SAFETY GUIDE

Small, Portable Oil & Gas

Production Facilities:
Recommended Solutions for
Design and Operation
July 2014

2014-0029
 The Canadian Association of Petroleum Producers (CAPP) represents companies,
large and small, that explore for, develop and produce natural gas and crude oil
throughout Canada. CAPPs member companies produce about 90 per cent of
Canadas natural gas and crude oil. CAPP's associate members provide a wide
range of services that support the upstream crude oil and natural gas industry.
Together CAPP's members and associate members are an important part of a
national industry with revenues of about $110 billion-a-year. CAPPs mission, on
behalf of the Canadian upstream oil and gas industry, is to advocate for and
enable economic competitiveness and safe, environmentally and socially
responsible performance. Competitiveness, in North America and globally, is
necessary so as to attract the capital necessary to grow production and expand
markets to deliver value to the Canadian public and to our investors. Social
License, from governments, Aboriginal peoples, the public, stakeholders and the
communities in which we operate, will be determined by our collective
performance and the effectiveness of our communications and outreach.

Disclaimer
This publication was prepared for the Canadian Association of Petroleum
Producers (CAPP). While it is believed that the information contained herein is
reliable under the conditions and subject to the limitations set out, CAPP does
not guarantee its accuracy. The use of this report or any information contained
will be at the users sole risk, regardless of any fault or negligence of CAPP or
its co-funders.

2100, 350 7 Avenue S.W. 1000, 275 Slater Street 403, 235 Water Street 310, 1321 Blanshard Street
Calgary, Alberta Ottawa, Ontario St. Johns, Newfoundland and Labrador Victoria, British Columbia
Canada T2P 3N9 Canada K1P 5H9 Canada A1C 1B6 Canada V8W 0B5
Tel 403-267-1100 Tel 613-288-2126 Tel 709-724-4200 Tel 778-410-5000
Fax 403-261-4622 Fax 613- 236-4280 Fax 709-724-4225 Fax 778-410-5001

www.capp.ca communication@capp.ca
Overview
This guide describes design and operation practices that support safe working conditions at
small, portable oil and gas production facilities, often classified as high hazard industrial
occupancies. The objective of the guide is to limit the probability that a person in or adjacent to a
facility may be exposed to an unacceptable level of risk of injury or illness.

This guide is an update of the 1993 CAPP Safety Guidelines and reflects subsequent national and
provincial amendments. The new guide is intended to supplement other applicable standards and
regulatory codes. It recommends solutions for safe design, operation and maintenance practices
for field facilities including worker training and competency. The guide addresses common
safety issues and establishes minimum safety standards. There are three main areas of focus:
process safety, public safety and occupational health and safety. Owners should assess their own
requirements to establish design, operating, maintenance, and worker competency standards to
create a safe work environment.

July 2014 Small, Portable Oil & Gas Facilities Guide Page i
 Contents
1 Introduction ................................................................................................................ 1-4
1.1 Background .............................................................................................. 1-4
1.2 Mission, Purpose and Scope .................................................................... 1-5
1.3 How to Use This Guide............................................................................ 1-5
2 Objectives .................................................................................................................. 2-6
2.1 Process Safety .......................................................................................... 2-6
2.2 Public Safety ............................................................................................ 2-6
2.3 Occupational Health and Safety............................................................... 2-6
3 Recommended Solutions for an Integrated Safety Management System .................. 3-7
3.1 Introduction to Process Safety Management (PSM) ................................ 3-8
3.2 Integrated Management System Recommendations ................................ 3-8
3.3 Hazard Assessment and Risk Management ............................................. 3-9
3.3.1 Regulatory Requirements........................................................... 3-10
3.3.2 When Hazard Assessments are Required .................................. 3-10
3.4 Applicable Regulations, Codes, Standards, and Industry Practices....... 3-10
3.4.1 Manufacturers Specifications and Engineering Certifications .. 3-10
3.4.2 Energy Regulator Directives ...................................................... 3-10
3.4.3 Industry Recommended Practices .............................................. 3-10
3.5 Integrity Management Programs............................................................ 3-11
4 Recommended Solutions for Facility and Building Design .................................... 4-12
4.1 Equipment Layout and Spacing ............................................................. 4-13
4.2 Skid Mounted Equipment ...................................................................... 4-16
4.2.1 Packaged Skid-Mounted Equipment.......................................... 4-16
4.2.2 Piping Design on Skid-Mounted Equipment ............................. 4-17
4.2.3 Minimizing Hazards In and Around Skid-Mounted Buildings.. 4-18
4.3 Oil and Gas Processing Packages .......................................................... 4-19
4.3.1 Compressor Packages ................................................................ 4-19
4.3.2 Heater Packages ........................................................................ 4-21
4.3.3 Pump Packages .......................................................................... 4-21
4.3.4 Separator Packages .................................................................... 4-22
4.3.5 Treater Packages ........................................................................ 4-22
4.4 Dehydrator Units .................................................................................... 4-22
4.5 Fired Equipment..................................................................................... 4-23
4.5.1 Design of Fired Equipment ........................................................ 4-23
4.5.2 Installation of Fired Equipment ................................................. 4-24
4.5.3 Operation and Maintenance of Fired Equipment ....................... 4-24
4.6 Liquid Petroleum Gas (LPG) Handling Facilities ................................. 4-24
4.7 Refrigeration Process Units ................................................................... 4-24
4.7.1 Piping, Connections and Valves ................................................ 4-25
4.8 Oil and Water Production Tanks............................................................ 4-25
4.9 Flare Systems and Vent Stacks .............................................................. 4-26

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 4.9.1 Flashback Protection .................................................................. 4-26
4.10 Detection and Emergency Shutdown Systems ...................................... 4-27
4.10.1 Safety Systems ........................................................................... 4-27
4.10.2 Personal Safety........................................................................... 4-28
5 Recommended Solutions for Operating and Maintenance Practices ....................... 5-28
5.1 Site Safety Management ........................................................................ 5-28
5.1.1 Safe Work Permits ..................................................................... 5-28
5.1.2 Concurrent Operations ............................................................... 5-29
5.2 Hazardous Substance Exposure and Control ......................................... 5-29
5.2.1 Hydrogen Sulphide (H2S) .......................................................... 5-30
5.2.2 Benzene ...................................................................................... 5-30
5.2.3 Chemicals ................................................................................... 5-30
5.2.4 Other Potential Occupational Exposures ................................... 5-31
5.3 Critical Safe Operating Procedures ........................................................ 5-31
5.3.1 Confined and Restricted Space Entry ........................................ 5-31
5.3.2 Critical Lifts and Safe Lifting Certifications ............................. 5-31
5.3.3 Electrical Safety (Including Working near Overhead Power
Lines) ......................................................................................... 5-32
5.3.4 Energy Isolation (Including Lock-Out/Tag-Out) ....................... 5-32
5.3.5 Flammable Atmospheres (Including Hot Work and Fire and
Explosion Prevention)................................................................ 5-32
5.3.6 Ground Disturbance (Including Damage Prevention) ............... 5-32
5.3.7 Hydrate Handling ....................................................................... 5-32
5.3.8 Purging ....................................................................................... 5-33
5.3.9 Vehicle OperationsJourney Management .............................. 5-33
5.3.10 Working Alone........................................................................... 5-33
5.3.11 Working at Heights .................................................................... 5-33
5.4 Site-Specific Procedures ........................................................................ 5-33
5.4.1 Knowledge of Equipment .......................................................... 5-33
5.4.2 Commissioning and Start-up...................................................... 5-34
6 Recommended Solutions for Worker Competency ................................................. 6-36
6.1 Worker Orientations............................................................................... 6-36
6.2 Basic Training & Competency Requirements ....................................... 6-37
6.2.1 Core Safety Training (Pre-Hire Confirmation and
Documentation).......................................................................... 6-37
6.2.2 Technical Training: Core and Operations-Specific ................... 6-38
6.3 Competency Management and Development ........................................ 6-40

July 2014 Small, Portable Oil & Gas Facilities Guide Page 1-2
 Figures
Figure 4.1 Surface Equipment Spacing ......................................................................... 4-14
Figure 4.2 Equipment Spacing for Well Servicing ........................................................ 4-15

Tables
Table 6.1 Required certification and training ................................................................ 6-38
Table 6.2 Technical Training: Core and Operations-Specific ....................................... 6-39

