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Delta-P Test Corp. Safety Handbook

Remember: The contents of this handbook were not intended to make your life difficult or to increase your paperwork. This book is designed to keep you and your co-workers safe.

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Delta-P Test Corp. Safety Handbook 1.0 Corporate Safety Policy....................................................................... 3 2.0 Petroleum Industry Guiding Principles for Worker Safety ............... 4 3.0 Introduction .......................................................................................... 5 4.0 Safety Responsibilities........................................................................ 6 4.1 Operating Company’s Responsibilities .................................................. 6 4.2 Management’s Responsibilities.............................................................. 6 4.3 Tester’s Responsibilities ........................................................................ 7 5.0 Hazard Identification............................................................................ 9 5.1 Introduction ............................................................................................ 9 5.2 Types of Inspections .............................................................................. 9 5.2.1 Vehicle Inspections ......................................................................... 9 5.2.2 Site Inspections ............................................................................ 10 5.3 Hazard Control..................................................................................... 10 5.4 Hazard Reporting................................................................................. 10 5.5 Implementation of Hazard Identification and Control ........................... 11 5.6 Hazard Control through Maintenance .................................................. 12 6.0 Rules and Work Procedures ............................................................. 13 6.1 General Safety Rules ....................................................................... 13 6.2 Personal Protective Equipment ........................................................ 14 6.3 Vehicles and Driving......................................................................... 15 6.4 Fire Prevention and Protection ......................................................... 16 6.5 Hazardous Materials......................................................................... 18 6.6 Equipment and Operations............................................................... 20 6.7 Testing Specific Rules ...................................................................... 24 6.8 Working Alone .................................................................................. 24 7.0 Communication.................................................................................. 25 7.1 General..................................................................................................... 25 7.2 Pre-Job Safety Meetings .......................................................................... 25 7.3 General Safety Meeting ............................................................................ 25 8.0 Training and Orientation ................................................................... 27 Appendix A: Inspection Sheets....................................................................... 29 Appendix B: Hazard Identification Report and Incident Report. .................. 30 Appendix C: Hazard Management .................................................................. 31 Appendix D: Workplace Hazardous Materials Information System (WHMIS) ........................................................................................................................... 35 Appendix E: Transportation of Dangerous Goods (TDG). ............................ 36 Appendix F: Industry Recommended Practices: Drill Stem Testing. .......... 37 Appendix G: Working Alone............................................................................ 38 Appendix H: Safety Meeting Forms ................................................................ 39

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Delta-P Test Corp. Safety Handbook 1.0 Corporate Safety Policy 1. The health and safety of employees, contractors, and sub-contractors are paramount in the conduct of our business. 2. Risks present in all operations must be managed to prevent injury and sickness, through proper work planning and organizing, hazard identification, hazard control, and accident investigation. 3. Management is responsible and accountable for providing a safe working environment and fostering safe working attitudes. 4. Management is responsible for establishing safety rules and procedures, as well as providing proper training and to ensure that everyone understands their responsibilities. 5. All employees, contractors, and sub-contractors must comply with all health and safety policies and follow all established rules and procedures at all times. 6. Company rules and procedures meet applicable laws, regulations, industry standards, and client requirements. 7. It is the responsibility of employees, contractors, and sub-contractors to work in a manner that ensures their personal safety as well as the safety of their fellow workers. 8. It is the responsibility of management, employees, contractors, and subcontractors to support, participate in, and enhance the safety program and communicate ideas to improve, and ultimately, achieve excellence in health and safety. 9. Everyone has the right and responsibility to refuse to do work when unsafe conditions exist. 10. By fulfilling our safety responsibilities, everyone who works for Delta P Test Corp. will share the benefits of a safe work environment.

President and CEO

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Date

Delta-P Test Corp. Safety Handbook 2.0 Petroleum Industry Guiding Principles for Worker Safety

There are two copies of the Petroleum Guiding Principles for Worker Safety included in this manual. One is on the following page; the other is laminated and loose. Please display the laminated copy (prominently) in your test unit. There is a laminated copy of Delta-P’s Corporate Safety Policy. Please display the laminated copy (prominently) in your test unit.

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Petroleum Industry Guiding Principles For Worker Safety We, the members of the petroleum industry, have a responsibility to protect all workers engaged in its activities from personal injury and health hazards. To meet our responsibility we will operate under the following guiding principles: RESPONSIBILITY The operating company, when acting as prime contractor, is responsible for coordination and general supervision of all activities at the work site, including activities carried out by contractors, subcontractors, service companies and suppliers. While all parties have a responsibility to promote worker safety, the operating company recognizes its leadership role in promoting worker health and safety on the basis that it has the greatest power to influence work site situations. It is the responsibility of workers and employers to refuse to perform unsafe work practices. PRIORITY Activities will be conducted on the basis that safety of all personnel is of vital importance, whether those personnel are employed by an operating company, a contractor, a sub-contractor, a service company or a supplier. RECOGNITION The process of selecting contractors, sub-contractors, service companies and suppliers, and the administration of contracts, will include recognition and support of good safety performance. Support and recognition based on good safety performance will also be provided by all employers to their employees. IMPROVEMENT The operating company, in cooperation with service companies within the industry, will promote methods and practices that have potential for improving safety performance.

Chairman of the Board Canadian Association of Petroleum Producers

Chairman of the Board Canadian Association of Geophysical Contractors

Chairman of the Board Canadian Association of Oilwell Drilling Contractors

Chairman of the Board Petroleum Services Association of Canada

Chairman of the Board Canadian Energy Pipeline Association

Chairman of the Board Small Explorers and Producers Association of Canada

Chief Executive Officer

Chief Operating Officer

Company Name

Company Name

October 2000

Delta-P Test Corp. Safety Handbook 3.0 Introduction Delta-P Test Corp. is sincerely concerned about the safety of its employees, contractors, and sub-contractors. It is the company policy to provide a safe working environment. This manual was designed to provide everyone working for Delta-P Test Corp. with the tools to ensure that they can work safely. Everyone must follow the safety procedures outlined in this manual and all applicable government regulations while working for Delta-P Test Corp. Testing, by the very nature of the work, is diverse and demanding. Working environments and condition are always changing – as such; rules cannot be established to cover all situations and scenarios. It is mandatory that good judgment and common sense prevail in all testing and traveling situations. Be alert and do not take chances. If the job can’t be done safely, it shouldn’t be done at all.

T.B. Bratrud, P.Eng. Chief Engineer Delta-P Test Corp.

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Delta-P Test Corp. Safety Handbook 4.0 Safety Responsibilities It is the responsibility of every employee, contractor, or sub-contractor or operating company (client) to meet the goals of Delta P’s corporate Safety Policy. To this end, the general safety responsibilities of each person involved in the work have been identified. It should be noted that due to the diverse nature of well testing, these lists should be used as guidelines for determining safe work, but safe work is not limited to the responsibilities contained on these lists. Common sense must prevail at all times and safety must be the paramount condition in all testing and traveling circumstances.

4.1

Operating Company’s Responsibilities

The operating Company’s Responsibilities are: •

Insist on safe performance throughout operations by ensuring contractors and employees are competent to do their work properly.

•

Have an effective safety program.

•

Ensure the safety program and operations comply with contractual and regulatory requirements.

•

Ensure contractors and employees know the operating company’s expectations.

•

Provide sufficient time for contractors and employees to perform their jobs safely.

•

Hire for employees and contractors only individuals who have good safety records.

4.2

Management’s Responsibilities

Management’s responsibilities are: •

Insist on performance and behavior that meet the standards of the company’s safety program.

•

Encourage employee involvement in safety by demonstrating management’s commitment to safety.

•

Ensuring company, contractor, and testing operations comply with government safety requirements.

•

Ensuring accidents and incidents are reported and investigated and corrective actions are taken.

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Delta-P Test Corp. Safety Handbook •

Ensuring that testers are adequately qualified to perform their work.

•

Ensuring that training needs are identified and met.

•

Ensure that testers, contractors, and sub-contractors know what is expected of them.

•

Ensure that testers, contractors, and sub-contractors understand the proper reporting procedures for accidents and incidents.

•

Conduct investigations, using outside specialists if required, of all accidents and incidents. Record all findings and take appropriate measures.

•

Establish equipment inspection and maintenance procedures and schedules.

•

Conduct safety meetings and record minutes; circulate and post meeting minutes.

4.3

Tester’s Responsibilities

A tester’s responsibilities are: •

Operate only the equipment and carry out tasks for which they have been adequately trained.

•

Properly use Personal Protective Equipment.

•

Abide by all government regulations, company policies (Delta-P and Client), procedures and standards pertaining to testing.

•

Refuse to work under conditions or perform tasks for which they are not adequately trained or prepared.

•

Be thoroughly familiar with the company safety program.

•

Report potential hazards to the Operating Company and the Drilling Contractor. Identified hazards should also be recorded and passed on to management.

•

Immediately report all accidents and incidents management.

•

Participate in the development and improvement of the safety program.

•

Know the location, type and operation of all emergency equipment on board testing units.

•

Participate in on-site safety meetings and orientations held by Operating Companies or Drilling Contractors.

•

Immediately correct unsafe conditions in test units.

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Delta-P Test Corp. Safety Handbook •

Inform Rig Crews of all known hazards prior to testing and measures for dealing with the hazards.

•

Inspect worksites for hazardous conditions and compliance with regulatory and Operating Company requirements.

•

Properly maintain testing vehicles and test equipment to minimize operating hazards.

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Delta-P Test Corp. Safety Handbook 5.0 Hazard Identification 5.1

Introduction

The Oilfield can is a dangerous place. Hazards exist on every drilling rig and lease. Every Drill Stem Test has potential hazards. Hazards are conditions that exist in every workplace. A HAZARD is a condition that, if not properly identified and mitigated, could lead to an incident, near miss, injury or accident. It is critical that hazards be identified BEFORE they can evolve or cause an incident. The best method for identifying hazards in the workplace is INSPECTION. INSPECTIONS are visual reconnaissance of a worksite with the intent of identifying hazards.

5.2

Types of Inspections

5.2.1 Vehicle Inspections Drill Stem testing can be broken into two segments: Travel to/from the jobsite and testing on the jobsite. Due to significant amount of hours that are spent driving, road, travel and vehicle related hazards pose a threat to the safety of the tester. It is essential that vehicles be inspected on a regular basis to minimize the incident potential. Three different inspection checklists have been included in Appendix A: •

Quick Visual Reviews

•

Detailed Visual Review

•

Documented Vehicle Inspection

The Quick Visual Review should be performed prior to every trip with the test vehicle. It consists of vehicle walk around to ensure that all tires are inflated, running lights are functioning, that there are no obstructions around the tires, exhaust pipes are free of clogs, and that all equipment bay door are secured. As part of the visual review, the driver should ask himself two questions: Am I in the proper condition to operate this vehicle in a safe and responsible manner? And What changes to my driving style will I have to make to properly accommodate the prevailing weather conditions. The Detailed Visual Review should be performed while the vehicle is stopped for refueling. It consists of fluid level checks in addition to tire pressure checks.

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Delta-P Test Corp. Safety Handbook The Documented Vehicle Inspection is to be performed every 5000km. This is a documented review of the vehicle’s operations and condition. A copy of the review is to be forwarded to the head office for review and filing. If a condition is identified as a potential hazard during an inspection, it must be repaired prior to travel to the jobsite.

5.2.2 Site Inspections Due to the diverse nature of drill stem testing, there are a continually changing range, number, and risk level of hazards. It is critical that every drilling site, rig, and rig crew, be inspected prior to engaging in testing operations. Site hazards can take many forms: trip hazards, slippery stairways, overhead wires, lifting loads, etc. Most of these hazards can be avoided – but avoiding a hazard can only occur if the hazard is recognized. These hazards do not have to be documented in any uniform fashion; however, a checklist has been provided to assist in identifying onsite hazards. See Appendix B for a copy of the Site Inspection Checklist. Some hazards, however, cannot be avoided and some other action must be taken to correct the hazard. If this is the case, the hazard should be identified to the Tool Push. If no action is taken, the hazard should be identified to the Site Engineer/Consultant. If there is still no action to mitigate the hazard, a hazard identification form and risk assessment form should be filled out and kept on file. Submit a copy of this form by email as soon as possible. See Appendix B for a copy of the Hazard Identification Report.

5.3

Hazard Control

After an inspection is complete, it is necessary to control any hazards that have been identified. There are three steps in hazard control: •

Identify and determine what needs to be done to control/remove the hazard.

•

Identify and determine what needs to be done to remove the hazard.

•

Establish a time to perform the hazard control.

See Appendix C for more information on Hazard Identification, Hazard Control, and Hazard Management.

5.4

Hazard Reporting

After an inspection is complete, sometimes it is necessary to report the hazard to someone other than yourself. A form for hazard reporting has been included in Appendix B. 19/06/01 10 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Delta-P Test Corp. Safety Handbook Most of the time, when a hazard has been identified, it can be corrected by verbal communication with the rig crew, Tool Push, or Company Engineer. However, if this not the case, a document may be required to properly record the hazard. These reports will be sent into the Delta-P head office for filing.

5.5

Implementation of Hazard Identification and Control

The preceding sections on hazard identification, control and reporting may seem like a great deal of work. This is not the case. Once you become familiar with the inspection sheets, they will become an asset to you. Not only will they help keep you safe, but they will also reduce vehicle breakdowns. In order to assist you with the understanding of Hazard Identification and Control, a few examples follow for you to read: Example #1 Inspection: Vehicle Detailed Visual Review. Hazard: Low oil level. - A hazard has been identified by visual inspection. It should be controlled. What needs to be done to remove hazard? Add oil to engine. Who needs to do it? You. (Or the station attendant, if available) When? Now. Note that the “when” question is open to discussion. The truck may be scheduled for an oil change the next day, adding a quart of oil is just a waste of money. In this case, the low oil level hazard is a low risk level. However, the oil level may be low and oil was just added on the previous fuel stop. In this situation, the action taken may be more than adding oil – a service stop may be required. If this is the case the “who” changes to a serviceman and the “when” question becomes more important.

Example #2 Inspection: Site Inspection Checklist. Hazard: Logging Truck has Gamma Ray source on lease. - A hazard has been identified with an inspection checklist. What needs to be done to remove the hazard? Wait for the logger to complete his task Who needs to do it? The logging operator

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Delta-P Test Corp. Safety Handbook When? Upon completion of logging rig-out operations. Note that in this case the “who” is someone other than you. If this is case, it is often necessary to avoid the hazard – i.e. stay away until the hazard is removed. This is also the case with excavations, overhead cables and other physical hazards. If they cannot be removed, they may be avoided. This is another reason for having inspections: you cannot avoid what you cannot identify!

5.6

Hazard Control through Maintenance

Hazards can be controlled by regular maintenance schedules performed on all tools. Refer to Appendix A for a copy of the DST Tool Maintenance form. All DST tools must be serviced as soon as possible after a test. After servicing, a Maintenance form must be filled out to record the details of the service procedures.

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Delta-P Test Corp. Safety Handbook 6.0 Rules and Work Procedures 6.1

General Safety Rules Smoking No Smoking signs on each worksite must be obeyed. Smoking is permitted in designated locations approved. Drugs and Alcohol The use of drugs and alcohol on any worksite where Delta-P is operating is strictly prohibited. Tester found to be under the influence of alcohol or illegal drugs while working for Delta-P will be asked to leave the operating company worksite. Prescription medications that may interfere with the safe execution of testing operations should brought to the attention of Management for review. Security All Thefts, burglaries and acts of vandalism must be reported to Management. Trucks and equipment should be locked at all times. Housekeeping Good housekeeping is a basic part of accident prevention. Clean test units and worksites encourage pride in the job and prevent hazards that lead to incidents. All work areas and shop spaces must be kept clean and free of obstructions. Tools, grease, and other materials left lying around can create tripping or slipping hazards. To prevent spills or accumulations of hazardous substances, leaks (vehicle or equipment) must be repaired as soon as possible. Spilled toxic materials must be cleaned up immediately. Refer to the Material Safety Data Sheets (MSDS) (found in the doghouse, Engineer’s shack, or Tool Push’s shack) for the correct method. Every worksite must be cleaned up at the end of each shift or at the conclusion of the job. All refuse must be disposed of in appropriate containers. Remember: if you are disposing of test data, do so in a manner that obscures the information (shredding or burning) contained on the paper. Emergency Response Plans. Every drilling rig and Operating Company will have detailed Emergency Response Plans (ERP) for every location. Testers must become familiar with the All testers must become familiar with the specific EPR for each test location. In the event of an emergency, Delta-P testers are required to follow the instructions of the Operating Company Representative.

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Delta-P Test Corp. Safety Handbook Delta-P Testers should also render support to secure the wellbore as necessary (i.e. shut-in hydraulic tool, shut-in test head, close manifold). Facial & Head Hair Head hair must be off the collar and above the ear. Facial hair must NOT be longer than 1 day of growth. Beards, goatees and manchurians are not permitted. Accidents, Incidents, and Injuries Al accidents, incidents, injuries, and near-misses that occur while operating for, or traveling to, a Delta-P jobsite must be reported to Management as soon as possible after they occur. First Aid All testers must hold valid first aid certificates and ensure that appropriate kits are supplied to each test unit. Additionally, testers should become familiar with the use and locations of emergency eye wash stations, emergency showers, and first aid facilities at each test.

6.2

Personal Protective Equipment Hard Hats Hard hats approved by the CSA (CAN/CSA Z94.1-92) must be worn at all times while on a drilling lease. The hat suspension must be properly adjusted to provide the proper protection. Only hard hats recognized by the CSA under the applicable standard will be acceptable. Hard hats do not have to be worn while in the cab, sleeper, or telemetry section of a test truck. Footwear Hard toed boots approved by the CSA (CAN/CSA Z195-M92) must be worn at all times while outside the test vehicle on a drilling lease. Clothing During testing, work clothing outer garments of fire retardant material must be worn. NOMEXIII or Proban are acceptable materials for outer garments. Nylon or other static electricity producing materials must not be worn at any time on a drilling lease. Cotton or wool should be worn under the fire-retardant outer layer so that it does not melt to the skin in the event of a flash fire. Gloves

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Delta-P Test Corp. Safety Handbook Gloves must be worn appropriate to the work being done and the nature of the hazard involved. For example, rubber or neoprene gloves should be worn for the handling of well fluids and cotton or leather gloves should be worn while handling test tools. Eye and Face Protection Eye protection must be worn at all times when outside of the test vehicle. The eyewear must meet or exceed the appropriate CSA standard (CAN/CSA-Z94.392). Hearing Protection Hearing protection must be worn in posted areas or where noise levels exceed the Provincial or Federal Government Regulations. Self-Contained Breathing Apparatus (SCBA) SCBA must be worn in areas where H2S concentrations exceed 10ppm and when the O2 concentration level in the air is below 18%.

6.3

Vehicles and Driving Inspections Vehicles must be inspected as per the guidelines documented in 5.2.1 – Vehicle inspections. Accidents All vehicle accidents must be reported. Defensive Driving All testers must: •

Hold a valid operator’s license of a class appropriate to the vehicle that they operate.

•

Comply with the rules of the road as outlined by the appropriate provincial or territorial jurisdiction.

•

Exercise courtesy in their driving habits.

•

Remain alert and try to anticipate road conditions and action of other drivers.

•

Drive in a manner appropriate to the conditions of the road.

•

Ensure all loads are properly secured and that all cargo/stowage doors are closed and locked.

•

Use seat belts.

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Delta-P Test Corp. Safety Handbook •

Employ a guide when backing up if in an area where obstructions, hazards, or personnel, cannot be readily identified by the side-view mirrors.

Winter Driving Additional caution must be exercised under winter driving conditions:

6.4

•

Avoid sudden changes of speed of direction when driving on icy or snow-covered roads to reduce the possibility of skidding.

•

Leave extra distance between the test vehicle and any vehicle in front of it. Stopping on ice can take eight times the distance as required on dry pavement.

•

Carry suitable warm clothing and emergency equipment and supplies for protection in the event travel is halted by mechanical breakdown or extreme weather.

•

Clear snow and ice from the hood and top of vehicle and all windows prior to driving.

•

Obey signs warning of slippery sections or icy bridges.

Fire Prevention and Protection General The best method for fighting a fire is to prevent it starting in the first place. The following components are required for a fire to ignite and undergo combustion: 1.

Fuel (in the form of a vapor or liquid)

2.

Oxygen (in the atmosphere, typically)

3.

Heat (temperatures high enough to ignite the fuel/air mixture. Note that exposure to temperatures can be VERY brief for ignition i.e. a static electric spark.)

The removal of any one of these three components will prevent a fire or cause a fire to be extinguished. However, control of #1 and #2 are the easiest sources to control. To prevent fires, tester should: •

Always follow safe work practices when handling flammable or explosive materials.

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Delta-P Test Corp. Safety Handbook •

Store oily rags, waste materials, paper and combustible materials in metal containers with lids and empty containers regularly.

•

Avoid overloading electrical outlets.

Classification of Fires Fires can be grouped into the following classifications: CLASS “A”:

Fires in ordinary materials: wood, paper, rags, rubbish, etc.

CLASS “B”:

Fires in petroleum products: oil, grease, and paint.

CLASS “C”:

Fires in live electrical equipment.

CLASS “D”:

Combustible metal fires: magnesium, sodium, cesium, etc.

Fire Extinguishers Each test vehicle must be equipped with a dry-chemical ABC rated fire extinguisher. Shops spaces must be equipped with a dry-chemical ABC rated fire extinguisher. Access to fire-fighting equipment must never be blocked by any material or equipment. All fire fighting equipment must be inspected at least monthly to ensure it is in place, accessible, and fully charges. Discharged fire extinguishers must be immediately replace with fully charged units. Operation of Fire Extinguisher Following is a stepwise procedure for operating fire extinguishers: •

Break the seal holding pin in place. Remove hose (if equipped)

•

Remove pin. Depress cartridge lever to charge the extinguisher (if equipped)

•

Point nozzle in safe direction (away from face and body) and give the operating handle a quick squeeze to verify operation.

•

Approach fire from the upwind side (wind at your back).

•

Engage the fire from a distance of 3 meters (10 feet).

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Delta-P Test Corp. Safety Handbook •

Direct the stream from the extinguisher towards the base of the fire. Use a rapid sweeping motion (side to side) to blanket the base of the fire with chemical.

•

Use the full stream – do not throttle the extinguisher.

•

If the extinguisher is not sufficient to kill the flame, back away from the area. NEVER TURN YOUR BACK ON A FIRE!

Care of Extinguisher Read and follow the manufacturer’s instructions with respect to the care and inspection of the extinguishers. Fire extinguishers must be inspected once per month to ensure operational reliability (i.e. seals must be in place, nozzle unobstructed, access to unit).

6.5

Hazardous Materials Before undertaking any work involving handling or exposure to any hazardous material workers must unsure: •

They are aware of the hazards and take appropriate precautions.

•

Approved PPE is used.

•

Adequate ventilation is in place.

•

Approved fire protection is in place (if required).

•

First aid supplies and facilities are readily available.

Workplace Hazardous Materials Information System (WHMIS) Workers must review the WHMIS documentation (Appendix D). Transportation of Dangerous Goods (TDG) Workers must review the TDG literature in Appendix E. Hydrogen Sulfide (H2S) Hydrogen sulphide gas is a killer. An extremely toxic, colorless and flammable gas occurs naturally as a by-product of organic decay. It is particularly prevalent in the petroleum industry as a component of produced oil and natural gas. It is imperative that every tester be aware of its physical properties, recognize its hazards, and know how to avoid exposure to it. The physical properties of H2S are: 19/06/01 18 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Delta-P Test Corp. Safety Handbook •

Color

colorless

•

Odor

offensive – similar to rotten eggs at low ppm

•

Vapor Density

SG = 1.189. Heavier than air

•

Explosive limits 4.3% to 46.0% by volume in air.

•

Flammability

auto ignition point = 260 deg. C (burns readily)

•

Solubility

readily soluble in water and oil.

•

Boiling Point

-60 deg. C. Usually a gas.

Three levels of Occupational Exposure Limits have been established to protect workers from the toxic effects of H2S: •

10 ppm Time Weighted Average (TWA) – the maximum exposure for an eight hour workday.

•

15 ppm Short-Term Exposure Level (STEL) – acceptable for no more than 15 minutes.

•

20 ppm Ceiling Exposure Level (Ce) – no one shall be exposed to H2S levels above 20ppm no matter how brief the duration.

Various concentrations of H2S and the toxic effect that can be expected on the body are listed below: •

1 ppm

Can be smelled.

•

10 ppm

eight hour OEL.

•

15 ppm

15-min. OEL

•

20 ppm

Ceiling OEL

•

100 ppm loss of smell in 2-15 min. nausea.

•

200 ppm rapid loss of smell, burning in eyes and throat.

•

500 ppm loss of reasoning and balance, respiratory upset in 2-15min. Prompt resuscitation required.

•

1000 ppm immediate unconsciousness, death or permanent brain damage will result without prompt resuscitation.

Burning in throat, headache and

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Delta-P Test Corp. Safety Handbook H2S content is also sometimes expressed as a total percentage of the air. The difference between parts per million (ppm) and percentage scales is significant. One ppm of H2S is a low concentration and (relatively) safe to be exposed to, however one percent H2S is lethal. If any H2S release occurs, testers must: •

Immediately leave the area in an upwind direction

•

Sound an alarm

•

Don SCBA

•

Rescue victim(s) if it safe to do so

•

Secure well bore.

•

Revive victim(s). If using CPR, do not inhale the victim’s exhalation!

•

Get medical aid

•

Alert Operating Company Emergency Services.

Testers must maintain a valid H2S alive certificate.

6.6

Equipment and Operations Compressed Air Cylinders Compressed gas cylinders are filled to a very high pressure and must be handled carefully to prevent rupture. When handling gas cylinders, testers must: •

Assume the cylinders are full.

•

When handling cylinders, remove regulators and replace caps to protect valves.

•

Prevent cylinders from bumping together during transport.

•

Refrain from rolling, dropping, or throwing cylinders.

•

Keep oxygen cylinders away from oil or grease.

•

Ensure that the proper regulator, designed for the contents of the cylinder, and appropriate for the pressure rating of the cylinder, is installed.

•

Do not interchange regulators for different gasses.

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Delta-P Test Corp. Safety Handbook •

When storing gas cylinders, chain or strap secure them in an upright position.

•

Do not store cylinders in areas where the heat may exceed 55 deg. C.

Electrical Safety Testers must maintain the following minimum distances between a power-line and themselves and test equipment. Safe Limits of Approach from Powerlines Jurisdiction Alberta

British Columbia/ Sask.

Federal (CLC)

Voltage (line to ground)

Distance

0-750 V Insulated of Polyethylene Covered Conductor.

300mm

Above 750 V Insulated Conductor

1.0m

0-40 kV

3.0m

69kV, 72kV

3.5m

138kV, 144kV

4.0m

230kV, 240kV

5.0m

500kV

7.0m

Over 750V to 75 kV

3.0m

Over 75kV to 250 kV

4.5m

Over 20kV to 550 kV

6.0m

Up to 50kV

3.0m

50 kV to 120 kV

4.5m

120 kV-250 kV

6.0m

250kV – 350 kV

7.5m

Over 350 kV

9.0m

Hand Tools

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Delta-P Test Corp. Safety Handbook All hand tools must be maintained in safe working condition. Before using any tool, testers must ensure that they know how to properly use the tool. They must also ensure that the tools used are the proper one for the job. Tools must be carried and handled properly to prevent injury to the user of the tool and other workers. Sharp or pointed tools should not be carried loosely or in the pockets or clothing. Air Tools When working with air tools, workers must ensure proper connections are made to the air supply. The air supply should always be shut off by the appropriate shut-off valve and never by the act of bending of kinking the hose. When an air tool is not in use, air supply must be shut off. Pressure in its hose must be relieved before the hose is disconnected from the air supply. Oxygen and other bottled gasses must never be used to operate air tools. High-Pressure Connections The pressure in high-pressure connections must be bled off before threaded or flanged connections are tightened. No connection, threaded or flanged, may be tightened under pressure. Hoisting and Winching Equipment Hoisting equipment must be operated according to these guidelines: •

Where signals are required, only one person must give signals and that person must have received signaling instructions. The signaler must remain in view of the hoist or winch operator.

•

When operating hoisting equipment, the worker must maintain the minimum powerline clearances in the above chart.

•

Hoisting equipment must not be subjected to loads in excess of the rated capacity of the hoist.

•

All hoisting equipment must be inspected before use. Excessively worn or damaged equipment components must be replaced before use.

•

All hooks on hoisting equipment must be equipped with safety latches.

•

Testers must not stand or pass under suspended loads. suspended load must be positioned, tag lines must be used.

•

Workers must not ride on the hoisting apparatus or on suspended loads.

•

Workers must not work or position themselves under raised loads such as vehicles or trailers unless the load is supported by a vehicle

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If a

Delta-P Test Corp. Safety Handbook hoist or adequate stands or blocks. Jacks DO NOT provide adequate protection by themselves. •

Ropes and cables under tension must be avoided by ground workers.

