental risk
1-33-41-7W5 WE 10-33-41-7W5 PL 43702 - 8 0.91 88.9 4 Environmental risk
14-22-41-7W5 BE 11-21-41-7W5 BE 44436 - 1 1.52 60.3 3.2 Line is not operated
13-17-41-7W5 BE 8-19-41-7W5 BE 46735 - 1 0.7 88.9 4 Line is not operated
5-20-41-7W5 WE 8-19-41-7W5 PL 46735 - 2 0.22 88.9 4.8 film C1210 3 20 20 quarterly review risks annually
13-20-41-7W5 WE 15-20-41-7W5 PL 48160 - 1 0.54 114.3 4.8 review risks annually sales gas from 16-02
8-3-41-7W5 WE 11-21-41-7W5 PL 52347 - 1 1.1 168.3 4 film C1210 3 104 95 quarterly Environmental risk
13-35-40-7W5 WE 8-3-41-7W5 PL 52347 - 2 2.36 168.3 4 film C1210 3 52 47 quarterly review risks annually
4-28-41-7W5 WE 4-28-41-7W5 PL 53316 - 1 0.19 88.9 3.2 review risks annually
2-29-41-7W5 WE 2-29-41-7W5 PL 53368 - 1 0.12 88.9 4 Multiple risks
8-30-41-7W5 WE 12-29-41-7W5 PL 53385 - 1 1.11 88.9 4.8 film C1210 3 20 20 quarterly review risks annually
13-16-41-7W5 WE 4-28-41-7W5 PL 53453 - 1 2.05 114.3 4.8 film C1210 3 30 27 quarterly review risks annually
12-16-41-7W5 WE 13-16-41-7W5 PL 53453 - 2 0.71 88.9 3.2 review risks annually
15-20-41-7W5 WE 15-20-41-7W5 PL 53453 - 3 0.37 88.9 4.8 film C1210 3 20 20 quarterly review risks annually
1-9-41-7W5 WE 16-9-41-7W5 PL 54571 - 1 1.47 114.3 4 film C1210 3 21 20 quarterly Environmental risk treated via injection at 14-18
4-12-41-7W5 WE 1-11-41-7W5 PL 55270 - 1 0.61 114.3 4 inj C1218 20 20 continous review risks annually
1-11-41-7W5 WE 1-10-41-7W5 PL 55273 - 1 1.63 114.3 4 film C1210 3 26 24 quarterly Environmental risk
1-15-41-6W5 BE 3-15-41-6W5 BE 55652 - 1 0.63 88.9 4 Line is not operated
3-28-41-7W5 WE 4-28-41-7W5 PL 56261 - 1 0.61 88.9 4 review risks annually
13-31-41-7W5 WE 2-31-41-7W5 PL 56545 - 1 1.63 88.9 3.2 film C1210 3 20 20 quarterly review risks annually
13-11-41-7W5 WE 8-10-41-7W5 PL 57486 - 1 1.23 88.9 4 film C1210 3 20 20 quarterly Identified parameter risk
2-31-41-7W5 WE 8-32-41-7W5 PL 57873 - 1 2.3 114.3 4.8 review risks annually
4-10-42-7W5 WE 6-3-42-7W5 PL 57873 - 2 1.41 114.3 4.8 review risks annually
8-16-41-6W5 BE 15-9-41-6W5 BE 58418 - 1 1.1 101 12 Line is not operated
6-18-41-5W5 WE 14-18-41-5W5 PL 58419 - 1 0.75 101 12 inj C1218 continous Not a bare steel pipeline
14-18-41-5W5 WE 2-19-41-5W5 PL 58419 - 2 0.98 101 12 inj C1218 9 continous Not a bare steel pipeline
16-25-39-7W5 WE 4-12-41-7W5 PL 58515-1,2,3 15.44 114.3 4 inj C1218 4 continous review risks annually
3-21-41-7W5 WE 13-16-41-7W5 B 58743 - 1 0.53 101 12 Not a bare steel pipeline
15-31-41-5W5 WE 16-31-41-5W5 PL 59259 - 1 0.28 88.9 3.2 film C1210 3 20 20 quarterly review risks annually
14-8-41-6W5 WE 15-8-41-6W5 PL 59530 - 1 0.28 101 12 Not a bare steel pipeline
4-12-41-7W5 WE 1-10-41-7W5 PL 59891 - 1 2.23 114.3 4 inj C1218 continous Identified parameter risk treated via injection at 04-04
14-7-41-6W5 PL 4-12-41-7W5 PL 59959 - 1 3.17 168.3 4 inj C1218 continous review risks annually treated via injection at 04-04 (inj based on surface)
15-7-41-6W5 WE 15-7-41-6W5 PL 59959 - 2 0.44 101 12 Not a bare steel pipeline
1-17-41-6W5 PL 15-7-41-6W5 PL 59959 - 3 2.86 168.3 4 inj C1218 continous Identified parameter risk partially treated via injection at 11-15 & 16-25 (1km will be batched)
15-8-41-6W5 PL 2-17-41-6W5 PL 59959 - 4 0.31 101 12 Not a bare steel pipeline batch volume includes appr. 1km of the 52347-1 segment
2-15-41-6W5 WE 11-15-41-6W5 PL 59959 - 5 1.12 101 12 Not a bare steel pipeline Combined with 60520-2
11-15-41-6W5 WE 8-16-41-6W5 PL 59959 - 6 2.12 168.3 4 inj C1218 continous Identified parameter risk proximity to North Saskatewan River
8-16-41-6W5 WE 4-16-41-6W5 PL 59959 - 7 2.07 168.3 4 inj C1218 continous Environmental risk proximity to Little Beaver Creek
1-26-41-7W5 WE 8-27-41-7W5 PL 60221 - 1 2.28 101 12 Not a bare steel pipeline confirm operating status
7-27-41-7W5 PL 3-27-41-7W5 PL 60221 - 2 0.77 101 12 Not a bare steel pipeline treated via injection at 04-04
8-27-41-7W5 PL 7-27-41-7W5 PL 60221 - 3 0.11 101 12 Not a bare steel pipeline treated via injection at 11-15 & 16-25
11-19-41-5W5 PL 15-15-41-6W5 PL 60222 - 1 5.5 168.3 4 inj C1218 continous Identified parameter risk Combined with 59970 & 60045
2-19-41-5W5 PL 11-19-41-5W5 PL 60222 - 2 1.03 130 15.5 Not a bare steel pipeline treated via injection at 11-15
15-31-41-5W5 WE 11-19-41-5W5 PL 60222 - 3 4.65 130 15.5 Not a bare steel pipeline treated via injection at 11-15
11-31-41-5W5 WE 15-31-41-5W5 PL 60222 - 4 0.72 130 15.5 Not a bare steel pipeline treated via injection at 11-15
1-29-43-9W5 WE 4-32-43-9W5 PL 57718 - 1 2.28 88.9 4 Identified chemical risks treated via injection at 03-23
13-29-43-9W5 WE 13-29-43-9W5 PL 57718 - 2 0.09 88.9 4 Identified parameter risk treated via injection at 04-04
1-29-43-9W5 WE 6-21-43-9W5 B 59996 - 1 1.72 130 15.5 Not a bare steel pipeline Combined with 59916 & 59970
7-14-43-3W5 BE 6-23-43-3W5 BE 45437 - 1 2.47 88.9 4 Line is not operated crosses Prairie Creek
2-14-43-3W5 BE 7-14-43-3W5 BE 53737 - 1 0.46 88.9 4.8 Line is not operated
14-11-43-3W5 WE 2-14-43-3W5 B 54958 - 1 0.74 88.9 4 film C1210 3 20 20 May/Nov Identified chemical risks combined with 52744-2
2-14-43-3W5 WE 10-11-43-3W5 PL 58048 - 1 0.63 101 12 Not a bare steel pipeline treated via injection at 03-23
NORTH Batch Table (2020)
SYSTEM OVERVIEW
Local Authorities Involvement FERRIER
Local Authorities Involvement
TypeName
The local authority is an MD, County, Indian Reserve, Municipality or Special Area in which the
property is located or may impact. The involvement of the local authority will vary depending on
where the incident has occurred, as the preparedness, response capability, and willingness to
participate will vary across the province. The company's primary responsibility is to manage the
public safety measures within the hazard area or defined EPZ. Support from the local authority
may be provided within these areas, however, is primarily focused on the areas beyond should the
incident escalate and pose a threat to the public. The local authority can usually be expected to
provide assistance with public safety measure, evacuations, roadblocks, and general
communications with members of the public.