July 2014 Small, Portable Oil & Gas Facilities Guide Page 1-3
1 Introduction
This document was developed to outline some design, operating procedures and
training recommendations to help mitigate facility accidents at small, portable oil
and gas facilities. The goal of these recommendations is to communicate the
design and work practices that facilitate safe working conditions. Much of the
content is based on CAPPs Safety Guidelines published in 1993.
Twenty years later, the original intent of this guideline continues to be relevant.
That said, over the past 20 years there have been significant regulatory changes in
Alberta. This new Safety Guide reflects amendments to the Alberta Occupational
Health and Safety (OHS) Act, Regulations and Code, Alberta Safety Codes Act
and Regulations, Energy Regulations, and the National Building and Fire Codes.
The recommended solutions outlined in this guide were developed with the help
of experienced facility operators. It is strongly recommended that this guide be
used to supplement other applicable standards and regulatory codes. These
recommendations address some of the most common issues, but are not all-
inclusive. Owners should assess their own requirements to establish:
design specifications and standards to meet their specific needs,
operating and maintenance procedures, and
worker competency programs.
This document is focused on Alberta Safety Code requirements. It is important to
keep in mind that each provincial jurisdiction may have its own unique
requirements that operators must be aware of and address.
1.1 Background
Accidents at oil and gas facilities can be prevented by a combination of the
following:
employer commitment to safety in every phase of facility development and
operation;
use of qualified personnel in every aspect of facility design, installation or
operation;
appropriate work plans and procedures during engineering, construction or
operation of the facility;
adequate training for operating personnel to ensure competency; and
safety awareness with an emphasis on hazard identification during
engineering, installation and operation.
To create a safe work environment, many oil and gas companies, in cooperation
with various government agencies, have researched and developed equipment
standards, work procedures and training to produce safety packages more
specific and more comprehensive than the Alberta Building Code or the Alberta
Fire Code.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 1-4
 1993 CAPP Safety Guidelines
In 1992, the Production Facility Safety Committee (PFSC) was established to
develop the original guideline document. The committee was made up of
representatives from government including OH&S and the AER (formerly
ERCB), key industry associations including CAPP, EPAC (formerly SEPAC),
the Alberta Pressure Vessel Manufacturers Association (APVMA), and
insurance industry representatives. The resulting guideline was released in
August 1993.
2007 STANDATA Building Code Variance
Effective September 2007, the Alberta Municipal Affairs Building Code
Variance STANDATA 06-BCV-001 Oil and Gas Processing Facilities
references the CAPP publication. This variance outlines the provisions which
exempt oil and gas processing facilities from the requirements of Group F,
Division 1, high hazard industrial occupancies of the 2006 Alberta Building
Code. Without this guideline, the variance will be removed.
1.2 Mission, Purpose and Scope
The original mission, purpose and scope for the 1993 guideline were
Mission
To promote safety in small, portable oil and gas production facilities
Purpose
To identify unsafe work practices and develop guidelines for design standards and
safe work procedures
Scope
To make recommendations for the safe design, operation and maintenance of
small, portable oil and gas production facilities with the aim of preventing
injury and loss of property
To address common safety issues identified by regulators, operators and
insurers for small, portable oil and gas production facilities
To establish the minimum safety standards and recommendations for design,
operation and maintenance of production facilities
To be a resource for industry and government agencies in matters pertaining
to safety in small, portable oil and gas production facilities, and to foster
exchange of information
1.3 How to Use This Guide
There are five key components to the working content of the new Safety Guide.
They are as follows
Section 2 outlines the Objectives of this Safety Guide. These are based on and
consistent with the objectives of the 2010 National Building and Fire Codes of
Canada.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 1-5
 Section 3 outlines the Recommended Solutions for Process Safety
Management Systems. This section also provides related risk assessment
recommendations for addressing the STANDATA Variance.
Section 4 summarizes the Recommended Solutions for Facility and Building
Design.
Section 5 summarizes the Recommended Solutions for Operating and
Maintenance Practices.
Section 6 summarizes Recommended Solutions for Worker Orientations and
Training.
2 Objectives
Portable oil and gas processing buildings and facilities are often classified as
Group F, Division 1, high hazard industrial occupancies because of the nature of
the processes being housed. Consistent with both the Building and National Fire
Codes of Canada, the objective of this guide is to limit the probability that a
person in or adjacent to the oil and gas processing buildings or facility will be
exposed to an unacceptable risk of injury or illness as a result of
activities related to the construction, use or demolition of the building or
facility
the condition of specific elements of the building or facility
the design or construction of the specific elements of the building or facility
inadequate built-in protection measures for the current or intended use of the
building or facility
More specifically, this guide focuses on three areas of safety:
process safety
public safety
occupational health and safety
2.1 Process Safety
An objective of this guide is to limit the probability that a person in or adjacent to
a portable facility will be exposed to an unacceptable risk of injury or illness due
to the loss of primary containment (LOPC) from that facility. Hazardous materials
include toxic, explosive or flammable substances including the potential ignition
of such a release and similar process safety incidents (PSI).
2.2 Public Safety
An objective of this guide is to limit the probability that, as a result of the design,
construction or operation of the oil and gas processing buildings or facility, the
public will be exposed to an unacceptable risk of injury or illness due to the
uncontrolled release of a hazardous substance or energy.
2.3 Occupational Health and Safety
An objective of this guide is to limit the probability that, as a result of the design,
construction or operation of the oil and gas processing buildings or facility, a
worker in or adjacent to the facility will be exposed to an unacceptable risk of

July 2014 Small, Portable Oil & Gas Facilities Guide Page 2-6
 injury or illness due to hazards. The risks of injury due to hazards addressed in
this guide are those caused by the following:
tripping, slipping, falling, contact, or collision,
contact with hot surfaces,
contact with energized equipment,
exposure to hazardous substances,
exposure to high levels of sound,
persons being trapped in confined spaces, and
persons being delayed in or impeded from moving to a safe place during an
emergency.
3 Recommended Solutions for an Integrated Safety Management System
Organizations are required to establish and maintain processes that implement
preventive and protective measures for the management of hazards and risks
identified. More specifically, preventive and control measures are normally
implemented according to the priorities shown in the diagram and list below.
1. elimination of the hazard Hierarchy of
Hazard Controls
2. substitution with other materials, processes,
or equipment Eliminate or Substitute Hazard
3. use of engineering controls
4. use of safer work systems that increase Engineering Controls
awareness of potential hazards (lights, Administrative
signage, etc.) Controls
5. implementation of administrative controls,
PPE
such as training and procedures
6. provision of personal protective equipment,
including measures to ensure its appropriate use and maintenance

July 2014 Small, Portable Oil & Gas Facilities Guide Page 3-7
 3.1 Introduction to Process Safety Management (PSM)
Recent process safety incidents have resulted in regulators and the oil and gas
industry becoming increasingly aware of the importance of process safety
management and its application to all phases of operations. It is recommended
that facility owners incorporate process safety concepts into their Health Safety
and Environment (HSE) management systems. Effective risk-based process safety
systems include the four main
accident prevention pillars 1 as
highlighted in the adjacent figure.
To address the principle of
process safety, the following
concepts must also be considered:
quality assurance/quality
control,
supply chain management,
operational readiness, and
management of change.
3.2 Integrated Management System Recommendations
It is important to develop an effective management system that integrates
operations and technical systems with the management of occupational health,
safety and environmental protection, and process safety to ensure compliance
with OHS Acts and Regulations.
The management system should correspond to the size, nature and complexity of
the operations and activities, hazards and risks associated with the operations.
System documentation should be controlled and set out in a logical and systematic
fashion to allow for ease of understanding and efficient implementation.
The management system should address the following basic safety considerations.
Management involvement and commitment: the policies on which the
system is based and personnel accountable for the establishment and
maintenance of the management system and the personnel responsible for
implementing it
Goals, objectives and continued improvement: the processes for setting
goals for the improvement of occupational health, safety and environmental
protection and process safety
Roles, responsibilities and accountability: the processes for making
personnel aware of their roles, responsibilities and accountability with respect
to them