•

Gloves must be worn by anyone handling ropes or cables. Ropes and cables should not be allowed to slide through the handler’s hands. A hand-over-hand technique should be used to slacken the line.

Hydrates Natural gas hydrates are solid compounds formed by natural gas and water. Some light hydrocarbons will form hydrates under pressure at temperatures above 0 deg. C. These hydrates form as crystals and look like snow. In pipe, they can pack solidly to form a restriction resulting in partial or complete flow blockages. Hydrates pose a real threat to people and equipment. If proper procedures are not used to remove hydrates from pipes, a potential pressure release could result. If hydrates are suspected to form a blockage in a pipe segment, the segment must be isolated by closing valves. If possible, the pipe should be re-charged to the original pressure prior to the initial bleed-down. After isolation is complete, the pipe segment should be steamed until the entire pipe length is heated to above 30 deg. C for a period not less than 15 minutes. After the pipe has been heated for 15 minutes, another bleed-down attempt may be made. If the pipe is still blocked, increase the temperature to 40 deg. C and the duration time to 20 min. Continue to bleed-down and heat in cycles until the blockage is released. Manual Handling and Lifting Whenever manually handling or lifting materials at all worksites, testers must: •

Wear appropriate gloves.

•

Obtain help from rig-crews when lifting heavy or bulky objects.

•

Lift with the leg muscles, not the back.

•

Remove slivers, nails, or sharp ends before handling.

•

Maintain a clear line of vision when carrying materials.

Valves Testers operating valves must: •

Keep the body and face away from the top of the stems when opening or closing high-pressure valves.

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Delta-P Test Corp. Safety Handbook

6.7

•

Open and close valves on high-pressure lines slowly to prevent radical pressure differentials or transients that may rupture or split pipe or fittings.

•

Never stop a leaking valve on a connection with a bull plug. A nipple and an extra valve must be used and the extra valve kept open until the connection has been made.

•

Service valves in accordance with manufacturer’s guidelines.

Testing Specific Rules The following section includes “Industry Recommended Practice(s)” [IRP] for Well Testing and Drill Stem Testing. These IRPs are recommended by: •

Canadian Petroleum Safety Council (PSC)

•

Canadian Association of Petroleum Producers (CAPP)

•

Canadian Association of Oilwell Drilling Contractors (CAODC)

•

Petroleum Services Association of Canada (PSAC)

•

Small Explorers and Producers Association of Canada (SEPAC).

Testers must review the IRPs and follow the outlined practices. See Appendix F for a copy of the IRPs.

6.8

Working Alone The provincial government has released a guide for working alone. Most of the time, testers will be working with others, however, due to the nature of the job, a significant amount of time will be spent alone while traveling. As such, precautions should be taken. Please refer to Appendix G for more information on Working Alone. In addition, to minimize the risk to testers, a call in procedure will be used: Prior to leaving for a test, the tester will report to the dispatcher/manager as to when they are leaving for a test. The tester will also supply an estimated time for arrival on location. If a call is received from the Operating Company Engineer (complaining that a tester is not on location at the appropriate time), the dispatcher will attempt to contact the tester to verify location and status. If there is no response, further action will be taken to assess the condition of the tester.

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Delta-P Test Corp. Safety Handbook 7.0 Communication 7.1 General There are two general categories of communication: communication with Operating Companies/Rig Crews and Delta-P internal communication. Much of the communication that occurs is informal and undocumented. In order to increase the focus on safety, formalized meetings will be held to specifically address issues of safety. Safety meetings have several purposes: •

Increase general safety awareness among participants.

•

Increase awareness of company and government safety requirements for specific jobs or projects.

•

Provide training in safety and procedures.

•

Encourage feedback on safety matters to improve safety program and overall safety.

7.2 Pre-Job Safety Meetings Prior to inflating packers, it will be mandatory to hold a safety meeting to alert rig crews to the specific hazards of testing. A Pre-Test Safety Meeting Form can be found in Appendix H. Who?: Anyone involved in the testing process and anyone who may be on the rig during a test. When?: Conduct the meeting prior to inflating packers. Where?: The drilling rig doghouse is the best location to hold the meeting. Why?: See above… What?: The sample Pre-Test Safety Meeting Form can be used as a guideline for safety issues

7.3 General Safety Meeting Delta-P Test Corp. will hold bi-annual safety meetings to discuss issues of safety and to orient new workers. Agenda Two weeks before the General Safety Meeting (GSM), an agenda will be circulated to all testers to alert them to the topics of the GSM. If anyone wishes to see an issue discussed at the meeting, they will have an opportunity to tell the meeting facilitator after they review the agenda. 19/06/01 25 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Delta-P Test Corp. Safety Handbook Meeting Minutes Minutes of the meeting will be kept and distributed 1 week after the conclusion of the meeting. The method of distribution will be e-mail. Any amendments or comments to the minutes can also be circulated via email. Follow-up Any action items that are generated at the GSM will be given a person responsible for completing the action. Management will communicate with the individual responsible and distribute reports to the other GSM attendants (via e-mail).

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Delta-P Test Corp. Safety Handbook 8.0 Training and Orientation Training Delta-P Test Corp. only hires individuals with experience and a proven record of accomplishment of safety and operational knowledge. New employees will be trained by a senior tester and evaluated “on-the-job”. For more information on Training, please refer to the Delta-P Test Corp. New Employee Manual.

Orientation Everyone will undergo an orientation to verify understanding of the corporate safety policy. Additionally, all testers will fill out the proceeding page to document their understanding of the contents of this Handbook.

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Delta-P Test Corp. Safety Handbook Orientation Acknowledgement Form Name:__________________________

Date:_____________________________

Please acknowledge that you have reviewed each element in the Safety Handbook by initialing and signing below: Element

Tester’s Initials

Management

Corporate Safety Policy

____________

___________

Tester’s Responsibilities

____________

___________

Company Safety Rules

____________

___________

Industry Recommended Practices (IRP)

____________

___________

Hazard Identification and Control

____________

___________

Driving Hazards

____________

___________

Working Alone

____________

___________

Safety Meeting

____________

___________

TDG

____________

___________

WHMIS

____________

___________

Guiding Principles posted in Test Unit

____________

___________

Corporate Safety Policy posted in Test Unit

____________

___________

I have reviewed the elements in this manual. I understand that safety is a significant component of my work. I will make every effort to uphold the Corporate Safety Policy and the Industry Guiding Principles

____________________________ Signature of Tester

_____________________________ Signature of Management

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Delta-P Test Corp. Safety Handbook Appendix A: Inspection Sheets

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Quick Vehicle Inspection

To be performed before driving. Walk around vehicle. Look for the following: • • • • • • • •

Flat Tires Are the tires/wheels free of obstructions? Is the exhaust clear? Are all compartments closed and cable reel handles stowed? Are the running and headlights functional? Are there any obvious leaks? Are there any loose panels or bodywork? Are loads tied down?

Look for anything that is out of the ordinary.

Quick Detailed Vehicle Inspection To be performed at fuel stops: • • • • • •

Check Oil Level Check Windshield Washer level Check tire pressure Check vehicle operating temperature Check brake and signal lights Clean lights and windshield

These steps are in addition to the Quick Vehicle Inspection

Detailed Vehicle Inspection (5000km) Date:

Operator:

Unit:

Milage: Drivers Compartment

Sun Visors

Horns & Switches

Instrument Lamps

Windshield Wipers

Windshield Defrost

Hazard warning kit

Side Windows

Hi-Beam Indicator

Air Pressure gauge

Pedal Pads

Acc. Pedal & Air Throttle

Steering Travel

Seats & Seatbelts

Steering & Power Assist

Clutch disengagement

Speedometer

Mirrors

Cabin Air Leakage

Windshield Body Exterior

Headlamp operation/aim

Clearance Lamps

Ext fuel tanks

Tail Lamps

Stop Lamps

Turn signals

Marker Lamps

Hazard Lamps

Reflectors

Tire Pressure

Secondary Attachments

Fenders/Mud Flaps

Air System

Paint

Body, Doors, Bumpers Under the Hood

Hood

Accessory Belts

Air compressor

Power Steering Fluid/sys

Fuel Pump & Filter

Battery and wiring

Exhaust

Fan fins and Belt

Distributor

Air Filter

Windshield washer pump

Cooling System

Undercarriage Transmission

Oil Pan

Muffler

Steering Box

Drag Link

Pitman Arm

Cotter pins

Tie-Rod

Differential

Tie-Rod Ends

Frame Rails

Suspension

Shocks

Springs

Axles

Brakes, Tires, and Wheels Brake Components

U-Joint

Brake Lining Thickness

Spring Caging Bolts

Brake Drums

Brake Failure Indicator

Disc Brakes

Brake lines and hoses

Parking Brake

Reservoirs and Valves

Tire Pressure

Brake Operation

Wheel Bearings

Vacuum System & Reserve

Brake Cams & Travel

Tire Wear

Detailed Vehicle Inspection (5000km) Inspection Checklist Resource Rating Legend N.A. = Not Applicable to this Unit P = Passed in good working Condition M = Passed but maintenance required R = Rejected – replacement necessary before returning to service. Vehicle Inspector must sign off on bottom of inspection sheet.

*** Attach inspection form to invoice/receipt for work performed and file.***

Site Inspection Checklist Item Site Driving Conditions? Overhead Wires or Cables? Other Activities (Logging/ Casing Unloading)? Trenches? Ground Cables? Wind Direction? SCBA Location? Rally Point? Fire Fighting Equipment? Eyewash/ Firstaid? Emg. Showers Breakers / Electrical ESD location? Tripping and slipping? Sharp projections on rig? H2S potential? Compressed gas cylinders? MSDS products? Flare Pit – Flaring OK? Other?

P

Comments/Notes

Delta-P Test Corp. Safety Handbook Appendix B: Hazard Identification Report and Incident Report.

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HAZARD IDENTIFICATION REPORT Date:_____________________________

H.I. Report Number:_______________________

Hazard Location:________________________________________________________________ Person Completing Report:________________________________________________________ Description of Hazard

R.A.C.

Personnel Involved Delta-P Tester

Contractor

Student

Visitor

Other

Client

Action Required

Responsible Party

Target Date

Completion Date

Hazard Classification – Risk Assessment Codes (R.A.C) Used the following categories and degrees to assign a Risk Assessment Code for the identified Hazard.

Consequence

Probability of Occurrence

Exposure (# of people affected)

Risk Assessment Code

I. Catastrophe II. Critical III. Marginal IV. Negligible

A. Likely to Occur B. Probably Occur C. Possibly Occur D. Unlikely

1. 2. 3. 4.

1. 2. 3. 4.

More than 50 10-49 5-9 Less than 5

Additional Notes and follow up comments are to be written on the back of this document.

Critical Serious Moderate Minor

EVENT REPORT (Accident or Near Miss) Date:_____________________________

Event Report Number:_______________________

Event Location:_________________________________________________________________ Person Completing Report:________________________________________________________ Type of Event Personal Injury

Equipment Failure

Fire/Explosion

Lost Time

Equipment Damage

Vehicle Accident

Medical Aid

Property Damage

Environmental

First Aid

Material Loss

Security/Theft

Restricted Duty

Business Interruption

Other

Personnel Involved Delta-P Tester

Contractor

Student

Visitor

Other

Client

Event Classification Critical** ** Full Investigation is required.

Serious**

General Information Name of Individual Involved: Employee/Contractor Name: Location of Event:

Event Description

Minor

Status of Injured/Immediate Action Taken

Follow Up Action to Be Taken Is an investigation required?

Action Required

Who is Responsible

___________________________________ Management Signature

Target Date

Completion Date

____________________________________ Date

Delta-P Test Corp. Safety Handbook Appendix C: Hazard Management

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Delta-P Test Corp. Safety Handbook Hazard Management Loop

No Yes Identify Hazard

Evaluation Did it work?

Implement Option

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Assess Hazard

Generate Options

Delta-P Test Corp. Safety Handbook Identify Hazard The first step to managing any hazard is to identify it. Many times hazards are not identified because they are not always obvious and there is often no deliberate effort to identify them. Use the following steps to identify hazards: 1. Before beginning a task, have all of the people involved in, or affected by, the proposed work discuss the job. Focus on Who, What, When, Where, How, and Why. 2. Participants ask questions to gain clarification on the work and identify where there could be exposure to a hazard. 3. Identify any procedures, equipment, or materials that may pose a hazard. 4. Use Company safe work permits to help guide discussions. Assess Hazard Determine which of the identified hazards apply to the planned work and which do not. Options must be generated to Control, Avoid, or Remove the hazards that apply to the specific work tasks. Other identified hazards should be documented and this information passed on to company supervisors for handling. Generate Options Once the hazards have been assessed and it has been determined that the hazard applies to the task/work, you must identify some method to manage the exposure. Deciding to take no action and leave the consequences to chance is not an acceptable way of managing a hazard. Seek the input of others to generate ideas about how to manage the assessed hazards. Do not be afraid to use the experience of others. Implement Options From the list of generated options, select the one that best manages the hazard and has the support of the people involved in the work (or affected by the work). Responsibilities for individuals must be make clear at this time. Evaluate Monitor the progress of the work and verify that the controls/mitigation/removal of the hazard is acceptable. If the implemented option is not working as required, proceed with the following actions: 1. Make sure you understand the hazard. influence what happens?

Are there other things that could

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Delta-P Test Corp. Safety Handbook 2. Review other options and maybe create new ones. 3. Select and implement another option, monitor results.

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Delta-P Test Corp. Safety Handbook Appendix D: Workplace Hazardous Materials Information System (WHMIS)

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Workplace Health & Safety WHMIS Information for Employers

WHMIS September 1999

WHMIS Information for Employers

Table of Contents Introduction.......................................................................................................................... 1 What does W-H-M-I-S mean?.............................................................................................................................. 1 What is the purpose of WHMIS?......................................................................................................................... 1

Legislation ........................................................................................................................... 2 What is the WHMIS law called and where can I get a copy?.................................................................... 2 But I’m already complying with TDG…. ............................................................................................................ 2 What happens if companies don’t comply with the WHMIS requirements?......................................... 3

Application........................................................................................................................... 4 Does WHMIS apply to every chemical?............................................................................................................ 4 Which products are excluded from WHMIS?.................................................................................................. 5 Which products are totally excluded?................................................................................................................ 5 Which products are excluded from the supplier aspects of WHMIS?.................................................... 6 Who’s going to classify our products for us?................................................................................................... 7

Roles and Responsibilities.................................................................................................. 8 What are my responsibilities as an employer?............................................................................................... 8 Do my workers have any WHMIS responsibilities?...................................................................................... 8 What can I expect from my suppliers?.............................................................................................................. 8 What happens if a supplier sends me a controlled product that doesn’t have a supplier label?.. 9 Some of my American suppliers aren’t co-operating. .................................................................................. 9 Can I get imported products to my plant to label them, or will they be stopped at the border?.... 9 What is the government’s role?......................................................................................................................... 10

Labels ................................................................................................................................ 11 What does a WHMIS label look like?............................................................................................................... 11 What does a basic supplier label look like?................................................................................................... 11 Variations on the basic supplier label .............................................................................................................. 13 What does the small container label look like? ............................................................................................ 13 How do the WHMIS labelling requirements apply to products purchased in bulk?......................... 14 And laboratory chemicals, what kind of label variations might I find on them?................................. 15 How are laboratory samples labelled? ............................................................................................................ 15 Is that all the variations on the basic supplier label?.................................................................................. 16 What does a WHMIS work site label look like?............................................................................................ 16 Are there any variations on the WHMIS work site label?.......................................................................... 17 Tell me about placards.......................................................................................................................................... 17 When is it okay for me to simply identify a controlled product?.............................................................. 17 Are there any controlled products that don’t require a WHMIS label of any kind?.......................... 17 Where do I get my WHMIS labels?.................................................................................................................. 18

Material Safety Data Sheets (MSDSs)............................................................................. 19 What is a Material Safety Data Sheet?........................................................................................................... 19 Are there any variations on the basic “MSDS”?........................................................................................... 19 How do I get MSDSs for the controlled products at my company?....................................................... 22 Am I responsible for updating all these MSDSs?........................................................................................ 22

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My supplier says that some of the ingredients in the product are secret. Can he get away with that?............................................................................................................................................................................. 23 We like to transfer supplier MSDSs onto our own MSDS format. Is that okay?.............................. 24 Are there any controlled products at the work site that don’t require MSDSs?................................. 24 Is there anything else that I need to know about MSDSs?...................................................................... 24

Worker Education ............................................................................................................. 25 What must be included in WHMIS worker education?............................................................................... 25 Do I have to provide WHMIS worker education for all my workers?..................................................... 25 How often do I have to conduct WHMIS worker education at my company?.................................... 26 What is the standard for WHMIS worker education? ................................................................................. 26 Where can I get my workers trained?.............................................................................................................. 26

Confidential Business Information .................................................................................... 27 What does “confidential business information” mean?.............................................................................. 27 What information may be withheld as confidential business information?.......................................... 27 What if the supplier claims that some of the hazard information is confidential?............................. 27 Who decides if the information really is confidential business information? ...................................... 27 How do I know if the claim has been validated?.......................................................................................... 28 What happens if a claim is not validated?...................................................................................................... 28 What happens if there’s an incident involving a controlled product that has a confidential ingredient?................................................................................................................................................................. 28

Glossary............................................................................................................................ 29 Appendix 1 Obtaining WHMIS legislation......................................................................... 36 Appendix 2 Resources ..................................................................................................... 37

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Introduction What does W-H-M-I-S mean? The letters W-H-M-I-S stand for “Workplace Hazardous Materials Information System”. WHMIS is a national hazard communication system. It affects suppliers, importers and distributors of potentially hazardous materials used at work sites, and employers and workers who use those materials.

What is the purpose of WHMIS? WHMIS was developed to ensure that persons at work sites receive adequate hazard information about chemicals that are used there. The system requires that suppliers and distributors of controlled products convey specified hazard information to their industrial customers, i.e. employers, and that the employers pass that hazard information on to their workers. WHMIS has three major elements: 1. Labels — WHMIS labels provide the essential information that a person needs to know to handle a particular product safely. 2. Materials Safety Data Sheets (MSDSs) — MSDSs provide basic technical information about a product’s physical characteristics and its hazardous properties. 3. Worker education — This element provides persons at work sites with two kinds of information. First, it explains just what information they can expect to receive as a result of WHMIS. And second, it teaches them specific hazard information and safe work procedures that they can use directly at their jobs. WHMIS was implemented through coordinated federal, provincial and territorial legislation.

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Legislation What is the WHMIS law called and where can I get a copy? There are two main bodies of WHMIS law (legislation). There are federal WHMIS laws, which deal mostly with the supplier aspects of the system. There are also provincial, territorial and Labour Canada WHMIS laws. These deal with the employer and worker aspects of WHMIS. The federal legislation consists of: § The Hazardous Products Act (HPA); § The Controlled Products Regulations (CPR); § The Ingredient Disclosure List; § The Hazardous Materials Information Review Act; and § The Hazardous Materials Information Review Regulation. This legislation specifies requirements for supplier labels and MSDSs and requires suppliers to provide users with MSDSs when products are purchased. It also makes provision for the protection of confidential business information. The federal WHMIS law is available from Supply and Services Canada or from federal government publication outlets across Canada (see Appendix I). The provincial, territorial and Labour Canada WHMIS laws deal with WHMIS at the work site level. This legislation defines the various responsibilities of employers and workers under WHMIS. Alberta’s WHMIS law is contained in Part 2 of the Chemical Hazards Regulation. It was developed under the authority of the Occupational Health and Safety Act, which establishes the fundamental principles of Alberta’s occupational health and safety law. All Alberta occupational health and safety regulations, including the Chemical Hazards Regulation, are available from the Queen’s Printer (see Appendix 1).

But I’m already complying with TDG…. The Transportation of Dangerous Goods (TDG) law is not the same as the WHMIS law. TDG was enacted to protect the general public from hazards associated with transporting dangerous materials on public roads, in the air, by rail or on waterways. WHMIS, on the other hand, was developed to protect the health and safety of people at work sites by providing them with hazard information about the chemicals they work with. The two systems often deal with the same chemicals — TDG while the product is in transit and WHMIS when the product reaches the work site.

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What happens if companies don’t comply with the WHMIS requirements? Companies found violating the WHMIS law are subject to various legal procedures. The outcome of the legal procedures depends on many factors such as the seriousness of the problem, the company’s compliance history, etc. Violation of the federal WHMIS law may result in seizure of products and/or prosecution. The outcome of prosecution may be a fine of up to $1,000,000 and/or imprisonment for up to two years. Violation of the provincial WHMIS law may result in orders to make changes, shut down of work site operations, or prosecution. The outcome of prosecution for violation of the Occupational Health and Safety Act or its regulations may be fines of up to $300,000 and/or imprisonment for up to one year.

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Application Does WHMIS apply to every chemical? No. WHMIS does not apply to every chemical product. WHMIS applies only to products that meet certain criteria. These products are called controlled products. There are six classes of controlled products. Any product that meets the criteria for any one (or more) of the six WHMIS classes is a controlled product and is included in WHMIS. A few products are covered by other legislation, so they have been excluded from WHMIS requirements. There is no comprehensive list of controlled products. The only way to find out if a product is a controlled product or not is to compare its properties with the criteria for each of the six classes of controlled products. Each class of controlled products has a distinct hazard symbol. Class D has one symbol for each of its three divisions. (Class B has six divisions, but all six are represented by the same hazard symbol.) Figure 1 shows the six WHMIS classes and their hazard symbols. The WHMIS classification criteria are contained in the federal Controlled Product Regulation.

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Figure 1

The WHMIS classes and hazards symbols

Which products are excluded from WHMIS? There are two groups of excluded products. The first is totally excluded from all WHMIS requirements. The second consists of products that are excluded only from the supplier aspects of WHMIS.

Which products are totally excluded? Products excluded from all aspects of WHMIS are: § wood and products made of wood; § tobacco and products made of tobacco; § manufactured articles; § dangerous goods while they are covered by TDG legislation i.e. while in transit; and § hazardous wastes (except that safe storage and handling are required through the combination of any mode of identification and worker training).

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“Products made of wood” and “products made of tobacco” do not include products made from wood and products made from tobacco. For example, lumber, which is made of wood, and cigarettes, which are made of tobacco, are excluded from WHMIS by this exemption. On the other hand, turpentine, which is made from wood, and nicotine, which is extracted from tobacco, are included. “Manufactured article” means a product that is manufactured to a specific shape, and whose function depends on that shape. Manufactured articles do not release controlled products during normal use. Coated pipe is an example of a product that is exempted from WHMIS by this provision. The coating material may have been a controlled product when it was applied, but it is not released during normal use of the pipe. Welding rods, on the other hand, are not exempted by this provision because they release controlled products (as part of the welding fume) during their normal use. You should note that the release of controlled products during the installation of a material does not prohibit its exemption from WHMIS by the “manufactured article” provision. New carpet, for example, usually releases certain gases during installation and for a short time afterward. But installation is not “normal use”. So carpet is considered a manufactured article and is totally exempted from WHMIS. Even though these products are exempt from WHMIS, the Alberta Chemical Hazards Regulation deals with materials that are hazardous but are not controlled products. These hazardous materials are called “harmful substances”. Employers have three responsibilities regarding harmful substances. They must: § ensure that harmful substances or their containers are clearly identified; § establish procedures to minimize worker exposure to these substances; and § train workers in those procedures and in the health hazards associated with exposure to the harmful substance.

Which products are excluded from the supplier aspects of WHMIS? This group of products includes: § explosives, which are covered by the Explosives Act; § cosmetics, devices, foods and drugs, which are covered by the Food and Drug Act; § pesticides and herbicides, which are covered by the Pest Control Products Act; § radioactive materials, which are covered by the Atomic Energy Control Act; and § consumer products that are restricted products and covered by the Hazardous Products Act (HPA). “Consumer product” means a product that is packaged in quantities appropriate for the public, available to the public in retail outlets and labelled with the “restricted product” labelling required by the HPA. For example, a solvent that is packaged in a 250 ml size, labelled with a restricted product label and offered for sale in a regular hardware store is considered a consumer product. The WHMIS consumer product exemption applies. The supplier does not have any WHMIS responsibilities to meet. Yet the same product in a 454 litre drum, sold at an industrial supply outlet, would not be permitted this exemption. It would be considered a controlled product and all WHMIS requirements would apply. Information requirements for these products were addressed by the Explosives Act, the Food and Drug Act, etc, long before WHMIS was developed. These laws are currently

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WHMIS Information for Employers

being reviewed to ensure that their information requirements are as stringent as those of WHMIS. If this is found not to be the case, the situation will be corrected. Those individual laws will be amended or the products will be brought into WHMIS so that users receive information that meets the WHMIS standard.

Who’s going to classify our products for us? Canadian suppliers must classify the controlled products they sell to you. But the classification of products you produce on-site for use on-site, products you obtained prior to WHMIS and still have on-site, and products you import, is your responsibility. Classification can be complicated. If you don’t have occupational health and safety personnel or chemists on your staff, you may wish to engage outside assistance. The Canadian Centre for Occupational Health and Safety (CCOHS) can help with the classification of pure substances. Private consultants are available to help with the classification of more complex products. Appendix 2 lists resources available to provide you with assistance.

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WHMIS Information for Employers

Roles and Responsibilities What are my responsibilities as an employer? Alberta’s Occupational Health and Safety Act requires employers to take all reasonable measures to protect the health and safety of workers at their companies. WHMIS is an important tool for employers to use in achieving this objective. Employers have an important role to play in the effective implementation of WHMIS. This role is documented in the Chemical Hazards Regulation as a series of responsibilities. The employer is responsible for ensuring that: § all controlled products at their work sites are labelled with appropriate WHMIS labels; § there are up-to-date (no more than 3 years old) WHMIS MSDSs for all controlled products at the site and these MSDSs are located in a place readily accessible to everyone who works there; and § workers at their work site have had the appropriate WHMIS worker education to protect their health and safety on the job.

Do my workers have any WHMIS responsibilities? The Occupational Health and Safety Act requires workers to cooperate with their employers to protect their own and other workers’ health and safety on the job. The Chemical Hazards Regulation specifically requires that they participate in WHMIS worker education provided by their employers. A Safety Bulletin similar to this one, (CH007) WHMIS – Information for Workers is also available from Alberta Human Resources and Employment, Workplace Health and Safety. It describes the WHMIS system in general, labels, Material Safety Data Sheets, worker education, suppliers’ responsibilities, employers’ responsibilities and workers’ responsibilities.

What can I expect from my suppliers? Canadian suppliers of controlled products have two main WHMIS responsibilities: 1. label each controlled product they sell to Canadian work sites with an appropriate WHMIS supplier label with information written in both English and French; and 2. develop a WHMIS MSDS for each controlled product they sell to Canadian work sites. They must provide a copy of that MSDS (in English or French, as the customer chooses), to each Canadian work site customer. Distributors of controlled products have the same responsibilities as suppliers. You can expect distributors to provide you with the same WHMIS information you would get from a supplier. Note: These responsibilities are described in detail in Safety Bulletin (CH009) WHMIS – Information for Supplier’s, also available from Workplace Health and Safety.

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What happens if a supplier sends me a controlled product that doesn’t have a supplier label? This is a very important question. You’re not allowed to use this product until you have received and applied the correct label. In fact, you have permission to store it on your site only if you are actively seeking the proper label, and if you have placed a placard over the product. (Placards are discussed on page 17) This situation is the same if a supplier sends you a controlled product for which you have not received a WHMIS MSDS. You may store the product, but you may not use it until you obtain the WHMIS MSDS. You may, of course, refuse to accept a product that arrives at your site without the proper WHMIS label or MSDS. The choice is yours.

Some of my American suppliers aren’t co-operating. WHMIS is Canadian law. It applies only in Canada. Your American suppliers, or any other foreign suppliers, may not be aware of it. Even if they do know about WHMIS, they may not be willing to comply with its supplier requirements. WHMIS responsibilities for controlled products imported into Canada for use at work sites fall to the importing companies. In other words, companies that import controlled products must ensure that WHMIS supplier labels are developed and applied to the products, and that WHMIS MSDSs for the products are obtained. Importers have these responsibilities for products that are imported for sale to other Canadian work sites and for products that are imported for use within the importing company. If you import a controlled product for use at your work site, you are responsible to ensure that it has a WHMIS supplier label and a WHMIS MSDS.

Can I get imported products to my plant to label them, or will they be stopped at the border? Importers may bring a controlled product into Canada without a WHMIS supplier label or a WHMIS MSDS, as long as the Alberta government is notified and the WHMIS requirements are met before the product is used or sold. Notification to the government must include: § identification and description, i.e. the classification of the product; § address in Alberta at which the supplier label will be applied, a list of the other provinces into which the product will be imported; and § if requested: • a sample of the product, • import schedule, and • quantity of product to be imported.

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Notification should be sent to: WHMIS Coordinator Alberta Human Resources and Employment Workplace Health and Safety 9th Floor, 10808-99 Avenue Edmonton, Alberta T5K 0G5 You must put WHMIS supplier labels on these products, and develop WHMIS MSDSs for them before you can use them or sell them.