The local authorities defined for this property and their declared limits of support are:
Local Authorities
Date Contacted
MOUNTAIN VIEW County 5/19/2020 10:41:00AM
Mountain View County will provide basic support in the event of an emergency with
roadblocks, including aspects of both physical barricades and personnel. In the
event of an evacuation, it is essential to contact the Mountain View County Alberta
Emergency Management for coordination purposes. For 24-hour emergency contact
the Emergency Liaison Officers by cell, (403) 586-0040, or 911.
The County can dispatch primary support services of between 2 and 10 personnel.
The County has a number of 4X4 vehicles. As they do their own road maintenance a
variety of heavy equipment would also be available. Communications within the
County during an emergency are through cell phones or mobile radios.
Mountain View County has requested that 1 digital copy (CD or USB) of any ERP
with which they're associated, be sent to their mailing address upon completion.
Support Role:
PONOKA County 6/9/2020 10:21:00AM
The County can provide assistance if an emergency were to reach beyond the
scope of the company's capabilities to effectively manage. Assistance roles and
responsibilities may include roadblock equipment and personnel, evacuation
assistance and coordination, and activation of various predetermined evacuation
centres.
Though the County of Ponoka will provide some assistance, it is their expectation
that industry take the lead role when it comes to such things as well blow-outs. Any
incident requiring formal response should be reported to Dennis Jones (Regional
Fire a Chief & DEM) and/or Charlie Cutforth (CAO & DDEM).
Numerous assorted roadblock equipment and signage is kept both in Ponoka, and
Rimbey. A mobile command centre with Hazmat and decontamination capability is
also stored in Ponoka, This includes Heavy equipment and assorted vehicles may
be available if needed and include loaders, gravel trucks, road graders, CAT
scrapers, trailers, and 4x4 trucks. A community spill response trailer is also available
through the fire services.
The County through FCSS keeps an inventory and contact list of community centres
that may be used as evacuation centres in the case of an emergency. The particular
Support Role:
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YANGARRA RESOURCES LTD. Page 1 of 4
Local Authorities Involvement FERRIER
centre used at any given time would depend on the location of the emergency.
The core administration and supervisory team (6 people) would be able to assist in
an emergency.
The primary communication method within the County would be by cell phone.
Coverage is pretty good across the county, though there are some dead spots. All
personnel have cell phones. Both fire services have digital/analog radios and all
public works staff have analog radios as well.
Ponoka has their own Emergency Response Manual in place, included is a section
that deals with the oil and gas industry. Ponoka County would like a hard or digital
copy of all company ERP's. Digital copies can be sent to
dennisjones@ponokacounty.com
CLEARWATER County 3/9/2020 4:07:00PM
Emergency Contacts
Main
Clearwater County Office 24 Hour Manager On-call Number: (403) 844-8500
Christine Heggart (DEM)
Office: (403) 845-4444
Cell: (403) 844-8500
Fire Chief
24 Hour on call cell: (403) 845-2200
Clearwater County requests your Emergency Response Plan reflects the following
roles and responsibilities of our jurisdiction.
-Initiates and manages the local disaster services response in accordance with
County Policy
-May dispatch representative(s) to the Government’s off-site Emergency
Coordination Centre
-Ensures all local emergency services and resources are available in accordance
with County Policy
-If required, activates the Municipal Emergency Operation Centre and coordinates
activities at this centre
-May assist with set up and maintenance of road blocks in accordance with County
Policy
-Assists with Fire Protection in accordance with County Policy
-If necessary, may declare a State of Local Emergency (SOLE) to provide local
authorities with special powers
-Supports the Company in dealing with the emergency in accordance with County
Policy.
The County will require a copy of all AER approved plans. Digital copies are
sufficient and can be sent to lmorrish@clearwatercounty.ca.
Support Role:
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Date ContactedTypeName
Municipalities Impacted by the EPZ
Support Role:
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Pipeline InformationYANGARRA RESOURCES LTD. NORTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
019415002 YANGARRA RESOURCES CORP. 08-23-040-06W5 B 06-19-040-05W5 PL NG 1720 0 O 2.40 88.9 3.18 S 5LX X42 W 8
042289007 YANGARRA RESOURCES CORP. 02-04-042-07W5 CS 10-33-041-07W5 PL NG 9850 0 O 0.65 168.3 4.00 S Z245.1 3591 W 58