1 American Institute of Chemical Engineers, 2007. Guidelines for Risk Based Process Safety. pp Iiii.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 3-8
 Compliance with standards: the processes for identifying the applicable
company standards, industry codes and regulations that apply to the design,
construction, operation, and maintenance activities
Hazard identification and risk assessment: the processes for identifying
hazards and for evaluating and managing the associated risks including design
and operational readiness reviews
Training and competence: the processes for ensuring that personnel are
trained and competent to perform their duties
Emergency response planning: the processes for developing and
implementing emergency response procedures
Incident reporting and investigation: the processes for the internal reporting
and analysis of hazards, minor injuries, incidents, and near-misses and for
taking corrective actions to prevent their recurrence
Performance measurement and corrective action: the processes for
conducting periodic reviews or audits of the system and for taking corrective
actions if reviews or audits identify areas of non-conformance with the system
and opportunities for improvement
Where applicable, the management system may need to incorporate process safety
management considerations.
Information management: the processes for ensuring that all documentation
associated with the system are current, valid and have been approved by the
appropriate level of authority
Asset and equipment integrity: the processes for inspecting and maintaining
the quality and integrity of all facilities, structures, installations, support craft,
and equipment necessary to ensure occupational health and safety,
environmental protection and process safety
Workforce interaction: the processes for coordinating the management of
operations of the proposed work or activity among the owner, the prime
contractor, the contractors, the suppliers, the operator, and workers, as
applicable
Human factors: the processes for reducing the risk and the potential for
human error though engineering and design
Change management: the processes for ensuring that changes are reviewed
for hazards before implementation of the change
An effective management system, together with operational discipline, is
important to maintaining safe and reliable operations and regulatory compliance.
3.3 Hazard Assessment and Risk Management
In the past 20 years, there has been a significant shift towards risk and objective
based regulation. The regulatory agencies responsible for oil and gas operations
have each established requirements to identify hazards related to the operations
being conducted and complete risk assessments.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 3-9
 3.3.1 Regulatory Requirements
The Alberta Occupational Health and Safety Code requires hazard assessments of
all worksites including a documented report of the methods used to control or
eliminate the hazards identified. Other acts and regulations also include a
requirement for hazard assessment and risk management. Employers must
identify all applicable requirements and ensure that management systems address
them.
3.3.2 When Hazard Assessments are Required
Workplace hazard identification, assessment and control are on-going processes.
They should be undertaken at various times, including:
if they have not been done before,
when a hazard has been identified,
when a change to the workplace occurs,
after an incident or workplace illness,
at regularly scheduled times appropriate to the workplace, and
when a change in personnel occurs.
3.4 Applicable Regulations, Codes, Standards, and Industry Practices
There are a number of regulations and industry standards important to the design
of oil and gas processing buildings and facilities which, when adequately
implemented, greatly contribute to the safe design and operation of oilfield
facilities.
3.4.1 Manufacturers Specifications and Engineering Certifications
Part 3 of the Alberta OHS Code identifies the engineering certification
requirements that dictate oilfield equipment requirements.
Those responsible for the planning and supervision of work should be familiar
with those circumstances that require the use of certified equipment.
3.4.2 Energy Regulator Directives
The AER has established regulations and directives specific to oil and gas
equipment design standards.
3.4.3 Industry Recommended Practices
In addition, the upstream petroleum industry has established a number of industry
recommended practices (IRPs) that drives equipment standards for wells. When
identified by the key petroleum industry associations, additional industry
recommended practices are developed. The Enform website should be checked
regularly to confirm the availability of new or revised IRPs.
Other regulatory considerations related to equipment standards include:
Equipment must be registered, certified or licensed in accordance with federal,
provincial and local requirements, even when equipment is used on private
property.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 3-10
 All licences and certifications required to operate equipment must be available
to the worker responsible for operating the equipment. If not, the equipment
must not be operated.
When purchasing manufactured equipment, the required engineering
specifications and certifications will normally have been addressed. As
highlighted in Part 3 of the Alberta OHS Code on specifications and
certifications, there are two situations where added care and attention is
required, specifically:
o whenever equipment is being specially constructed for circumstances
identified on that equipment that require certification by an engineer; and
o whenever certified equipment is being repaired or modified in a manner
that may affect the structural integrity or stability, the repairs or
modifications must be certified by an engineer.
International Standard NACE MR0175/ISO15156Petroleum and Natural
Gas IndustriesMaterials for use in H2S-containing Environments in Oil and
Gas Production must be consulted when designing sour service facilities and
equipment. Refer to CAPP Guide on the use of the NACE MR0175 Standard.
3.5 Integrity Management Programs
Current regulations governing the design and operation of oil and gas processing
buildings and facilities require companies to establish integrity management
programs. The focus of the programs is to improve both process and occupational
safety by reducing the number and severity of process-related incidents,
especially loss of primary containment events.
Key plans and programs integral to meeting the objectives of this guide include:
Well Equipment Standards
The critical issue is ensuring the equipment provided by each contractor is
aligned with objectives of the owners well program and the technical
requirements needed to achieve the drilling objectives. Well equipment
standards are based on a combination of AER well-related directives and
industry recommended practices developed by the Drilling and Completions
Committee (DACC).
Boilers and Pressure Equipment Safety Code Compliance
Owners and contractors are responsible for the safe operation of their boilers
and pressure equipment. They are required to establish an inspection program
to ensure that these responsibilities are met, ensuring that the inspection of all
boilers, fired heaters, pressure vessels, and piping systems that contain an
expansible fluid above 103 kPa (15 psi) are completed under an approved
pressure equipment integrity management plan, as required under the
provincial pressure vessel regulations (ABSA AB 512: Pressure Equipment
Integrity Management Requirements in Alberta). Important: ABSA AB-512
requires that key components of a process safety management system be
addressed including: management of change (MOC), hazard assessments,
design documentation, and purchasing controls.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 3-11
 Management Plan Requirements for Storage Equipment
The owner, and in some cases contractors, are responsible for implementing
an integrity management plan for storage equipment to ensure that operation
of all storage facilities is in compliance with AER Directive 055: Storage
Requirements in the Upstream Petroleum Industry. Similar requirements have
been established by both the British Columbia and Saskatchewan energy
regulators.
Pipeline Integrity Management Plans
Once a pipeline is successfully constructed and tested for operation, it is the
responsibility of the owner/licensee to ensure that it is operated and
maintained in a manner consistent with the regulations. To address this
requirement, owners are required to develop a Pipeline Integrity Management
Plan Manual (formerly referred to as Pipeline Operating and Maintenance
Manual) to provide guidelines for the operation and maintenance of their
production pipeline systems.
Electrical Safety Code Compliance
It is important to utilize licensed contractors to ensure that the design,
construction, maintenance, and operation of electrical equipment are in
compliance with provincial electrical regulations and standards. Both the
owner and service contractors are responsible for ensuring electrical
inspections and maintenance are completed in accordance with CSA C22.1-06
Canadian Electrical Code Part 1, the Code for Electrical Installations at Oil
and Gas Facilities (2006) and provincial regulations established by the
responsible authority.
Gas Safety Code Compliance
To comply with provincial gas safety requirements, all fuel gas installations
for gas fired equipment are to be installed in accordance with CSA B149.1-05,
Natural Gas and Propane Installation Code and provincial gas regulations.
This includes the installation of propane tanks at wellheads and installations
where raw gas is being used as fuel.
Measurement Equipment QA/QC
The owner is responsible for ensuring measurement activities at each facility
are completed in accordance with regulations AER Directive 017:
Measurement Requirements for Oil and Gas Operations or BC OGC 07-21.
4 Recommended Solutions for Facility and Building Design
This section provides design recommendations for small, portable oil and gas
production facilities. Key areas of concern include the following
layout and spacing of equipment, particularly with respect to ignition sources
such as fired equipment and flare stacks
potential for entrapment of hydrocarbon liquids and vapours beneath the skid
floor
electrical area classifications needs to be determined for portable facilities to
ensure that the correct electrical equipment is purchased and installed
building design and layout to ensure adequate ventilation and heating
including confirmation of building air changes to maintain electrical

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-12
 classifications is an important consideration for winter operation for skid
packages (Note: The Division 2 electrical classification may be voided if the
proper air changes are not provided in winter and may require an upgrade to
Division 1.)
equipment spacing and separation distances as required to comply with AER,
OHS and Canadian Electrical Code requirements
safe worker egress in an emergency, safe location of equipment air intake, and
gas exhaust
flare and closed-drain systems design
fire, gas and H2S detection and shutdown systems
protection from freeze-up of lines, vents and equipment
dehydration unit design, particularly with respect to freeze-up, pressure relief
on reboilers and separators for wet gas
fired heater design, particularly with respect to location of the heaters, design
of flame arrestors and use of ignition systems
product loading facilities, including design of safety systems and location
away from hazardous areas
There are other design concerns that have not been covered here. Owners should
do their own hazard assessments to identify specific design requirements.
Design of oil and gas facilities should be carried out by a professional engineer
registered with the Association of Professional Engineers and Geoscientists of
Alberta (APEGA) or a qualified technologist. The design should be in accordance
with all codes and regulations referenced in this document and other relevant
sources. This guide is intended as a supplement to, not a replacement for, existing
guidelines and regulations.
Owners should remember that not all safety-related concerns can be designed out.
In these cases, written operating procedures will need to be put in place and
operating personnel must be trained to identify hazards and implement site-
specific operating procedures.
Construction and installation of small portable oil and gas production facilities
should be performed by competent personnel under the direction of a prime
contractor with control over the work being performed.
4.1 Equipment Layout and Spacing
All storage areas, facilities and rigs must comply with the equipment spacing
requirements identified and detailed in the Alberta Oil and Gas Conservation
Rules and summarized in AER Directives 036, 055 and 056. IRP Volume #20
Wellsite Design Spacing Recommendations provides guidelines on wellsite size
and spacing. Specifically, this IRP provides a set of best practices to ensure
consistent and legal lease size information for typical drilling, completions, and
production facilities in Western Canada and the North West Territories. Diagrams
illustrating Alberta Energy Regulator spacing requirements are included on the
following pages.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-13
Figure 4.1 Surface Equipment Spacing
(source: AER Directive 056: Energy Development Applications and Schedules, Appendix 6)

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-14
Figure 4.2 Equipment Spacing for Well Servicing
(source: AER Directive 037: Service Rig Inspection Manual, Schedule 11)

Note: The doghouse and light plant shall be positioned in accordance with smoking and open
flame regulations under the Electrical Protection Act.
All distances shown are minimum distances.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-15
 4.2 Skid Mounted Equipment
Skid-mounted equipment must be installed with an understanding of the hazards
involved. This section provides recommendations for the following:
packaged skid-mounted equipment,
piping design on skid-mounted equipment, and
minimizing hazards in and around skid-mounted buildings.