What is the government’s role? Government has two major roles in implementing WHMIS at Alberta workplaces. These roles are consultation and enforcement. Alberta Human Resources and Employment, Workplace Health and Safety deals with all aspects of WHMIS in the province. The Department consults with Alberta employers, suppliers and workers to help them understand their WHMIS responsibilities. The Department can provide information materials, including this booklet and the accompanying ones for workers and suppliers, pamphlets and booklets on many aspects of chemical safety, and references to other resources. Workplace Health and Safety enforces both federal and provincial WHMIS legislation in Alberta. Occupational Health and Safety Officers inspect Alberta work sites for compliance with WHMIS (and for compliance with other Alberta occupational health and safety legislation). They explain any violations that are observed to the parties responsible for the work site, specifying a date for compliance. If violations continue, more stringent measures may be taken, including compliance orders, site closure, product seizure and prosecution.

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Labels What does a WHMIS label look like? There are two main kinds of WHMIS labels — supplier labels and work site labels. Supplier labels are the labels that must be present on controlled products in their original (supplier) containers. These include: § controlled products sold by Canadian suppliers and distributors to Canadian work sites; § controlled products imported into Canada for use at work sites; and § “old” controlled products which employers obtained prior to WHMIS coming into effect and that are still present at the work site. Work site labels are used only by employers and workers. They are applied to: § containers into which controlled products are transferred; § containers of controlled products that are produced at the work site for use there; and § supplier containers, to replace supplier labels (and labels that are accepted as supplier labels, such as labels on pesticides and consumer products) that have been accidentally damaged or defaced, where new supplier labels cannot be obtained. There are different information requirements for supplier labels and work site labels. In addition, there are some situations in which the basic requirements for each type of label are relaxed and less detailed labels may be used.

What does a basic supplier label look like? An example of a WHMIS supplier label is shown in Figure 2. These labels are easy to recognize because they have a unique, rectangular slash-marked border.

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Figure 2

An example of a WHMIS supplier label

The basic WHMIS supplier label has seven required pieces of information which must be contained within the rectangular border. Figure 3 lists these requirements. The supplier label information must be written in both French and English. The only acceptable alternative to this provision is the use of two, equally visible labels, one in French and one in English. There is no specified format for the WHMIS supplier label. There is no size requirement either, but the label must be large enough to be legible. Finally, the label must be located on some area of the product where it will be readily seen.

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Figure 3 1.

Information required on a WHMIS supplier label Product Identifier Same as on MSDS.

2.

Supplier Identifier Identifier of manufacturer or distributor, as appropriate

3.

Hazard Symbols All WHMIS hazard symbols applicable to the product’s classification.

4.

Risk Phrases Brief statements on the main risks associated with the product.

5.

Precautionary Measures Brief statement of main precautions to be taken.

6.

First Aid Measures Main first aid measures to be taken in case of acute overexposure.

7.

Reference to the Material Safety Data Sheet For more detailed information

Variations on the basic supplier label There are five variations that you might encounter: 1. small containers (less than 100 ml) are permitted to carry a shorter version of the supplier label; 2. suppliers who provide controlled products in bulk shipments may provide the supplier label information in three different forms; 3. laboratory supply houses are permitted to use three unique variations of the basic supplier label on certain controlled products they sell; 4. samples sent to laboratories for analysis are allowed to have a different type of label; and 5. labels on compressed gas cylinders may have a curved shape to reduce distortion.

What does the small container label look like? Containers with a capacity of 100 ml or less are permitted to carry WHMIS supplier labels which do not have Risk Phrases, Precautionary Measures or First Aid Measures. An example of the “Small Container Label” is shown in Figure 4.

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Figure 4

An example of a WHMIS small container label

How do the WHMIS labelling requirements apply to products purchased in bulk? “Bulk shipment” has a special meaning in WHMIS. It is: “a shipment of a controlled product that is contained without intermediate containment or intermediate packaging, in (a) a vessel with a water capacity of more than 454 litres, (b) a freight container, a road vehicle, a railway vehicle, a portable tank, a freight container carried on a road vehicle, railway vehicle, ship or aircraft, or a portable tank carried on a road vehicle, railway vehicle, ship or aircraft, (c) the hold of a ship, or (d) a pipeline.” Suppliers of materials which are shipped in bulk have three choices when satisfying the WHMIS labelling requirements. They can: § provide you with a regular supplier label, and give it to you when the product is delivered or in advance of the delivery; § modify the MSDS for the product so that it contains the supplier label information as well as information required on the MSDS; or § send you the supplier label information as a separate document. Keep in mind that the supplier gets to make this choice. If the supplier sends you a supplier label, you must attach it to your container of the product. On the other hand, if

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the supplier chooses one of the other two options, you must use the information provided to make a work site label and apply that label to the product’s container.

And laboratory chemicals, what kind of label variations might I find on them? Controlled products used in laboratories may have regular WHMIS supplier labels. However, controlled products that are: § from laboratory supply houses; § intended for use in laboratories; and § packed in quantities of 10 kg or less may be labelled with either of two supplier label variations: 1. they may be labelled with all of the information required on a WHMIS MSDS, in which case the supplier is not required to provide a separate MSDS to the customer; or 2. they may be labelled with a basic supplier label from which the WHMIS border, the hazard symbols, and the supplier identifier have been omitted.

How are laboratory samples labelled? Samples for laboratory analysis can present a unique situation. Sometimes it isn’t possible to determine whether the sample is a controlled product or not. Sometimes samples are sent for analysis to determine if the product meets one or more of the WHMIS classification criteria. If you find yourself faced with this dilemma, you are expected to make your best judgement as to whether the material is a controlled product and to treat it accordingly. Samples sent to a laboratory should, as a general rule, have a basic supplier label and be accompanied by a WHMIS MSDS. Sometimes there is no MSDS for the product because its properties have not yet been determined. For example, the sample may be from a newly developed product. It isn’t possible to have an MSDS when the product is first being evaluated. Such a sample (if it is less than 10 kilograms) may still be sent to the laboratory, even though the MSDS cannot accompany it. These special samples must be labelled with the following information: § sample identifier; § identity of the ingredients in the sample which are themselves controlled products, if known; § name of the person sending the sample; and § the statement “Hazardous Laboratory Sample. For hazard information or in an emergency call”, followed by an emergency telephone number of the person sending the sample. This label does not require the cross-hatched border. An example is shown in Figure 5.

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Figure 5

Label for a sample of a controlled product that has no MSDS Sample for Analysis

Sample number:

203

Contents:

Toluene, xylene, water

Name of person sending sample:

John Ranchman

Hazardous Laboratory Sample For hazard information, or in an emergency call: (403) 297- 4034 (emergency telephone number)

Is that all the variations on the basic supplier label? That’s it. There aren’t any other variations on the basic supplier label. But don’t forget, the federally-legislated labels on explosives, pesticides, consumer products, etc., as described on page 6, are acceptable for these products.

What does a WHMIS work site label look like? Work site labels are “performance-oriented”. That means that there are very few requirements about their content and format but the labels must be effective in providing workers with the information needed to handle the product safely. Work site labels have only three required content elements: § product identifier; § information for safe use of the product; and § reference to the MSDS. There are no format requirements or language requirements and the WHMIS border is not required. An example of a work site label is shown in Figure 6. Figure 6

An example of a WHMIS work site label

TOLU-SOLV All Purpose Cleaner Flammable: Keep away from all sources of heat, sparks, and open flames Toxic:

When handling, use neoprene gloves, goggles, and organic vapour respirator See MSDS for more information

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Are there any variations on the WHMIS work site label? Variations from the WHMIS work site label include the use of placards, warning signs, and coding (either by colour, number or lettering system).

Tell me about placards Sometimes it’s more practical to placard controlled products than to label them. The WHMIS law permits this variation in the following situations: § controlled products that are not in containers; § controlled products that are produced for sale, but that have not yet reached the labelling stage of the production process; and § controlled products that are destined for export only. The placards must include the information required on WHMIS work site labels. They must be large enough to be easily legible and must be located in a position that will make them readily obvious to workers. There’s one other situation where placards are permitted. This is the situation where the controlled product arrives on-site without the required supplier label and you store it while you track down the WHMIS supplier label. See page 9.

When is it okay for me to simply identify a controlled product? There are five situations where you may use any method of clear identification to “label” controlled products. They are: 1. controlled products in on-site transport or reaction systems such as pipes, tank trucks, ore cars, conveyor belts, reaction vessels, etc.; 2. mixtures and substances undergoing analysis, tests or evaluation in a laboratory; 3. controlled products that are transferred from other (adequately labelled) containers, kept under the control of the person who made the transfer, and that are used up during the shift in which the container was filled; 4. controlled products for use in laboratories that are transferred from the supplier’s containers to laboratory containers, or controlled products produced in laboratories for use there only; and 5. hazardous wastes produced in the workplace. These materials may be identified by any clear means, such as painted-on, stencilledon, or even hand-written identifiers or colour codes.

Are there any controlled products that don’t require a WHMIS label of any kind? There are only two groups of controlled products in this category. They are: § controlled products for immediate use; and § fugitive emissions. A “controlled product for immediate use” is one that is transferred from a properly labelled container to another container, and that will be transferred immediately from the second container into some chemical process where it will be totally consumed. The

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transfer container need not have any type of WHMIS label. An example of this situation is the measuring of a reagent before adding it to a chemical reaction vessel. Fugitive emissions cannot be labelled because they are spread through the air or over a surface. However, the equipment from which the emissions escape must be labelled with an appropriate work site label.

Where do I get my WHMIS labels? Supplier labels come with the controlled products you purchase from Canadian suppliers. However, you may have “old” controlled products at your site. You may also import controlled products for use at your company. Both these kinds of controlled products require the application of supplier labels. You may be fortunate enough to have suppliers who are able, and willing, to provide these supplier labels to you. If not, the responsibility falls to you. You may have staff who can perform this task for you, otherwise you will need to seek outside expertise. Once you have developed the content and design of the labels, you can have them produced at in-house or commercial printing facilities. Many printing houses and safety equipment suppliers carry commercially printed, blank work site labels. If you don’t want to buy labels, you may write the required information directly on product containers or use readily available materials, such as paper or plastic, to make the labels.

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Material Safety Data Sheets (MSDSs) What is a Material Safety Data Sheet? Material Safety Data Sheets are commonly known as MSDSs. These documents contain information that is more detailed and more technical than the information on WHMIS labels. MSDSs have nine categories of information. The categories and the information to be contained in them are listed in Figure 7. There are no format requirements for WHMIS MSDSs. Writers may use any format they choose, as long as the required information is included. However, each of the nine categories must be identified by a heading identical, or similar, to that shown in Figure 8. The WHMIS border is not required. Figure 8 shows a model of a WHMIS MSDS. The final requirement for MSDSs is that they be up-to-date. Suppliers must update an MSDS whenever they become aware of new information which could cause the current one to be outdated, or every three years, whichever comes first. You should never receive an MSDS from a Canadian supplier which is more than three years old.

Are there any variations on the basic “MSDS”? Just two. Generic MSDSs are permitted for groups of controlled products that are basically the same but have small variations in ingredients from one product to another. A line of paints is an example of such a group. The (generic) MSDS for each individual product must indicate the product identifiers for all products in the group. It must also be supplemented with any information that is different for the individual product than for the group. Additional ingredients, variations in concentration of ingredients, and different hazard information, are examples of information that might vary from product to product within a group. An MSDS that uses the ISO, ILO, ECC, or ANSI 16-heading format is also acceptable as long as all of the required information is provided. Under the Regulatory Information heading the following statement should be provided: “This product has been classified in accordance with the hazard criteria of the Controlled Products Regulation and the MSDS contains all the information required by the Controlled Products Regulations.” The heading format requires inclusion of the following information:

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Figure 7 1.

Information required on a WHMIS Material Safety Data Sheet Hazardous ingredients i Required ingredients i CAS registry number i PIN i LD50 (species and route) i LC50 (species and route)

i i i i i

Lower flammable limit Auto-ignition temperature Hazardous combustion products Explosion data- sensitivity to mechanical impact Explosion data – sensitivity to static discharge

2.

Preparation information i Person or group responsible for preparation, and telephone number i Date of preparation

3.

Product Information i Product identifier i Product name i Product use i Manufacturer’s name, address, and emergency telephone number i Supplier’s name, address and emergency telephone number

4.

Physical data i Physical state i Odour and appearance i Odour threshold i Specific gravity i Vapour pressure i Vapour density

5.

i i i i i

Fire or Explosion Hazard i Conditions of flammability i i Means of extinction i i Lower flammable limit i i Auto-ignition temperature i i Hazard combustion products

Evaporation rate Boiling point Freezing point pH Coefficient of water/oil distribution

Flash point and method of determination Upper flammable limit Explosion data – sensitivity to mechanical impact Explosion data – sensitivity to static discharge

6.

Reactivity Data i Conditions of instability i Substances with which product is incompatible i Condition of reactivity i Hazardous decomposition products

7.

Toxicological Properties i Route of entry i Effects of acute exposure i Effects of chronic exposure i Exposure limits i Irritancy of product i Sensitizing properties

i i i i i

Carcinogenicity Reproductive toxicity Teratogenicity Mutagenicity Toxicologically synergistic products

Preventive Measures i Personal protective equipment i Engineering controls i Spill/leak procedures i Waste disposal

i i i

Handling procedures/equipment Storage requirements Shipping information

8.

9.

First Aid Measures i Specific first aid measures

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Figure 8

An example of the basic WHMIS MSDS

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1. Chemical product and company information; 2. Composition/information on ingredients 3. Hazards identification; 4. First aid measures; 5. Fire fighting measures; 6. Accidental release measures; 7. Handling and storage; 8. Exposure controls, personal protection; 9. Physical and chemical properties; 10. Stability and reactivity; 11. Toxicological information; 12. Ecological information; 13. Disposal considerations; 14. Transport information 15. Regulatory information; and 16. Other information. Note: ISO ILO ECC ANSI

= = = =

International Organization for Standardization International Labour Organization European Community Commission American National Standards Institute

How do I get MSDSs for the controlled products at my company? Canadian suppliers (or distributors) will send you WHMIS MSDSs when you buy controlled products from them. They’ll provide those MSDSs in your choice of English or French. If you don’t specify which language you prefer, the supplier will send the MSDS in whichever of those languages you and the supplier usually communicate. You should note however that the supplier does not have to send you an MSDS with every shipment of a specific controlled product. The supplier will send a WHMIS MSDS with the first shipment. After that, the supplier is only required to send you a new MSDS for the product with the next shipment you buy after the MSDS has been updated. Employers are responsible for obtaining or developing MSDSs for the other controlled products at their work sites. These include controlled products purchased before WHMIS came into effect, controlled products obtained from foreign suppliers and controlled products produced at the work site for use there. Suppliers may be able, and willing, to provide WHMIS MSDSs (as well as supplier labels) for “old” products or imported products. If not, your company will have to take on this task.

Am I responsible for updating all these MSDSs? As you know, Canadian suppliers are required to provide you with a current MSDS (upto-date and less than three years old) when you buy a controlled product. You can expect your supplier will provide updated MSDSs (whenever one is available) for controlled products you buy on a regular basis. Whenever you receive an updated

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MSDS from one of your regular suppliers, replace the MSDS you have with the updated one. You may have a number of controlled products that you buy on a one-time-only or an irregular basis. Keeping the MSDSs for these products up-to-date might be a bit more complicated. Whenever you become aware of new hazard information which pertains to one of these products, or whenever one of these MSDSs becomes three years old, your company will have to update the sheet. You could contact the supplier and request the current MSDS. But remember that the supplier doesn’t have a legal obligation to provide it to you until you buy more of the product. Alternatively, you can ask the supplier for enough information to update the MSDS yourself. If the supplier does not cooperate you will either have to use your company resources to get the MSDS updated or stop using the product. MSDSs for controlled products which are produced at your company or which you import for use at your company must be updated by your company. They must be reviewed every three years (or more often if new hazard information becomes available in the interim), and updated as necessary.

My supplier says that some of the ingredients in the product are secret. Can he get away with that? WHMIS makes provision for the protection of certain secret information, called “confidential business information,” from disclosure on WHMIS supplier labels or MSDSs. Only certain specific information qualifies as confidential business information. Even this specific information may be withheld from disclosure only when certain conditions are met. Suppliers may withhold the identity of any ingredient(s) in a controlled product, the concentration of any ingredient(s), or the identity of any toxicology study which would identify the ingredient(s), as confidential business information. Employers may withhold the product identifier and information which would identify the supplier, as well as the same information which suppliers may withhold. Other information — physical properties, hazard information and preparation — must always be revealed on the MSDS. It can never be withheld as confidential business information. If confidential business information has been withheld from a supplier label or MSDS, this fact will be clearly indicated. The secret information will be replaced with a Hazardous Materials Information Review Commission (HMIRC) Registry number and the date on which the claim was filed (or date when the information was validated as secret.) Confidential business information is discussed later in this Safety Bulletin.

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We like to transfer supplier MSDSs onto our own MSDS format. Is that okay? WHMIS does not discourage this practice. In fact, standard format company MSDSs have many advantages. A consistent format from one sheet to the next makes it much easier for readers to find the specific information they are looking for. And the use of consistent terminology throughout the complete collection of MSDSs improves readability. Employer MSDSs must contain all of the information that was on the supplier MSDS. Additional hazard information that the employer is aware of should also be included on the employer MSDS. The original supplier MSDSs must be available to persons at the work site, and the employer MSDS must indicate this fact.

Are there any controlled products at the work site that don’t require MSDSs? Certain controlled products such as pesticides, explosives, etc., are excluded from the supplier aspects of WHMIS. (These are discussed on page 6.) Suppliers are not required to provide MSDSs for these products, and employers are not required to obtain them. MSDSs are not required for intermediate products in reaction vessels either. These chemicals have a very short life. Often, they are not even identified. Finally, laboratory supply houses are permitted to sell certain controlled products without providing MSDSs. These controlled products must be less than 10 kilograms in quantity and sold for use in laboratories only. Instead of the basic supplier label, they must be labelled with all of the information that is required for the basic WHMIS MSDS.

Is there anything else that I need to know about MSDSs? Just one thing. MSDSs for the controlled products at your work site must be readily available to workers who might want to see them. There’s no requirement about where you should keep them, but it has to be a place where workers have access to the information on the MSDSs whenever they need it. You may wish to make extra copies of MSDSs so you can locate them in different areas of your work site. MSDSs can be available in electronic format as long as workers can readily access them.

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Worker Education What must be included in WHMIS worker education? WHMIS worker education includes four areas of instruction: 1. 2. 3. 4.

WHMIS labels and MSDSs; hazard information; identification codes; and procedure for the safe use, storage and handling of controlled products, and procedures for dealing with fugitive emissions and emergencies.

Provision of information about WHMIS labels and MSDSs is referred to as “generic WHMIS worker education”. It includes instruction in the content that must be present on WHMIS supplier labels, WHMIS work site labels and WHMIS MSDSs, as well as instruction in the meaning of that information and its significance to persons at the work site. Generic WHMIS worker education is extremely important. Labels, and to an even greater extent, MSDSs, are the major source of hazard information for persons at most work sites. For this reason, it’s imperative that people know what information to expect on labels and MSDSs and that they understand what that information really means. Instruction in hazard information, identification codes and safe work procedures is known as “work site specific WHMIS worker education”. Hazard information includes all pertinent hazard information on the controlled products a person works with or the controlled products a person is involved in producing. All the hazard information provided by suppliers of the products, and all other hazard information of which the employer is aware, must be included in the worker education. “Identification Codes” includes colour codes, number codes and any other means of clear identification that is used to “label” controlled products in transfer systems, reaction vessels, etc. Instruction in procedures may have been provided already, during operations training or other occupational health and safety training. If so, and if that training meets the WHMIS worker education standard for effectiveness, the training need not be repeated for WHMIS purposes.

Do I have to provide WHMIS worker education for all my workers? The answer to that question depends on the work that each person performs. All persons at your work site who work with or in proximity to controlled products, or who do work involved in the manufacture of a controlled product, must be provided with WHMIS worker education. The generic worker education will be the same for all persons who participate in your worker education program. But the work site specific component of the program will

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probably vary among groups of workers. The hazard information a person needs to know and the procedures in which a person is trained depends on the work they do.

How often do I have to conduct WHMIS worker education at my company? The WHMIS law doesn’t specify how frequently worker education must be conducted. Instead, it provides a standard for the effectiveness of the training and requires that the standard be achieved on an ongoing basis.

What is the standard for WHMIS worker education? The program is considered to be effective when workers can apply the information they were taught to protect their own health and safety on the job. You might use a variety of methods to decide if this standard has been achieved. These could include practical or written tests, job observation, etc. The legislation does not specify how to conduct the training, how frequently to conduct it, or how to test for achievement of the standard. It leaves all those decisions to you, to do in the way that works best at your company. Adequately informed workers can be identified by their ability to answer four questions: 1. 2. 3. 4.

What are the hazards of the controlled product? How are you protected from those hazards? What do you do in case of an emergency? Where can you get additional hazard information? (this checks the worker’s ability to read and understand a WHMIS label and MSDS)

The employer must review the program of instruction at least once each year, or more often if conditions at the work site change or new information on a controlled product becomes available. This does not necessarily mean that re-instruction is required, but is meant to identify whether the program should be updated.

Where can I get my workers trained? Many private companies provide training services to assist you with developing or presenting generic WHMIS worker education. Or, of course, you can design and present it in-house. Work site specific WHMIS worker education is another matter. It involves training personnel in procedures that are specific to your company. Only rarely would an outside firm be familiar enough with those procedures to teach your staff to conduct them. This training is best designed and provided by on-site personnel.

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Confidential Business Information What does “confidential business information” mean? Confidential business information is specific information that would otherwise have to be revealed on a WHMIS label or MSDS but is a company secret that is financially valuable to the company. Genuine confidential business information may be withheld from disclosure on WHMIS labels or MSDSs.

What information may be withheld as confidential business information? Suppliers may withhold: § the identity or concentration of one or more ingredients of a controlled product; or § the name of toxicological studies that would identify those ingredients, if this information is genuine confidential business information. An employer may need to protect the identity of a product used at the company. The supplier may need to keep this information secret even from staff. For example, the product may be a secret ingredient in an important product that the company produces, or it may be a catalyst in a chemical reaction that occurs along the production line. The employer may need to keep this information secret even though the supplier of the product has no particular need to do so. Employers may withhold the same information as suppliers. They may also withhold the product identifier or information that would identify the supplier if it is genuine confidential business information.

What if the supplier claims that some of the hazard information is confidential? Hazard information can never be withheld from disclosure. Only the information described in the previous section may be withheld. Even that limited amount of information may be withheld only if it is validated as WHMIS confidential business information.

Who decides if the information really is confidential business information? Suppliers or employers who wish to withhold any of the information described above must file a claim with the Hazardous Materials Information Review Commission (HMIRC) that the information is genuine confidential business information. Parties who have claims of confidential business information must submit the following information to the Commission: § the secret information; § evidence that the information is confidential; § the MSDS and/or label in the form in which the claimant wants to use it, i.e. with the “confidential information” omitted but with all other required information included; and § a filing fee.

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Staff at the HMIRC review the claim to determine its validity and review the product’s MSDS and/or label to ensure that the information is complete and accurate. For importers of controlled products, trade secrets, proprietary information, or a registered trade secret claim in another country are not valid in Canada. The manufacturer must register with HMIRC if they wish to withhold confidential business information.

How do I know if the claim has been validated? Claimants are given a registry number when they submit their claims to the Commission. They are required to record this number and the date the claim was submitted on their label and/or MSDS in place of the withheld information. If the claim is accepted, the claimant must indicate this fact on the label and/or MSDS along with the registry number and the date the claim was validated.

What happens if a claim is not validated? If the Commission decides that a claim is not valid, the claimant will be ordered to reveal the information they had applied to withhold, or to remove the product from the market. Decisions of the Commission may be appealed to a tripartite appeals panel. This is the final step that may be taken in the effort to protect information from disclosure on WHMIS labels or MSDSs.

What happens if there’s an incident involving a controlled product that has a confidential ingredient? Suppliers or employers who have been granted an exemption from disclosure of confidential business information must reveal that information to a medical professional if the information is needed for diagnosis or treatment of a medical emergency. They must also reveal the information to government inspectors who need it to conduct investigations into the health and safety of workers at companies where the product is being used. Persons who receive confidential business information under these circumstances are required to keep the information confidential. Anyone violating this requirement is subject to the same penalties as persons who violate the Hazardous Products Act.

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Glossary Acute exposure — a single exposure, or exposure over a short time. Acute toxic effects (acute toxicity) — effects that take place after a single exposure or after a short series of exposures within 24 hours. Alberta Occupational Health and Safety Act — lays out employers’ and workers’ fundamental responsibilities for health and safety at work sites in Alberta. The authorities of the Alberta government to enforce these responsibilities are also found in this Act. Details of employers’ and workers’ responsibilities are specified in regulations written under the authority of the Act. American Conference of Government Industrial Hygienists (ACGIH) — an international association of occupational hygienists who develop many guidelines for the practice of occupational hygiene. One of the most important of these guidelines is Threshold Limit Values and Biological Exposure Indices. An updated version is published every year. This publication serves as the basis for occupational exposure limits in many jurisdictions around the world. Autoignition temperature — the lowest temperature at which a substance will ignite when no spark or flame is present. Boiling point — the temperature above which a product boils. Vapour is given off very rapidly at temperatures above the boiling point. CAS Registry Number — Chemical Abstracts Service Registry Number. This is a unique reference number used when looking up research information about a particular chemical. Canadian Centre for Occupational Health and Safety (CCOHS) — an occupational health and safety information service, located in Hamilton, Ontario. The Centre provides publications on many occupational health and safety subjects and access to a very large collection of advice on occupational health and safety problems. www.ccohs.org Chemical Hazards Regulations — the Alberta regulation that contains details of employers’ and workers’ WHMIS responsibilities. It also contains other requirements regarding chemicals at workplaces. Chronic exposure — exposure to a low concentration of a substance over an extended period of time. Chronic toxic effects (chronic toxicity) — effects that occur after chronic exposure or that occur a long time after exposure. Coefficient of water/oil distribution — the ratio of a product’s distribution between the water and oil portions of a mixture of water and oil. A value of less than 1 indicates that the product is more soluble in oils. A value of greater than 1 indicates that the product is more soluble in water.

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Combustion product — a product formed when a material is burned. Complex mixture — a mixture that is a combination of many chemicals, has a commonly known generic name and is: (a) naturally-occurring; (b) a fraction of a naturally-occurring mixture that results from a separation process; or (c) a modification of a naturally-occurring mixture or a modification of a fraction of a naturally-occurring mixture that results from a chemical modification process. Condensation — a type of chemical reaction in which water is formed as a by-product. Conditions of flammability — a subsection of the WHMIS MSDS that describes conditions under which a product will polymerize, decompose, condense or become selfreactive. These conditions could include pressure, heat, vibration, jarring or the presence of moisture or air. Conditions of reactivity — a term on the WHMIS MSDS to describe conditions under which two or more materials will react together. These conditions could include the presence of light, elevated temperatures, aging, or the absence of an inhibitor. Controlled products — products, materials or substances that meet the criteria for one or more of the six WHMIS classes of products. Controlled products are dealt with in Part II of the Hazardous Products Act. Controlled Products Regulations — federal regulations written under the authority of the Hazardous Products Act. They contain the details of suppliers’ WHMIS responsibilities, including classification, supplier labels and WHMIS MSDSs. Cumulative toxic effects — effects that usually occur after long exposure to a substance. The exposures occur many times and the effects “accumulate”. Even very small individual exposures may result in a toxic effect. Date of preparation — is included on the WHMIS MSDS to indicate the date when the sheet was last updated. This date must never be more than three years old. Decomposition — breakdown of a material into two or more different materials. Decomposition product — a product that may be released as a result of aging or reaction with airborne oxygen or moisture. Edema — accumulation of fluid in tissue i.e. swelling. Engineering controls — a subsection of the WHMIS MSDS that includes measures for eliminating or reducing chemical hazards to which workers may be exposed. Examples include the substitution of less hazardous products for more hazardous ones, enclosure of processes to prevent the release of hazardous materials, or local exhaust ventilation to remove airborne contaminants at their point(s) of generation. Erythema — patches of reddened, bumpy skin.