042289008 YANGARRA RESOURCES CORP. 10-04-042-07W5 BE 11-04-042-07W5 BE NG 0 0 D 0.42 114.3 4.80 S Z245.1 3592 W 33
042289009 YANGARRA RESOURCES CORP. 02-15-042-07W5 WE 04-10-042-07W5 PL NG 9930 0 O 2.78 114.3 4.80 S Z245.1 3592 W 33 CC
042289010 YANGARRA RESOURCES CORP. 05-11-042-07W5 WE 04-10-042-07W5 PL NG 9930 0 D 2.50 114.3 4.00 S Z245.1 3592 W 40 CC
043702001 YANGARRA RESOURCES CORP. 11-21-041-07W5 WE 07-29-041-07W5 PL NG 9930 2.00 O 2.38 168.3 4.00 S Z245.1 3591 W 58
043702002 YANGARRA RESOURCES CORP. 11-04-042-07W5 WE 02-04-042-07W5 CS NG 9930 2.00 O 1.10 114.3 4.80 S Z245.1 3591 W 33
043702003 YANGARRA RESOURCES CORP. 06-03-042-07W5 WE 02-04-042-07W5 CS NG 9930 2.00 O 1.80 168.3 4.00 S Z245.1 3591 W 58
043702004 YANGARRA RESOURCES CORP. 12-29-041-07W5 WE 07-29-041-07W5 PL NG 9930 2.00 O 0.81 114.3 4.80 S Z245.1 3591 W 33
043702005 YANGARRA RESOURCES CORP. 07-29-041-07W5 PL 12-33-041-07W5 PL NG 9930 2.00 O 2.25 168.3 4.00 S Z245.1 3591 W 58 CC
043702006 YANGARRA RESOURCES CORP. 12-33-041-07W5 PL 02-04-042-07W5 CS NG 9930 2.00 O 1.42 168.3 4.00 S Z245.1 3591 W 58
043702007 YANGARRA RESOURCES CORP. 08-19-041-07W5 WE 07-29-041-07W5 PL NG 9930 2.00 O 2.80 114.3 4.80 S Z245.1 3592 W 33 CC
043702008 YANGARRA RESOURCES CORP. 01-33-041-07W5 WE 10-33-041-07W5 PL NG 9930 2.00 O 0.91 88.9 4.00 S Z245.1 3591 W 31 CC
044436001 YANGARRA RESOURCES CORP. 14-22-041-07W5 BE 11-21-041-07W5 BE NG 0 0 D 1.52 60.3 3.20 S Z245.1 2901 W 32
045437001 YANGARRA RESOURCES CORP. 07-14-043-03W5 BE 06-23-043-03W5 BE OE 0 0 D 2.47 88.9 4.00 S Z245.1 2901 W 38
046735001 YANGARRA RESOURCES CORP. 13-17-041-07W5 BE 08-19-041-07W5 BE NG 0 2.00 D 0.70 88.9 4.00 S Z245.1 3592 W 31
046735002 YANGARRA RESOURCES CORP. 05-20-041-07W5 WE 08-19-041-07W5 PL NG 9930 2.00 O 0.22 88.9 4.80 S Z245.1 3592 W 26 UN
048014001 YANGARRA RESOURCES CORP. 16-25-039-07W5 BE 13-30-039-06W5 BE NG 0 0 D 0.34 114.3 4.00 S Z245.1 3592 W 0
048160001 YANGARRA RESOURCES CORP. 13-20-041-07W5 WE 15-20-041-07W5 PL NG 9930 0 O 0.54 114.3 4.80 S Z245.1 3592 W 33
048695001 YANGARRA RESOURCES CORP. 13-19-040-06W5 BE 02-30-040-06W5 BE NG 0 0 D 1.38 88.9 3.20 S Z245.1 3592 W 38
052347001 YANGARRA RESOURCES CORP. 08-03-041-07W5 WE 11-21-041-07W5 PL NG 9930 0 O 8.10 168.3 4.00 S Z245.1 3592 W 58 CC
052347002 YANGARRA RESOURCES CORP. 13-35-040-07W5 WE 08-03-041-07W5 PL NG 9930 0 O 1.36 168.3 4.00 S Z245.1 3592 W 58
053316001 YANGARRA RESOURCES CORP. 04-28-041-07W5 WE 04-28-041-07W5 PL NG 9930 0 O 0.19 88.9 3.20 S Z245.1 3592 W 38
053368001 YANGARRA RESOURCES CORP. 02-29-041-07W5 WE 02-29-041-07W5 PL NG 9930 2.00 O 0.12 88.9 4.00 S Z245.1 3592 W 31
053385001 YANGARRA RESOURCES CORP. 08-30-041-07W5 WE 12-29-041-07W5 PL NG 9930 2.00 O 1.11 88.9 4.80 S Z245.1 3592 W 26
053453001 YANGARRA RESOURCES CORP. 13-16-041-07W5 WE 04-28-041-07W5 PL NG 9930 0 O 2.05 88.9 4.00 S Z245.1 3592 W 31
053453002 YANGARRA RESOURCES CORP. 12-16-041-07W5 WE 13-16-041-07W5 PL NG 9930 0 O 0.71 88.9 4.00 S Z245.1 3592 W 31
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Pipeline InformationYANGARRA RESOURCES LTD. NORTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
053453003 YANGARRA RESOURCES CORP. 15-20-041-07W5 WE 15-20-041-07W5 PL NG 9930 0 O 0.37 88.9 4.80 S Z245.1 3592 W 26
053737001 YANGARRA RESOURCES CORP. 02-14-043-03W5 BE 07-14-043-03W5 BE OE 0 0 D 0.46 88.9 4.80 S Z245.1 3592 W 26
054571001 YANGARRA RESOURCES CORP. 01-09-041-07W5 WE 16-09-041-07W5 PL NG 9930 0 O 1.47 114.3 4.00 S Z245.1 3592 W 40 CC
054958001 YANGARRA RESOURCES CORP. 14-11-043-03W5 WE 02-14-043-03W5 B OE 9920 0 O 0.74 88.9 4.00 S Z245.1 3592 W 31
055270001 YANGARRA RESOURCES CORP. 04-12-041-07W5 WE 01-11-041-07W5 PL NG 9930 0 O 0.61 114.3 4.00 S Z245.1 3592 W 40
055273001 YANGARRA RESOURCES CORP. 01-11-041-07W5 WE 01-10-041-07W5 PL NG 9930 0 O 1.63 114.3 4.00 S Z245.1 3592 W 40 CC
055652001 YANGARRA RESOURCES CORP. 01-15-041-06W5 BE 03-15-041-06W5 BE NG 0 0 D 0.63 88.9 4.00 S Z245.1 3592 W 30
056261001 YANGARRA RESOURCES CORP. 03-28-041-07W5 WE 04-28-041-07W5 PL NG 9930 0 O 0.61 88.9 4.00 S Z245.1 3592 W 31
056545001 YANGARRA RESOURCES CORP. 13-31-041-07W5 WE 02-31-041-07W5 PL NG 9930 0 O 1.63 88.9 4.00 S Z245.1 3592 W 31
057486001 YANGARRA RESOURCES CORP. 13-11-041-07W5 WE 08-10-041-07W5 PL NG 9930 0 O 1.23 88.9 4.00 S Z245.1 3592 W 31
057718001 YANGARRA RESOURCES CORP. 01-29-043-09W5 WE 04-32-043-09W5 PL NG 9930 0 O 2.28 88.9 4.00
057718002 YANGARRA RESOURCES CORP. 13-29-043-09W5 WE 13-29-043-09W5 PL NG 9930 0 O 0.09 88.9 4.00
057873001 YANGARRA RESOURCES CORP. 02-31-041-07W5 WE 08-32-041-07W5 PL NG 9930 2.00 O 2.30 114.3 4.80 S Z245.1 3592 W 33
057873002 YANGARRA RESOURCES CORP. 04-10-042-07W5 WE 06-03-042-07W5 PL NG 9930 2.00 O 1.41 114.3 4.80 S Z245.1 3592 W 33