4.2.1 Packaged Skid-Mounted Equipment

The oil and gas industry usually "packages" or "modularizes" process equipment.
A skid package may include all the equipment completely piped with
instrumentation installed and electrical work completed. It may also include a
building. The packages are usually set on steel driven piles or a concrete slab.
There are unique potential hazards associated with skid space and transport of this
type of equipment.
4.2.1.1 Skid-Space Hazards
Possible hazards include inadequate under-floor (skid-space) ventilation and
combustibility of materials. The following safeguards are recommended:
When pile-mounting skids, eliminate depressions where liquids or heavier-
than-air vapours can accumulate.
If checker-plate flooring is used, provide ventilation on all sides of the area
beneath the floor or fill the space between the beams completely with a solid
non-combustible material that will not settle.
Weld all checker-plate seams, ensuring no holes remain in the floor.
Use non-combustible, non-hydrocarbon absorbent materials to insulate under
floor areas that are freely ventilated. Closed-cell plastic material must be fire
retardant.
Have a drain opening for each 6.5 m2 (70 ft2) of floor area. The drain should
be piped to the skid edge and from there to on-skid containment with suitable
vent, dip stick and tank truck-out connections. (Note: Environmental
regulations require all liquids be contained. Also note that underground
storage is not recommended due to longer-term integrity concerns.)
Seal weld sleeves with a 50 mm (2 in) rise for electrical cables coming
through the floor.
Use drip pans under pumps to contain possible seal leakage.
4.2.1.2 Transport Hazards
When moving skid-mounted equipment:
do not bend skids during loading and transport (over-stress of piping or
equipment nozzles may result),
use at least a four-point lift or the jack-and-roll method, and
leak-test all connections after transport.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-16
 4.2.2 Piping Design on Skid-Mounted Equipment
Piping design recommendations include issues encountered during installation,
applicable specifications, connections, valves, and instrumentation.
4.2.2.1 Facility Piping Installation
The following specifications apply to carrying out piping installations:
Check that the vendor has supplied all materials and equipment as specified.
Use only professional engineers or qualified technologists to design piping
additions or modifications to existing facilities. Update drawings in
accordance with Alberta Boilers Safety Association (ABSA) requirements.
Use only qualified personnel to perform and direct field construction and
facility installation.
Do not install pressure piping under floors. If required, under-floor piping
should be butt or socket welded.
If packaged equipment includes flare piping, set elevations to prevent the flare .,1.

header from being trapped at the skid boundary. Flare piping should slope
towards the flare knockout drum.
4.2.2.2 Piping Specifications
Make sure piping meets all necessary specifications.
Use insulation or protective guards in accordance with OHS regulations to
protect workers against contact with high temperature piping.
Consider the weldability of the materials (e.g., low carbon content as per
NACE MR-01-75) and the need for post-weld heat treating (e.g., stress
relieving of the welds as per ASME B31.3) in specifying sour process piping
when required by the welding procedure or in circumstances where it is
required to mitigate hardness or residual stress.
Do not use copper or brass in sour service.
Comply with the applicable American National Standards Institute (ANSI)
ratings for relief valve protection and piping both upstream and downstream
of packaged units.
4.2.2.3 Valves
The following recommendations apply to valves:
\ Provide over-pressure protection for all specification breaks (changes in pipe
pressure rating), taking temperature effects into consideration.
Do not use check valves for isolation. Use spectacle blinds or double block
and bleed if pressure piping is frequently opened.
Use indicating-type isolation valves below relief valves in accordance with
ABSA requirements. (Valves must be car-sealed or chained and locked open.)
Install double-block valves at sampling points. Do not use process
connections for routine sampling.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-17
 4.2.2.4 Connections
The following recommendations apply to piping connections:
Use a minimum of Schedule 80 material for threaded connections. Note: This
is the recommended minimum up to 60.3 mm (2 in) for mechanical strength,
but not above 60.3 mm (2 in).
Avoid using threaded connections if H2S partial pressure is more than 0.30
kPa for the main process connections.
For small diameter side branch connections in vibrating service, consider the
use of gusseting and ensure that the design and installation of piping supports
will be adequate for the design loads. Consider the use of armoured flex
connections to minimize the use of threaded connections in vibrating service.
4.2.2.5 Instrumentation
The following recommendations apply to piping instrumentation:
Use dry air for instruments if possible. If a flammable or inert gas is used,
ensure instruments are safely vented outside and instrument housing seals are
periodically checked for leaks.
Never use sour gas for instruments (i.e., gas with detectable concentration of
H2S).
Never interconnect air and gas instrumentation systems without purging.
System purging is necessary if gas is to be used as a backup to eliminate the
potential for explosive mixtures. (Note: A nitrogen cylinder is preferred.)
Externally mount level switches if possible. If internal switches are used, they
must be tested while in service.
Match level gauges to the design pressure of the equipment and blow down
into the drain system. Leave valves turned off, or use appropriate automatic
shut off valves when not taking a reading. Use level gauge valves with ball-
check shut-off valves.
Install compression-type tube fittings in strict accordance with the
manufacturers recommendations. Check fittings with a gap gauge.
4.2.3 Minimizing Hazards In and Around Skid-Mounted Buildings
Minimize potential hazards in buildings by doing the following:
Ensure adequate gravity ventilation or exhaust fan activation if hydrocarbon-
containing equipment is inside a building. In buildings where sour gas may be
present there should be a minimum of 12 air changes per hour; in sweet gas
packages there should be at least six changes per hour.
Have a minimum of two doors with panic hardware in buildings larger than
7.4 m2.
Incorporate alternate escape routes (including windows) in the building
layout.
Leave a clearance of at least one meter between major equipment for easy
evacuation.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-18
 Install canopies and/or ice rakes above doors located under the down slope of
the roof.
Locate hydrocarbon accumulators outside buildings and making sure building
heaters, for structures where hydrocarbons are present in piping or vessels, are
approved for use in hazardous locations.
Vent and install catalytic heaters with start-ups, shut-offs and guards in
compliance with electrical protection branch regulations. Fuel gas scrubbers
supplying catalytic heaters should have a high-level shut-off device.
o Note: Propane is acceptable as an alternate fuel in catalytic heaters. Sour
gas should never be used in catalytic heaters.
o Prevent liquid hydrocarbons (which have a lower ignition temperature
than natural gas) from coming into contact with catalytic heaters.
4.3 Oil and Gas Processing Packages 2
Additional recommendations are provided for the following types of packages:
compressor
heater
pump
separator
treater
4.3.1 Compressor Packages
To help ensure compressor packages operate safely:
Minimize flow through rotating equipment (especially centrifugal
compressors) during depressurizing or purging as this will also help
prevent damage to the equipment.
Use engine ignition systems approved for use in hazardous locations.
Use gussets for Pressure Safety Valve (PSV) in vibrating service.
Install industry standard shutdown devices in all packages in accordance
with risk assessment results.
4.3.1.1 Compressor Intake and Start Gas Systems
The following steps help ensure compressor intake and start gas systems function
safely:
Direct start gas exhaust piping to the building exterior above the building eave
following the precautions outlined in CAPP's Flammable Environments
Guideline.