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Evaporation rate — a term on a WHMIS MSDS that indicates how quickly a substance vapourizes compared with butyl acetate. (The evaporation rate of butyl acetate is 1.) Substances with a high evaporation rate can get into the air very quickly. Explosion data – sensitivity to impact — a term on a WHMIS MSDS to indicate whether a product will explode if it is jarred or scraped. Explosion data – sensitivity to static discharge — a term on a WHMIS MSDS to indicate whether a product will explode if it is exposed to static electricity. Exposure limits — the concentrations of chemicals that may not be exceeded in workplace air. Exposure limits have different names and often have different numerical values in different provinces and territories. In Alberta they are called Occupational Exposure Limits (OELs) and are listed in the Chemical Hazards Regulation. First aid measures — a subsection of the WHMIS MSDS that describes the main first aid actions to be taken if a worker is seriously overexposed. Flash point — the lowest temperature at which a product will give off enough vapour to catch fire when it is exposed to a source of ignition. The lower the flash point, the greater the potential fire hazard. There should be a notation beside the flash point value to indicate the test method that was used. Freezing point — the temperature below which a liquid material turns into a solid. It is identical to the melting point, the temperature above which a solid material becomes liquid. Generic WHMIS worker education — the component of the WHMIS worker education program that includes a general introduction to WHMIS, training in the required content of WHMIS labels and MSDSs, and training in the purpose and significance of that information to workers’ health and safety on the job. Handling procedures/equipment — a subsection of a WHMIS MSDS that describes the basic precautions to be observed when handling the product or the basic equipment to be used during handling. Hazard information — all information on the safe use, storage, and handling of a controlled product, including toxicological information. Hazardous Materials Information Act — the federal act that allows the protection of confidential business information. It specifies what information may be protected and establishes the Hazardous Materials Information Review Commission. Hazardous Materials Information Review Commission — the organization, located in Ottawa, which reviews claims of confidential information, i.e. the conditions under which information may be protected, the procedures for filing a claim, etc. Hazardous Products Act — the act that specifies suppliers’ responsibilities regarding “prohibited products”, “restricted products” and “controlled products”. WHMIS includes only controlled products.

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Importer — a person or company that brings a controlled product into Canada for sale to, or use at, a work site. Importers have the same WHMIS responsibilities as suppliers. Incompatible substances — materials which, when combined with a specific product, will cause the production of toxic or corrosive materials, excessive heat or an explosion. Ingredient Disclosure List — a list of 1,736 chemicals which, if present as an ingredient in a controlled product at concentrations greater than the cut-off concentrations specified on the List, must be revealed on the MSDS. The Ingredient Disclosure List is not a list of controlled products. (There is no comprehensive list of controlled products.) Irritancy — the ability of a product to cause local effects in the area where it contacts the body, such as the throat, eyes or skin. Effects could include redness, itching or swelling. Laboratory — any location where samples are taken or analyzed. LC50 (Lethal Concentration50 ) — this is the unit for measuring the toxicity of chemicals that are inhaled into the body. It represents the amount of a chemical that will cause death in 50% of a group of test animals. LC50 values are usually expressed as ppm (parts of chemical per million parts of air) for dusts, mists or fumes. They vary with the species of animal and the length of exposure. You can expect to see this information in brackets beside the LC 50 value, for example, LC 50 = 2ppm (mouse, 4 hours). LD50 (Lethal Dose 50 ) — this is the unit for measuring toxicity of chemicals that enter the body by any route other than inhalation e.g. through ingestion or skin absorption. It represents the amount of a chemical that will cause death in 50% of a group of test animals. LD 50 values are usually expressed in mg/kg (milligrams of chemical per kilogram of animal body weight). They vary with the animal species, the route of exposure, and the length of exposure. You can expect to see this information in brackets beside the LD 50 value, for example, LD 50 = 5 mg/kg (rat, oral, 8 weeks). Lower explosive limit (LEL) or Lower flammable limit (LFL) — the lowest concentration of a substance in air that will explode when it is exposed to a source of ignition. At concentrations below the LEL, the mixture is “too lean” to explode. The LEL is the same as the LFL. Means of extinction — a subsection of a WHMIS MSDS that describes the type of fire extinguisher that should be used on a small fire involving the product and the main firefighting agents to be used for a major fire. Mutagenicity — a product’s ability to change the genetic materials in the body cells of exposed persons. Mutations in germ cells (sperm and ova) may be passed on to the exposed person’s children. Mutations to other cells affect only the person who was exposed. Odour threshold — the lowest concentration of a substance in air at which most people can smell it. Organic peroxide — a particular type of chemical. It is a very powerful oxidizer, highly self-reactive if heated or shocked, and very irritating to skin, eyes, throat and respiratory tract.

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Oxidizing material — any material that can give up oxygen or other oxidizing materials. Oxidizing materials stimulate combustion and are incompatible with flammable substances. Personal protective equipment (PPE) — the clothing or equipment that a worker who is handling a hazardous material can wear to reduce or prevent their exposure to the substance. PPE may include coveralls, goggles, a faceshield, apron, gloves or respirator. pH — a measure of a substance’s acidity or alkalinity. A pH of 7 is neutral. Substances with a pH greater than 7 are alkaline (caustic). Alkalinity increases as the number increases. Substances with a pH less than 7 are acidic. Acidity increases as the pH decreases. Physical state — indicates whether a product is a solid, liquid or gas. Polymerization — the combination of simple molecules to form large chain-like macromolecules. This reaction can sometimes be observed as the “hardening” of a “noninhibited” liquid product. Prohibited products — products that may not be sold, advertised or distributed in Canada. These products are dealt with in Part I of the Hazardous Products Act. They are not involved in WHMIS. Preparation information — a subsection of the WHMIS MSDS that identifies a person or group that can explain the information on the MSDS or can give further information about the product if it is needed. A telephone number for this person or group is also included. Reproductive toxicity — a product’s ability to affect the fertility of persons exposed to it. The effects include changes in sperm or ova, and miscarriages. Restricted products — products that must be labelled in a particular way if they are to be sold in Canada. They are dealt with in Part I of the Hazardous Products Act. Restricted products that are packaged in sizes appropriate for the general public, labelled as required by the HPA and offered for sale in ordinary retail outlets are considered, for the purposes of WHMIS, to be “consumer products”. Route of entry — the way a product enters the body. The most common routes for workplace chemicals to enter the body are inhalation, ingestion and absorption through the skin. Note: Contact between a product and the skin does not necessarily result in the material being absorbed into the body. The material could cause a chemical burn or a rash on the surface of the skin or eye and never enter the body. Sale (of a controlled product) — includes “offer for sale”, “expose for sale” or “distribute”.

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WHMIS Information for Employers

Sensitization — a product’s ability to affect the body’s immune system so that further exposures may result in symptoms. These symptoms may be as minor as a slight irritation of the skin or as profound as severe respiratory distress. Different sensitizers cause different types of symptoms. Shipping information — specific instructions on the WHMIS MSDS for preventing “conditions of flammability, instability, or reactivity” from developing during shipping. Specific gravity — the weight of a substance compared to the weight of an equal volume of water. Substances with a specific gravity greater than 1 are heavier than water. Substances with a specific gravity of less than 1 are lighter than water. Spill/leak procedures — a term on a WHMIS MSDS. These procedures describe the steps to be taken in the event of a spill or leak of the controlled product. Storage requirements — specific instructions on the WHMIS MSDS for preventing “conditions of flammability, instability, or reactivity” from developing during storage. Supplier — a person or company that manufactures, processes or packages a controlled product, or that sells or imports a controlled product. Synergism — a phenomenon involving the simultaneous effects of exposure to two substances. Synergistic substances cause effects that are greater than the sum of the effect caused by the two individual substances alone. Teratogenicity — a product’s ability to cause damage to a fetus without affecting the pregnant female. Threshold limit values (TLVs) — airborne concentrations of substances. TLVs represent conditions to which it is believed that nearly all workers may be exposed day after day, without suffering adverse effects. ACGIH developed this term. Toxicity — a basic property of a substance. It is the substance’s ability to cause adverse effects in persons exposed to it. Transportation of Dangerous Goods legislation (TDG) — legislation that controls the conditions under which dangerous materials may be transported on public roads, in the air, by rail or by ship. Its purpose is to protect the health and safety of persons in the vicinity of transport accidents involving those materials. Upper explosive limit (UEL)or Upper flammable limit (UFL) — the greatest concentration of a substance in air that will explode when it is exposed to a source of ignition. At concentrations greater than the UEL, the mixture is “too rich” to explode. The UEL is the same as the UFL. Vapour density — the weight of a vapour or gas compared to the weight of an equal volume of air. Substances with vapour densities greater than 1 sink to low lying areas and accumulate there. If the substance is flammable, a dropped match or a spark can cause a fire or explosion. If toxic, persons working in low areas (such as mechanics’ pits) may be exposed to high concentrations of the vapour and suffer the acute effects of the product.

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WHMIS Information for Employers

Vapour pressure — the pressure exerted by the vapour formed over a liquid in a closed container, under standard test conditions, reported as an absolute pressure. Vapour pressure increases as temperature increases until the criteria temperature is reached. The presence of these vapours in the air may be a hazard, especially if the vapours are flammable or toxic, or in confined spaces where they may displace breathable air out of the space. Waste disposal — a term on a WHMIS MSDS that describes effective and environmentally safe ways to dispose of waste that contains the controlled product. Work site – specific WHMIS worker education — the portion of the WHMIS worker education program in which workers are trained in the hazard information applicable to the controlled products they work with or near, and in work procedures applicable to those products.

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WHMIS Information for Employers

Appendix 1

Obtaining WHMIS legislation

Alberta WHMIS legislation Alberta’s Occupational Health and Safety Act (RSA 1980, Ch. 0-2) and its regulations, including the Chemical Hazards Regulation (AR 393/88), may be purchased from the Queen’s Printer: 11510 Kingsway Avenue Edmonton, Alberta T5G 2Y5 (780) 427-4952

Main Floor, 455-6th Street SW Calgary, Alberta T2P 4E8 (403) 297-6251

The Act and its regulations are also available at the Alberta Human Resources and Employment, Workplace Health and Safety Web site at : www.whs.gov.ab.ca

Federal WHMIS legislation The Hazardous Products Act (am. S.C. 1987, c.30) and its regulations: § the Controlled Products Regulations (SOR/DORS/88-66; am. SOR/88/555); and § the Ingredient Disclosure List (SOR/DORS/88/64), along with The Hazardous Materials Information Review Act (am.S.C. 1987, c.30) and its regulation, the Hazardous Materials Information Review Regulation (SOR/88-65; am. SOR/88-510; am. OR/89-288), may be obtained from federal government publication outlets across Canada or: Supply and Services Canada Ottawa, Ontario K1A 0S9 (819) 997-2560

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WHMIS Information for Employers

Appendix 2

Resources

Books §

British Columbia Workers’ Compensation Board (January 1991) WHMIS Core Manual. A Resource Manual for the Application and Implementation of WHMIS, Richmond, BC: Workers’ Compensation Board of British Columbia. (604) 276-3068, www.wcb.bc.ca

§

Logan, Jeanette, E.C. (ed.) (1989) WHMIS Compliance Manual, Canada: The Carswell Company.

§

Moser, Cindy (Project Manager) (1988) The WHMIS Handbook, Don Mills, Ontario: Corpus Information Services, A Division of Southam Communications Ltd.

§

WHMIS Current Issues Committee, WHMIS Education and Training Programs: Guidelines for Employers, Workers and Regulatory Agencies. Distributed by Workers’ Compensation Board of British Columbia, Richmond, B.C.

Booklet* and Safety Bulletin § §

WHMIS – Information for Workers (CH007) WHMIS – Information for Suppliers (CH009)

Poster* §

Check The Signs (CH006)

*Available from Alberta Human Resources and Employment, Workplace Health and Safety.

Personal Assistance Canadian Centre for Occupational Health and Safety (CCOHS) 250 Main Street Hamilton, Ontario L8N 1H6 www.ccohs.org A list of WHMIS consultants (e.g. occupational hygienists, trainers, publishers, etc.) is available, upon request, from Alberta Human Resources and Employment, Workplace Health and Safety.

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WHMIS Information for Employers

For more information about workplace safety or safe work practices, contact the Alberta Human Resources and Employment, Workplace Health and Safety Call Centre by dialling toll-free:

%

1-866-415-8690

Deaf or hearing impaired call: ä

Edmonton

(780) 427-9999

Other locations

1-800-232-7215

For more publications, visit our Web site at: www.whs.gov.ab.ca To obtain copies of the Alberta Occupational Health and Safety Act and Regulations, view and download them from our Web site or contact the Queen’s Printer by dialling toll-free 310-0000 and one of the numbers listed below: ä

Edmonton……(780) 427-4952

CH008 Revised September 1999

Calgary………..…(403) 297-6251

38

Delta-P Test Corp. Safety Handbook Appendix E: Transportation of Dangerous Goods (TDG).

19/06/01 36 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Transports Canada Transport Canada Safety and Security Sécurité et sûreté Marchandises dangereuses Dangerous Goods

? 8

5.1

2

Classification EXPLOSIVE

1.1D 1

and

RADIOACTIVE

7

Safety Marks 4

INFECTIOUS INFECTIEUX

4

IN CASE OF DAMAGE EN CAS DE DOMMAGE OR LEAKAGE OU DE FUITE COMMUNIQUER IMMEDIATELY NOTIFY IMMÉDIATEMENT LOCAL AVEC LES AUTORITÉS AUTHORITIES LOCALES OR OU CANUTEC 613-996-6666

6

TP10164

NOVEMBER 1996 © Minister of Supply and Services Canada 1996 Cat. No. T44-3/16-1993, 2nd Edition ISBN 0-662-59538-6

Dangerous Goods

Classification and Safety Marks

Table of Contents Topic Introduction .................................................................................................................................... 1 Explanation of Terms ..................................................................................................................... 1 Classification .................................................................................................................................. 2 Safety marks ................................................................................................................................... 3 The Nine Classes ........................................................................................................................... 4 Class 1 Explosives .................................................................................................... 4 Class 2 Gases ........................................................................................................... 6 Class 3 Flammable Liquids ....................................................................................... 7 Class 4 Flammable Solids ......................................................................................... 8 Class 5 Oxidizing Substances and Organic Peroxides.............................................. 9 Class 6 Poisonous Substances and Infectious Substances .................................... 10 Class 7 Radioactive Materials ................................................................................. 11 Class 8 Corrosive Substances ................................................................................ 12 Class 9 Miscellaneous Substances ......................................................................... 12 Danger Placard .......................................................................................................... 13 Marine Pollutant ......................................................................................................... 13 Special Labels and Placards ...................................................................................... 13 Contacts: Federal .......................................................................................................................... 14 Contacts: Provincial/Territorial ....................................................................................................... 15

Dangerous Goods - Classification and Safety Marks Introduction

The Transportation of Dangerous Goods Act and Regulations were enacted to promote public safety when dangerous goods are transported in Canada. This legislation is the result of a cooperative effort among the federal, provincial and territorial governments and industry. Since the responsibility for controlling and regulating transportation is a shared one, the federal provincial and territorial governments are working together to ensure that dangerous goods requirements are uniform across the country for manufacturers and shippers and apply to all modes of transport - air, marine, rail and road. This brochure provides a general outline of the classes of dangerous goods and their characteristics as well as general information on the responsibility of consignors to properly identify consignments of dangerous goods with the correct safety marks. For specific information, the Act and Regulations must be consulted.

Explanation of Terms

The explanations listed below are provided for ease of understanding only and may not be substituted for the definitions as they appear in the Regulations. Compatibility Group - identifies the kinds of Class 1 explosive substances and articles that can be transported together without significantly increasing either the probability of an accident or, for a given quantity, the magnitude of the effects of such an accident. Consignor - the person who offers the shipment for transport (normally the shipper). Lables - small diamond-shaped safety marks placed on packages and small containers to identify the hazard of the dangerous goods. Packing Group - indicates the degree of danger of a product or substance. Group I, great danger; II, moderate danger; III, minor danger. Placards - large diamond-shaped safety marks used on a vehicle or large container to identify the hazard of the dangerous goods. Primary Classification - the classification of a dangerous good that takes precedence over any other classification. Product Identification Number - a four-digit United Nations or North American number used to identify the dangerous goods. Subsidiary Classification - other classifications that further identify the hazards of the dangerous goods.

1

Classification

The Transportation of Dangerous Goods Act divides dangerous goods into nine classes, defined on pages 4 to 13, according to the type of danger they present. Some of these classes are further divided into divisions which are also associated with hazard characteristics. For example, for Class 1.2 explosives, the numeral 1 is the class and 2 is the division. Below is a pictorial summary to help manufacturers or importers use the Regulations to classify dangerous goods for domestic transport. For transborder transport, Parts IV, V and VII should also be consulted and for international transport the ICAO Technical Instructions or IMDG Code should be consulted, where applicable.

Is the product completely and accurately described by the shipping name (and its attached description) in normal-type face in List I or List II of the Schedule II?

YES

NO

Use the information in the various columns corresponding to that name and the applicable Special Provisions from Schedule III.

Consult Part III of the Regulations.

If item is in Class 1, 7, 9.1 or 9.2, it will be classified pursuant to another regulatory authority. Class 9.2 will be regulated in accordance with Schedule II or Schedule XIII.

Classes 2, 3, 4, 5, 6.1, 8 and 9.3 have criteria and require tests to be completed as detailed in Part III. For Class 6.2, definitions and professional expert judgement are required; Class 6.2 must also be based upon Schedule VII. Based on the definitions and criteria, three scenarios exist.

Falls out of all classes

Falls into one class and division

Falls into more than one class and/or division

Not regulated.

Consult List II of Schedule II for appropriate name in caps and the applicable special provisions from Schedule III.

Determine primary classification, subsidiary classification(s) and Packing group(s) for each hazard and the precedence of hazards as found in Part III and Schedule I and consult List II of Schedule II for the appropriate name in caps and the applicable special provisions from Schedule III.

2

Safety Marks

Safety marks communicate by colour and symbol the degree and nature of the hazard of dangerous goods. These safety marks are displayed on containers, packages, tanks and cylinders and on transport units. There are four groups of safety marks: labels, placards, signs and other safety marks. Labels indicate the primary classification of dangerous goods and, in some cases, the subsidiary classification. Unless otherwise specified, they must be applied to every small container, package and cylinder that contains dangerous goods and is to be offered for transport. (They need not be applied to inner receptacles in packages). Placards also indicate the primary and, where applicable, the subsidiary classification of dangerous goods by colour, symbol and, in some cases, product identification number. Unless otherwise specified, they must be applied on each side and each end of the large container or the transport unit so that they are visible from any direction. Other safety marks are not necessarily symbols but additional information which may be required. For example, the shipping name and the product identification number must appear on a small container or package. For more detailed information, please refer to the Regulations (section 5.37). There are also special labels and placards for use in certain situations, such as “Ventilation requirements”, “Fumigation sign”, “Residu (e)”, “Polychlorinated biphenyls” and “This side up.” For more detailed information, please refer to the Regulations.

3

The Nine Classes

A brief description of the nine classes, their divisions, where applicable, common examples and uses and the appropriate placard and label is provided below.

Class 1 Explosives

As defined by the Explosives Act: 1.1 - A substance or article with a mass explosion hazard. 1.2 - A substance or article with a fragment projection hazard, but not a mass explosion hazard. 1.3 - A substance or article which has a fire hazard along with either a minor blast hazard or a minor projection hazard or both, but not a mass explosion hazard.

EXPLOSIVE

EXPLOSIVE A

EXPLOSIVE B

*1

*1

*1

EXPLOSIVE

EXPLOSIVE A

EXPLOSIVE B

*1

*1

*1 Domestic

U.S./Canada

* Divisions 1.1, 1.2 or 1.3 and compatiblity group. 1.4 - A substance or article which presents no significant hazard; explosion effects are largely confined to the package and no projection or fragments of appreciable size or range are to be expected.

1.4

1.4

EXPLOSIVE

1.4 EXPLOSIVE

*1

EXPLOSIVE C

1.4

*1

EXPLOSIVE C

*1

*1

Domestic

U.S./Canada

* Compatiblity group. * Compatibility Group There are 13 compatibility group letters used for segregation purposes in the transportation of Explosives: A, B, C, D, E, F, G, H, J, K, L, N and S. The appropriate letter must be displayed on the label and/or placard.

4

Class 1 Cont’d

1.5 - A very insensitive substance which nevertheless has a mass explosion hazard like those substances in 1.1.

1.5

1.5

1.5

D

BLASTING AGENTS D

1.5

1

D

BLASTING AGENTS D

1

1

Domestic

U.S./Canada

1

1.6 - An extremely insensitive substance which does not have a mass explosion hazard.

1.6

*1

1.6 *1 * Compatiblity group. Explosives are considered to be “compatible” with other explosive substances if they can be transported together without significantly increasing either the probability of an accident or, for a given quantity, the magnitude of the effects if an accident should occur. The 13 compatibility groups are listed in the United Nations Recommendations on the Transport of Dangerous Goods, also called the “Orange Book”. Commonly used in mining and construction operations (example: blasting agents).

Hazards mass explosion projection of missile hazards mass fire, minor blast effects toxic fumes

5

Class 2 Gases

2.1 - Flammable Gas. Commonly used as fuel (example: propane).

Cont’d

2

2

2.2 - Non-Flammable, Non-Poisonous, Non-Corrosive Gas. Commonly used in food refrigeration (example: nitrogen).

2

2

2

Oxygen only

2.3 - Poison Gas (Toxic Gas). Commonly used in pulp bleaching (example: sulphur dioxide).

Poison gas / Gaz toxique

2

2

Poison gas / Gaz toxique

2

2

6

Class 2 Cont’d

2.4 - Corrosive Gas. Commonly used in fertilizers (example: anhydrous ammonia).

2

2

Hazards BLEVE (Boiling Liquid Expanding Vapour Explosion) asphyxiation explosion or fire toxicity corrosiveness irritation container rupture container rocketing frostbite

Class 3 Flammable Liquids

A liquid which has a closed-cup flash point* not greater than 61o C. Commonly used as fuel (example: gasoline, ethanol, fuel oil (diesel)).

3

3

* Flash point: the minimum temperature at which a liquid gives off sufficient vapour to form an ignitable mixture with the air near the surface of the liquid.

Hazards BLEVE (Boiling Liquid Expanding Vapour Explosion) fire toxic fumes corrosivity unconfined vapour cloud explosion water contamination

7

Class 4 Flammable Solids; Substances liable to spontaneous combustion; Substances that on contact with water emit flammable gases

4.1 - A solid that under normal conditions of transport is readily combustible, or would cause or contribute to fire through friction or from heat retained from manufacturing or processing, or is a self-reactive substance that is liable to undergo a strongly exothermic reaction, or is a desensitized explosive that is liable to explode if they are not diluted sufficiently to suppress their explosive properties. Commonly used in lacquers (example: nitrocellulose).

4

(water-reactive substances)

4

4.2 - A substance liable to spontaneous combustion under normal conditions of transport, or when in contact with air, liable to spontaneous heating to the point where it ignites. Commonly used in rocket fuel (example: diethylzinc).

4

4

4.3 - A substance that, on contact with water emits dangerous quantities of flammable gases or becomes spontaneously combustible on contact with water or water vapour. Commonly used in heat exchangers (valves) (example: sodium).

4

4

8

Class 4

Hazards

Cont’d

Class 5 Oxidizing Substances and Organic Peroxides

may ignite may burn violently may be air or water reactive may be spontaneously combustible may also be toxic and/or corrosive may give off toxic/corrosive fumes 5.1 - A substance which causes or contributes to the combustion of other material by yielding oxygen or other oxidizing substances whether or not the substance itself is combustible. Commonly used in fertilizers (example: ammonium nitrate).

5.1

5.1

5.2 - An organic compound that contains the bivalent “-O-O-” structure which is a strong oxidizing agent and may be liable to explosive decomposition, be sensitive to heat, shock or friction, react dangerously with other dangerous goods or may cause damage to the eyes. Commonly used in automobile body shops as body filler (example: dibenzoyl peroxide).

5.2

5.2

Hazards burn easily and intensely readily supply oxygen (intensifies a fire) sensitive to heat, shock, friction may react to contamination may form explosive mixture may be toxic may explode

9

Class 6 Poisonous Substances and Infectious Substances

6.1 - Poisonous (Toxic) Substances: A solid or liquid that is poisonous through inhalation of its vapours, by skin contact or by ingestion. Packing Groups I, II and III I - Commonly used as chemical reagent in the extraction of gold and silver (example: sodium cyanide). II - Commonly used as a germicide or general disinfectant (example: phenol).

6

6

Harmful (Packing Group III) III - Commonly used in solvents and paint removers (example: methylene chloride).

6

6

or 6

6

6.2 - Infectious Substances (label only). Commonly used in disease research (example: rabies).

INFECTIOUS INFECTIEUX IN CASE OF DAMAGE EN CAS DE DOMMAGE OR LEAKAGE OU DE FUITE COMMUNIQUER IMMEDIATELY NOTIFY IMMÉDIATEMENT LOCAL AVEC LES AUTORITÉS AUTHORITIES LOCALES OR OU CANUTEC 613-996-6666

6

Hazards 6.1 may be toxic by inhalation, absorption or ingestion 6.2 may be infectious to humans, animals or both

10

Class 7 Radioactive Materials

Radioactive materials within the meaning of the Atomic Energy Control Act with activity greater than 74 kBq/kg. Commonly used in nuclear fuel rods (example: radioactive material - LSA (yellow cake)).

Placard

RADIOACTIVE

7

Labels There are three categories which indicate the surface radiation level for a package with Category I being the lowest level and Category III the highest.

RADIOACTIVE I

RADIOACTIVE II

RADIOACTIVE III

CONTENTS..........................CONTENU ACTIVITY..........................ACTIVITÉ

CONTENTS..........................CONTENU ACTIVITY..........................ACTIVITÉ INDICE DE TRANSPORT INDEX

CONTENTS..........................CONTENU ACTIVITY..........................ACTIVITÉ INDICE DE TRANSPORT INDEX

7

7

7

Category I - white

Category II - yellow

Category III - yellow

Hazards exposure to radiation release of radioactive contents (contamination)

11

Class 8 Corrosive Substances

A substance that causes visible necrosis of skin or corrodes steel or non-clad aluminum. Commonly used in batteries and industrial cleaners (example: sulphuric acid and sodium hydroxide).

8

8

Hazards destroy living tissue corrode metals and other materials may ignite combustibles

Class 9 Miscellaneous Products or Substances

9.1 - Miscellaneous Dangerous Goods; a substance or product presenting dangers sufficient to warrant regulation in transport but which cannot be ascribed to any other class. Commonly used in brake shoes (example: asbestos). 9.2 - An environmentally hazardous substance. Commonly used in dry cell batteries (example: ammonium chloride) (no label or placard required). 9.1 - A dangerous waste. Commonly found in waste sludges from industrial sources or treatment sludges from industrial processes (example: waste type 20) (no label required).

9

9

9

9

Hazards may be toxic through inhalation of dust particles may produce toxic fumes toxic to the environment may be toxic to humans

12

Danger Placard

For most “mixed loads” of dangerous goods having different classifications the “DANGER” placard may be used for large containers transported by road and rail.

DANGER

Marine Pollutant

International Convention for the Prevention of Pollution from Ships 1973 (MARPOL 73/78).

MARINE POLLUTANT

Special Labels and Placards

DANGER The lading of this container or vehicle has been fumigated or treated with

Le chargement de ce conteneur ou véhicule a été fumigé ou traité au

(Name of poisonous liquid, solid or gas)

(Nom du liquide, solide ou gaz toxique)

Before entering for loading or unloading open all portals and test to ensure the cargo space is free of gas.

Avant d'entrer pour charger ou décharger ouvrir toutes les portes et vérifier que l'espace est vide de gaz.

Fumigation Sign

DANGER

Package Orientation

VENTILATE BEFORE ENTERING AÉRER AVANT D'ENTRER

Ventilation requirements ATTENTION

PCB - DPC

CONTAINS CONTIENT DES POLYCHLORINATED BIPHENYLS DIPHÉNYLES POLYCHLORÉS

RESIDU(E)

Tank Car Only Residues after unloading

Elevated Temperature

A TOXIC ENVIRONMENTAL CONTAMINANT SCHEDULED UNDER THE ENVIRONMENTAL CONTAMINANTS ACT. IN CASE OF ACCIDENT, SPILL OR FOR DISPOSAL INFORMATION CONTACT THE NEAREST OFFICE OF THE ENVIRONMENTAL PROTECTION SERVICE, ENVIRONMENT CANADA.

PRODUITS TOXIQUES MENTIONNÉS DANS L'ANNEXE DE LA LOI SUR LES CONTAMINANTS DE L'ENVIRONNEMENT. EN CAS D'ACCIDENT, OU DE DÉVERSEMENT, OU POUR SAVOIR COMMENT LES ÉLIMINER, CONTACTER LE BUREAU DU SERVICE DE LA PROTECTION DE L'ENVIRONNEMENT, MINISTERE DE L'ENVIRONNEMENT, LE PLUS PRES.