058048001 YANGARRA RESOURCES CORP. 02-14-043-03W5 WE 10-11-043-03W5 PL NG 8270 0 O 0.63 101.0 12.00 G FPLP 601 M 0
058418001 YANGARRA RESOURCES CORP. 08-16-041-06W5 WE 15-09-041-06W5 PL NG 9930 0 D 1.10 101.0 12.00 G FPLP 601 M 0
058419001 YANGARRA RESOURCES CORP. 06-18-041-05W5 WE 14-18-041-05W5 PL NG 9930 0 O 0.75 101.0 12.00 G FPLP 601 M 0
058419002 YANGARRA RESOURCES CORP. 14-18-041-05W5 WE 02-19-041-05W5 PL NG 9930 0 O 0.98 101.0 12.00 G FPLP 601 M 0
058515001 YANGARRA RESOURCES CORP. 16-25-039-07W5 WE 06-12-040-07W5 PL NG 9930 0 O 5.10 114.3 4.00 S Z245.1 3592 W 40
058515002 YANGARRA RESOURCES CORP. 14-13-040-07W5 PL 04-12-041-07W5 PL NG 9930 0 O 8.15 114.3 4.00 S Z245.1 3592 W 40 CC
058515003 YANGARRA RESOURCES CORP. 11-12-040-07W5 PL 14-13-040-07W5 PL NG 9930 0 O 2.19 114.3 4.00 S Z245.1 3592 W 40
058743001 YANGARRA RESOURCES CORP. 03-21-041-07W5 WE 13-16-041-07W5 B OE 9930 0 O 0.53 101.0 12.00 G FPLP 601 M 0
058811001 YANGARRA RESOURCES CORP. 16-03-044-10W5 BE 16-03-044-10W5 BE NG 0 0 D 0.15 101.0 12.00 G FPLP 601 M 0
059001001 YANGARRA RESOURCES CORP. 16-03-044-10W5 CS 07-03-044-10W5 PL NG 9930 0 O 0.92 88.9 4.00 S Z245.1 3592 W 31
059026001 YANGARRA RESOURCES CORP. 13-13-040-06W5 WE 08-23-040-06W5 PL NG 1720 0 O 1.10 97.0 10.00 G FPLP 301 M 0
059259001 YANGARRA RESOURCES CORP. 15-31-041-05W5 WE 16-31-041-05W5 PL NG 9930 0 D 0.28 88.9 4.00 S Z245.1 2901 W 38
059530001 YANGARRA RESOURCES CORP. 14-08-041-06W5 WE 15-08-041-06W5 PL NG 4960 0 O 0.28 101.0 12.00
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Pipeline InformationYANGARRA RESOURCES LTD. NORTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
059556001 YANGARRA RESOURCES CORP. 15-36-039-06W5 WE 10-36-039-06W5 PL NG 9930 0 O 0.41 101.0 12.00 G FPLP 601 M
059787001 YANGARRA RESOURCES CORP. 03-02-042-08W5 WE 06-02-042-08W5 PL NG 4950 0 O 0.51 97.0 10.00 G FPLP 301 M
059891001 YANGARRA RESOURCES CORP. 04-12-041-07W5 WE 01-10-041-07W5 PL NG 9930 0 O 2.23 130.0 15.50 G FPLP 601 M
059941001 YANGARRA RESOURCES CORP. 01-19-042-07W5 WE 14-17-042-07W5 PL OE 4960 0 O 1.14 101.0 12.00 G FPLP 601 M
059959001 YANGARRA RESOURCES CORP. 14-07-041-06W5 PL 04-12-041-07W5 PL NG 9930 0 O 3.17 168.3 4.00 S Z245.1 3592 W 58
059959002 YANGARRA RESOURCES CORP. 15-07-041-06W5 WE 15-07-041-06W5 PL NG 9930 0 O 0.44 101.0 12.00 G FPLP 601 M
059959003 YANGARRA RESOURCES CORP. 01-17-041-06W5 PL 15-07-041-06W5 PL NG 9930 0 O 2.86 168.3 4.00 S Z245.1 3592 W 58
059959004 YANGARRA RESOURCES CORP. 15-08-041-06W5 PL 02-17-041-06W5 PL NG 9930 0 O 0.31 101.0 12.00 G FPLP 601 M
059959005 YANGARRA RESOURCES CORP. 02-15-041-06W5 WE 11-15-041-06W5 PL NG 9930 0 O 1.12 101.0 12.00 G FPLP 601 M
059959006 YANGARRA RESOURCES CORP. 11-15-041-06W5 WE 08-16-041-06W5 PL NG 9930 0 O 2.12 168.3 4.00 S Z245.1 3592 W 58
059959007 YANGARRA RESOURCES CORP. 08-16-041-06W5 WE 04-16-041-06W5 PL NG 9930 0 O 2.07 168.3 4.00 S Z245.1 3592 W 58 C
059996001 YANGARRA RESOURCES CORP. 01-29-043-09W5 WE 06-21-043-09W5 B NG 9930 0 O 1.72 130.0 15.50 G FPLP 601 M
060221001 YANGARRA RESOURCES CORP. 01-26-041-07W5 WE 08-27-041-07W5 PL NG 9930 0 O 2.28 101.0 12.00 G FPLP 601 M
060221002 YANGARRA RESOURCES CORP. 07-27-041-07W5 PL 03-27-041-07W5 PL NG 9930 0 O 0.77 101.0 12.00 G FPLP 601 M
060221003 YANGARRA RESOURCES CORP. 08-27-041-07W5 PL 07-27-041-07W5 PL NG 9930 0 O 0.11 101.0 12.00 G FPLP 601 M
060222001 YANGARRA RESOURCES CORP. 11-19-041-05W5 PL 15-15-041-06W5 PL NG 9930 0 O 5.50 168.3 4.00 S Z245.1 3592 W 58
060222002 YANGARRA RESOURCES CORP. 02-19-041-05W5 PL 11-19-041-05W5 PL NG 9930 0 O 1.03 130.0 15.50 G FPLP 601 M
060222003 YANGARRA RESOURCES CORP. 15-31-041-05W5 WE 11-19-041-05W5 PL NG 9930 0 O 4.65 130.0 15.50 G FPLP 601 M
060222004 YANGARRA RESOURCES CORP. 11-31-041-05W5 WE 15-31-041-05W5 PL NG 9930 0 O 0.72 130.0 15.50 G FPLP 601 M
060446001 YANGARRA RESOURCES CORP. 07-03-044-10W5 PL 13-34-043-10W5 B NG 9930 0 O 1.91 130.0 15.50 G FPLP 601 M
060446002 YANGARRA RESOURCES CORP. 13-34-043-10W5 B 07-03-044-10W5 PL NG 9930 0 O 1.91 130.0 15.50 G FPLP 601 M
060809001 YANGARRA RESOURCES CORP. 11-30-043-07W5 WE 10-30-043-07W5 PL NG 3450 0 O 0.68 97.0 10.00 G FPLP 301 M
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S FERRIER SYSTEM PIPELINE LIST
Pipeline InformationYANGARRA RESOURCES LTD. SOUTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
037170001 YANGARRA RESOURCES CORP. 07-28-033-01W5 BE 15-29-033-01W5 BE NG 0 0 D 1.63 88.9 12.17 P 3408 9 B 50
052744002 YANGARRA RESOURCES CORP. 05-31-037-07W5 WE 12-31-037-07W5 PL NG 9930 0 O 0.35 114.3 4.00 S Z245.1 3592 W 40
053228001 YANGARRA RESOURCES CORP. 13-31-037-07W5 BE 12-31-037-07W5 BE OE 0 0 D 0.73 88.9 4.00 S Z245.1 3592 W 31
053932001 YANGARRA RESOURCES CORP. 01-35-037-08W5 WE 03-34-037-08W5 PL NG 9930 0 O 2.94 168.3 4.00 S Z245.1 3592 W 58
054016001 YANGARRA RESOURCES CORP. 03-11-038-08W5 WE 03-11-038-08W5 PL NG 9930 0 O 0.19 168.3 4.80 S Z245.1 3592 W 48