2
Section 4.3 References
American Petroleum Institute. RP7C-11F, Recommended Practice for Installation, Maintenance, and Operation of
Internal Combustion Engines.
Occupational Health and Safety Act (OSHA) Fact Sheet, Internal Combustion Engines as Ignition Sources.
CAPP. Flammable Environments Guideline.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-19
 Avoid the intake of hydrocarbon vapours by making sure the combustion air
intake draws from outside air for gas-enginedriven compressors at hazardous
locations. Make sure that air intakes are at a safe distance from gas headers.
4.3.1.2 Compressor Piping, Connections, and Valves
The following steps help ensure compressor piping, connections and valves
function safely:
Insulate or guard engine exhaust piping inside the building.
Minimize the use of threaded piping in vibrating service.
Threaded piping is acceptable for:
o low-pressure service such as fuel and start gas,
o connections for pressure and temperature indicators,
o small pipe sizes (e.g., Nominal Pipe Size [NPS] less than 48.3 mm [1.5
in]).
Use vibration analysis to pinpoint sources of vibration and correct problems
before piping fails.
Provide adequate support to process piping. Vibration effects must be
considered.
Separate drain-line headers for glycol and oil waste storage tanks.
Install fire-safe valves on makeup controls and day tanks.
Use flanged connections, not threaded control and drain connections, in sour
service.
Locate pressure taps on adjacent upstream/downstream piping.
Minimize the number of flanged connections on compressor cylinder
pulsation bottles to reduce the risk of failure from equipment vibration.
Use external level cages with flanged isolating valves for mounting
instrumentation on sour service scrubbers. Ensure that adequate drains and/or
vents are installed on external level legs and gauge glasses.
Provide flanged spool pieces to allow adequate maintenance access or access
as required by process considerations. Mount breaking flanges on supports.
Locate unit block valves outside the package building if possible. If the valves
are located inside, they must be installed as close to the building wall as is
allowable.
Install relief valves on each compression stage of the unit with set points
appropriate for the maximum working pressure of the compressor.
Provide over-pressure protection from shut-in pressures occurring upstream.
Connect relief valves to the flare system or above the building eave line and
secure them against reaction forces.
Use socket or butt welding on sour gas piping for packing vents and drains.
Connect compressor distance piece vents and drains to an independent vent-
and-drain system to prevent back pressure on the system. Also provide
integral packing vent- and drain-tanks with drain-out and atmospheric-vent
connections.
Keep oil drains independent of all other drain systems. Provide waste oil tanks
with drain-out and atmospheric-vent connections.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-20
 Locate glycol/water header tanks so leakage will not drain onto exhaust piping
or insulation.
Provide gauge glasses, protected against mechanical damage, for glycol/water
and lubricating oil header tanks. (Lube oil header tank auto shut-off valves
may be used.)
Install crankcase explosion-relief valves on compressor engines.
4.3.1.3 Compressor Instrumentation
The following recommendations apply to compressor instrumentation:
Use intrinsically safe instrumentation systems or systems approved for use in
hazardous areas.
Use gas detection and fire detection equipment as specified in Section 4.10 of
this guide.
4.3.2 Heater Packages
The following steps help ensure heater packages operate safely:
Install adequate expansion tanks on bath heaters.
Protect heater shells with a tank hatch outside the building or a pressure-
relieving device that discharges outside the building.
Use heater coils designed to withstand full field shut-in pressure or that are
protected by PSVs.
Provide a stack-inspection/clean-out port at the bottom of the stack.
Use stainless steel flame arrestors on combustion air intake of salt bath heaters
or arrange arrestor to prevent contact with nitrate/nitrite salts in the event of
fire-tube failure.
Size the fuel gas scrubber PSV to handle full upstream flow and pressure.
(Design must consider possible fuel gas regulator failure.)
Install liquid knockout facilities with a high-level shutdown on the fuel gas
supply.
Also consider the recommendations in Section 4.5, Fired Equipment.
4.3.3 Pump Packages
The following steps help ensure pump packages operate safely:
Use belt drives of the approved static conductive type.
Use pulsation dampeners on plunger-type positive displacement pumps as
required by the manufacturer.
Use vibration analysis to pinpoint sources of vibration and correct problems.
(Concrete mass for foundations should be sufficient to minimize vibration.)
Install vibration shutdowns on pumps where appropriate.
Install PSVs between the pump and pump discharge block valve that are of
adequate size rating for use with positive displacement reciprocating pumps.
Install a filter separator upstream of the pump if there is a possibility that the
fluid contains abrasives.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-21
 4.3.4 Separator Packages
The following steps help ensure separator packages operate safely:
Use inlet separators that have high-level and high-pressure alarm and
shutdown switches and can handle the predicted quantities of liquids,
including slugging.
Use dump valves that are fail-close and provide shut-off at the maximum
vessel operating pressure differential.
Consider the addition of abrasives (e.g., sand) filter upstream if abrasives are
anticipated (e.g., frac sand or reservoir sands).
Provide man ways that are a minimum of 500 mm (20 in) internal diameter
(I.D.) on vessels with an I.D. greater than or equal to 900 mm.
4.3.5 Treater Packages
The following steps help ensure treater packages operate safely:
Use packages that contain the following shutdowns: high and low level, high
temperature, high pressure, and flame failure.
Use electrostatic treaters that have circuit breakers and an indicator light that
shows if the grid is energized.
Install vent hoods and drains on sample boxes.
Use coalescing media (other than wood excelsior) to minimize the hazards
associated with confined space entry to treater for cleanout.
Use purge-gas connections on treaters designed to eliminate potential air trap
points so a complete purge can be made.
Use corrosion coupons and internal coatings for the treater if in corrosive
service.
Use external caged level controls to provide a safe means of isolation and
removal.
Use high-pressure transparent or reflex-type level gauges instead of tubular
glass columns.
Also consider the recommendations in Section 4.5, Fired Equipment.
4.4 Dehydrator Units 3
The following steps help ensure dehydrator units operate safely:
Install heat tracing to prevent freezing on the top of the still column and on
any extension of the piping on the vapour outlet connection of glycol
regenerator still columns. Insulate with foam glass or a non-permeable
material. Alternatively, reroute the still column vent down through the
packing section.
Slope the vent line continuously to drain.
3
Section 4.4 References
CAPP. Control of Benzene Emissions from Glycol Dehydrators.
CAPP. Guideline for the Prevention and Safe Handling of Hydrates.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-22
 Route the vent line off the still column to a storage tank with a heat-traced
vent to make sure the vapour steaming off is visible.
Install the storage tank as far as possible from the reboiler flame arrestor, and
provide for level gauging and pump out.
Prevent overpressure of the reboiler by installing a U-tube, a witch's hat cone-
type check, a liquid relief regulator, or other pressure relief device on the
reboiler.
Use pressure regulators and PSVs on gas-powered glycol pump installations.
Vent gas lines to the eave line away from openings and provide protection
against water surges.
Use hydrocarbon flash tanks complete with skimmer connections on
dehydrators treating rich gas.
Install a 0-to-70 kPa pressure gauge on the reboiler that is big enough to be
easily visible to the operator.
Also consider the recommendations in Section 4.5, Fired Equipment.
4.5 Fired Equipment4
The following recommendations for fired equipment apply to the design,
installation, operation and maintenance and shall be in accordance with CSA
B149 Code and Provincial Regulations.
4.5.1 Design of Fired Equipment
The following recommendations apply to the design of fired equipment:
Use burner pilots that will shut down in an ESD situation.
Install ignition systems that eliminate the need for torch lighting.
Add safety floats to ensure dry fuel.
Use appropriate sight glass and burner-access ports. Where possible use
screwed-on access ports instead of bolted types.
Use only fired equipment that has high-temperature, flame failure and low-
level shutdown devices.
Mount the high temperature shutdown thermostat below the temperature
control thermostat and above the fire tube to ensure liquid coverage.
Provide a clean-out port at the bottom of the stack.
On the pilot piping, do not use a burner that has a trap where liquids can
accumulate.
Use five-piece mitred firebox returns and a removable fire tube.
Bolt flame arrestor housing to an external flange.

4
Section 4.5 References
American Petroleum Institute. RP 12N Operations, Maintenance and Testing of Firebox Flame Arrestors.
Occupational Health and Safety. Safe Operation of Fired Equipment in Hazardous Locations Bulletin, SH014.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-23
 4.5.2 Installation of Fired Equipment
The following recommendations apply to the installation of fired equipment:
Locate fired equipment outside of areas classified as hazardous locations. It is
better to use remote/indirect heating of process equipment than direct fire-tube
heating.
For existing facilities where it is not possible to locate fired equipment outside
hazardous locations:
o never locate firebox ends of fired equipment in enclosed hazardous areas,
o equip firebox air intakes with adequate flame arrestors,
o do not locate points of hydrocarbon venting near firebox air intakes, and
o use a firebox that is air tight except for the air intake flame arrestor's
element.
4.5.3 Operation and Maintenance of Fired Equipment
The following recommendations apply to the operation and maintenance of fired
systems:
Maintain clean flame arrestor cells.
Never increase fuel pressure to burners above maximum pressure suggested
by the manufacturer.
4.6 Liquid Petroleum Gas (LPG) Handling Facilities
The following recommendations will help ensure the safe operation of LPG-
handling facilities:
Provide for the safe venting of any LPG trapped between the truck and
loading line valves after loading or unloading.
Locate loading and unloading facilities in well-ventilated areas that are well
separated from site facilities and equipment.
Install back check valves in process rundown lines and unloading lines close
to storage tanks.
Install excess flow valves in truck loading lines from pressure storage tanks.
Install emergency shut-off valves on truck loading lines to ensure valves close
when trucks pull away or start up.
Install bulkheads and shear points downstream of valves to ensure there is a
reliable failure point downstream of valves.
Ensure grounding cables and clamps are in place and are used.
4.7 Refrigeration Process Units
The following recommendations will help ensure the safe operation of
refrigeration units:
Locate propane accumulators outside buildings because propane can be a
significant hazard if it remains in the plant. (Propane refrigerant is not
normally depressurized to flare, but it can be blown down to flare if fire is
detected in the plant.)
Double-valve all propane drain and vent lines.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-24
 Use indirect-fired reboilers if possible. If it is necessary to use direct-fired
reboilers, locate them away from hazardous areas. Also see this guide, Section
4.5, Fired Equipment, for more information.
Use antistatic belts on belt-driven engines.
Sleeve and air cool the engine exhaust. The crankcase vent should be short
and vented to the atmosphere. Mount the engine air intake on a natural-gas-
driven engine outside hazardous areas.
Provide engine oil-change facilities for motors and compressors to avoid
and/or contain spills.
Use a glycol flash tank to prevent hydrocarbon carryover into the glycol
reboiler.
4.7.1 Piping, Connections and Valves
The following recommendations will help ensure the safe operation of
refrigeration piping, connections and valves:
Match low-temperature cast steel valves to the pressure rating of standard
flange materials. Both A352 LCB and A352 LCC valves are suitable for
service at -45oC (-50oF). (The A352 LCB has a lower pressure and
temperature rating than Standard A-105 or A350-LF2 flanges.)
Use flexible connections as little as possible. If vibration is a problem, use
high-pressure rated steel wire reinforced flex connections.
Install adequate ESD stations with shutdown logic to ensure the safe and
timely shutdown of the facility.
Install isolation valves on sensing points.
4.8 Oil and Water Production Tanks
The following recommendations will help ensure the safe operation of production
tanks and oil batteries:
Use emergency venting of tanks for storage of production liquids that
complies with API 2000.
The design of tank vents and pressure relief devices shall consider potential
overpressure from high pressure gas discharged through the liquid side of the
upstream pressure vessel if the liquid dump valve fails to open or the manual
bypass is left open.
Make provision for upsets or flows in overpressure/vacuum protection,
including the failure of blanket gas regulators and emergency relief systems.
Use remote level gauges on tanks to eliminate the need to climb a tank to
gauge the fluid level.
Locate all truck loading/unloading stations outside designated hazardous
areas.
Use grounding cables and clamps.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-25
 4.9 Flare Systems and Vent Stacks 5
The following recommendations will help ensure the safe operation of flare
systems and vent stacks:
Lock off in the field all valves identified by "CSO" (car-seal open) or "CSC"
(car-seal closed). This includes block valves under relief valves and bypasses
around emergency shutdown valves.
Install and record the locks in compliance with ABSA requirements.
Provide for venting and blowing down instruments and instrument manifolds
during design.
Provide flare knockout drums that are large enough and have the required
instrumentation to prevent the liquids blowing out the flare stack.
Protect fuel gas purge/high-pressure piping connections from backflow to the
fuel system. If sweet gas is used to purge sour gas piping, the connection must
incorporate a double block with bleed between to a safe location. If sweet gas
is not used, the connection should be removed.
Do not direct dump valves from hot oil heaters to the flare system in an ESD
condition as a major fire may result.
Do not restrict relief vent lines by swages or any obstructions. Ensure the
relief system is carefully designed if field-gathering lines have a design
pressure higher than that of the plant.
If fuel gas is used as the instrument medium, use a flare header that will not
backpressure the system (ESD valve open) and over-pressure the actuators.
Design gas plants and production facilities to minimize escape of low-pressure
vapours and comply with AER regulations and CAPP flaring guideline.
Design relief systems for facilities with multiple compressors to provide
protection for all possible combinations of suction pressure and number of
operating units.
Size flare headers to handle the total volume of gas that the facility could
receive during an ESD.
Slope flare headers to allow liquid drainage into the flare knockout drum. Use
rain covers and weep holes to protect relief valve vent stacks against water
accumulation.
4.9.1 Flashback Protection
The following considerations help ensure adequate flashback protection:
For permanently lit flares, maintain a minimum purge pressure of sweet
natural gas flow to protect against air inflow and to keep flowing vapours
above the upper explosive limit (UEL).