Special PCB requirements

13

Contacts

Federal

Further information is available from:

Transport Dangerous Goods Directorate CANUTEC Transport Canada Ottawa, Ontario K1A 0N5 Telephone: (613) 992-4624 Facsimile: (613) 993-5925 Pacific Region Chief Transport Dangerous Goods Transport Canada 625 Agnes Street, Suite 225 New Westminster, British Columbia V3M 5Y4 Telephone: (604) 666-6740 Facsimile: (604) 666-7747 Prairie and Northern Region Chief Transport Dangerous Goods Transport Canada Federal Building, Room 305, 3rd Floor 101-22nd Street East Saskatoon, Saskatchewan S7K 0E5 Telephone: (306) 975-5059 Facsimile: (306) 975-4555 Prairie and Northern Region Transport Dangerous Goods Transport Canada 402 - 344 Edmonton Street Winnipeg, Manitoba R3B 2L4 Telephone: (204) 983-5969 Facsimile: (204) 983-8992 Ontario Region Chief Transport Dangerous Goods Transport Canada 20 Toronto Street, Suite 600, 6th Floor Toronto, Ontario M5C 2B8 Telephone: (416) 973-9820 Facsimile: (416) 973-9907 Eastern Region Chief Transport Dangerous Goods Transport Canada 702 - 685 Cathcart Street Montreal, Quebec H3B 1M7 Telephone: (514) 283-0303 Facsimile: (514) 283-8234

Atlantic Region Chief Transport Dangerous Goods Transport Canada 45 Alderney Drive, Suite 1415 Queen Square Building Dartmouth, Nova Scotia B2Y 2N6 Telephone: (902) 426-9351 Facsimile: (902) 426-6921 Air Transportation of Dangerous Goods Headquarters Chief, Dangerous Goods Standards Aviation Regulation Directorate Transport Canada - Aviation Place de Ville, Tower “C” 330 Sparks Street Ottawa, Ontario K1A 0N8 Telephone: (613) 990-1060 Facsimile: (613) 954-1602 Marine Senior Surveyor Dangerous Goods Ship Safety Directorate Canadian Coast Guard Transport Canada Ottawa, Ontario K1A 0N5 Telephone: (613) 991-3143 Facsimile: (613) 993-8196 Railway Transport Chief of Operations Transport Canada Operations Branch 344 Slater Street, 15th Floor Ottawa, Ontario K1A 0N5 Telephone: (613) 990-7077 Facsimile: (613) 990-2012 Explosives Explosives Division Natural Resources Canada 580 Booth Street Ottawa, Ontario K1A 0E4 Telephone: (613) 995-8415 Facsimile: (613) 995-0480 Radioactive Materials Directorate of Fuel Cycle and Materials Regulation Atomic Energy Control Board Ottawa, Ontario K1P 5S9 Telephone: (613) 995-0553 Facsimile: (613) 995-5086

14

Contacts Cont’d

For Dangerous Goods Waste Waste Mangement Branch Environment Canada Place Vincent Massey 351 St. Joseph Boulevard Hull, Quebec K1A 0H3 Telephone: (819) 997-3378 Facsimile: (819) 997-3068

Provincial/Territorial Manager, Dangerous Goods Motor Vehicle Department Ministry of the Attorney General 2631 Douglas Street Victoria, British Columbia V8T 5A3 Telephone: (604) 387-5585 Facsimile: (604) 356-8986 Director Dangerous Goods Control Regional Co-ordination Alberta Transportation and Utilities 1st Floor, Twin Atria Building 4999 - 98th Avenue Edmonton, Alberta T6B 2X3 Telephone: (403) 427-8901 Facsimile: (403) 427-1044 Saskatchewan Highways and Transportation Transportation Legislation and Safety Branch Dangerous Goods Transport 1855 Victoria Avenue, 8th Floor Regina, Saskatchewan S4P 3V5 Telephone: (306) 787-5527 Facsimile: (306) 787-8610 Dangerous Goods Information Manitoba Environment 139 Tuxedo Avenue, Building 2 Winnipeg, Manitoba R3N 0H6 Telephone: (204) 945-7025 Facsimile: (204) 948-2420 Operational Policy and Standards Office Compliance Branch Ministry of Transportation 301 St. Paul Street St. Catherines, Ontario L2R 7R4 Telephone: (905) 704-2434 Facsimile: (905) 704-2008

15

Direction du transport multimodal Service de la normalisation technique en transport routier Ministère des Transports du Québec 700 est, boulevard René Lévesque 23e étage Québec (Québec) G1R 5H1 Telephone: (418) 643-3242 Facsimile: (418) 646-6196 Registrar of Motor Vehicles Department of Transportation King’s Place, York Tower York Street, P.O. Box 6000 Fredericton, New Brunswick E3B 5H1 Telephone: (506) 453-2407 Facsimile: (506) 453-3076 Motor Vehicle Inspection Department of Transportation and Communication 6061 Young Street, P.O. Box 156 Halifax, Nova Scotia B3J 2M4 Telephone: (902) 424-7283 Facsimile: (902) 424-0544 Director Highway Safety Division Department of Transportation and Public Works P.O. Box 2000 Charlottetown, Prince Edward Island C1A 7N8 Telephone: (902) 368-5220 Facsimile: (902) 368-5236 National Safety Office Motor Registration Division Department of Works, Services and Transportation Viking Building, Crosbie Road P.O. Box 8710 St. John’s, Newfoundland A1B 4J6 Telephone: (709) 729-3454 Facsimile: (709) 729-0102 Dangerous Goods Coordinator Department of Community and Transportation Services Box 2703 Whitehorse, Yukon Y1A 2C6 Telephone: (403) 667-5313 Facsimile: (403) 668-7864

Contacts Cont’d

Director Motor Vehicle Division Department of Transportation Government of the Northwest Territories 4510 - 50th Avenue Highways Building, 1st Floor P.O. Box 1320 Yellowknife, Northwest Territories X1A 2L9 Telephone: (403) 873-7406 Facsimile: (403) 873-0120

The brochure provides general information only. For specific information, the Transportation of Dangerous Goods Act and Regulations must be consulted.

16

Delta-P Test Corp. Safety Handbook Appendix F: Industry Recommended Practices: Drill Stem Testing.

19/06/01 37 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

INDUSTRY RECOMMENDED PRACTICE (IRP)

VOLUME 4 - 2000

WELL TESTING AND FLUID HANDLING

PRINTED: 2000/2

2000/02

WELL TESTING AND FLUID HANDLING

The Mission of the PSC is to: •

Coordinate an organized approach to achieve continuous improvement in health and safety for everyone involved in or affected by the Petroleum Industry.

•

Continually strive to eliminate the number and magnitude of work-related injuries and illnesses through the promotion of health and safety principles, processes and practices for everyone in the industry.

•

Promote improved and standardized petroleum industry health and safety practices that meet regulatory requirements throughout Canada.

•

Promote worker safety and their right and responsibility to refuse to perform unsafe work.

Recommended by: Canadian Petroleum Safety Council (PSC) Canadian Association of Petroleum Producers (CAPP) Canadian Association of Oilwell Drilling Contractors (CAODC) Petroleum Services Association of Canada (PSAC) Small Explorers and Producers Association of Canada (SEPAC)

All PSC members will be listed at the beginning of the document indicating they recommend and encourage the use of the IRP.

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WELL TESTING AND FLUID HANDLING

This document as well as future revisions and additions are available from: The Petroleum Industry Training Service #13, 2115 - 27 Ave. N.E. Calgary, AB T2E 7E4 (403) 250-9606

Document Price: $ 20.00

2000, 02

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WELL TESTING AND FLUID HANDLING

Document Title

Number

Well Testing and Fluid Handling

2000-04

Custodian (organization) Canadian Petroleum Safety Council

Revision History Rev No

Effective Date

Description

Latest revision approved by (name):

Prepared by (name)

Reviewed by (name)

Signed:

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TABLE OF CONTENTS 4.0 4.0.1 4.0.2 4.0.3 4.0.4 4.0.5 4.0.5.1 4.0.5.2 4.0.5.3 4.0.5.4 4.0.5.5 4.0.5.6 4.0.5.7 4.0.5.8

ACKNOWLEDGEMENTS.................................................................................. 1 FOREWARD.................................................................................................... 2 SCOPE ........................................................................................................... 3 INTRODUCTION .............................................................................................. 4 IRP REVISIONS .............................................................................................. 4 REFERENCES ................................................................................................. 4 Alberta Heavy Oil and Oil Sands Practices Steering Committee ............. 4 American Petroleum Institute (API).......................................................... 5 American Society Of Mechanical Engineers (ASME)................................ 5 American Society Of Testing And Materials (ASTM)................................. 5 Canadian Association of Petroleum Producers (CAPP)............................ 5 Canadian Petroleum Association (CPA) ................................................... 6 Canadian Standards Association (CSA).................................................... 6 Drilling And Completions Committee (DACC) Industry Recommended Practices Volume II Completing And Servicing Sour Wells......... 6 4.0.5.9 Alberta Energy And Utilities Board (AEUB)............................................... 6 4.0.5.10 Government Of Alberta, Alberta Occupational Health And Safety (AOH&S)....................................................................................... 7 4.0.5.11 Government of Canada ............................................................................ 7 4.0.5.12 National Association of Corrosion Engineers (NACE)................................ 7 4.0.6 CONTENTS INDEX .......................................................................................... 7 4.0.7 DEFINITIONS .................................................................................................. 7 4.0.7.1 Adequate Lighting ................................................................................... 7 4.0.7.2 Bleed-off .................................................................................................. 7 4.0.7.3 Caution .................................................................................................... 8 4.0.7.4 Certified Pressurized Flowback Tank....................................................... 8 4.0.7.5 Closed System ......................................................................................... 8 4.0.7.6 Coiled Tubing Unit Operations (CTU) ....................................................... 8 4.0.7.7 Confined Space ....................................................................................... 8 4.0.7.8 Drilling Company ..................................................................................... 8 4.0.7.9 Drill Stem Test ......................................................................................... 8 4.0.7.10 Employer.................................................................................................. 9 4.0.7.11 Enclosed Environment ............................................................................. 9 4.0.7.12 ESD ..................................................................................................... 9 4.0.7.13 Flowback ................................................................................................. 9 4.0.7.14 High Vapor Pressure Hydrocarbons ......................................................... 9 4.0.7.15 Inline Test ................................................................................................ 9 4.0.7.16 Mud Can................................................................................................... 9 4.0.7.17 Non-certified Pressurized Storage tank or Vessel .................................. 10 4.0.7.18 Occupational Exposure Limits - Worker Safety Consideration............... 10 4.0.7.19 Open System.......................................................................................... 10 4.0.7.20 Other Flowbacks.................................................................................... 10 4.0.7.21 Owner ................................................................................................... 11 4.0.7.22 PPE ................................................................................................... 11 4.0.7.23 Positive Pressure ................................................................................... 11 4.0.7.24 Pressurized Truck Tank.......................................................................... 11 4.0.7.25 Purge ................................................................................................... 11 4.0.7.26 Qualified Well Testing Person ............................................................... 11

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WELL TESTING AND FLUID HANDLING 4.0.7.27 SABA - SCBA.......................................................................................... 12 4.0.7.28 Safety Service Company........................................................................ 12 4.0.7.29 Safety Standby Method.......................................................................... 12 4.0.7.30 Service Company................................................................................... 12 4.0.7.31 SITHP ................................................................................................... 12 4.0.7.32 Stimulations........................................................................................... 12 4.0.7.33 Swabbing............................................................................................... 12 4.0.7.34 Swivel Joint ........................................................................................... 13 4.0.7.35 Test Line ................................................................................................ 13 4.0.7.36 Test Plug................................................................................................ 13 4.0.7.37 Well Killing Operations.......................................................................... 13 4.0.7.38 Well Testing........................................................................................... 13 4.0.7.39 Worker ................................................................................................... 13 4.0.7.40 Underbalanced Drilling.......................................................................... 13 4.0.8 COMMON TERMS OF REFERENCE AND IRP’S FOR ALL OPERATIONS IN THIS VOLUME................................................................................................. 14 4.0.8.1 Responsibilities of Owners and Service Contractors.............................. 14 4.0.8.2 Drilling Service Company Responsibilities............................................ 17 4.0.8.3 Drill Stem Testing Company Responsibilities......................................... 17 4.0.8.4 Safety Service Company Responsibilities.............................................. 17 4.0.8.6 Fluid Hauling Company Responsibilities................................................ 18 4.0.8.7 Well Designation for Worker Safety in H2S Environments...................... 18 4.0.8.7.1 Sweet Well .............................................................................................. 18 4.0.8.7.2 Sour Well ................................................................................................ 19 4.0.8.7.3 Critical Sour Well ..................................................................................... 19 4.0.8.8 Metallurgy considerations for H2S environments.................................... 19 4.0.8.9 Gas Detection Monitoring for Explosive and Flammable Limits............. 20 4.0.8.10 Monitoring for Explosive Mixtures.......................................................... 23 4.0.8.11 Calibration of Explosive Mixture Monitors ............................................. 23 4.0.8.12 Hydrates: Awareness and Handling ....................................................... 23 4.0.8.13 Pressure Rating Formula For Seamless Pipe - Appendix I .................... 25 4.0.8.13.1 Tables - Pressure Rating Of Seamless Pipe....................................... 27 4.0.8.14 Worker Safety ........................................................................................ 32 4.0.8.15 Minimum Workwear Requirements........................................................ 32 4.0.8.16 Minimum General Safety Standards...................................................... 33 4.0.8.17 Pre-job Safety Meeting .......................................................................... 34 4.0.8.18 Opening a Closed Tank System for Inspection after Flowing or after Purging with a Flammable or Inert Medium .............................. 34 4.0.8.19 Gas Flares.............................................................................................. 35 4.0.8.20 Venting Gas to Atmosphere ................................................................... 36 4.0.8.21 Flare Pits................................................................................................ 36 4.0.8.22 H2S Scrubbers........................................................................................ 36 4.0.8.23 Produced Fluids..................................................................................... 37 4.0.8.23.1 General Fluids.......................................................................................... 37 4.0.8.23.2 Fluid Properties and Characteristics........................................................... 37 4.0.8.23.3 Oils ................................................................................................... 37 4.0.8.23.4 Gas ................................................................................................... 37 4.0.8.23.5 Water ................................................................................................... 37 4.0.8.23.6 Kill Fluids, Frac Fluids, Acids and Solvents ................................................ 38 4.0.8.24 Tanks ................................................................................................... 38 4.0.8.24.1 Rig Tanks ................................................................................................ 38

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WELL TESTING AND FLUID HANDLING 4.0.8.24.2 Atmospheric Tanks (64m3 style)................................................................ 38 4.0.8.24.3 Certified Pressurized Flowback Tanks ........................................................ 39 4.0.8.24.4 Non-certified Pressurized Storage Tanks .................................................... 39 4.0.8.24.5 Other Tanks............................................................................................. 39 4.0.8.25 Location of Tanks................................................................................... 40 4.0.8.25.1 Location of Rig Tanks ............................................................................... 40 4.0.8.25.2 Location of Atmospheric Tanks (64m3 style)................................................ 40 4.0.8.25.3 Location of Certified Pressurized Flowback Tanks ....................................... 40 4.0.8.25.4 Location of Non-certified Pressurized Storage Tanks.................................... 40 4.0.8.26 Air Entrainment and Purging ................................................................. 41 4.0.8.26.1 General ................................................................................................... 41 4.0.8.26.2 Prevention of Air Entrainment in Storage Tanks .......................................... 41 4.0.8.26.3 Purging the Well String and Wellhead ........................................................ 42 4.0.8.26.4 Purge Mediums for Purging Surface Equipment ........................................... 42 4.0.8.26.5 Pre-Purging Procedures and Checks.......................................................... 42 4.0.8.26.6 Purge Vapor Measurement ........................................................................ 43 4.0.8.26.7 Purge Amounts ........................................................................................ 43 4.0.8.26.8 Purging With Wellhead Gas (Sweet or Low Concentration of H2S)................. 43 4.0.8.26.9 Purging Sequence.................................................................................... 43 4.0.8.26.10 Ending The Purge..................................................................................... 44 4.0.8.26.11 Intermediate Purging................................................................................. 44 4.0.8.27 Opening A Well With Air In The Flowstring ........................................... 44 4.1 DRILL STEM TESTING .................................................................................. 46 4.1.1 Scope ................................................................................................... 46 4.1.2 Planning A Drill Stem Test ..................................................................... 46 4.1.2.1 Drill Stem Test Plan............................................................................... 46 4.1.2.2 Lithological and Reservoir Information................................................. 46 4.1.2.3 Qualifications......................................................................................... 46 4.1.3 On-Site Pre-Test Guidelines................................................................... 47 4.1.3.1 Pre-test Safety Meeting.......................................................................... 47 4.1.3.2 Pre-Test Inspection ................................................................................ 47 4.1.3.3 Pre-test Training .................................................................................... 48 4.1.4 Drill Stem Testing Guidelines................................................................ 48 4.1.4.1 DST Tool Retrieval During Daylight ....................................................... 48 4.1.4.2 DST Tool Retrieval During Darkness ...................................................... 49 4.1.4.3 Annulus Fluid Level ............................................................................... 49 4.1.4.4 Workers On Rig Floor............................................................................. 49 4.1.4.5 Test Line ................................................................................................ 49 4.1.4.6 Floor Manifold........................................................................................ 50 4.1.4.7 Swivel Joints and Flexible Pipe ............................................................ 50 4.1.4.8 Fire Prevention ...................................................................................... 50 4.1.4.9 Pipe Tally............................................................................................... 50 4.1.4.10 Flow Checks........................................................................................... 50 4.1.5 Sour Drill Stem Test Guidelines............................................................. 51 4.1.5.1 Safety Guidelines................................................................................... 51 4.1.5.2 Sour Drill Stem Testing Equipment........................................................ 51 4.1.5.3 Corrosion Inhibition While Sour Drill Stem Testing ............................... 52 4.1.5.4 Limitations of Sour Drill Stem Testing ................................................... 52 4.1.5.5 Sour Hydrocarbon Recovery .................................................................. 52 4.1.5.6 Neutralizing H2S During Trip Out of Hole ............................................... 52 Appendix I Recommended Drill Stem Testing Services Inspection Checklist ......... 53

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WELL TESTING AND FLUID HANDLING 4.2 WELL TESTING ............................................................................................ 55 4.2.1. Scope ................................................................................................... 55 4.2.2 Wellhead Control.................................................................................. 55 4.2.2.1 General .................................................................................................. 55 4.2.2.2 Standard ................................................................................................ 55 4.2.2.3 Wellhead Minimum Requirements......................................................... 56 4.2.2.3.1 Pressure Rating ....................................................................................... 56 4.2.2.3.2 Master Valves .......................................................................................... 56 4.2.2.3.3 Flow Tee and Flow Cross .......................................................................... 56 4.2.2.3.4 Wing Valve .............................................................................................. 57 4.2.2.3.5 Pressure Testing ...................................................................................... 57 4.2.2.3.6 Temporary Wellheads ............................................................................... 57 4.2.3 Well Testing Equipment Capacities And Pressure Ratings..................... 58 4.2.3.1 Capacities.............................................................................................. 58 4.2.3.1.1 General ................................................................................................... 58 4.2.3.1.2 Separator Systems................................................................................... 58 4.2.3.1.3 Heat Requirements................................................................................... 59 4.2.3.1.4 Liquid Storage.......................................................................................... 59 4.2.3.2 Pressure Ratings.................................................................................... 59 4.2.3.2.1 Pressure Vessels..................................................................................... 59 4.2.3.2.2 Pressure Piping........................................................................................ 59 4.2.3.2.3 Flanges ................................................................................................... 60 4.2.3.2.4 Other Connections.................................................................................... 60 4.2.3.2.5 Flexible Piping ......................................................................................... 60 4.2.3.2.6 Welding of Pipe and Fittings ...................................................................... 60 4.2.3.2.7 Pipe and Fitting Threading......................................................................... 60 4.2.4 H2s Service Equipment Requirements.................................................... 61 4.2.4.1 Metallic Materials................................................................................... 61 4.2.4.1.1 General ................................................................................................... 61 4.2.4.1.2 Welding of Carbon and Low Alloy Steels..................................................... 61 4.2.4.1.3 Exceptions .............................................................................................. 61 4.2.4.2 Elastomers ............................................................................................. 62 4.2.4.3 Internal Trims of Valves, Controllers, Etc. .............................................. 62 4.2.5 Well Testing Equipment Material Conformance..................................... 62 4.2.5.1 General .................................................................................................. 62 4.2.5.2 Pressure Vessels.................................................................................... 63 4.2.5.3 Pipe, Forging and Fittings...................................................................... 63 4.2.5.4 Valves, Controllers Meters, Etc............................................................... 63 4.2.5.5 Connections (Hammer Unions, Flanges, Etc.)......................................... 63 4.2.6 Equipment Inspections........................................................................... 63 4.2.6.1 General .................................................................................................. 63 4.2.6.2 Inspection Guidelines............................................................................ 63 4.2.7 Well Testing Equipment Spacing........................................................... 64 4.2.7.1 Equipment Spacing For Propane Tanks................................................. 65 4.2.7.2 Equipment Spacing For More Than One Certified Pressurized Tank ..... 65 4.2.7.3 Equipment Spacing For Non-Certified, Non-Registered Vessels Or Pressure Tanks........................................................................... 65 4.2.8 Pre-Test Equipment Check And Pressure Test ....................................... 66 4.2.8.1 Pressure Testing in Daylight/Darkness ................................................... 66 4.2.8.2 Wellhead to Choke ................................................................................ 66 4.2.8.3 Pressure Testing on Critical Sour Wells................................................. 67

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WELL TESTING AND FLUID HANDLING 4.2.8.4 4.2.8.5 4.2.9 4.2.9.1 4.2.9.2 4.2.9.3 4.2.9.4 4.2.10 4.2.10.1

Downstream of Choke ............................................................................ 67 Open Ended Piping and Production Tanks ............................................ 67 Operational Safety................................................................................. 67 Start Up at Night..................................................................................... 67 General Start Up Procedure................................................................... 67 Test Performance................................................................................... 68 Shut In And Post-Test Procedures.......................................................... 68 Well Testing Workers............................................................................. 69 Recommended Minimum Well Testing Workers on a Wellsite During Testing Operations..................................................................... 69 4.2.10.2 One Qualified Well Testing Worker Per Shift......................................... 69 4.2.10.3 Two Qualified Well Testing Workers Per Shift....................................... 70 4.2.10.4 Three Qualified Well Testing Workers Per Shift .................................... 71 4.2.10.5 Minimum Well Testing Worker Qualifications........................................ 71 Appendix II Lease Layout Schematics..................................................................... 73 Appendix II - Production Testing Services Inspection Checklist............................... 80 Appendix IV - Logic Chart........................................................................................ 85 4.3 OTHER FLOWBACKS.................................................................................... 86 4.3.1 Scope ................................................................................................... 86 4.3.2 Flowing, Pumping Or Circulating A Well To An Open Tank System ...... 86 4.3.3 Wellhead Control................................................................................... 88 4.3.4 Location Of The Rig Pump..................................................................... 88 4.3.5 Procedures............................................................................................. 88 4.3.5.1 Well Killing Operations.......................................................................... 88 4.3.5.2 Coiled Tubing Unit (CTU) Operations Using Air ...................................... 89 4.3.5.3 Operations at Night ................................................................................ 89 4.3.5.4 Monitoring and Supervision of Open System Rig Tank.......................... 90 4.3.5.5 Swabbing............................................................................................... 90 4.3.5.6 Control of Potential Ignition Sources..................................................... 91 4.3.5.7 Safety Checklists.................................................................................... 91 4.3.6 Well Site Workers.................................................................................. 91 4.3.6.1 Minimum Workers and Training Requirements...................................... 91 4.4 LOADING, UNLOADING AND TRANSPORTATION OF FLUIDS........................ 93 4.4.1 Scope ................................................................................................... 93 4.4.2 Fluid Hauling Company Procedures...................................................... 93 4.4.3 Fluid Charactaristics .............................................................................. 94 4.4.4 Loading, Unloading and Transportation Practices................................. 94 4.4.4.1 Closed Systems...................................................................................... 94 4.4.4.2 Tank Truck Loading and Unloading - Temporary Production Testing Operations – Sweet and Sour Fluids.......................................... 95 4.4.4.2.1 Using Atmospheric or Pressure Certified Tank Trucks.................................. 95 4.4.4.2.2 Venting Tank Trucks to Flare Stacks.......................................................... 97 4.4.4.3 Permanent Production Facilities – Sweet or Sour Fluids....................... 97 4.4.4.4 Transportation – Sour Fluids.................................................................. 98 4.4.5 Fluid Hauling Company Worker Qualifications...................................... 98 4.4.6 Tank Truck Requirements to Transport Hydrocarbon Fluids Containing Hydrogen Sulphide (H2s) ............................................................ 99 4.4.6.1 Transporting Fluid With 88 Ppm Hydrogen Sulphide Content or Less:... 99 (Not TDG Sub-Class 6.1 (I))....................................................................... 99 4.4.6.2 Transporting Fluid With More Than 88 Ppm Hydrogen Sulphide ........... 99

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WELL TESTING AND FLUID HANDLING 4.4.6.3 4.5 4.5.1 4.5.2

Hydrocarbon Transportation: Class & Packing Group (Boiling Point, Flash Point & Vapor Pressure)............................................................100 KEY WORDS AND PHRASES INDEX .............................................................101 Scope ..................................................................................................101 Key Words And Phrases Index..............................................................101

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4.0

ACKNOWLEDGEMENTS Acknowledgments for participation on, or submissions to, the steering committee preparing these revisions and updates and thank you to their employers for providing the time to work on this project. Lou Doiron, Central Production Testing Ltd. Robert Knowles – Angie Vogt, Norward Energy Services Ltd. Jerry Penner, Computest Oilfield Services Inc. Andy Saboe – Tim Gibbs, Alpine Oil Services Verleen Barry, Alberta Occupational Health and Safety Dwaine Ferguson, Wabash Manufacturing Ltd. Dave Meston - Dennis Saboe, AmGas Scrubbers Ltd. Chris Jackson, AEC West Ltd. Dave Krezanoski – Len Barteaux, British Columbia Oil and Gas Commission Barry Holland, Workers Compensation Board of British Columbia Bob Ross, Saskatchewan Labour, Occupational Health & Safety Division Larry Knight, Alberta Transport, Dangerous Goods Department Russ Nelson, Shell Canada Limited Doug Ashford, PanCanadian Petroleum Limited Art Congdon, Petro Canada Craig Popoff, Canadian Hunter Exploration Ltd. Ron Rowbotham, Roll’n Oilfield Services Ltd. Don Pack – Lonnie Campbell, Drive Well Servicing Ltd. Gord Dunn, Alberta Energy and Utilities Board Rick Meyers, Canadian Natural Resources Limited Jim Peta, Anderson Exploration Ltd. Craig Goodall, Talisman Energy Ltd. Jack Thacker - Ron Chapman, Husky Oil Operations Limited Rick Hanson - Bonus Resource Services Corp. Lawrence Fobes - Summit Energy Services Inc.

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4.0.1

FOREWARD In 1988 a Well Testing and Fluid Handling Subcommittee (WTFHSC) consisting of representatives from CAODC, CAPP, PSAC, Alberta OH&S and the Alberta ERCB was formed. Under the auspices of the Drilling and Completion Committee (DACC), the WTFHSC mandate was to investigate and develop minimum recommended practices respecting equipment, procedures and workers for the safe testing of wells and handling of fluids. The Recommended Practice (ARP) documents were developed during well testing and fluids handling operations at wells in Alberta; and were fully supported by the Alberta ERCB and Alberta OH&S. In 1999, the scope and breath of recommended practices encompasses many more issues, companies, associations and governments. The reference to Alberta in the title of these practices is changed to “Industry” (IRP – Industry Recommended Practice) to better reflect the broader scope. Where industry has grown to other regions of Western Canada, these IRP’s continue to assist companies in their daily operations,. These IRP’s are intended to follow the user to any site, anywhere in the world, as a minimum operating practice. INDUSTRY RECOMMENDED PRACTICE VOLUME 4 – Well Testing and Fluid Handling consists of five (5) components; 4.0 4.1 4.2 4.3 4.4

Scope, Contents, Definitions, Common Terms of Reference and Common IRP’s for all Operations Covered in this Volume Drill Stem Testing Well Testing Other Flowbacks Loading, Unloading and Transportation of Fluids

The process of revisions and upgrades in this IRP was steered by the WELL TESTING COMMITTEE of the PETROLEUM SERVICES ASSOCIATION of CANADA (PSAC) under the auspices of DACC. Future revisions will be prompted by the Canadian Petroleum Safety Council (PSC). DACC, Drilling and Completions Committee is a standard industry committee which oversees the development and revisions of industry standards. The DACC Committee has representation from the Canadian Association of Oilwell Drilling Contractors (CAODC), Canadian Association of Petroleum Producers (CAPP), Alberta Energy Utilities Board (AEUB), Petroleum Services Association of Canada (PSAC) and the Petroleum Safety Council (PSC) representing other industry and government interests across Canada.

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WELL TESTING AND FLUID HANDLING While every effort has been made to ensure the accuracy and reliability of the data contained in the IRP’s, and to avoid errors and omissions, the Committee work groups and individual members make no representation, warranty or guarantee in connection with the publication of the contents of any IRP recommendation, and hereby disclaim liability or responsibility for loss or damage resulting from the use of the IRP’s, or for any violation of any statutory or regulatory requirements this IRP may have not referenced or overlooked. IRP’s are viewed as highly desirable features of any well evaluation program but do not take precedence over legislated requirements in the jurisdiction you are working. Local regulatory agencies may have adopted these IRP’s, in whole or in part, as a guiding principle for their role in the industry. Regulatory agencies who have endorsed these practices will be referred to in the documentation or through subsequent communiqués.