054970001 YANGARRA RESOURCES LTD. 03-11-038-08W5 PL 16-02-038-08W5 B NG 9930 0 O 0.82 168.3 4.80 S Z245.1 3592 W 48
055029001 YANGARRA RESOURCES CORP. 16-35-037-08W5 PL 16-02-038-08W5 B NG 9930 0 O 2.70 168.3 4.00 S Z245.1 2901 W 72
055029002 YANGARRA RESOURCES CORP. 16-02-038-08W5 B 16-35-037-08W5 PL NG 9930 0 O 2.70 168.3 4.00 S Z245.1 2901 W 72
055029003 YANGARRA RESOURCES CORP. 15-35-037-08W5 WE 16-35-037-08W5 PL NG 9930 0 O 0.27 88.9 4.00 S Z245.1 3592 W 31
055029004 YANGARRA RESOURCES CORP. 02-02-038-08W5 WE 15-35-037-08W5 PL NG 9930 0 O 0.32 101.0 12.00 G FPLP 601 M 0
055030001 YANGARRA RESOURCES CORP. 03-34-037-08W5 PL 01-33-037-08W5 PL NG 9930 0 O 0.59 168.3 4.00 S Z245.1 3592 W 58
055033001 YANGARRA RESOURCES CORP. 15-26-037-08W5 WE 01-35-037-08W5 PL NG 9930 0 O 0.77 114.3 4.00 S Z245.1 3592 W 40
055033002 YANGARRA RESOURCES CORP. 15-26-037-08W5 WE 01-35-037-08W5 PL NG 9930 0 P 0.77 130.0 15.50 G FPLP 601 M
055063001 YANGARRA RESOURCES CORP. 16-35-037-08W5 PL 01-35-037-08W5 PL NG 9930 0 O 1.53 168.3 4.00 S Z245.1 2901 W 72
055063002 YANGARRA RESOURCES CORP. 01-35-037-08W5 PL 16-35-037-08W5 PL NG 9930 0 O 1.53 168.3 4.00 S Z245.1 2901 W 72
055895001 YANGARRA RESOURCES CORP. 04-07-039-05W5 WE 13-06-039-05W5 PL NG 4960 0 O 0.49 88.9 4.00 S Z245.1 3592 W 15
056048001 YANGARRA RESOURCES CORP. 16-08-039-05W5 WE 07-08-039-05W5 PL NG 4960 0 O 1.03 88.9 4.00 S Z245.1 3592 W 15
056068001 YANGARRA RESOURCES CORP. 04-02-038-08W5 WE 16-35-037-08W5 PL NG 9930 0 O 1.40 88.9 4.00 S Z245.1 3592 W 31
056302001 YANGARRA RESOURCES CORP. 11-11-039-05W5 WE 12-11-039-05W5 PL NG 4960 0 O 0.27 88.9 4.00 S Z245.1 3592 W 15
057591001 YANGARRA RESOURCES CORP. 01-35-037-08W5 WE 01-35-037-08W5 PL NG 9930 0 O 0.07 88.9 4.00 S Z245.1 2901 W 38
057601001 YANGARRA RESOURCES CORP. 02-35-037-08W5 WE 01-35-037-08W5 PL NG 9930 0 O 0.19 88.9 4.00 S Z245.1 2901 W 38
059079001 YANGARRA RESOURCES CORP. 06-25-037-08W5 PL 07-26-037-08W5 PL NG 9930 0 O 1.10 114.3 4.00 S Z245.1 3592 W 40
059263001 YANGARRA RESOURCES CORP. 07-26-037-08W5 WE 15-26-037-08W5 PL NG 9930 0 O 1.14 101.0 12.00 G FPLP 601 M 0
059541001 YANGARRA RESOURCES CORP. 14-07-038-06W5 WE 03-18-038-06W5 PL NG 9930 0 O 0.67 101.0 12.00 G FPLP 601 M
059806001 YANGARRA RESOURCES CORP. 08-34-037-08W5 WE 02-35-037-08W5 PL NG 9930 0 O 1.49 130.0 15.50 G FPLP 601 M
059924001 YANGARRA RESOURCES CORP. 12-28-037-08W5 WE 01-34-037-08W5 PL NG 9930 0 O 3.75 130.0 15.50 G FPLP 601 M
059986001 YANGARRA RESOURCES CORP. 03-23-038-07W5 WE 12-14-038-07W5 PL NG 9930 0 O 1.33 168.3 4.00 S Z245.1 3592 W 58
Monday, June 15, 2020 Page 1 of 4
Pipeline InformationYANGARRA RESOURCES LTD. SOUTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
059986002 YANGARRA RESOURCES CORP. 05-23-038-07W5 BE 03-23-038-07W5 BE NG 0 0 D 0.84 114.3 3.20 S Z245.1 3592 W 0 C
059986003 YANGARRA RESOURCES CORP. 12-14-038-07W5 PL 13-10-038-07W5 PL NG 9930 0 O 3.54 168.3 4.00 S Z245.1 3592 W 58 R
059986004 YANGARRA RESOURCES CORP. 09-15-038-07W5 B 12-14-038-07W5 PL NG 9930 0 O 0.09 168.3 4.80 S Z245.1 3592 W 48
059986005 YANGARRA RESOURCES CORP. 12-14-038-07W5 PL 09-15-038-07W5 B NG 9930 0 O 0.09 168.3 4.80 S Z245.1 3592 W 48
059986007 YANGARRA RESOURCES CORP. 05-10-038-07W5 WE 01-09-038-07W5 PL NG 4960 0 O 1.63 114.3 4.00 S Z245.1 3592 W 20
059986008 YANGARRA RESOURCES CORP. 05-03-038-07W5 WE 04-10-038-07W5 PL NG 4960 0 O 1.89 114.3 4.00 S Z245.1 3592 W 20
059986009 YANGARRA RESOURCES CORP. 13-10-038-07W5 PL 05-10-038-07W5 PL NG 9930 0 O 1.02 130.0 15.50 G FPLP 601 M
059986010 YANGARRA RESOURCES CORP. 13-10-038-07W5 BE 15-09-038-07W5 BE NG 0 0 A 1.02 168.3 4.00 S Z245.1 3592 W 0 R
059986011 YANGARRA RESOURCES CORP. 05-10-038-07W5 BE 06-10-038-07W5 BE NG 0 0 A 0.53 114.3 4.00 S Z245.1 3592 W 0
060041001 YANGARRA RESOURCES CORP. 03-03-039-05W5 WE 08-04-039-05W5 PL NG 4960 0 O 1.48 97.0 10.00 G FPLP 301 M 0
060062001 YANGARRA RESOURCES CORP. 07-18-037-07W5 PL 07-30-037-07W5 PL NG 9930 0 O 3.62 168.3 4.00 S Z245.1 2901 W 0 C
060062002 YANGARRA RESOURCES CORP. 12-20-037-07W5 B 16-19-037-07W5 PL NG 9930 0 O 0.66 168.3 4.00 S Z245.1 3592 W 58
060062003 YANGARRA RESOURCES CORP. 16-19-037-07W5 PL 12-20-037-07W5 B NG 9930 0 O 0.66 168.3 4.00 S Z245.1 3592 W 58
060062004 YANGARRA RESOURCES CORP. 12-20-037-07W5 B 16-19-037-07W5 PL NG 9930 0 O 0.66 130.0 15.50 G FPLP 601 M
060062005 YANGARRA RESOURCES CORP. 16-19-037-07W5 PL 06-30-037-07W5 PL NG 9930 0 O 1.10 130.0 15.50 G FPLP 601 M
060311001 YANGARRA RESOURCES CORP. 07-30-037-07W5 PL 06-25-037-08W5 PL NG 9930 0 O 2.46 130.0 15.50 G FPLP 601 M
060311002 YANGARRA RESOURCES CORP. 16-08-037-07W5 WE 10-18-037-07W5 PL NG 9930 0 O 3.26 130.0 15.50 G FPLP 601 M
060311003 YANGARRA RESOURCES CORP. 14-06-037-07W5 WE 10-18-037-07W5 PL NG 9930 0 O 2.97 130.0 15.50 G FPLP 601 M
060311004 YANGARRA RESOURCES CORP. 06-30-037-07W5 PL 06-30-037-07W5 PL NG 9930 0 O 0.05 130.0 15.50 G FPLP 601 M