5
Section 4.9 References
CAPP. Best Management Practice for Fugitive Emissions Management.
CAPP. Best Management Practices for Facility Flare Reduction,
CAPP. Best Management Practices for the Efficient Use of Fuel Gas in Flaring Operations.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-26
 Install an adequate means of protection when venting off of a tank system.
Alternatives include installing a positive purge gas system or a flame arresting
device at the bottom of the flare stack as a secondary means of protection.
Do not use in-line flame arrestors marketed as UL-listed because they are not
capable of stopping flashback under most conditions that may occur in the
flare system. Use detonation or second-generation flame arrestors that have
been tested according to API RP 12N.
Be aware of the hazard of flame stabilization at the flame arrestor.
4.10 Detection and Emergency Shutdown Systems
Safety systems and personal safety are integral to effective facility design. Process
designers use a variety of safeguards or layers of protection to provide a defence
system against serious incidents. Potential safeguards include
inherently safe design features
safety instrumented systems
physical protection such as relief devices
post-release protection systems
facility and community emergency responses
4.10.1 Safety Systems
A risk assessment of each facility should be performed and the following
equipment installed as required:
Install emergency shutdown device (ESD) stations with remote activators and
locate ESD valves outside of skid limits. ESD valves should be of a fireproof
and fail-safe design and must be accessible and unobstructed.
If reliable power supplies are available, install combustible gas and fire
detection equipment. This gas detection equipment should activate alarm/call-
out devices and auxiliary ventilation at gas readings of 20 per cent of the
lower explosive limit (LEL). The facility should be shut down at 40 per cent
LEL.
If reliable power is not available, use temperature-rated plastic tubing or alloy
plugs in steel tubing as a simple fire detection shutdown system.
Install a reliable pilot in the flare stack to ignite the sour gas in case the
facility depressurizes as a result of high H2S.
Install H2S detection (if power is available) to
o activate alarm/call out devices
o start auxiliary ventilation at 10 ppm H2S
o start shut in and depressurize at 20 ppm H2S
Install fire detection equipment to automatically shut down and depressurize
the facility.
In sour gas facilities, mount alarm-activated warning beacons inside and
outside buildings.
If H2S exceeds, or may exceed 10 ppm, use wind direction indicating devices.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 4-27
 4.10.2 Personal Safety
The following steps help ensure the safety of workers:
Ventilate the building as required to maintain a safe work environment.
Insulate engine exhaust piping to protect workers from burns.
Include escape routes and access to escape windows in the layout design.
Install adequate guards for fans, belts and all moving equipment.
Install combustible gas and fire detection equipment.
Install appropriate signage to alert operators and maintenance personnel to
specific hazards.
Provide enough clearance around equipment for safe access.
Carefully evaluate the use of quarter-turn valves that open to the atmosphere.
They can be accidently knocked open and result in equipment damage or
injury to workers.
Vent sample lines to the outside.
Provide adequate clearance for drain valves that terminate close to the floor or
ground level.
5 Recommended Solutions for Operating and Maintenance Practices
Ensure workers follow these recommendations for facility operations and
maintenance or equivalent as determined through risk assessment. Review the
guidelines during employee orientations, post them in appropriate locations at the
site and discuss them at regular safety meetings. The guidelines address the
following unsafe practices:
failure to take precautions around ignition sources near vents or blow downs
using poorly maintained or incorrectly calibrated gas/explosive meters
installing non-specification piping components
failure to develop and follow equipment start-up, shutdown, operating and
maintenance procedures
failure to take account of the ramifications of process changes
5.1 Site Safety Management
5.1.1 Safe Work Permits
Before an operation begins, it is important to establish a plan for controlling and
coordinating the work including the what, who, where, how, and when of
completing the operation. This information should be included on safe work
permits issued to permanent, temporary and contract personnel involved in critical
or hazardous equipment maintenance tasks.
Ensure workers obtain a hot work permit before proceeding with any work
involving pressurized or live equipment, or using equipment that could ignite a
flammable source. When there are unanticipated upsets, ensure workers follow
company procedures or prepare special work permits before responding. Do not
allow workers to improvise.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-28
 Alberta Workplace Health and Safety Bulletin SH013General Safety provides
additional guidance on safe work permits.
5.1.2 Concurrent Operations
In those situations where multiple activities are taking place on the same worksite,
the development of a site-specific, concurrent operations plan is recommended.
The purpose of the plan is to address the operational safety risks and should
consider the following:
chain of command and supervisor/worker responsibilities for the site
regulatory requirements related to minimum equipment and operational
spacing, fire control requirements and risk assessments
the identification and communication of unique hazards related to the planned
drilling, well servicing, construction, and operating activities and the
confirmation of any required safe work procedures
communication and coordination with other operators if well(s) owned by
different companies
physical and fire safety protection of in-place wellheads, facilities, etc. when
working on adjacent well(s) and confirmation of emergency response
procedures
5.2 Hazardous Substance Exposure and Control
WHMIS is an information system about hazardous and potentially hazardous
materials which are found in the work place and which, when handled, may cause
injury, illness or death to the worker.
Key WHMIS requirements include the following:
All controlled products, including all hazardous waste, on a worksite or used
by workers of the owner and all contractors are required to have the
appropriate WHMIS labels affixed.
Material safety data sheets (MSDS) are required for all production streams
and for all controlled products being used at each worksite. Copies must be
kept on site in such a manner that they are easily accessible to all workers
using controlled products.
All workers, including contractor workers, on worksites where controlled
products may be handled, shall be fully trained in understanding and using the
WHMIS system and the safe handling of controlled products and hazardous
waste.
Clients and contractors are required to review their WHMIS program at least
annually, or more frequently if required by a change in work conditions or
available hazard information, with instruction and training provided to
workers concerning controlled products.
Owners and contractors are required to update all MSDS every three years.
The Canadian Environmental Protection Act (CEPA) also includes important
requirements such as the following:

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-29
 Companies who own or manage specified toxic and hazardous substances at
or above the specified thresholds must provide required information on the
substance(s), including quantities and must prepare and implement
environmental emergency plans.
Hazardous substances commonly associated with portable oil and gas processing
buildings and facilities include hydrogen sulphide (H2S), benzene and other
chemicals.
5.2.1 Hydrogen Sulphide (H2S)
Hydrogen sulphide is a common petroleum contaminant. It may be present as a
gas or may be dissolved in produced water, crude oil or natural gas condensate.
Hydrocarbons contaminated with H2S are called sour.
For health and safety purposes, all facilities processing hydrocarbons
contaminated with any concentration of H2S should be evaluated for the potential
of worker overexposure. If the potential exists, then a code of practice should be
implemented.
CAPP has developed a Hydrogen Sulphide (H2S) Guideline to assist member
companies in the development of their codes of practice.
5.2.2 Benzene
Benzene and the associated compounds of toluene, ethylbenzene and xylene
(commonly referred to as BTEX) have an anesthetic effect and primarily attack
the central nervous system. Prolonged exposure to benzene concentrations of 100
ppm (IRP 14) will have adverse consequences.
BTEX compounds are normally found as liquids in gas condensates and crude oil
streams. If liquid hydrocarbon streams at a gas plant have concentrations of
benzene that exceed the 0.1 per cent level and are in the range of 0.5 to 1.5 per
cent, extra caution must be taken. Normally, condensate is stored and transported
in a closed system of vessels, lines and pumps but workers can be exposed when
those systems are opened for maintenance.
CAPP has developed a Best Management Practice for the Control of Benzene
Emissions from Glycol Dehydrators.
5.2.3 Chemicals
Owners and employers are required to identify the potential for worker exposure
to harmful chemicals as part of the hazard identification and assessment process.
It is important to ensure that a workers exposure to any substance does not
exceed occupational exposure limits specified in Part 4 of the Alberta OHS Code.
Employers are required to assess the need for atmospheric testing before workers
are exposed.
Regulations and recommended industry practices may require an exposure control
plan (ECP) to be prepared to protect workers and building occupants from
potential risks identified in a risk assessment.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-30
 5.2.4 Other Potential Occupational Exposures
Other potential occupation exposures include
asbestos
hantavirus
normally occurring radioactive materials (NORM)
silica
Under normal circumstances, the development of a code of practice will be the
responsibility of either the prime contractor or the employer completing the work.
5.3 Critical Safe Operating Procedures
As previously stated, any critical task to be undertaken by workers must be
preceded by a hazard assessment of that task. Codes of practice may be required
for the following critical tasks. In addition, a hazard assessment may be
completed prior to commencing the task:
IMPORTANT: Company representatives are responsible for ensuring that a code
of practice is available and being applied for key critical tasks. When critical tasks
are undertaken by a contractor, the contractor will be responsible for development
of a code of practice pertinent to the equipment and personnel required for
completing the work safely. In most circumstances, the contractor completing the
work should have an acceptable code of practice. If not, the owners code of
practice must be referenced and applied as required.
5.3.1 Confined and Restricted Space Entry
A written code of practice is required that outlines the procedures to be followed
whenever a worker enters a confined space. This practice must identify existing
and potential confined space work locations at a worksite, training, hot work, and
confined space entry permit requirements.
5.3.2 Critical Lifts and Safe Lifting Certifications
Prior to performing a lift, the operator shall determine the weight of the object to
be lifted and ensure that cables, lifting devices, slings, wire ropes, chains, etc., are
of sufficient strength, in safe condition and positioned to support the weight of the
load. Lift/load calculations MUST be conducted for lifts exceeding 75 per cent of
lifting device capacity. Only competent/qualified, authorized workers shall
operate lifting devices. Critical lifts are further defined in provincial OHS
regulation and can include heavy lifts, lifts over process equipment, lifts involving
two cranes, lifts where the operator cannot see the load, lifts using personnel-
baskets, etc.
When critical lifts are being made, a critical lift plan must be developed and
communicated to all personnel involved in the critical lift at a documented pre-job
meeting. A critical lift plan identifies the minimum requirements that must be
evaluated before completing a critical lift.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-31
 5.3.3 Electrical Safety (Including Working near Overhead Power
Lines)
Contractors are required to take precautions when working near overhead power
lines.
5.3.4 Energy Isolation (Including Lock-Out/Tag-Out)
A written Code of Practice is required that outlines the minimum requirements for
locking out and tagging equipment.
This practice is to be applied when a worker removes or bypasses a safeguard
on equipment that is not under the workers direct control. In these cases, the
worker must control hazardous energy (e.g., lockout), as required by Part 15
of the Alberta OHS Code and Part 10 of the BC OHS Regulation. This
ensures that the equipment cannot be activated by another worker.
This is an important consideration any time a worker is required to work on or
near active production equipment (e.g., pumps jack, pressurized piping and
vessels, etc.). In these cases, lockout protocols must be reviewed to determine
who is required to place a lock on the equipment in question.
5.3.5 Flammable Atmospheres (Including Hot Work and Fire and
Explosion Prevention)
The OHS regulations highlight the need for having a process for managing hot
work. In addition, AER 033 requires licensees to have a documented fire and
explosion prevention plan available at the wellsite for the safe management of the
potential for explosive mixtures and ignition in wells and associated surface
equipment.
5.3.6 Ground Disturbance (Including Damage Prevention)
The Alberta OHS Code and the AER under the Pipeline Act identify the specific
procedures required for ground disturbances. This includes digging sumps,
placing anchors and other similar ground disturbances associated with drilling and
completion operations. Also refer to IRP 17 Ground Disturbance Checklist and
AER Backfill Inspection Report.
5.3.7 Hydrate Handling
Hydrates in wells, gas piping and pipelines are very hazardous. The uncontrolled
removal of hydrates has caused pipes to be knocked off supports, equipment
damaged due to ruptures, and injuries and even death to occur. Therefore, it is
extremely important for workers to know about the prevention and safe removal
of hydrates in gas lines.
The purpose of the CAPP Guideline for Hydrate Prevention and Handling is
to provide an understanding of the conditions under which hydrates are
formed so that, when possible, they can be prevented
to ensure that hydrates are removed safely