4.0.2

SCOPE The purpose of this series of Industry Recommended Practices (IRP’s) is to enhance safety during well testing and fluid handling operations of gas and oil wells. 4.1 Drill Stem Testing contains recommended practices for DST operations including: test planning, as well as pre-test, post-test, and sour testing guidelines. 4.2 Well Testing details recommended practices for Well Testing operations, including: equipment design and operation, worker requirements and qualifications, purging and pressure testing, operational safety, and safety equipment. 4.3 Other Flowbacks addresses recommended practices for service rig operations involving the flowback of fluids from the well. Matters addressed include: produced fluids, venting, well control, equipment, procedures, and wellsite workers. 4.4 Loading, unloading and transportation of fluids provides recommended procedures for the safe transfer of fluids from temporary and permanent production facility tanks to trucks. The procedures emphasize sour fluids and high vapour pressure hydrocarbon mixtures. The IRP also addresses transportation. 4.5 This index helps the reader locate key words and phrases used in well testing and fluid handling.

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WELL TESTING AND FLUID HANDLING The practices described in the IRP’s should be considered in conjunction with other industry recommended practices, individual operator’s well testing and fluid handling practices and site specific considerations. It is recognized that other procedures and practices as well as new technological developments may be equally effective in promoting safety and efficiency.

4.0.3

INTRODUCTION An integral part of the exploration and development of oil and gas resources is reservoir evaluation. Evaluation methods with the greatest inherent environmental and safety concerns are those which remove reservoir fluids by means of drill stem testing, well testing or any other methods of flowback. The avoidance of developing a combustible hydrocarbon gas/air mixture, and the safe handling of highly volatile reservoir or stimulation fluids, and/or corrosive or toxic fluids are of concern when evaluating a well. The environmental, safety and health risks associated with well testing and fluid handling can be minimized by properly trained workers implementing prudent procedures and using properly designed equipment.

4.0.4

IRP REVISIONS The current editions of reference specifications, standards and recommended practices were used when the Well Testing and Fluid Handling IRP’s were published. Revisions in these documents may result in a need to periodically revise the IRP’s. In addition, periodic updating of the IRP’s will be necessary as new equipment and procedures are developed. Revisions can be recommended to the Drilling and Completions Committee (DACC) through the Canadian Petroleum Safety Council (PSC). A regular timed review every 5 years is recommended by the PSAC Well Testing Committee with provision for a review at anytime should industry or technology change in a significant manner that would necessitate a revision to these IRP's.

4.0.5

REFERENCES

4.0.5.1

Alberta Heavy Oil and Oil Sands Practices Steering Committee ARP 3.2, Well Servicing, 1991, PITS, Calgary. ARP 3.3, Production Equipment and Procedures, 1991, PITS, Calgary.

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4.0.5.2

American Petroleum Institute (API) API, Recommended Practices for Drill Stem Design and Operating Limits, Thirteenth Edition, April 1, 1989, RP7G, Dallas, Texas API, Recommended Practices for Occupational Safety and Health for Oil and Gas Well Drilling and Servicing Operations First Edition, January, 1981, RP54, Dallas, Texas. API, Specification for Wellhead and Christmas Tree Equipment, Spec. 6A Edition, Dallas, Texas

4.0.5.3

American Society Of Mechanical Engineers (ASME) ASME, Code for Pressure Piping, B31, Chemical and Petroleum Refinery Piping, ASME B31.3, 1990 Edition, 345 East 47th Street, New York, N.Y. 10017. ASME, B16.5 Pipe Flanges and Flanged Fittings, 1988 Edition, 345 East 47th Street, New York, N.Y. 10017. ASME, Boiler & Pressure Vessel Code, Section VIII, Div I, 345 East 47th Street, New York, N.Y. 10017.

4.0.5.4

American Society Of Testing And Materials (ASTM) ASTM, Standard Test Method for Vapour Pressure of Petroleum Products (Reid Method), Philadelphia, PA. ASTM, D56-79: Standard Test Method for Flash Point by Tag Closed Tester, Philadelphia, PA. ASTM, D93-80: Standard Test Method for Flash Point by Penski-Martens Closed Tester, Philadelphia, P.A. ASTM, D3278-82: Standard Test Method for Flash Point of Liquids by Setaflash Closed Tester, Philadelphia, P.A.

4.0.5.5

Canadian Association of Petroleum Producers CAPP Publication #1994-0002 Guideline for Prevention and Safe Handling of Hydrates (1994). CAPP Publication #1999-0002 Occupational Health and Safety of Light Hydrocarbons. CAPP Publication #1999-0005 Consumer Guideline for the Selection of Fire Resistant Workwear for Protection Against Hydrocarbon Flash Fires. CAPP Publication #1999-0014 Recommended Practices for Flaring of Associated and Solution Gas at Oil Production Facilities. CAPP Publication #1999-0015 CAPP Safety Guideline for Ground Disturbance in the Vicinity of Underground Facilities.

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4.0.5.6

Canadian Petroleum Association (CPA) CPA, 1987 Tank Vapour Flaring Committee Report Recommendations Surrounding Tank Vapour Flaring During Sour Well Testing, Calgary, Alberta. CPA, DRILL STEM TESTING SAFETY GUIDELINES 1986, Calgary, Alberta.

4.0.5.7

Canadian Standards Association (CSA) CSA, Industrial Protective Headwear, Z94.1, Rexdale, Ontario. CSA, Hearing Protectors, Z94.2, Rexdale, Ontario. CSA, Industrial Eye & Face Protectors, Z-94.3, Rexdale, Ontario. CSA, Protective Footwear, Z195, Rexdale, Ontario. CSA, B620-1987: Highway Tanks and Portable Tanks for the Transportation of Dangerous Goods, Rexdale, Ontario. CSA, B621-1987: Selection and Use of Highway Tanks, Portable Tanks, Cargo Compartments and Containers for the Transportation of Dangerous Goods, Classes 3, 4, 5, 6, and 8 in Bulk by Road, Rexdale, Ontario. CSA, B622-1987: Selection and Use of Highway Tanks, Multi-unit Tank Cars and Portable Tanks for the Transportation of Dangerous Goods, Class 2, by Road, Rexdale, Ontario. CSA, B620-98: Highway Tanks and Portable Tanks for the Transportation of Dangerous Goods, Rexdale, Ontario.. CSA, B621-98: Selection and Use of Highway Tanks, Portable Tanks, Cargo Compartments and Containers for the Transportation of Dangerous Goods, Classes 3, 4, 5, 6.1, 8 and 9, Rexdale, Ontario.. CSA, B622-98: Selection and Use of Highway Tanks, Multi-unit Tank Cars and Portable Tanks for the Transportation of Dangerous Goods, Class 2, Rexdale, Ontario..

4.0.5.8

Drilling And Completions Committee (DACC) Industry Recommended Practices Volume II Completing And Servicing Sour Wells DACC, ARP 2.5 Fluids and Circulating Systems, PITS, Calgary, Alberta. DACC, ARP 2.10 Quality Programs for Pressure Containing Equipment, PITS, Calgary, Alberta. DACC, ARP 2.15 Well Site Worker Training and Experience, PITS, Calgary, Alberta.

4.0.5.9

Alberta Energy And Utilities Board (AEUB) ERCB, Guide G-37 Service Rig Inspection Manual, 1988, ERCB, Calgary, Alberta. ERCB, Informational Letter IL 91-2 Sour Gas Flaring Requirements and Change to Regulations.

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WELL TESTING AND FLUID HANDLING 4.0.5.10

Government Of Alberta, Alberta Occupational Health And Safety (AOH&S) AOH&S, Alberta Occupational Health and Safety Act and Regulations, Edmonton, Alberta. AOH&S, Well Testing – Minimum Guidelines for Enhanced Field Operations, June 1990, Edmonton, Alberta. AOH&S, Safety Codes Act. AOH&S, Boiler & Pressure Vessel Exemption Order. AOH&S, Transportation of Dangerous Goods Control Act & Regulation.

4.0.5.11

Government of Canada Transportation of Dangerous Good Act and Regulations WHMIS National Safety Code

4.0.5.12

National Association of Corrosion Engineers (NACE) NACE, MR0175 Sulphide Stress Cracking Resistant Metallic Materials for Oilfield Equipment, Houston, Texas.

4.0.6

CONTENTS INDEX

4.0.7

DEFINITIONS

4.0.7.1

Adequate Lighting Adequate lighting exists when the site is illuminated sufficiently to ensure that the worker is able to perform routine duties safely. The visibility must be such that the worker will be able to exit the worksite to a secure area in the event of an emergency. Flashlights, rig lights, and vehicle lights can be considered as emergency back-up lighting. References/Links Workers Compensation Board of British Columbia Saskatchewan Dept of Labour, Occupational Health and Safety

Note:

Regulations in the Provinces of British Columbia and Saskatchewan define lighting with specific measurement criteria. This should be referred to when operating in these provinces.

Note:

Consideration must be given to additional lighting on complex operations.

4.0.7.2

Bleed-off Where pressure is present on the well and requires depressuring before work can commence.

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4.0.7.3

Caution Caution must be exercised on wells known to contain lower levels of H2S and/or have harmful or toxic substances, and/or have severe abrasives (e.g. frac sand) and/or have other unusual hazards. The term "Caution" does not categorize a well outside of Sweet or Sour. It is intended to alert Owners, employers and workers to dangers that may exceed those of routine Sweet Wells and wells with minimal H2S concentration where prescriptive equipment requirements are not provided.

4.0.7.4

Certified Pressurized Flowback Tank A pressurized vessel which has been constructed following a program of quality control, designed for the application, and is registered with the provincial agency that applies a stamp of certification on the vessel nameplate. All vessels must have a CRN (Canadian Registration Number) registered in all provinces of intended use.

4.0.7.5

Closed System A closed system refers to a handling system in which fluids are scrubbed, gas is flared at a stack or vented to atmosphere through an H2S scrubber, in a controlled manner, and fluids are contained.

4.0.7.6

Coiled Tubing Unit Operations (CTU) Coiled tubing units are commonly used in "other flowbacks" to recover wellbore effluent. Nitrogen, carbon dioxide or air is used to move and lift proppant, produced sand or stimulation fluids such as acid, chemicals or hydraulic fracture treatment fluids from the wellbore. Coiled tubing unit operations may also be undertaken to evaluate well production capability.

4.0.7.7

Confined Space -

4.0.7.8

Is enclosed or partially enclosed. Has limited or restricted means for entry/exit. Is not designed or intended for continuous human occupancy. Is or may become partially hazardous to a worker entering OR that may complicate the provision of first aid, evacuation, rescue or other emergency response services.

Drilling Company An individual or company that enters into a contract with an owner of a wellsite to drill for oil and gas.

4.0.7.9

Drill Stem Test A method of determining the producing potential of a formation. This is done by removing the hydrostatic pressure of the drilling fluid column and allowing formation fluids and/or gas to flow into an evacuated or partially evacuated drill string or production string. This allows the formation pressures to be monitored and measured to calculate flow and depletion rates. A Drill StemTester represents the company responsible for the down hole and surface equipment

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WELL TESTING AND FLUID HANDLING used in identifying the content and production capability of the formations to be tested. 4.0.7.10 Employer Means a person, firm, association or body that has, in connection with the operation of a place of employment, one or more workers in the service of the person, firm, association or body. 4.0.7.11

Enclosed Environment A building or structure with limited or restricted means for entry/exit and minimal ventilation that will not allow rapid movement of hazardous vapors.

4.0.7.12

ESD Acronym for Emergency Shutdown system (valve). It is a pneumatically operated, high-pressure valve installed on the wellhead with remote shutdowns. Its purpose is to provide a means to remotely shut in the well in an emergency. In Alberta, an ESD is required on wells to be flowed having a surface pressure greater than 1379 kPa and an H2S content greater than 1%.

4.0.7.13

Flowback Where pressure on a well is bled off and the well continues to flow, and is allowed to flow to establish a rate of gas and fluid from the well.

4.0.7.14

High Vapor Pressure Hydrocarbons Hydrocarbon mixtures with a Reid vapor pressure greater than 14 kPa or an API gravity greater than 50° are considered to be high vapor pressure hydrocarbons.

Note:

Reid Vapor Pressure is determined in a laboratory test. API gravity can be readily measured in the field. C1-C7 content can also be indicative of a fluid’s flammability. Flammability increases with increasing C1-C7 content. Fluid analyses, if available should be reviewed. Fluid and ambient temperatures should be considered.

4.0.7.15

Inline Test An inline test is "closed" when all well effluents measured at the test separator are diverted to the pipeline.

4.0.7.16

Mud Can A device used to contain fluids and direct them away from the drill pipe when breaking connections.

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4.0.7.17

Non-certified Pressurized Storage tank or Vessel A vessel that does not require certification for use in pressure applications. The vessel must have some form of pressure relief valve (PSV). If the tank is to be used as the primary vessel, the tank must have been constucted under a quality control program. Construction, design and material specification data must be available when requested by the well owner. Government departments may also request this data.

Caution:

The vessel must be designed for its intended use. Example: In Alberta a vessel operated below 103.4 kPa (15 psi) working pressure does not require provincial certification from the Alberta Boilers Safety Association (ABSA) but is required to be constructed under a quality control program in this IRP.

4.0.7.18

Occupational Exposure Limits - Worker Safety Consideration The Occupational Exposure Limit (OEL of H2S is, 8 hour OEL: 10 ppm In most cases when well testing, workers are in open-air environments and work shifts longer than 8 hours. Therefore planning consideration must review situations when workers are exposed to short-term levels greater than 10ppm and longer-term levels less than 10ppm. The Ceiling Limits vary through the various regulatory authorities. Most common is a Ceiling Limit of 10ppm and 20 ppm. References/Links Alberta Occupational Health and Safety Act – Chemical Hazards Saskatchewan Occupational Health and Safety Act Workers Compensation Board of British Columbia – OHS & Regulation

4.0.7.19

Open System An open system refers to a handling system, such as a rig tank, in which any gas vapors produced from fluids are vented to atmosphere in an uncontrolled manner. This type of system requires constant monitoring to ensure transient vapors/gas are maintained below 20% of LEL and 10ppm H2S.

4.0.7.20

Other Flowbacks Other flowbacks refers to operations, other than production testing and drill stem testing, in which gas and/or fluids are flowed or induced to flow from the wellbore. This includes well killing operations and the recovery of well stimulation fluids and solids by flowing, pumping, swabbing or by the circulation of fluids with coiled tubing. Refer to IRP’s 4.1, Drill Stem Testing and IRP 4.2, Well Testing for information specific to testing.

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4.0.7.21

Owner A person, partnership, company or group of persons who, under contract and agreement of ownership, direct the activities of one or more employers involved at a worksite.

4.0.7.22

PPE Acronym for personal protective equipment. It is equipment designed and used to protect workers.

4.0.7.23

Positive Pressure Positive pressure refers to a pressure greater than 0 kPa gauge.

4.0.7.24

Pressurized Truck Tank A pressurized truck tank must comply with all the CSA B620 requirements as determined by CSA B621. If the maximum allowable working pressure (MAWP) is greater than 101.3 kPa (15 psi) then ABSA/ASME certification is also required. The MAWP is specified on the nameplate of most oilfield production equipment such as all transport and pressure vessel equipment.

4.0.7.25

Purge Where a vessel, container or piping system is evacuated of its gas and/or fluid contents and replaced with another gas and/or fluid. The general purpose of purging is to remove explosive and/or flammable fluids and gases from a closed piping system prior to opening the system to atmosphere or prior to entry of the system by workers. The practice of purging usually entails replacing the explosive/flammable contents with a product that is non-explosive/flammable or to create an atmosphere with an acceptable LEL (Lower Explosive Limit) and UEL. (Upper Explosive Limit) for workers. Purging is also used to aid the removal hazardous gases and fluids from vessels and piping systems prior to shipment of equipment or transportation of fluids.

4.0.7.26

Qualified Well Testing Person An individual who has had a minimum of three months previous experience with a service company or well owner and understands the concept of gas and liquid separation using pressure equipment and flaring. Without this prior experience, the individual is considered “in training”. The individual must be able to provide documented evidence, when requested, of this experience. The individual must have all certifications required by provincial regulatory agencies and/or this IRP. Section 4.2.10 of this IRP identifies the qualifications required for a well testing worker to handle various levels of responsibility.

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4.0.7.27

SABA - SCBA SABA: acronym for Supplied Air Breathing Apparatus. It consists of a small air cylinder (less than 5 minutes of breathing air) and air mask intended to be carried on the hip of a worker with the ability to connect, by hose, to numerous larger air cylinders. This type of configuration is used for extended work periods where a worker is in an H2S environment. SCBA: acronym for Self-contained Breathing Apparatus It consists of an air cylinder and mask intended to be carried on the back of the worker and has (+) (-) 30 minutes of breathing air contained in the cylinder. This device is used for short work periods where a worker is in an H2S environment.

4.0.7.28

Safety Service Company A company that provides equipment, workers, training and neutralising chemicals to reduce the risk to on-site workers and equipment during various sour well operations.

4.0.7.29

Safety Standby Method Where a person outside of the hazardous area monitors the work of persons inside the hazardous area, with no other purpose than to monitor air supplies and implement rescue procedures when necessary.

4.0.7.30

Service Company Means a person, corporation or association who is contracted to supply, sell, offer or expose for sale, lease, distribute or install a product or service to another company, usually the owner of the worksite.

4.0.7.31

SITHP Acronym for Shut In Tubing Head Pressure. It is the pressure at surface on the tubing in the well.

4.0.7.32

Stimulations Stimulations are operations designed to improve well production capability or, in the case of injection or disposal wells, to improve the ability of a well to accept fluid. These operations may include the use of hydrocarbon and water based fracturing fluids, acids, various chemicals and proppants.

4.0.7.33

Swabbing Swabbing is an operation conducted to reduce the hydrostatic pressure in the wellbore to initiate flow from a formation. Swabbing operations utilize a lubricator.

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4.0.7.34

Swivel Joint A series of short steel pipe sections that are joined by swivel couplings. The unit functions as a flexible flow line that provides a flow path between the control head and the floor manifold.

4.0.7.35

Test Line A flow line from the drill stem tester's floor manifold to move fluid and/or gas to flare or storage.

4.0.7.36

Test Plug A valve attached to the top of each stand of pipe being pulled from the hole to prevent flow up the drill pipe while tripping.

4.0.7.37

Well Killing Operations Well killing operations are operations in which well effluent is circulated from the wellbore using a fluid of sufficient density to prevent further influx of reservoir fluids. The process is continued until the well is dead.

4.0.7.38

Well Testing Well Testing is an operation where a company supplies equipment and the continuous presence of qualified test workers for the purpose of measurement through production equipment. Such operations include, but are not limited to: Flowing a well to production equipment or tank. Flow measurement with chokes, flow provers or other meters. Initiating flow by swabbing, coiled tubing or any such artificial lift method. Flowing a well while drilling operations are in progress, known as Underbalanced Drilling. References/Links IRP 4.2 Well Testing and Fluid Handling IRP 6.0 Underbalanced Drilling (under development 1999) Alberta Energy and Utilities Board Interim Directive 94-3

4.0.7.39

Worker Means a person who is engaged in an occupation in the service of an employer.

4.0.7.40

Underbalanced Drilling Entails allowing a well to flow oil, gas and formation fluids to surface as it is being drilled as opposed to conventional or overbalanced drilling where one of the prime considerations is in preventing hydrocarbons from flowing during the drilling process. References/Links IRP 6.0 Underbalanced Drilling for Critical Sour Wells Alberta Energy and Utilities Board Interim Directive ID94-3

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4.0.8

COMMON TERMS OF REFERENCE AND IRP’S FOR ALL OPERATIONS IN THIS VOLUME

4.0.8.1

Responsibilities of Owners and Service Contractors

IRP

The wellsite Owner is responsible for all activities on a lease. The safety of on-site workers and environmental protection take precedence over well testing data requirements. Owners shall maintain general health and safety at the well site by coordinating all activities and ensuring proper equipment, materials and workers are provided to accomplish the program and to satisfy all applicable regulatory requirements.

IRP

The wellsite owner shall provide the following breathing equipment as a minimum:

Section 4.0

-

On all wells, regardless of designation, two(2) Self-contained Breathing Apparatus (SCABA) must be on location at all times. (In British Columbia , 4 must be present)

-

When well testing wells where the H2S concentration is greater than 100 ppm, the Owner must provide supplied air breathing apparatus (SABA’s) in addition to the self-contained breathing apparatus (SCBA). As a minimum this package must contain an adequate air supply system complete with air cylinders, manifold, work lines and egress packs (SABA’s) and a minimum of two (2) back packs (SCBA’s).

-

On simple well-servicing operations (such as rod jobs, tubing changes, bleed-offs, plug retrieval, abandonments, swab cleanouts) where the H2S concentration is greater than 100 ppm and where the venting of gas to atmosphere is minimal and the bleed-off period is short in duration and where more than two (2) workers are present at the same time, an additional two (2) back packs would be adequate instead of a supplied air system. (This does not apply to well testing.) Therefore a minimum of four (4) back packs are required on the wellsite. Two (2) of the back packs must be designated for emergency use only. The other packs are for use by workers where breathing equipment is necessary to complete operational tasks, protection for the workers on the site and nearby residents, from over-exposure to H2S, must be maintained when considering this option.

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-

Where workers are expected to work on a continued basis in enclosed environments, SABA’s must be supplied to meet the Occupational Exposure Limits (OEL of 10 ppm.

-

The air equipment be properly housed for use and transport.

Note:

In British Columbia ( WCB Regulation 23.5) requires owners to provide a program of quality assurance for the respiratory air and date of last air change. The program must be in writing.

Note:

In British Columbia ( WCB Regulation 5.54) the Service Contractor needs to have a respiratory protection program including education, training, fit testing, cleaning and maintenance, air change and air quality assurance.

IRP

Where an Owners representative is assigned to the site, the representative shall be present during all operations where gas will be vented from open tank systems. Where an Owner representative is not assigned to the site, the contractor assigned to flow the well to open tank systems must have a supervisor present during the operation.

IRP

Where the Owner does not have a site representative, the Owner shall ensure a gas detection meter is available to the site workers.

IRP

The Owners on-site representative shall have training and competence in the operation of an LEL meter. The Owners representative shall possess or ensure availability of an LEL meter on all sites where vapors are expected to be vented to atmosphere.

IRP

The Owner shall or instruct the Service Contracting company to: -

Provide signage ordering vehicles to stop at the lease entrance on all sites where gas is being vented to atmosphere

-

Ensure there are an adequate number of qualified workers on the wellsite at all times to conduct operations safely

-

Provide fluid hauling companies with shipping documents such as a waste manifest that describes the properties and potential hazards associated with fluids to be transported in appropriate TDG terms References/Links Transport Canada TDG Act, Sections 5, 6, 8 & 14. Transport Canada TDG Regs, Part 3. Transport Canada TDG Act, Section 40.

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WELL TESTING AND FLUID HANDLING -

Ensure fluid hauling workers are oriented to site-specific procedures

-

Ensure sour fluids are transported during normal hours of operations unless special arrangements and precautions have been made between the Owner and the truck operator. This may include standby workers, equipment and monitoring devices

-

Ensure appropriate safety equipment (i.e. H2S monitor, explosive mixture monitor and respiratory protective equipment) are available

-

Maintain a contingency plan including procedures for truck loading, unloading, and transportation-related spills.

IRP

The Owners representative is responsible for conducting an on-site prejob equipment inspection to ensure the equipment is operational and as ordered.

IRP

Owners shall prepare a program of operations. The program should include but not be limited to:

IRP

Section 4.0

-

The purpose of the operation

-

Relevant well data

-

Identify any potential hazards

-

Equipment requirements and layout having regard for pressures and flows expected

-

Environmental and safety considerations, relative to on-site workers and the public

-

Special procedures to be employed

-

Emergency contacts

-

Minimum worker requirements and qualifications

-

Test objectives

-

Test sequence in appropriate detail

-

Technical contact in case of unexpected program deviations

-

Emergency response plan, contacts and procedures

-

Shall ensure the program is available for viewing participating contractors prior to job commencement.

by

all

The Owner shall ensure that the owners representative on site is able to provide competent and effective supervision of the operations being carried out. The Owners representative shall have the following: -

First Aid Certificate

-

If well servicing, an appropriate blow-out prevention (BOP) certificate

-

If drilling, an appropriate blow-out prevention (BOP) certificate

-

H2S Training and Certification for sour wells ( > 10 ppm)

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Transportation of Dangerous Goods Certificate where hazardous materials will be shipped

-

WHMIS training

-

Complete awareness of IRP Volume 4.0 , Well Testing and Fluids Handling as they pertain to the operation being carried out and a full understanding of the hazards related to the physical properties of the fluid being handled, prior to conducting the operation

-

Shall make available and be competent in the operation of equipment used to detect hazardous or explosive mixtures

-

An understanding of section 8.110 of the AEUB Regulations when hydrocarbon mixtures with a Reid vapour pressure greater than 14 kPa or with an API gravity exceeding 50 degrees, are encountered.

4.0.8.2

Drilling Service Company Responsibilities

IRP

The Drilling Service Company shall ensure that all required rig workers are available during operation the workers are physically capable and have been properly trained to carry out their designated responsibilities. The Drilling Service Company shall ensure that the equipment and facilities it is contracted to supply are available during operation and it is designed for the parameters of the project. Pressure test certification, material inspections, and sour service specifications shall be made available when requested.

4.0.8.3

Drill Stem Testing Company Responsibilities

IRP

The Drill Stem Testing Company shall ensure that the workers it provides are available during the drill stem test, the workers are physically capable and have been properly trained to carry out their designated responsibilities during the drill stem test at the worksite. The Drill Stem Testing Company shall ensure that the equipment and facilities it is contracted to supply are available during the drill stem test, are in good working order and is designed for the parameters of the project. Pressure test certification, material inspections, and sour service specifications shall be made available when requested.

4.0.8.4

Safety Service Company Responsibilities

IRP

The Safety Service Company shall ensure that the workers it provides are available during operations, the workers are physically capable and have been properly trained to carry out their designated responsibilities. The Safety Service Company shall ensure that the equipment it is contracted to supply is available during the operation, is in good working order and is designed for the parameters of the project. The Safety Service Company must ensure proper equipment for respiratory protection, H2S gas detection, breathing-air supply, determining explosive limits, and neutralising chemicals is in sufficient quantities at the worksite. Consideration should be given to providing an LEL meter. The Safety Service Company must provide training of all workers on the worksite in the specific use of this equipment.

Section 4.0

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WELL TESTING AND FLUID HANDLING

4.0.8.5

Well Testing Company Responsibilities

IRP

The Well Testing Company shall ensure their employees are physically capable to carry out their designated responsibilities during the operation. Well Testing personnel must carry certificates of training with them. The Well Testing Company shall ensure the equipment and facilities it is contracted to supply are designed and suited for the application. Pressure test certification, material inspections, and sour service specifications shall be made available when requested.

4.0.8.6

Fluid Hauling Company Responsibilities

IRP

Fluid Hauling Companies shall ensure the workers it provides are available during the operations, the workers are physically capable to carry out their designated responsibilities and the workers carry certificates of training with them. The Fluid Hauling Company shall ensure that the equipment and facilities it is contracted to supply are available during the operation, are in good working order and are designed for the parameters of the project. Pressure test certification, material inspections, and sour service specifications shall be made available when requested.

4.0.8.7

Well Designation for Worker Safety in H2S Environments “Sweet” and “Sour” designations are used by industry and legislative bodies as a reference for administrative purposes. For technical purposes specific concentrations of Hydrogen Sulphide will dictate appropriate equipment requirements to conduct a task safely, maintaining the health and safety of the worker while ensuring the integrity of the equipment. The well designations of this IRP are centered on Hydrogen Sulphide (H2S) content, which through inhalation, is the most frequently encountered hazardous substance by well testing workers. There may be other substances as onerous for maintaining worker safety and must be considered when planning work programs. Provincial Occupational Health and Safety Acts define the exposure limits for numerous substances. Those documents should be referred to when substances other than hydrogen sulphide (H2S) are known to be present at the wellsite. The well designations in this IRP are designed for worker safety when working in Hydrogen Sulphide (H2S) environments.