060311005 YANGARRA RESOURCES CORP. 13-01-037-08W5 WE 14-06-037-07W5 PL NG 9930 0 O 2.13 168.3 4.00 S Z245.1 3592 W 58
060311006 YANGARRA RESOURCES CORP. 14-06-037-07W5 WE 10-18-037-07W5 PL NG 9930 0 O 2.97 130.0 15.50 G FPLP 601 M C
060311007 YANGARRA RESOURCES CORP. 05-17-037-07W5 WE 10-18-037-07W5 PL NG 9930 0 O 1.21 168.3 4.00 S Z245.1 3592 W 58
060311008 YANGARRA RESOURCES CORP. 13-10-037-08W5 WE 13-01-037-08W5 PL NG 9930 0 O 4.14 168.3 4.00 S Z245.1 3592 W 58 C
060520001 YANGARRA RESOURCES CORP. 09-31-037-07W5 PL 16-35-037-08W5 PL NG 9930 0 O 3.94 168.3 4.00 S Z245.1 3592 W 58
060520002 YANGARRA RESOURCES CORP. 12-31-037-07W5 PL 12-31-037-07W5 PL NG 9930 0 O 0.04 168.3 4.00 S Z245.1 3592 W 58
060520003 YANGARRA RESOURCES CORP. 14-32-037-07W5 PL 09-31-037-07W5 PL NG 9930 0 O 1.67 168.3 4.00 S Z245.1 3592 W 58
060520004 YANGARRA RESOURCES CORP. 03-05-038-07W5 PL 14-32-037-07W5 PL NG 9930 0 O 0.12 168.3 4.00 S Z245.1 3592 W 58
Monday, June 15, 2020 Page 2 of 4
Pipeline InformationYANGARRA RESOURCES LTD. SOUTH FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
060520005 YANGARRA RESOURCES CORP. 01-09-038-07W5 WE 03-05-038-07W5 PL NG 9930 0 O 4.33 168.3 4.00 S Z245.1 3592 W 58
060544001 YANGARRA RESOURCES CORP. 07-26-037-08W5 WE 15-26-037-08W5 PL NG 9930 0 O 1.14 130.0 15.50 G FPLP 601 M
061238001 YANGARRA RESOURCES CORP. 11-18-038-06W5 WE 03-23-038-07W5 PL NG 9930 0 O 3.57 114.3 3.20 S Z245.1 3592 W 49
061238002 YANGARRA RESOURCES CORP. 03-18-038-06W5 WE 11-18-038-06W5 PL NG 9930 0 O 0.65 114.3 4.00 S Z245.1 3592 W 40
061501001 YANGARRA RESOURCES CORP. 05-17-037-07W5 WE 10-18-037-07W5 PL NG 9930 0 P 1.21 168.3 4.00 S Z245.1 3592 W 58 C
061613001 YANGARRA RESOURCES CORP. 16-08-037-07W5 BE 08-18-037-07W5 BE OE 0 0 D 1.80 88.9 4.00 S Z245.1 2901 W 0 C
061613002 YANGARRA RESOURCES CORP. 08-08-037-07W5 BE 16-08-037-07W5 BE OE 0 0 D 0.98 88.9 4.00 S Z245.1 2901 W 0
Monday, June 15, 2020 Page 3 of 4
Monday, June 15, 2020 Page 4 of 4
W FERRIER SYSTEM PIPELINE LIST
Pipeline InformationYANGARRA RESOURCES LTD. WEST FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
031390002 YANGARRA RESOURCES CORP. 11-33-039-08W5 PL 09-36-039-09W5 PL NG 9930 0 O 4.23 219.1 5.60 S Z245.1 3592 W 54
031390003 YANGARRA RESOURCES CORP. 03-36-039-09W5 PL 09-36-039-09W5 PL NG 9930 0 O 1.24 219.1 5.60 S Z245.1 3592 W 54
047376001 YANGARRA RESOURCES CORP. 04-04-040-08W5 WE 11-33-039-08W5 PL NG 9520 0 O 1.70 88.9 3.20 S Z245.1 3591 W 37
047376002 YANGARRA RESOURCES CORP. 04-33-039-08W5 WE 11-33-039-08W5 PL NG 9520 0 O 0.60 88.9 3.20 S Z245.1 3591 W 37
047376003 YANGARRA RESOURCES CORP. 04-04-040-08W5 PL 11-33-039-08W5 PL NG 9930 0 O 1.14 130.0 15.50 G FPLP 601 M
047376004 YANGARRA RESOURCES CORP. 04-33-039-08W5 PL 11-33-039-08W5 PL NG 9930 0 O 0.49 130.0 15.50 G FPLP 601 M
056665001 YANGARRA RESOURCES CORP. 10-32-042-09W5 WE 03-31-042-09W5 PL NG 9930 0 O 2.28 88.9 4.00 S Z245.1 3592 W 31
057466001 YANGARRA RESOURCES LTD. 10-35-041-08W5 WE 10-02-042-08W5 PL NG 4950 0 O 2.44 91.0 8.00 G FSLP 750 M 0
058050001 YANGARRA RESOURCES CORP. 04-14-042-08W5 WE 10-15-042-08W5 S NG 4950 0 O 1.14 60.3 3.18 S 5L B W 19
058050002 YANGARRA RESOURCES CORP. 10-02-042-08W5 WE 14-02-042-08W5 PL NG 4950 0 O 0.28 60.3 3.90 S Z245.1 2901 W 13
058050003 YANGARRA RESOURCES CORP. 14-02-042-08W5 PL 14-02-042-08W5 PL NG 4950 0 O 0.10 60.3 3.90 S Z245.1 2901 W 13 CC
058050004 YANGARRA RESOURCES CORP. 14-02-042-08W5 PL 04-11-042-08W5 PL NG 4950 0 O 0.60 60.3 3.90 S Z245.1 2901 W 13
058050005 YANGARRA RESOURCES CORP. 04-11-042-08W5 PL 04-14-042-08W5 PL NG 4950 0 O 1.70 60.3 3.91 S Z245.1 2901 W 13
058739001 YANGARRA RESOURCES CORP. 01-02-040-09W5 BE 13-02-040-09W5 BE NG 0 0 D 1.72 101.0 12.00 G FPLP 601 M 0
058932001 YANGARRA RESOURCES CORP. 08-10-040-08W5 WE 01-15-040-08W5 PL NG 8960 0 O 1.85 101.0 12.00 G FPLP 601 M 0
059260001 YANGARRA RESOURCES CORP. 06-02-040-09W5 BE 01-02-040-09W5 BE NG 0 0 D 1.01 101.0 12.00 G FPLP 601 M 0
059552001 YANGARRA RESOURCES CORP. 04-04-040-08W5 WE 04-04-040-08W5 PL NG 8040 0 O 0.17 101.0 12.00 G FPLP 601 M
059587001 YANGARRA RESOURCES CORP. 04-01-040-09W5 WE 01-02-040-09W5 PL NG 9930 0 O 1.06 168.3 4.00 S Z245.1 3592 W 58
059892001 YANGARRA RESOURCES CORP. 10-30-039-08W5 WE 01-36-039-09W5 PL NG 9930 0 O 1.77 130.0 15.50 G FPLP 601 M
059916001 YANGARRA RESOURCES CORP. 14-06-040-08W5 PL 09-02-040-09W5 PL NG 9930 0 O 2.55 168.3 4.00 S Z245.1 3592 W 58
059918001 YANGARRA RESOURCES CORP. 14-33-039-08W5 WE 14-33-039-08W5 PL NG 9930 0 O 0.37 101.0 12.00 G FPLP 601 M
059943001 YANGARRA RESOURCES CORP. 11-05-040-08W5 PL 04-04-040-08W5 PL NG 9930 0 O 1.64 168.3 4.00 S Z245.1 3592 W 58
059943002 YANGARRA RESOURCES CORP. 04-04-040-08W5 PL 04-04-040-08W5 PL NG 9930 0 O 0.15 168.3 4.00 S Z245.1 3592 W 58