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-32
 5.3.8 Purging
Purging operations may require a code of practice to provide pertinent
information, minimum requirements and a consistent approach to safely remove
air, combustible, chemical, toxic, or other reactive gases or liquids from vessels,
equipment and piping.
5.3.9 Vehicle OperationsJourney Management
Vehicle operation and driving practices are a significant hazard for Canadian
oilfield workers. Companies should consider developing minimum vehicle
operating practices and journey management guidelines.
5.3.10 Working Alone
Employers are not required to have a written code of practice for workers working
alone. Notwithstanding this, companies are required to develop a code of practice
outlining the working-alone risk assessment strategy adopted by the company. It
is important for company representatives and contractors to establish working-
alone procedures when applicable.
5.3.11 Working at Heights
An employer must develop procedures in a fall protection plan for a worksite if a
worker at the worksite may fall three metres (3 m) or more and workers are not
protected by guardrails. This plan must specify the fall hazards, the fall protection
system to be used at the worksite, and the procedures for maintenance, inspection
and rescue.
5.4 Site-Specific Procedures
In some cases it may be necessary to develop site-specific procedures to better
address unique equipment and operating hazards not addressed by standard
operating and maintenance procedures.
5.4.1 Knowledge of Equipment
Ensure workers understand the process, equipment and materials they use. For the
safety of themselves and fellow workers, it is important that workers
Follow site-specific procedures to lock out mobile equipment.
Know the locations and operations of all safety equipment and portable fire
extinguishers.
Exercise caution when draining a vessel (flashing liquid becomes cold and
metal failures can occur).
Isolate, depressurize and purge before working on equipment vessels and
piping.
Install blind flanges on all nozzles before working on a vessel, section of
piping or other equipment.
Lock out and tag all valves, switches and brakes used to isolate systems and
equipment.
Use appropriate test equipment such as "sniffers to detect gases, and
voltmeters to detect live circuits before proceeding with maintenance.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-33
 Ensure all electrical equipment is adequately grounded.
Use the correct fuses and breakers on all electrical equipment installed.
Ensure that all relief valves required to protect pressurized equipment are
correctly installed and maintained.
Steam out or chemically wash vessels in sour service to remove all traces of
hydrogen sulphide and iron sulphides before anyone enters the vessel.
Cold cut the checker plate and check for explosive vapours before working on
or under skid floors.
5.4.2 Commissioning and Start-up
The start-up of operations can be especially hazardous. Develop start-up
procedures and communicate them to all persons involved in start-up operations.
See Sections 5.4.2.1 to 5.4.2.8 for methods to reduce key safety risks during start-
up.
5.4.2.1 Air Blowing (Depressurizing Lines of Air)
Make sure workers
Notify all personnel in blow-off areas and keep them away from blow-off
points.
Wear ear protection (if noise levels are high) and safety goggles.
Check the entire system before blowing.
5.4.2.2 Water Flushing
Make sure workers
Check lines to be flushed before starting.
Notify all personnel in the area and limit access if necessary.
Discharge flushing fluids into areas where they will not create a hazard.
Drain all dead legs (low points in the piping) during winter to prevent damage
from freezing.
5.4.2.3 Leak Checking with Air
Make sure workers
Thoroughly check equipment for loose connections before starting (an
overlooked leak at this stage may later develop into a serious hazard).
Isolate equipment that is not designed for pressure.
5.4.2.4 Purging
Use an inert medium for purging. If an inert medium like nitrogen (N2) cannot be
used, take the following precautions:
Tightly control or prohibit all sources of ignition in the area (including
smoking).
Allow only essential personnel in areas where purging is done.
Purge at atmospheric pressure.
Purge very slowly to keep gas velocities low.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-34
 Use hoses to direct vented gas outside buildings and confined areas. Make
sure hose ends are secured.
Purge each line separately and track using colour coding on a mechanical flow
diagram.
5.4.2.5 Pre-start-up Check
Operations personnel need to be satisfied that the facility is safe to start.
Operational readiness considerations include
procedures in place
maintenance plans in place
documentation necessary to manage risks in the facility are available
action items from risk assessments that are necessary to be completed prior to
start-up have been completed
commissioning activities completed, etc.
After purging and before start-up, make sure workers complete the following:
Test oxygen levels in lines or vessels. Oxygen levels must be below 5 per
cent.
Visually check the facility for any tools or purging equipment left behind that
could create hazards during start-up.
Complete a full electrical and controls system check.
Refer to manufacturer's start-up manuals (or contact manufacturer) for safe
procedures.
Evaluate hazardous conditions before start-up (Refer to HAZOP API RP750).
5.4.2.6 Production Chemistry
The potential effect of downhole chemistry on the operation of surface equipment
needs to be reviewed. Consideration may have to be given to corrosion protection,
hydrate management, scale, etc. A production chemistry consultant may need to
be engaged to develop an appropriate chemical program.
5.4.2.7 Building Entry
There are many hazards involved when entering buildings on various locations,
personnel must be aware of all the risks and challenges of completing this task.
An obvious increase in risk is encountered when dealing with buildings in sour
applications and should be dealt with accordingly. Employers must ensure all
reasonable precautions are taken to ensure the safety of personnel and property
when entering onto a lease and into buildings that may contain toxic gas vapours,
combustible atmosphere or lack of sufficient oxygen.
5.4.2.8 Working with Steam
Ensure workers take the following precautions when using steam hoses:
Use only approved steam hoses that have a sufficiently high pressure rating.
Always shut off the steam supply to the hose before closing the valve at the
discharge end.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 5-35
 Wear leather gloves and appropriate hearing protection when noise levels
warrant.
Do not blow off steam where workers may be endangered.
Secure open ends of the blow-off hose (if used) and fence off the blow-off and
drain areas.
When steaming lines, watch line expansion, check pipe supports, sliders and
hangers. Stop steaming if undue stress occurs.
5.4.2.9 Housekeeping
Make sure the following basic "good housekeeping" rules are part of every
workers daily routine:
Keep floors, stairs and platforms clean and free of tools and other loose
materials.
Keep oily rags and paint rags in tightly sealed metal containers.
Clean up oil spills immediately using only approved solvents, never gasoline.
Have a place for everything and keep everything in its place.
6 Recommended Solutions for Worker Competency
This section describes the safety and technical training workers and contract
operators at oil and gas facilities need to understand in order to respond to the
hazards they may encounter in their daily work.
It is important that training prepare workers to both recognize the hazards in a
task and to take appropriate safety measures. Basic safety training must be
supplemented with technical training and site-specific safety training.
Employers are responsible for ensuring workers complete this training and work
in a manner that safeguards everyone on or near the
worksite.
6.1 Worker Orientations
Site Specific Employer
As shown in the adjacent diagram, the industry
Orientation Onboarding
has identified four phases of the safety
orientation process:
Prime
Contractor GSO/eGSO
1. employer onboarding Orientation
2. oil and gas industry General Safety
Orientation (eGSO)
3. prime contractor messaging (optional)
4. site specific orientation
The responsibility of company representatives is to ensure that all on-site workers
(workers and contractors) receive a site-specific safety orientation. The
orientation process is an introduction to critical aspects of an HSE Management
Program and provides immediate information that workers need to know,
including a review of any relevant company policies and practices,
responsibilities and expectations, as well as relevant administrative issues.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 6-36
 6.2 Basic Training & Competency Requirements
Section 1(g) of the Alberta OHS Regulation defines a competent worker as one
who is adequately qualified, suitably trained and with sufficient experience to
perform work safely. Specific to worker training, the above regulation requires
the following:
Section 13General Protection of Workers
o the employer shall ensure that work is done only by a competent worker
o workers must be familiar with any procedures developed by employer
o workers must be competent in care and use of safety equipment
o employers must ensure workers perform duties
Section 15Safety Training
o workers must be trained in safe operation of equipment
o worker training must include: use of equipment, limitation of the
equipment, inspections and basic maintenance, and associated hazards
specific to the operation of the equipment
o workers must participate in training provided by employer
o workers must apply training
In consideration of this, the following components should be considered by
employers when establishing worker competency standards:
core safety training
technical training
6.2.1 Core Safety Training (Pre-Hire Confirmation and
Documentation)
Core safety training requirements should be determined and scheduled as soon as
possible. It is recommended that companies maintain a detailed file for their
worksite supervisors to ensure that the training certifications are maintained for
all required courses, with an expiry date. In addition to training certifications,
copies of a current rsum, orientation completion, and other documents relevant
to the competency and safety performance of personnel should be obtained.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 6-37
Table 6.1 Required Certification and Training

On-Site
Certification Required Training Requirements Supervisor
Worker
General Safety
Best Practice (ENFORM) Recommended Required
Orientation
Safety Management Industry Recommended
and Regulatory Practice 7 Recommended Recommended
Awareness for Wellsite
Supervision (3 Yr) Alberta OHS Act Section 3

Standard First Aid (3

Alberta OHS Code Part 11 Required Required
Yr)
H2S Alive (3 Yr) Alberta OHS Code Part 04 Required Required
WHMIS Alberta OHS Code Part 04 Required Required
TDG (3 Yr) Federal TDG Requirements Required Required
Alberta OHS Code Part 32 +
Ground Disturbance Required Recommended
AER
Detection and Control
of Flammable Alberta OHS Code Part 10 Recommended Recommended
Substances
Confined Space Pre-
Alberta OHS Code Part 05 Recommended Recommended
Entry
Emergency Response AER Directive 071 Required Required
Industry Practice (Enform
Spill Response Recommended Recommended
WCSS)
Best Practice (Canada Safety
ATV Training Recommended Recommended
Council)

Note: The majority of safety courses are valid for a three-year period. Employers are
responsible for ensuring training is kept current and training records are maintained. Where
a project or regulation requires certificates of competency to perform designated tasks, a
record of the certificates will be taken at time of employment or orientation prior to workers
being able to perform those tasks. The certificates of competency must be readily available
for management review.

6.2.2 Technical Training: Core and Operations-Specific

In addition to core safety training, all oil and gas facility operators should receive
both general and specific technical training applicable to facility operations.
Recommended technical training is summarized in Table 6.2.
Contractors are responsible for providing trained and competent workers.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 6-38
Table 6.2 Technical Training: Core and Operations-Specific
Type of Training Training Elements
General Technical Introduction to oil and gas operations and equipment:
Flow measurement: orifice plates
Level measurement
Pressure measurement
Pumps (including pd and centrifugal pumps)
Static electricity
Temperature measurement
Valves
Gas and fire detection equipment
Handling of hydrocarbon fluids
Hydrates and ice plugs
Hydrocarbon fluid storage and loading
Internal combustion engines
Isolation of mechanical and electrical equipment
Oil and gas composition and sales specifications
Pressure safety devices
Purging
Produced water handling and disposal
Worksite inspection and hazardous area classification
Oil Well Operations Oilfield operations overview
Pumpjacks
Sucker rod strings
Bottomhole pumps
Pipeline pigging
Production testing
Battery Operations Battery operations overview
Oil and emulsion treating
Operation of fired vessels
Oil and water storage and custody transfer
Gas Well Operations Gas production overview including problem prevention
Field operations
Design and normal operation
Gas dehydration
Gas-line heating
Separation procedures and equipment
Properties and characteristics of natural gas
Compressor Station Classification and types of gas compressors
Operations Basic controls

July 2014 Small, Portable Oil & Gas Facilities Guide Page 6-39
 Compressor components
Drivers and operational controls
Lubrications
Valve and rod packing
Gas Plant Operations Condensate stabilization systems
Dehydration chemicals, liquid desiccants dehydration, testing
Development and types of gas plant processes
Glycol equipment and operation
Inlet equipment and operation
Inlet separation process description
Process flow refrigeration
Stabilization equipment
Sweetening processes, equipment and chemicals

6.3 Competency Management and Development

A training program needs to address the following due diligence factors related to
worker competence and training initiatives:
level of worker competence based on prior training and experience
level and amount of worker training required to competently operate the
assigned facilities
operating and maintenance requirements for the equipment in use
safe work practices and industry guidelines appropriate for the operations
work conditions, including any specific personal protective equipment
consultation and use of experts when appropriate
In developing a worker capability management system, employers should
consider the following:
Capability management and development system (CMD)
A capability management and development system is a supportive
administrative system and process, the purpose of which is to ensure the status
for each worker is maintained and monitored. Regular reports are prepared
and issued to field management summarizing the status of each worker.
Safety critical task analysis and skill profile development
Development of an area skills profile is based on the nature of job
requirements and a safety critical task analysis. The skills profile is reviewed
regularly to ensure the tasks specific to the job are included. Regular review is
required to identify and maintain appropriate skills profiles. This includes the
addition of any skills required to address site-specific procedures required by
the company.
Prior learning assessments and validations
Validation of competency includes two recommended steps:
o All workers should complete a self-assessment of prior learning to confirm
their knowledge level.

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 o An on-the-job validation should be completed by a qualified person to
confirm each workers knowledge level and verify competency.
Competency development and support
Upon completion of the on-thejob validation, appropriate measures are taken
to address any knowledge and skill gaps. A worker-specific training plan may
be developed in those circumstances where a more structured learning plan is
required. Once skill gaps are addressed, the worker validation is updated. A
wide range of capability development tools are available to support the
program, including standard operating practices which are supplemented as
company activities evolve.

July 2014 Small, Portable Oil & Gas Facilities Guide Page 6-41