4.0.8.7.1

Sweet Well 10 ppm Hydrogen Sulphide Content or less: Designated as SWEET A well with a hydrogen sulfide (H2S) content of 0.01 moles / kilomole (10 ppm) or less relative to worker safety is designated as SWEET. The hazards of Sweet Gas to the worker, from exposure or inhalation, are less than those imposed by sour gas and therefore require a minimum of two (2) Self Contained Breathing Apparatus (SCBA’s) on all wells to aid in protecting the worker. Other requirements are detailed throughout these IRP’s. Material

Section 4.0

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WELL TESTING AND FLUID HANDLING specifications relative to metallurgy for equipment used to flow wells containing zero H2S content are not as stringent as those required for wells containing H2S. References/Links IRP 4.2 NACE (National Association of Corrosion Engineers) ASME B31.3 4.0.8.7.2

Sour Well More than 10 ppm Hydrogen Sulphide Content: Designated as SOUR Any well with a hydrogen sulfide (H2S) concentration greater than 0.01 moles/ kilomole (10ppm) relative to worker safety is designated as SOUR. Sour Gas hazards relative to worker safety requires specific equipment to protect the worker. Prescriptive guidelines for the quantity and use of breathing equipment to protect the worker are outlined in this IRP and other Provincial regulations. Additionally, gas, containing H2S, is more corrosive to metals and thus, requires precautions when selecting equipment to perform well testing operations. Section 4.2.4 of this IRP provides guidelines relating to equipment selection for use in H2S environments. References/Links IRP 4.2 Provincial Occupation Health and Safety Acts Alberta Chemical Hazards Regulation Sections 2 & 9 NACE MR 01-75 LATEST EDITION ASME B31.3

4.0.8.7.3

Critical Sour Well Critical Sour Wells are defined by appropriate Provincial Regulatory Agencies. They generally include all the elements of a Sour Well plus an amplified concern for residents in close proximity to the wellsite along with environmental issues. In Alberta refer to AEUB ID 97-6.

4.0.8.8

Metallurgy considerations for H2S environments H2S effects the integrity of metals not designed for use in H2S environments. Other elements such as CO2 also have corrosive affects on metals. The requirement for special metallurgy in equipment is not related to a Sour designation of a well. It is related to H2S Partial Pressure and Sulphide Stress Cracking as defined by the National Association of Corrosion Engineers (NACE). References/Links Section 4.2.4 NACE MR 01-75 LATEST EDITION specifications

Section 4.0

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4.0.8.9

Gas Detection Monitoring for Explosive and Flammable Limits

IRP

The Owners site representative must be trained and competent in the use of gas detection meters. The site representative must possess or make available at the wellsite, a gas detection meter capable of measuring LEL.

IRP

Where the Owner does not have a site representative, the Owner shall ensure a gas detection meter is available to the site workers.

IRP

One person per shift must be trained and competent in the use of gas detection meters where gas vapors will be vented to atmosphere.

IRP

No worker shall enter the 50 meter “safety zone” around an open tank system where gas vapors have been vented to atmosphere until cleared to do so by the Owners site representative or the worker who is responsible for monitoring the area with a gas detection meter.

Note:

Refer to Section 4.3, Other Flowbacks, for more detail on the requirement of gas detection and flowing wells to open tank systems.

Introduction: Gas detectors have become an everyday part of equipment requirements on an oil and gas site. There must be accurate methods of detecting the absence or presence of various gases, so the workplace can be maintained safe and productive. Explosive or Flammability Limits: The term limits of flammability, or explosive limits, refers to the percentage by volume of a fuel in a fuel/air mixture which will burn. The flammable range spreads between the lower flammable limit and the upper flammable limit. Fuel /air mixtures outside the flammable range will not burn or explode. Flammable limits for some common flammable gases and vapors are listed below. Explosive limits (% by vol. in air) LEL Ammonia Butane Carbon monoxide Ethane Hydrogen Sulphide Ethyl Alcohol Methane Propane Toluene

Section 4.0

15.0 1.8 12.5 3.0 4.0 3.3 5.0 2.2 1.3

28.0 9.0 74.0 12.5 45.0 19.0 15.0 10.0 7.0

UEL

Flash point degrees Celsius Gas Gas Gas Gas Gas +13 Gas Gas +4

Vapor Density Air = 1.0 0.58 2.0 0.97 1.0 1.19 1.59 0.55 1.5 3.14

Ignition Temp. degrees Celsius 630 410 570 472 260 365 538 450 535

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WELL TESTING AND FLUID HANDLING A flammable gas is considered to be a gas that will burn when there is a concentration of oxygen in the air. Flammable mixtures cannot be ignited and continue to maintain a flame, unless the concentration of fuel is greater than the Lower Explosive Limit (LEL) and lower than the Upper Explosive Limit (UEL). A methane/air mixture must contain more than 5% methane by volume for the mixture to burn. If the mixture contains more than 15% methane by volume, it is considered to be too rich and will not burn. The concentration must be within the flammable range to maintain a fire. Oxygen: The normal concentration of oxygen in ambient air is 20.9%. Abnormal circumstances can cause this level to be increased or decreased. Oxygen deficiency refers to abnormally low oxygen levels that can be serious and is often an undetected risk to human life. Reduction of oxygen levels is usually caused by the consumption of oxygen by some chemical reaction or combustion within a confined area or by displacement by other gases. Oxygen enrichment refers to abnormally high concentrations of oxygen that can be dangerous because of its tendency to increase the flammability and explosiveness of materials and fuels. The leaking of compressed oxygen containers in confined areas usually causes enrichment. Flammable and Explosive Gases: Explosions occur when a flammable mixture of gas comes into contact with a heat source that exceeds the ignition temperature of the gas mixture. Not all concentrations of flammable gases will explode. The Lower Explosive Limit (LEL) determines the minimum concentration of the flammable gas in air that will burn. Concentrations below the LEL and above the Upper Explosive Limit (UEL) will not burn. Unfortunately, gas/air mixtures are seldom uniform so it is likely that if any amount of combustible gas is detected then at some point in the system or container, the concentration may be explosive. Flammable liquids normally have a low flash point. This refers to the temperature at which the liquid releases vapors at a rate sufficient to form an explosive mixture with air. Liquids with flash points below ambient temperature will immediately release dangerous concentrations of gas. Liquid leaks can be as hazardous as gas leaks. Vapor Density: When monitoring for the presence of gases or vapors, it is important to understand vapor density, which provides valuable clues as to where to locate gas sensors. Density is a characteristic of materials and is similar to weight. For gases and vapors, air is considered to be the standard reference and its density is set at 1.0. Gases and vapors lighter than air have densities less than 1.0 while those heavier than air have densities greater than 1.0. Assuming that air currents are negligible, it can be said that gases and vapors with densities less than 1.0, such as methane, will tend to rise from the point of escape and subsequently disperse into the atmosphere or accumulate in spaces under roof structures of buildings.

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WELL TESTING AND FLUID HANDLING Heavier-than-air gases such as propane and H2S tend to fall from the point of escape, perhaps to floor level where some mixing with air occurs thus creating pockets of mixtures, some explosive, others not. If there are sub-floor spaces such as drain channels, pipe and cableways and storage pits, then these heavier than air gases tend to accumulate there. A suitable source of ignition in such areas will surely result in explosion and fire. Ignition Temperature: Ignition temperature is the temperature that will cause a combustible mixture of gas vapor to explode or burst into flame. Various fuels mixed in a variety of concentrations can be explosive when ignited by the presence of a spark, flame or hot surface that exceeds the ignition temperature. Variables such as concentrations, pressure and temperature all have an affect on ignition temperature. Location of Gas Sensors: Location of the gas sensor is very important. In general, lighter than air gases requires the sensor to be positioned near the ceiling and heavier than air gases require sensors positioned at low levels or in pits or trenches. Some things to consider include: -

Hydrogen sulphide mixed with methane in a process stream may follow the same migration patterns as methane during a gas leak

-

Temperature, humidity, and air ventilation patterns

-

Mounting detectors close to the entrance of buildings, on the outside wall.

Gas Detectors Measuring Percent LEL: Some gas detectors have two scales; the 100% scale measuring the % of a flammable gas in a mixture, and the 4% scale for measuring the % of the LEL Assume that the meter has been designed to measure hydrogen in a mixture. The LEL of hydrogen is 4%. If a reading taken on the 100% scale indicates 10%, then the mixture is 10% hydrogen and within the LEL of hydrogen. If a reading on the 4% range indicates 10%, then the mixture contains 10% of the hydrogen necessary to produce a flammable mixture. The mixture actually contains 4% x 0.1 = 0.4% hydrogen by volume. The equipment operator must understand the difference between measuring the % LEL and the % of flammable gas. Always consult the manufacturers operating instructions and procedures prior to interpreting the results. Caution:

When testing gas for LEL remember that the H2S concentration is important relative to the safety of the worker conducting the LEL test. The LEL of hydrogen sulphide is 4% gas by volume, which equates to 40,000 parts per million H2S. This exceeds the exposure limit for people working in H2S environments; 10ppm for 8 hours. At 40,000 ppm H2S, a worker would be immediately overcome while testing for LEL

Preparing the Meter: Be sure to follow the directions supplied by the manufacturer of your gas detector. Testing the atmospheres for the safety of workers requires that the gas detection equipment be in perfect condition, properly calibrated and will be operated by competent people. Some portable equipment is designed to test for a combination of oxygen levels, flammable levels and hydrogen sulphide levels.

Section 4.0

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4.0.8.10 Monitoring for Explosive Mixtures IRP

Monitoring for explosive mixtures with a suitable calibrated monitoring device in the vicinity of potential ignition sources (e.g. pump) during pumping/flow back operations is recommended. The monitoring device must be calibrated to propane. The operations must be suspended or an alternate method of flowback initiated to eliminate an explosion risk around potential ignition sources.

IRP

Wind direction devices should be strategically located around the lease.

Note:

Monitoring for explosive mixtures with a suitable device is the only practical method of determining safe operating conditions. Judging conditions based on sight, smell, wind directions, etc., may be very deceiving in that explosive mixture levels can change rapidly during a flow back situation. Portable monitoring devices are available that give direct readout of combustible gas explosive limits. A fixed sensor could be located in an enclosed rig pump house.

4.0.8.11

Calibration of Explosive Mixture Monitors

IRP

Explosive mixture monitors should be calibrated regularly by the Owners representative or other qualified individual prior to each operation. Monitoring devices must be calibrated to propane. Defective devices must be replaced or serviced prior to commencing a flow back operation where monitoring for explosive mixture will be required. The Owners representative should be aware of the limitations of the monitor for the fluids expected.

Note:

As with any safety device, the degree of dependability of a gas detector is directly proportional to the care it receives. All explosive mixture monitors require routine maintenance on a regular basis, which includes cleaning the device and its sampling system, checking voltage supply to the unit and performing regular calibrations. Some of this servicing may require the services of a qualified technician.

4.0.8.12

Hydrates: Awareness and Handling Gas Hydrates are crystalline compounds formed, by the chemical combination of natural gas and water, under pressure at temperatures considerably above the freezing point of water. In the presence of free water, hydrates will form when the temperature of the gas is below a certain temperature, called the “hydrate” temperature. Hydrate formation is often confused with condensation and the difference between the two must be clearly understood. Condensation of water from natural gas under pressure occurs when the temperature is at or below the dew point at that pressure. Hence, the hydrate temperature would be below and perhaps the same as, but never above the dew

Section 4.0

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WELL TESTING AND FLUID HANDLING point temperature. (Dew point is the state of a system characterized by the coexistence of a vapor phase with an infinitesimal quantity of liquid phase in equilibrium. Dew point pressure is the fluid pressure in a system at its dew point.) While conducting tests, it becomes necessary to define, and thereby avoid, conditions that promote the formation of hydrates. This is essential to the proper field conduct of tests since hydrates may choke the flow string, surface lines, and the well testing equipment. Hydrate formation in the flow string would result in a lower value for measured wellhead pressures. In a flowrate-measuring device, hydrate formation would result in a lower flow rate. Excessive hydrate formation may also completely block flowlines and surface equipment. In summary, conditions promoting hydrate formation are: Primary conditions: Gas must be at or below its water dew point with free water present Low temperature High pressure. Secondary conditions: High velocities Pressure pulsations Any type of agitation Presence of H2S and C02 Iintroduction of a small hydrate crystal. For the purpose of well testing it is convenient to divide hydrate formation into two categories: 1.

Hydrate formation due to decrease in temperature, with no sudden drop in pressure, such as in flow string or surface lines.

2

Hydrate formation where a sudden expansion occurs such as in flow provers, orifices, backpressure regulators and chokes.

Ice buildup may occur on the inside of pipe when left idle, after flowing, due to condensation residue left on the inside walls of piping systems. This is not a hydrate although it could lead to the formation of a hydrate by the introduction of a hydrate crystal to the flow stream. IRP

Section 4.0

For the awareness and prevention of hydrates: -

Programs supplied by the well owner should identify potential hydrate problems by way of bottom hole temperatures, presence of free water, H2S and CO2 content and downhole restrictions

-

Prejob safety meetings should reference the possibility of hydrates

-

Incorporate the primary and secondary conditions listed above

-

Provision for the injection of methanol should be planned prior to flowing of the wel.

-

Consideration should be given to batching or injecting methanol down the tubing and the annulus, if applicable, prior to flowing Page 24

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WELL TESTING AND FLUID HANDLING -

-

Methanol should be batched or injected into the wellhead flowline before opening the well to flow and during any future shutdown periods so as to prevent ice build up on the inside walls of piping systems Flowlines should be purged with a gas medium (propane/N2), where available and when extended shut down periods are anticipated, especially during cold weather operations

-

The introduction of surface heating facilities, such as line heaters, will assist in the prevention of hydrates in surface equipment

-

Staging pressure drops will assist in the prevention of hydrates in surface equipment.

IRP

Where hydrate formation or ice buildup is suspected in surface flowlines, the lines must be proven to be clear by purging with methanol or a warm gas or fluid before the lines are broken apart.

IRP

During the pressure testing procedure and start up, all non-essential workers must vacate the surrounding area of the testing equipment, flowlines and wellhead.

4.0.8.13

Pressure Rating Formula For Seamless Pipe - Appendix I

The standard is ANSI/ASME B31.3, "Chemical Plant & Petroleum Refinery Piping". From Section 304.12 (3b) : P=2SE t / D Where: P – is a maximum allowable working pressure, in psi, S – is the basic allowable stress, in psi, for a given material, as defined in ANSI / ASME B31.3 Table A-1, Note:

for the common piping materials A 53 Gr. B, A106 Gr. B, A 333 Gr. 6, A 334 Gr. 6, and API 5L Gr. B, the allowable stress below 204 Celsius (400 Farenheit) is 20,000 psi

E – is the basic quality factor for longitudinal welds, as defined in ANSI / ASME B31.3 Table A – 1B, Note:

for seamless pipe, forgings and fittings E = 1.00, and for electric resistance welded pipe, E = 0.850

t – is the minimum pipe wall thickness, in inches. t = ( tnominal x 0.875) - H, where: tnominal – is the nominal wall thickness, in inches, of the pipe as defined in ASME B36.10M (see attached table for common pipe sizes, thicknesses and diameters).

Section 4.0

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WELL TESTING AND FLUID HANDLING 0.875 - represents the manufacturers allowable under tolerance of 12.5% for seamless pipe. H - is thread depth. For NPT threads, H = 0.07531 "up to 50.8mm(2in) pipe ”, and H = 0.10825 "above 50.8mm(2in) pipe”. D – is the outside diameter, in inches ( see attached table for common pipe sizes, thicknesses and diameters) , Note:

the above calculation does not include corrosion allowance. If a corrosion allowance is required to be added: t – ( tnominal x 0.875) – H – c, where c is the required corrosion allowance, in inches.

Section 4.0

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4.0.8.13.1

Tables - Pressure Rating Of Seamless Pipe The attached tables DO NOT include a corrosion allowance. In well testing, sudden and violent erosion is certain to destroy well test pipe before corrosion.

Pipe Size Inches

Actual O.D. Inches

Pipe Schedule

Nominal Wall Inches

Nominal I.D. Inches

Welded Carbon Steel

NPT Threaded Carbon Steel

1/2

.840

40 (STD) 80 (XH) 160 XXH

.109 .147 .187 .294

.622 .546 .466 .252

1000 2700 4550 9850

3/4

1.050

40 (STD) 80 (XH) 160 XXH

.113 .154 .219 .308

.824 .742 .612 .434

900 2350 4850 8400(5000*)

1

1.315

40 (STD) 80 (XH) 160 XXH

.133 .079 .250 .358

1.049 .957 .815 .599

1300 2600 4800 8250(5000*)

Welded 4130 HRC 18-22 Max.

*VALUES IN BRACKETS ARE LIMITED TO API 6A

Section 4.0

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WELL TESTING AND FLUID HANDLING

Pipe Size Inches

Actual O.D. Inches

Pipe Schedule

Nominal Wall Inches

Nominal I.D. Inches

Welded Carbon Steel

NPT Threaded Carbon Steel

Welded 4130 HRC 18-22 Max.

1 1/2

1.900

40 (STD) 80 (XH) 160 XXH

.145 .200 .281 .400

1.610 1.500 1.338 1.100

2

2.375

40 (STD) 80 (XH) 160 XXH

.154 .218 .344 .436

2.067 1.939 1.689 1.530

2400 3450 5650 7400

1000 2500 4100 5750(5000*)

3400 4900 8000 10450

2 1/2

2.875

40 (STD) 80 (XH) 160 XXH XXXH

.203 .276 .375 .552 .750

2.469 2.323 2.125 1.771 1.375

2600 3600 5000 7750 10900

1000 1950 3250(3000*) 5800(3000*) 8800(3000*)

3700 5100 7100 11000 15400

1100 2200 3850 6500(5000*)

*VALUES IN BRACKETS ARE LIMITED TO API 6A

Section 4.0

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WELL TESTING AND FLUID HANDLING

Pipe Size Inches

Actual O.D. Inches

Pipe Schedule

Nominal Wall Inches

Nominal I.D. Inches

Welded Carbon Steel

NPT Threaded Carbon Steel

Welded 4130 HRC 18-22 Max.

3

3.500

40 (STD) --80 (XH) --160 XXH -----

.216 .254 .300 .375 .438 .600 .750 1.000

3.068 2.992 2.900 2.750 2.624 2.300 2.000 1.500

2250 2800 3200 4050 4800 6850 8750 12000

950 1350 1850 2650 3350(3000*) 5300(3000*) 7100(3000*) 10250(3000*)

3200 3800 4500 5750 6800 9700 12400 17000

3 1/2

4.000

40 (STD) 80 (XH) --XXH -------

.226 .318 .500 .636 .750 1.000 1.250

3.548 3.364 3.000 2.728 2.500 2.000 1.500

2050 2950 4800 6250 7550 10400 13200

900 1750 3500(3000*) 4900(3000*) 6150(3000*) 8900(3000*) 11650(3000*)

2900 4200 6800 8850 10700 14700 18700

*VALUES IN BRACKETS ARE LIMITED TO API 6A

Section 4.0

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WELL TESTING AND FLUID HANDLING

Pipe Size Inches

Actual O.D. Inches

Pipe Schedule

Nominal Wall Inches

Nominal I.D. Inches

Welded Carbon Steel

NPT Threaded Carbon Steel

Welded 4130 HRC 18-22 Max.

4

4.500

40 (STD) ----80 (XH) --120 --160 XXH ---------

.237 .250 .312 .337 .364 .438 .500 .531 .674 .750 1.000 1.250 1.500

4.026 4.000 3.875 3.826 3.772 3.624 3.500 3.458 3.152 3.000 2.500 2.000 1.500

1900 2000 2550 2750 3000 3650 4200 4500 5850 6600 9100 11650 14100

900 1000 1500 1700 1950 2550 3100(3000*) 3400(3000*) 4700(3000*) 5400(3000*) 7850(3000*) 10300(3000*) 12700(3000*)

2700 2850 3600 3900 4250 5200 6000 6400 8300 9350 12900 16500 19950

4 1/2

5.000

40 (STD) --80 (XH) ----XXH ---------

.247 .250 .355 .375 .500 .710 .750 1.000 1.250 1.500

4.506 4.500 4.290 4.250 4.000 3.580 3.500 3.000 2.500 2.000

1800 1800 2600 2750 3750 5500 5850 8100 10400 12650

900 900 1650 1800 2800 4450(3000*) 4800(3000*) 6700(3000*) 9200(3000*) 11400(3000*)

2550 2550 3700 3900 5350 7800 8300 11500 14700 17900

*VALUES IN BRACKETS ARE LIMITED TO API 6A

Section 4.0

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WELL TESTING AND FLUID HANDLING

Pipe Size Inches

Actual O.D. Inches

Pipe Schedule

Nominal Wall Inches

Nominal I.D. Inches

Welded Carbon Steel

NPT Threaded Carbon Steel

Welded 4130 HRC 18-22 Max.

5

5.563

40 (STD) 80 (XH) 120 160 XXH ---

.258 .375 .500 .625 .750 1.000

5.047 4.813 4.563 4.313 4.063 3.563

1700 2500 3350 4250 5200 7200

850 1650 2500 3350(3000*) 4300(3000*) 6200(3000*)

2400 3500 4750 6050 7400 11900

6

6.625

--40 (STD) ----80 (XH) --120 160 XXH -------

.250 .280 .312 .375 .432 .500 .562 .718 .864 1.000 1.125 1.250

6.125 6.065 6.001 5.875 5.761 5.625 5.501 5.189 4.897 4.625 4.375 4.125

1350 1500 1700 2050 2400 2800 3150 4100 5000 5900 6800 7600

700 850 1000 1350 1700 2050 2450 3350(3000*) 4250(3000*) 5100(3000*) 5950(3000*) 6750(3000*)

1900 2150 2400 2900 3400 3950 4450 5800 7100 8350 9600 10800

*VALUES IN BRACKETS ARE LIMITED TO API 6A

Section 4.0

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4.0.8.14 Worker Safety IRP

Before commencing any operation a pre-job safety meeting must be held. Suggested topics are: -

Scope of work

-

Procedures to be followed

-

Pertinent well and fluid characteristics

-

Responsibilities of each person involved in the operation

-

Emergency procedures, special hazards, and safe briefing areas.

Note:

Equipment should be routinely serviced and tested by certified workers as per the manufacturer's specifications or regulatory requirements. The Owners representative is responsible for conducting an on-sight pre-job safety equipment inspection to ensure the safety equipment is operational.

IRP

All applicable federal and provincial regulations must be adhered to, such as TDG, WHMIS and Occupational Health and Safety and WCB.

4.0.8.15

Minimum Workwear Requirements

IRP

A written protective clothing policy must be available on-site. The following minimum workwear requirements must be followed: -

A hardhat must be worn in the work area

-

Safety (steel toed) footwear must be worn in the work area

-

Safety goggles or safety prescription glasses must be worn where the possibility of flying debris or hazardous chemicals exists

-

Hearing protection where over exposure to noise may occur

-

Gloves must be worn as required, e.g. specialty gloves for chemicals, leather gloves for handling pipe, etc

-

Untorn, fitted clothing must be worn in the work area

-

Outer or covering apparel must be fire retardant where the potential for fires exists. Natural fibers for innerwear is preferred over synthetic fibers

-

All clothing that becomes contaminated with hazardous chemicals or flammable fluids must be removed and replaced

-

Minimum safe standards for hard hats, footwear, eyewear and ear protection should be determined by the Well Testing Company. The following standards are appropriate: • • • •

Section 4.0

Hardhats: CSA Z94.1 Footwear: CSA Z195 Grade 1 Eyewear, Goggles: CSA Z94.3 Hearing Protection: CSA Z94.2

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4.0.8.16

Minimum General Safety Standards

IRP

The following minimum standards must be followed: -

No smoking within 50 m of potentially flammable vapors

-

Facial hair must not impede the sealing of respiratory equipment

-

Intoxicating substances and intoxicated persons are not allowed on location

-

Firearms on location are discouraged, except for flare ignition (if required)

-

An adequate supply of potable water must be on location (for drinking, and emergency washing)

-

Good housekeeping practice is required for all of the location

-

The requirements of Workplace Hazardous Material Information System and Transportation of Dangerous Goods must be followed

-

A form of wind direction indicators must be present on location, e.g. windsocks, flagging tape, etc.

-

A field phone must be present on location

-

A list of emergency contacts must be conspicuously posted on location

-

A means of transport for injured persons must be on location

-

An unobstructed exit path must be available

-

The Safety Standby Method must be employed for all hazardous work.

-

H2S detection apparatus must be on location

-

H2S determinations must be performed while wearing breathing apparatus. A minimum of two (2) positive pressure type apparatus must be at location and maintained in accordance with the manufacturer's specifications

-

On Sour wellsites where the H2S concentration is greater than 100 ppm, the Owner must provide supplied air breathing apparatus (SABA’s) in addition to self-contained breathing apparatus (SCBA). See Common Terms Section 4.0.8.1 for additional information

-

When a significant volume of wellhead gas is produced, either to an orifice device, or through a separator, notification should be given to the local provincial authority. See Section 4.0.8.19

-

A First Aid Kit as specified by the provincial OH&S authority must be on location

-

Fire Extinguishers must be charged and on location.

Section 4.0

•

Cold separator or pressure tank rig-up: Minimum 2 Class

•

ABC, 9 kg

•

Heated Unit and flare stack or line heater, pressure tank and

•

flare stack: Minimum 3 Class ABC, 9 kg

•

Heated unit or line heater/pressure tank combination withsecond stage separation or more than one item of auxiliary flow equipment: Minimum 4 Class ABC, 9kg

Wellsite illumination must be sufficient to safely perform the job Page 33

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WELL TESTING AND FLUID HANDLING -

Safety Stairs (or equivalent devices that would allow a rescue at the top of a tank other than by ladder access) are required whenever breathing apparatus is required at the top of a tank

-

In Alberta, an ESD valve must be installed on wells with more than 1379 kPa pressure and an H2S content greater than 1%. Additional considerations for use of an ESD valve are wells that •

Have harmful or toxic substances

•

Have severe abrasives (i.e. frac sand)

•

Have high operating pressure

•

Have other unusual hazards.

Note:

These points are by no means all of the General Safety Standards that should be followed. The points are listed as having special relevance to well testing. Provided that it does not contradict the Well Owners policy, well testing companies may use a fixed period to certify newer employees while on the job, provided that such persons are adequately protected by other certified workers on location.

Note:

These points are minimum standards and contractors should determine whether the Well Owner has additional standards.

4.0.8.17 Pre-job Safety Meeting IRP

A pre-job safety meeting must be held involving all workers who will be on location during operations. The meeting should be recorded and the agenda should include the following: -

Responsibilities and work programs

-

Safety procedures, general and specific to the job

-

Safety equipment location and operation. Drills are appropriate

-

Emergency contacts.

Note:

Holding the safety meeting prior to purging could be appropriate depending on workers present and the time between purging and well opening. The contractors daily shift change is considered, in part, a safety meeting. The agenda should include a complete de-briefing of the previous shift and the noting of any new hazards. It is appropriate to hold interim safety meetings at any time when conditions have changed from initial expectations. The flare permit, if applicable, must be reviewed and conspicuously posted.

4.0.8.18

Opening a Closed Tank System for Inspection after Flowing or after Purging with a Flammable or Inert Medium It is recognized that it is not always practical to have an inert purge medium for all operations. Flammable purge mediums, such as propane, are successfully used throughout the industry as long as workers follow special precautions and procedures. An inert medium also presents its own hazard; lack of oxygen and non-breathable. The following is meant to assist the worker in assessing the hazards.

Section 4.0

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WELL TESTING AND FLUID HANDLING IRP

Closed tanks must be depressured and not be on vacuum before opening the system. If available on site, purge the system with inert gas. Evacuate as much fluid (and solid) as possible before opening the system. Prior to opening the closed tank system to check its contents, a hazard assessment must be conducted by the systems owner representative on shift. The assessment must be documented and signed by both the systems owner representative and, if present, the well owner representative. The individual who conducts the hazard assessment must have Confined Space training. (A grace period to August 1, 2000 is in place to allow companies time to provide Confined Space training to their personnel.) -

Eliminate all potential ignition sources

-

Remove all non-essential people from the immediate area

-

Ensure individuals involved in opening the closed system have proper personal protective equipment such as fire retardant coveralls and breathing apparatus

-

Where workers are preparing to enter a closed system, confined space legislation must be followed.

References/Links for Confined Space Legislation Alberta General Safety Regulations Sec15, Sec 177, Sec 178, Sec 188 British Columbia Workers Compensation Board OH & S Regulations 296/97 Section 9.2 Consideration should be given to the use of purge mediums such as N2, CO2, steam, engine exhaust and water flood. The use of combination flush/vacuum pump trucks will help to clean out the system as much as possible prior to opening for inspection. 4.0.8.19

Gas Flares

IRP

Notification should be given to the local provincial regulatory authority prior to a flowback or production test where gas is planned to be vented, not flared.

Note:

In British Columbia, Drilling and Production Regulation s. 58 (3): the operator of a well or production facility must not, without the approval of the commission, permit discharge to the atmosphere of any gas produced, including stock tank vapors unless burned in accordance to subsection (4). This subsection goes on to discuss the design of a flare line and associated flare stack. In Alberta, the AEUB does not have a regulation requiring owners to report the venting of gas to atmosphere. They do however, prefer to be informed when volumes in excess of 500 m3 per day are being vented to atmosphere.