059943003 YANGARRA RESOURCES CORP. 08-10-040-08W5 WE 04-04-040-08W5 PL NG 9930 0 P 4.16 168.3 4.00 S Z245.1 3592 W 58
059970001 YANGARRA RESOURCES CORP. 11-06-040-08W5 WE 14-06-040-08W5 PL NG 9930 0 O 0.14 168.3 4.00 S Z245.1 3592 W 58
059971001 YANGARRA RESOURCES CORP. 01-36-039-09W5 WE 03-36-039-09W5 PL NG 9930 0 O 1.00 130.0 15.50 G FPLP 601 M
059976001 YANGARRA RESOURCES CORP. 01-02-040-09W5 WE 06-02-040-09W5 B NG 9930 0 O 1.03 168.3 4.00 S Z245.1 3592 W 58
Monday, June 15, 2020 Page 1 of 2
Pipeline InformationYANGARRA RESOURCES LTD. WEST FERRIER
CROSSINGSTRESS
LVJOINTSGRADETYPE
MAT
CODE
WT
(mm)
DI
(mm)
LGTH
(KM)STH2SMOPSUBFCTOFCFROMOPERATORUPI
060003001 YANGARRA RESOURCES CORP. 14-05-040-08W5 WE 11-05-040-08W5 PL NG 9930 0 O 0.31 168.3 4.00 S Z245.1 3592 W 58
060006001 YANGARRA RESOURCES CORP. 06-02-040-09W5 B 03-02-040-09W5 PL NG 9930 0 O 0.54 130.0 15.50 G FPLP 601 M
060020001 YANGARRA RESOURCES CORP. 09-36-039-09W5 PL 04-01-040-09W5 PL NG 9930 0 O 1.51 168.3 4.00 S Z245.1 3592 W 58
060045001 YANGARRA RESOURCES CORP. 09-02-040-09W5 PL 08-02-040-09W5 PL NG 9930 0 O 0.50 168.3 4.00 S Z245.1 3592 W 58
060151001 YANGARRA RESOURCES CORP. 10-28-039-08W5 WE 04-33-039-08W5 PL NG 9930 0 O 1.23 101.0 12.00 G FPLP 601 M
060151002 YANGARRA RESOURCES CORP. 10-28-039-08W5 WE 04-33-039-08W5 PL NG 9930 0 O 1.23 130.0 15.50 G FPLP 601 M
Monday, June 15, 2020 Page 2 of 2
AREA OPERATORS
Company Area Operators FERRIER
Company Name Office Name
Area Operators Description
Office Phone Numbers
BONAVISTA OIL & GAS LTD. Head Office Phone: (403) 213-4300
700, 311 - 6 Avenue SW Fax:
Calgary, Alberta T2P 3H3 24hr: (403) 213-4300
HARVEST OPERATIONS CORP. Head Office Phone: (403) 265-1178
2100, 330 - 5 Avenue SW Fax:
Calgary, Alberta T2P 0L4 24hr: (800) 760-2826
KEYERA ENERGY LTD. Head Office Phone: (403) 205-8300
600, 144 - 4 Avenue SW Fax:
Calgary, Alberta T2P 3N4 24hr: (403) 205-8300
NAL RESOURCES LIMITED Head Office Phone: (403) 294-3600
600, 550 - 6 Avenue SW Fax:
Calgary, Alberta T2P 0S2 24hr: (403) 294-3600
PLAINS MIDSTREAM CANADA ULC Head Office Phone: (403) 298-2100
1400-607 8 Ave SW Fax:
Calgary, Alberta T2P0A7 24hr: (866) 875-2554
TAQA NORTH LTD. Head Office Phone: (403) 724-5000
2100, 308 - 4 Avenue SW Fax:
Calgary, Alberta 24hr: (403) 724-5000
BAYTEX ENERGY LTD. Head Office Phone: (403) 269-4282
2200, 205 - 5 Avenue SW Fax:
Calgary, Alberta T2P 2V7 24hr:
CANADIAN NATURAL RESOURCES
LIMITED
Head Office Phone: (403) 517-6700
2500, 855 - 2 Street SW Fax:
Calgary, Alberta T2P 4J8 24hr:
CANLIN ENERGY CORPORATION Head Office Phone: (403) 266-6393
1000, 111 - 5 Avenue SW Fax:
Calgary, Alberta T2P 3Y6 24hr:
ENERPLUS CORPORATION Head Office Phone: (403) 298-2200
3000 333 7 AVE SW Fax:
Calgary, Alberta T2P2Z1 24hr:
ENTRADA RESOURCES INC. Head Office Phone: (587) 393-0932
717 - 7 Avenue SW Fax:
Calgary, Alberta T2P 0Z3 24hr: (844) 547-2666
FIRENZE ENERGY LTD. Head Office Phone: (403) 410-6790
2550-700 2 St SW, c/o Toscana Resource
Corporation
Fax:
Calgary, Alberta T2P2W2 24hr:
GAIN ENERGY LTD. Head Office Phone: (403) 294-1336
30th Floor, 520 - 3 Avneue SW Fax:
Calgary, Alberta T2P 0R3 24hr:
June 15, 2020
Page 1 of 4YANGARRA RESOURCES LTD.
Company Area Operators FERRIER
Company Name Office Name
Area Operators Description
Office Phone Numbers
INPLAY OIL CORP. Head Office Phone: (587) 955-9570
920, 640 - 5 Avenue SW Fax:
Calgary, Alberta T2P 3G4 24hr: (403) 648-8201
NOVA GAS TRANSMISSION LTD. Head Office Phone: (403) 920-6233
450 - 1 Street SW Fax:
Calgary, Alberta T2P 5H1 24hr:
OBSIDIAN ENERGY LTD. Head Office Phone: (403) 777-2500
200, 207 - 9 Avenue SW Fax:
Calgary, Alberta T2P 1K3 24hr: (877) 792-2990
PARAMOUNT RESOURCES LTD. Head Office Phone: (403) 290-3600
4700, 888 - 3 Street SW Fax:
Calgary, Alberta T2P 5C5 24hr:
PEMBINA PIPELINE CORPORATION Head Office Phone: (403) 231-7500
2000, 700 - 9 Avenue SW Fax:
Calgary, Alberta T2P 3V4 24hr:
REPSOL OIL & GAS CANADA INC. Head Office Phone: (403) 237-1234
2000, 888 - 3 Street SW Fax:
Calgary, Alberta T2P 5C5 24hr: (888) 723-9576
SHELL CANADA LIMITED Head Office Phone: (403) 691-3111
400 - 4 Avenue SW, PO Box 100 Stn M Fax:
Calgary, Alberta T2P 2H5 24hr:
BACCALIEU ENERGY INC. Head Office Phone: (403) 261-1500
500, 635 - 8 Avenue SW Fax:
Calgary, Alberta T2P 3M3 24hr:
HARD ROCK RESOURCES LTD. Head Office Phone: (403) 340-2550
Box 326 Fax:
Blackfalds, Alberta T0M 0J0 24hr:
ORLEN UPSTREAM CANADA LTD. Head Office Phone: (403) 265-4115
400, 850 - 2 Street SW Fax: (403) 232-8463
Calgary, Alberta T2P 0R8 24hr: (866) 835-6132
SITKA EXPLORATION LTD. Headoffice Phone: (403) 237-0900
1500-505 3 St SW Calgary, AB T2P 3E6 Fax:
24hr:
WHITECAP RESOURCES INC. Head Office Phone: (403) 266-0767
500-222 3 Ave SW Fax:
Calgary, Alberta T2P0B4 24hr:
BELLATRIX EXPLORATION LTD. Head Office Phone: (403) 266-8670
2300 530 8 AVE SW Fax:
Calgary, Alberta T2P3S8 24hr:
June 15, 2020
Page 2 of 4YANGARRA RESOURCES LTD.
Company Area Operators FERRIER
Company Name Office Name
Area Operators Description
Office Phone Numbers
SECURE ENERGY SERVICES INC. Head Office Phone: (403) 984-6100
1900-205 5 Ave SW Fax:
Calgary, Alberta T2P2V7 24hr:
SIGNALTA RESOURCES LIMITED Head Office Phone: (403) 265-5091
1000, 605 - 5 Avenue SW Fax:
Calgary, Alberta T2P 3H5 24hr:
SINOPEC DAYLIGHT ENERGY LTD. Head Office Phone: (403) 266-6900
2700, 112 - 4 Avenue SW Fax: (403) 266-6988
Calgary, Alberta T2P 0H3 24hr: (866) 616-6300
GEAR ENERGY LTD. Head Office Phone: (403) 262-0242
650, 910 - 7 Avenue SW Fax:
Calgary, Alberta T2P 3N8 24hr:
CERTUS OIL & GAS INC. Head Office Phone: (587) 323-8390
600, 635 - 8 Avenue SW Fax:
Calgary, Alberta T2P 3M3 24hr: (800) 887-0605
June 15, 2020
Page 3 of 4YANGARRA RESOURCES LTD.
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June 15, 2020
Page 4 of 4YANGARRA RESOURCES LTD.
PIGGING SCHEDULE
REPAIR LOG
CORROSION CONTROL
CHEMICAL INHIBITOR PROGRAM
MAPS
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039-06-W5039-07-W5
042-05-W5
041-05-W5
040-05-W5
039-05-W5
043-07-W5 043-06-W5 043-05-W5
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28
LAKE ERNIE
NORTH SASKATCHEWAN RIVER
CLEARWATER RIVER
LASTHILL CREEKCHICKEN CREEK
LOBSTICK CREEK
BUSTER CREEK
ROSE CREEK
EAST LOBSTICK CREEK
HORSEGUARD CREEK
OPEN CREEK
WELCH CREEK
LOBSTICK CREEK
WEST LOBSTICK CREEK
OP12
OP22
OP11
OP53
OP598
OP11A
OP756
OP752
CRIMSON LAKE
CRIMSON LAKE
ROCKY MOUNTAIN HOUSE
ORAS
BINGLEY
MILL ISLANDNATURAL AREA
048014001(SOUTH FERRIER)
058515002
052347001
060222001
058515001
060222003
059959001
042289009
059959003
043702007
042289010
059891001
060221001
043702005
058515003
043702001
059959006
059959007
053453001
043702003
055273001
056545001
044436001
054571001
043702006
048695001
052347002
057486001
059941001
043702002
053385001
059959005
058418001
059026001
060222002
058419002
043702008
043702004
053453002
058419001
042289007
053453004
055270001
046735001058743001
048160001
059959002
053453003
059959004
059259001
046735002
055652001
056261001
042289008
059530001
053316001
060221003
053368001
YANGARRA 02-04
CLEARWATER COUNTYAHS CENTRAL ZONE
AER - RED DEER FIELD CENTRE
060222004
OBSIDIAN ENERGY LTD.014283022
057873001
PARAMOUNT RESOURCES LTD.021381052 PARAMOUNT RESOURCES LTD.
021381051
PARAMOUNT RESOURCES LTD.021381025
059556001
NOVA GAS TRANSMISSION LTD.080108086
PLAINS MIDSTREAM CANADA ULC008295005
PLAINS MIDSTREAM CANADA ULC011852032
HARVEST OPERATIONS CORP.023315001
NOVA GAS TRANSMISSION LTD.080108044
HARVEST OPERATIONS CORP.023315032
PEMBINA PIPELINE CORPORATION055740004
HARVEST OPERATIONS CORP.043019006
PLAINS MIDSTREAM CANADA ULC006842003
CANLIN ENERGY CORPORATION030679004
OBSIDIAN ENERGY LTD.048643006
BONAVISTA ENERGY CORPORATION022220001
ENTRADA RESOURCES INC.058619001
PLAINS MIDSTREAM CANADA ULC008295001
PEMBINA PIPELINE CORPORATION055740006
ENERPLUS CORPORATION033539001
PLAINS MIDSTREAM CANADA ULC056404053
PLAINS MIDSTREAM CANADA ULC017185014
BONAVISTA ENERGY CORPORATION049768002
ENTRADA RESOURCES INC.018893019
TAQA NORTH LTD.024521001
OBSIDIAN ENERGY LTD.040801005
OBSIDIAN ENERGY LTD.014283011
OBSIDIAN ENERGY LTD.035002002
GAIN ENERGY LTD.056434004
OBSIDIAN ENERGY LTD.014283001
KEYERA ENERGY LTD.054972001
REPSOL054431002
TAQA NORTH LTD.041652003
INPLAY OIL CORP.050315035
ENTRADA058578016
GEAR061469001
PLAINS MIDSTREAM CANADA ULC056404028
BONAVISTA ENERGY CORPORATION061385077
BONAVISTA ENERGY CORPORATION061385034
TAQA NORTH LTD.041652008
OBSIDIAN ENERGY LTD.014283035
BONAVISTA029550043
BONAVISTA ENERGY CORPORATION022220002
BONAVISTA ENERGY CORPORATION061385070
BONAVISTA061385033
BONAVISTA ENERGY CORPORATION061385040
OBSIDIAN ENERGY LTD.014283037
ENTRADA RESOURCES INC.018893018
BONAVISTA ENERGY CORPORATION061385024
BONAVISTA ENERGY CORPORATION034810001
TAQA NORTH LTD.024521005
OBSIDIAN ENERGY LTD.014283023
BONAVISTA027472021
BONAVISTA061385073
GAIN ENERGY LTD.049174001
OBSIDIAN ENERGY LTD.014280014
INPLAY OIL CORP.050315036
INPLAY OIL CORP.050315037
FIRENZE ENERGY LTD.046542002
BONAVISTA ENERGY CORPORATION027916021
BONAVISTA ENERGY CORPORATION020633002
BONAVISTA ENERGY CORPORATION061385076
PLAINS MIDSTREAM011852008
OBSIDIAN ENERGY LTD.014283009
OBSIDIAN ENERGY LTD.044310001
OBSIDIAN ENERGY LTD.014283002
BONAVISTA053858010
OBSIDIAN ENERGY LTD.045806002
BONAVISTA027472014
OBSIDIAN ENERGY LTD.014283021
BONAVISTA ENERGY CORPORATION054723003
BONAVISTA ENERGY CORPORATION061385031
ENTRADA RESOURCES INC.018893017
BONAVISTA040621046
OBSIDIAN ENERGY LTD.014280013
OBSIDIAN ENERGY LTD.014283024
BONAVISTA027472019
BONAVISTA061385071
BONAVISTA ENERGY CORPORATION061385027
BONAVISTA027472022
GAIN ENERGY LTD.049174003
HARVEST OPERATIONS CORP.047642001
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