Section 4.0

Page 35

2000/02

WELL TESTING AND FLUID HANDLING Gas flares must be designed with the following considerations: -

H2S / SO2 hazards. Owners are required to define flare stack diameters and height to prevent H2S emissions and reduce SO2 fallout, within regulatory requirements. Flare Permits are required for Critical Sour Wells, and when H2S content exceeds 50 mole / kilomole ( 5% ). From 10 to 50 moles / kilomole (1 - 5%), a minimum flare stack height of 12 m is required

-

Nearby combustible material. Flare stacks should be designed to prevent combustion of vegetation

-

Flarestacks must be adequately anchored.

4.0.8.20

Venting Gas to Atmosphere

Note:

Venting of gas vapors while flowing, circulating, or pumping to open tank systems is covered in Section 4.3 Other Flowbacks.

IRP

Notification should be given to the provincial local authority prior to venting gas to atmosphere. See Section 4.0.8.19

IRP

Sour gas (>10ppm) must not be vented to atmosphere where it will compromise the safety of workers or the general public. If these two conditions cannot be met, all sour gas must be piped to a system where the sour gas is burned or flowed to a pipeline.

IRP

All gas must be vented in an upward motion directly from the wellhead or through a riser. In all cases, vented gas must be directed upward and away from any workers in the area or workers who may enter the area.

IRP

Where gas vapors are vented to atmosphere while flowing, signage indicating “gas vapors are venting to atmosphere” must be positioned to impede entrance to the wellsite by all vehicles.

4.0.8.21

Flare Pits

IRP

Flare pits may only be used in an emergency.

4.0.8.22

H2S Scrubbers

IRP

Where ammonia type scrubbers are used, the scrubber must be sized such that the concentrations and volume of H2S vapor present are adequately handled. The frequency of ammonia change-out is dependent on the H2S concentration and gas volume flowing through the scrubbing system. Fluid pH and liquid level must be maintained at all times. It is recommended that ammonia be changed out if the pH drops below 10.5.

Section 4.0

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WELL TESTING AND FLUID HANDLING

4.0.8.23

Produced Fluids

4.0.8.23.1

General Fluids

IRP

Where fluid is produced, steps must be taken to ensure the safety of site workers from vapors allowed to escape to atmosphere from the fluid.

4.0.8.23.2

Fluid Properties and Characteristics

IRP

The properties of any produced fluids or solids should be evaluated to: Identify any potential hazards Select appropriate fluid handling procedures Establish criteria for shutdown when using an open tank system Establish disposal methods and for Toxic effects Radioactive material environmental impact of escaped fluids Corrosive effects Possible degradation of elastomers NORM (Naturally Occurring Radioactive Material).

4.0.8.23.3

Oils

IRP

The properties of the produced oils should be evaluated for the following hazards: Flammability; ignition of oil and oil vapors Solid deposition problems (e.g. paraffins).

Note:

There is a general relationship between flammability and the C1-C7 content of a hydrocarbon fluid. Flammability increases with C1-C7. Also Reid vapor pressure increases with increasing C1-C7 content.

4.0.8.23.4

Gas

IRP

The properties of the produced gases should be evaluated for the following hazards: Ignition of contained and escaped vapors Solid deposition problems (e.g. sulphur) Hydrate potential.

4.0.8.23.5

Water

IRP

The properties of the produced water should be evaluated for possible gas entrainment and ignition potential.

Section 4.0

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WELL TESTING AND FLUID HANDLING

4.0.8.23.6

Kill Fluids, Frac Fluids, Acids and Solvents

IRP

The properties of such fluids should be evaluated for the following hazards: erosive potential (e.g. frac sand) radioactive tracer in sand special toxic effects flammability, including ability to be retarded special reactive effects possible degradation of elastomeric materials.

Note:

Material Safety Data Sheet and Transportation of Dangerous Goods information may provide valuable information to assess any toxicological or flammability hazards related to the produced fluids. Properties that should be considered include explosive limits, flash point, Reid Vapor Pressure (RVP), chemical composition and toxicity information.

4.0.8.24

Tanks

4.0.8.24.1

Rig Tanks

IRP

Where gas vapours are vented to atmosphere from an open tank system, the tank must be a minimum of 50 meters from the wellhead.

IRP

Where a degasser is used to separate gases and liquids, it should be located in a separate compartment of the rig tank. The degasser should be configured such that a sufficient head of fluid in the tank is maintained for efficient gas separation.

IRP

Flowback operations must be discontinued if liquid carry over from the degasser vent line occurs, and an appropriately sized separator or pressurized tank must be employed.

Note:

IRP 1.3 Mud Gas Separators, provides an overview of degasser design factors including vent line sizing.

Note:

In British Columbia, WCB Regulations requires an external gauge system on tanks where sour fluids are produced and no person is to be on a tank while open to a well.

4.0.8.24.2

Atmospheric Tanks (64m3 style)

IRP

Atmospheric tanks are predominantly used for storage of fluids and are not considered capable of containing pressure. Most atmospheric tanks are designed with 7 kPa (16oz) hatches and the roof is typically designed to shear at 14 kPa (2 psi).

Section 4.0

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WELL TESTING AND FLUID HANDLING IRP

When producing sour fluids, atmospheric tanks must be equipped with a suitable vapour gathering, flaring or scrubbing system to ensure that H2S vapours are not released to atmosphere. The system may also include a pressurized tank.

4.0.8.24.3

Certified Pressurized Flowback Tanks

IRP

Pressurized tanks used for flow back or storage of fluids produced from a sour well must be manufactured under a quality program to ensure conformance with design specifications utilizing materials meeting the requirements of NACE MR 01-75 LATEST EDITION.

4.0.8.24.4

Non-certified Pressurized Storage Tanks

IRP

If using a non-certified tank or vessel for primary separation and storage of fluids while swabbing, flowing to establish a rate, circulating, pumping or bleeding off rather than using a certified tank or vessel, the non-certified tank or vessel must be constructed under a quality control program. Construction, design and material specification data must be available when requested by the well owner. Government departments may also request this data.

4.0.8.24.5

Other Tanks

IRP

Owners must have regard for the volume of the various fluids to be utilized and where possible, provide sufficient tank storage to provide for a suitable retention time or provide for other measures such as heating or agitation to allow for separation of entrained gas, prior to transportation.

IRP

Pressurized tanks or a closed system should be used for flowbacks, storing, producing, pumping, swabbing or killing wells with high vapour pressure hydrocarbons (see Section 4.0.7.14).

IRP

When flowtesting from a sour well (>10ppm) during servicing, drilling or testing operations, a closed system must be used to prevent the escape of sour gas to the atmosphere. Flowback duration, proximity to and notification of area residents must be considered. H2S scrubbers must be operated within the manufacturers operating parameters and ammonia monitored and changed accordingly.

Note:

Hydrometers are readily available to determine the density of hydrocarbons to be pumped as well as fluids subsequently returned during the flowback. In Alberta, AEUB inspection policies regarding the handling of sour effluents are included in AEUB Guide G-37 Service Rig Inspection Manual. Section 2.5 Fluids and Circulating Systems in ARP 2.0, Completing and Servicing Critical Sour Wells, contains additional information regarding necessary fluid handling equipment for critical sour wells. Section 2.10 Quality Programs for Pressure Containing Equipment includes basic information regarding quality programs.

Section 4.0

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WELL TESTING AND FLUID HANDLING NACE MR 01-75 LATEST EDITION, Sulphide Stress Cracking Resistant Metallic Materials for Oilfield Equipment has a 350 kPa pressure limit below which the requirements do not apply. A 1987 CPA Tank Vapour Flaring Committee report provides information regarding the design and selection of a suitable vapour recovery system. 4.0.8.25

Location of Tanks

IRP

Rig and/or other tanks should not be placed in proximity to the lease road exit.

Note:

If it is necessary to locate tanks next to the lease road exit, for example on small leases or remote locations, to comply with other spacing requirements, ensure adequate transportation for workers is available in the event of an emergency. This transportation should be off the lease when no other means of egress are available.

4.0.8.25.1

Location of Rig Tanks

IRP

Where gas vapours are anticipated, the rig tank(s) must be 50 meters from the wellhead and any open flame.

4.0.8.25.2

Location of Atmospheric Tanks (64m 3 style)

IRP

Where gas vapours are anticipated, or the tank is rigged with a venting/scrubbing system, atmospheric tank(s) must be 50 meters from the wellhead and any open flame.

4.0.8.25.3

Location of Certified Pressurized Flowback Tanks

IRP

It is recommended to place certified pressurized flowback tanks 25 meters from the wellhead even though there is no regulated distance requirement. Where the tank is preceded by a flame arrested line heater, the line heater and tank must be a minimum of 25 meters from the wellhead.

4.0.8.25.4

Location of Non-certified Pressurized Storage Tanks

IRP

Non-certified pressurized tanks must be 50 meters from the wellhead. The tank must be designed for its intended use. If the tank is to be used as the primary vessel, the tank must have been constucted under a quality control program. Construction, design and material specification data must be available when requested by the well owner. Government departments may also request this data.

Section 4.0

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4.0.8.26

Air Entrainment and Purging

4.0.8.26.1

General

IRP

Owners and Service Contractors must understand and attempt to eliminate an explosive hazard due to air entrainment in pipes, vessels and tanks.

Note:

Air entrainment explosions occur upstream of the flowline choke and downstream of the flowline choke (usually in storage tanks). The fuel source is the well product, or it can be the purge medium if propane or natural gas is used to purge. Ignition sources are not always identifiable, but possibilities include: -

flashbacks from flares

-

static electricity

-

friction heat (from valve operation or high velocity debris)

-

localized "hot spots" in partially open (unbalanced) valves

-

spontaneous combustion at critical pressures and temperatures

-

spontaneous combustion of compounds such as sulfides

-

electrical currents from lightning and power sources (including cathodic protection).

Air sources upstream of the choke include: -

air from dry run tubing (e.g. for underbalanced perforating.

-

coiled tubing unit operations using air

-

swabbing, when the well goes on vacuum

-

reaction productions (e.g. hydrogen peroxide washes).

Air sources downstream of the choke include:

4.0.8.26.2 IRP

-

initial air, as the equipment arrived

-

air re-introduced from the wellhead side

-

air pulled into production tanks through open or leaking hatches when a vacuum condition exists. The vacuum can be caused by fluid withdrawal, and by excessive venturi action at flare stacks when tanks are vented to flare.

Prevention of Air Entrainment in Storage Tanks Air entrainment during the testing operation must be continuously monitored so that storage tanks and associated equipment vented to flare do not become air contaminated. The Logic Chart in Section 4.2, beginning at "Start Test/Production" must be understood and followed. System elements suspected to have become contaminated with air must be repurged.

Section 4.0

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WELL TESTING AND FLUID HANDLING Note:

The Logic Chart does not address tank vacuum created by excessive liquid withdrawal. That should be prevented by a combination of increasing the blanket gas (or other make-up source), and reducing the withdrawal rate.

4.0.8.26.3

Purging the Well String and Wellhead

IRP

Dry tubing should be displaced by N2 or CO2 or alternatively the procedures of Section 4.0.8.27 should be employed. When dry tubing with air is opened to the formation, a fluid cushion should be run in the string. If the well has enough energy, the cushion can be brought back to a tank. The returning cushion purges the tubing string. Wellhead pressure should not be allowed to build up prior to the cushion return.

Note:

It is recognized that it is not always practical to displace tubing air prior to operations such as underbalanced perforating or drill stem testing. Owners and Well Testing Companies must assess the planned procedure when air exists in the well string.

4.0.8.26.4

Purge Mediums for Purging Surface Equipment

IRP

Purging should be performed by a purge medium vapor displacing air. Non-flammable vapors are preferred. Propane or sweet gas is acceptable with extra precautions, recognizing that the purge medium will create explosive mixtures before air purging is complete.

4.0.8.26.5

Pre-Purging Procedures and Checks

IRP

The following pre-purging procedures and checks are required:

IRP

Section 4.0

-

Production tanks should be clean

-

Production tanks must have hatch seals and pre-set pressure thief hatches

-

All system elements must be electrically bonded to each other, with the wellhead or ground rods as "ground" (or "common").

Where production tanks are vented to flare, the configuration must be: -

The vent line to flare is a minimum 76.2 mm (3”)

-

A manual block valve is placed in the vent line

-

A pressure measurement tap and low pressure measurement device (e.g.: U tube manometer) exists between the tank top(s) and block valve

-

A flame arrestor exists between the block valve and the flare stack (minimum Underwriters Laboratories approved)

-

A regulated or manually valved tank top(s) blanket line exists

-

The purge medium should be manifolded to a control purging/ measurement point, e.g. the test separator

-

All pilots on flare stacks or other open flames within 50 meters of the equipment to be purged must be extinguished.

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WELL TESTING AND FLUID HANDLING Note:

Regulations in British Columbia do allow the wellhead as a grounding mechanism. Refer to Production and Drilling Regulation s. 66, Grounding and Bonding.

Note:

If a gas boot precedes the production tank(s), it must be vented to flare. The vent line should be minimum of 76.2 mm (3.0”). A block valve at the gas exit is required for the purging process, but, if the gas boot does not have a pressure relief device, this valve must be locked open or removed during flow. Owners and Well Testing Companies must recognize that flame arrestors do not guarantee the prevention of flash-backs, and therefore the elimination of initial air and subsequent air entrainment is required. A gas boot is meant to strip solution gas at very low pressures. A flame arrestor should be considered in the gas boot line if a positive liquid seal cannot be maintained.

4.0.8.26.6

Purge Vapor Measurement

IRP

The purge vapor should be measured.

Note:

Liquid-volume-to-vapor or mass-to-vapor conversions are allowed if the liquidvolume or mass vaporized is measured accurately, and if it is ensured that all of the liquid is vaporized. Numerous measurement devices are available.

4.0.8.26.7

Purge Amounts

IRP

The volume to be purged must be calculated prior to purging. For purge mediums heavier than air, purging should be a minimum of 1.5 times calculated volume, and purging should be from the bottom up. For purge mediums lighter than air, purging should be a minimum of 2.5 times calculated volume, and purging should be from the top down.

Note:

Top down purging is impractical in some situations. If bottom up purging is employed with purge mediums lighter than air, a minimum of 5 times calculated volume should be displaced. Small lines and vessels may be purged for a number of minutes instead of rigorous calculations if it is certain that the time chosen would exceed the overpurge guidelines.

4.0.8.26.8

Purging With Wellhead Gas (Sweet or Low Concentration of H2S)

IRP

The well should be flowed slowly to the separator unit, then to the flareline, then to downstream vessels/tanks. Downstream vessels/ tanks must be isolated and purged one at a time.

Note:

Production tanks that will not be vented to flare do not required purging.

4.0.8.26.9

Purging Sequence

IRP

Purging should be in a downstream sequence, flowline (and heater, if present) then separator, then flareline then to downstream vessels/ tanks. Downstream vessels/tanks must be isolated and purged one at a time.

Section 4.0

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WELL TESTING AND FLUID HANDLING Note:

The flowline would be purged from the wellhead to the separator unit, if the vapor was introduced at the wellhead. It is also acceptable to use the separator as a point of origin for the purge vapor. In that case, the flowline would be purged back to the wellhead (with the line disconnected at the wellhead).

4.0.8.26.10 Ending The Purge IRP

Where practical, oxygen meters are recommended for large vessel/tanks, regardless of the calculated overpurge. The sensing should be performed at points other than the purge exit of the component (in case of air bypassing instead of displacement). Oxygen content must be such that the gas mixture is below its lower explosive limit.

4.0.8.26.11 Intermediate Purging IRP

Vessels/tanks should be re-purged whenever air is accidentally or operationally introduced during the test.

4.0.8.27

Opening A Well With Air In The Flowstring

IRP

It is recognized that, sometimes, wells are required to be opened when there is air behind the wing valve. Owners and Well Testing Companies should consider some or all of the following procedures:

Section 4.0

-

All non-essential workers should be removed from the test area Manifolding should exist so that all vessels/tanks can be bypassed

-

It is not necessary to purge an open tank system where gas is vented to atmosphere

-

It is important that the tubing be flow-purged of explosive mixtures as soon as possible after operations such as tubing conveyed perforating. The well should not be shut-in for buildup until the purge is completed because pressuring up the volatile mixture increases the danger of an in-line explosion

-

On sour wells, the well can initially be flowed through a by-pass directly to flare until the air is displaced from the tubing and the flare is burning steadily. This will contain possible fires in openended pipe. The well can then be shut-in or directed to pre-purged vessels prior to liquids arriving at surface. An operator could also obtain permission from the local authority for short term flow to an unlit flare to displace air from the tubing. The flow should be sampled with an 02 or gas detector to verify the mixture is out of the explosive limits

-

The wing or master valve can be balanced by downstream pressure (N2, CO2 or H2O) prior to opening, to reduce friction and initial inrush

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WELL TESTING AND FLUID HANDLING -

Where a well could go on vacuum during swabbing, a check valve must be inserted in the flowline system. A manual valve should also be in the system. The saver-sub should be tightened. A regulated purge vapor to follow the swab cups back down the hole should be considered

-

All suspect lines/vessels/tanks must be repurged when the wellstring air is eliminated.

Note:

Section 4.0

Owners should notify nearby residents before commencing operations respecting the potential for short-term odors that may occur during start up.

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WELL TESTING AND FLUID HANDLING

4.1

DRILL STEM TESTING

4.1.1

Scope Normal drilling procedures control formation pressures and fluids through the use of a hydrostatic head. Drill stem testing brings these formation pressures and fluids to the surface, thereby presenting a unique set of conditions since pressure control is then maintained by mechanical systems. Safe work guidelines, such as those set out in this IRP, minimize the probability of either the mechanical or human systems failing during a test, as well as establishing minimum health and operating standards. This IRP is intended to supplement existing standards and regulations rather than replace them, and is directed mostly towards drill stem tests that are to be run on onshore wells.

4.1.2

Planning A Drill Stem Test

4.1.2.1

Drill Stem Test Plan

IRP

Owners shall provide a plan for all drill stem tests. This plan shall include at least: the zones to be tested, the depths of tests, the method of testing, the type of equipment to be used, the duration of the test, and a reference to an emergency response plan, where applicable. The emergency response plan shall be discussed with all employers and workers involved with the drill stem test.

4.1.2.2

Lithological and Reservoir Information

IRP

Operators shall provide lithological and reservoir information on the zones to be tested. This shall include potential H2S zones, possible well problems, anticipated recovery, anticipated flow rates, H2S rates, and anticipated pressures. This information shall be discussed with all employers and workers involved with the drill stem test.

4.1.2.3

Qualifications

IRP

Workers conducting drill stem testing operations shall have the minimum qualifications detailed in Table 4.1

Section 4.1

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WELL TESTING AND FLUID HANDLING

TABLE 4.1 PITS BOP SECOND LINE

THE WORKER

PITS BOP FIRST LINE

H2S COURSE (*1)

FIRST AID (*2)

WHMIS (*3)

TDG (*4)

EXPERIENCE IN OVERALL OPERATIONS

OWNERS REP.

X

X

X

X

X

X

RIG MANAGER

X

X

X

X

X

X

X

X

X

DRILLER

X

TESTER

X

SAFETY SUPERVISOR

X

1* 2* 3* 4*

X

**X

X

X

**X

X

X

**X

A course with an exam or certificate. (See IRP 4.1.5.3) Any two of the crew, on any shift, must have first aid qualifications. WHMIS: Workplace Hazardous Materials Information System. TDG: Transportation of Dangerous Goods.

** The lead Driller, Tester and Safety Supervisor should have a good understanding of the overall operation.

4.1.3

On-Site Pre-Test Guidelines

4.1.3.1

Pre-test Safety Meeting

IRP

The worksite Owner or designated representative shall hold a pre-test safety meeting with all workers on the site that may be involved with the drill stem test. This meeting shall review the testing plan, testing procedures, test prognosis, operation of surface equipment, and assign specific worker responsibilities. The pre-test safety meeting shall be recorded, along with a record of those who attended the meeting. The pre-test safety meeting will include a discussion of the emergency response plan where applicable, including any revisions orrecommendations to accommodate the specific well environment.

4.1.3.2

Pre-Test Inspection

IRP

The worksite Owner or designated representative shall visually inspect all equipment and facilities that may be used during the drill stem test including:

Section 4.1

-

The drilling floor and hoisting equipment

-

Safety equipment

-

Surface equipment and lines

-

Drill stem test tools including test head and floor manifold

-

Drill pipe, drill collars, drilling fluid and additives

-

Blow-out prevention equipment

-

Fluid containment or storage equipment.

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2000/02

WELL TESTING AND FLUID HANDLING The inspection shall ensure proper distances are used in placing the equipment on the worksite. IRP

Swivel joints and flow lines upstream of the choke manifold shall be subjected, prior to the drill stem test, to a pressure test. The lines shall be visually inspected for leaks at both low pressures and high pressures. The high pressure test shall be to the maximum anticipated surface pressure. Lines downstream of the manifold should be secured to restrict them from movement. Reference: Safety Checklist - see Appendix 1

4.1.3.3

Pre-test Training

IRP

The worksite Owner or designated representative shall ensure that all workers involved with a drill stem test are properly trained in the operation of drill stem testing equipment, safety equipment, and personal safety equipment.

4.1.4

Drill Stem Testing Guidelines

4.1.4.1

DST Tool Retrieval During Daylight

IRP

Liquids recovered during Drill Stem Tests should be reverse circulated from the drill pipe. Prior to reversing out, drill pipe may be pulled from the hole until fluids are encountered at surface. Test plugs should be utilized if liquid recovery is expected. When using test plugs, they should be used from the very first stand pulled, then continuously throughout trip. If reverse circulation is not possible, the trip may be continued using test plugs and mud can with extreme caution.

IRP

When testing sour wells a certified pressurized tank and flare stack should be used to ensure efficient separation and burn of all gases. A flare permit from the local authority may be required.

Cautions: A pump-out-sub or downhole circulating device should be run in the test string to reverse. Reverse circulation requires proper disposal of the contents of the drill string. Pump to a tank truck or a vacuum truck. Ensure that all lines are secured so as to restrict their movement, engines are off, and the receiving vessel is properly grounded and vented. Refer to IRP 4.1.6.2 if the recovery is sour. See IRP 4.2 Well Testing and IRP 4.3 Other Flowbacks for other information.

Section 4.1

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2000/02

WELL TESTING AND FLUID HANDLING Extra care must be taken once the pump-out-sub has reached the rig floor since hydrocarbons may be present below the pump-out-sub. Reverse circulation may not always be possible if a pump-out-sub fails to operate, or the owner chooses not to reverse circulate liquid recoveries in order to obtain better quality formation fluid samples. Owners may choose to reverse circulate prior to encountering fluids depending on the fluid recovery expected. The use of telemetry for surface readout will indicate potential fluid recovery. Monitoring the flare through final shut-in may also show indications of fluid in the drill pipe. 4.1.4.2

DST Tool Retrieval During Darkness

IRP

Drill stem tests may be conducted during darkness until liquid recovery is encountered, if IRP 4.1.6 is followed and there is adequate lighting. At this point the recovery must be reverse circulated. If reverse circulation is not possible, pulling drill pipe shall not be continued until daylight.

Note:

Extra care must be taken once the pump-out-sub has reached the rig floor since hydrocarbons may be present below the pump-out sub.

4.1.4.3

Annulus Fluid Level

IRP

The fluid level in the annulus shall be monitored at all times. Should the packer seat fail and the level of fluid in the annulus drop, a method for filling the hole shall be in place at all times.

Note:

A drop in the fluid level would reduce hydrostatic pressure and could allow zones above the packers to kick. Such a loss could be caused by a packer seat failure or fluid loss to an upper formation.

4.1.4.4

Workers On Rig Floor

IRP

All workers shall be fully aware of their responsibilities during the test including what to do in an emergency.

IRP

Clear all non-essential workers from the rig floor during the drill stem test.

4.1.4.5

Test Line

IRP

A separate drill stem test line shall be rigged up to the floor manifold and run to the flare pit or other area to dispose of or to store the fluid. The flare line must be adequately secured and the igniter lit prior to the start of the test, if applicable. Do not use the BOP blowdown line as the test line. When testing sour wells a certified pressurized tank and flare stack should be used to ensure efficient separation and burn of all gases.

Section 4.1

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WELL TESTING AND FLUID HANDLING Note:

If a hydrate or sulphur plug is suspected in the drill pipe, be very cautious before disconnecting any of the pipe. Plugging can be monitored best by the use of telemetry, surface readout system. Monitoring the flare through the final shut-in may also aid in identifying plugging.

4.1.4.6

Floor Manifold

IRP

The line of flow shall be directed through a floor manifold to allow for control and measurement of flow. The manifold shall have a pressure rating which exceeds that of the maximum anticipated surface pressure to be encountered. A floor manifold may also be referred to as a choke manifold on the rig floor. The floor manifold must be secured so as to restrict it from movement in the event of a break in the piping system.

4.1.4.7

Swivel Joints and Flexible Pipe

IRP

All swivel joints and flexible pipe shall be secured with a safety cable. The integrity of flexible piping should be ensured through pressure testing.

4.1.4.8

Fire Prevention

IRP

Non-essential electrical systems, motors and engines within 25 m of the wellhead shall be shut down. Any essential diesel motor within 25 m of the wellbore should be equipped with an exhaust extension and emergency shut-off system. The rig floor and sub area shall be well ventilated. This may include opening "man-doors" in prefabs during winter operations.

4.1.4.9

Pipe Tally

IRP

A pipe tally shall be taken while pulling out of the hole for the drill stem test and a tally shall be taken while running the test to depth. This tally shall be reviewed and checked by the wellsite owner before starting the test.

4.1.4.10

Flow Checks

IRP

After completion of the drill stem test, flow checks should be done prior to starting the test string out of the hole and should be done at appropriate intervals while pulling out of the hole. A flowcheck is when the pulling of pipe is stopped and a waiting period is used to see if there is any inflow into the annulus. Ensure the test string is pulled slowly to avoid a swabbing effect. Follow rigorous hole filling procedures. Appropriate intervals for flow checks are:

Section 4.1

-

After pulling the first 3-5 stands

-

When half way out of the hole

-

When the test tools are at the casing shoe

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WELL TESTING AND FLUID HANDLING -

At any warning sign When the drill collars are reached When totally out of the hole.

Flow checks should be 10-15 minutes in length, with flow temporarily diverted to the trip tank. 4.1.5

Sour Drill Stem Test Guidelines

4.1.5.1

Safety Guidelines

IRP

The safety of the worker and equipment takes precedence over any test information to be collected. Prior to starting a sour drill stem test, it is essential that all workers on the lease understand the dangers of H2S. They should be fully informed of and trained in appropriate safety procedures, including the use of safety equipment and breathing apparatus.

IRP

A safety company representative must be on-site during the testing of any well that has the potential of producing sour gas.

Caution:

Hydrogen sulphide gas is colourless, heavier than air, and is extremely toxic. It is explosive when mixed with air in the range of 4.0% to 45%, and it is soluble in fluids. The principal danger to the worker is poisoning by inhalation. Tubulars and metals in an H2S environment can be very susceptible to hydrogen embrittlement and sulphide stress cracking.

4.1.5.2

Sour Drill Stem Testing Equipment

IRP

A drill stem test that may encounter H2S shall have sour service surface equipment meeting the requirements of NACE MR 01-75 latest edition, "Sulphide Stress Cracking Resistant Metallic Materials for Oilfield Equipment". A certified pressurized tank and flare stack for efficient separation and handling of sour gas or fluids must be used.

Note:

Hydrogen embrittlement and sulphide stress cracking are influenced by a complex interaction of parameters, including: -

Metal chemical composition, strength, heat treatment and microstructure

-

Type and pH of the drilling fluid

-

H2S concentration and total pressure

-

Total tensile stress

-

Temperature of the interval being tested

-

Length of time tools are exposed to H2S

-

Other factors.

The decision on which surface equipment, downhole equipment and testing tubulars to run for a sour drill stem test should include an evaluation of the above parameters to best combat the corrosive effects of hydrogen sulphide. The selection of tubulars is especially critical, and consideration should be

Section 4.1

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WELL TESTING AND FLUID HANDLING given to using sour service tubing instead of drill pipe. Numerous charts and graphs are available to demonstrate, both theoretically and empirically, conditions where drill pipe may potentially be used safely for sour drill stem testing. An in-depth examination of using drill pipe in a sour gas environment can be found in Section 1.2 of IRP Volume No. 1 - Drilling. 4.1.5.3

Corrosion Inhibition While Sour Drill Stem Testing

IRP

Inhibit water based drilling fluids by maintaining a pH above 10. Inhibit oil based muds with the addition of commercially available scavengers.

IRP

Use a filming amine inhibitor to protect the interior of the test string when running a sour drill stem test. If no water cushion is used, the inhibitor should be dumped down the test string. If a water cushion is used, mix the inhibitor with the cushion, and also put inhibitor on top of the cushion. Both water soluble and oil soluble inhibitors are available from safety service companies.

4.1.5.4

Limitations of Sour Drill Stem Testing

IRP

Drill stem tests that produce sour fluids to surface shall be shut-in immediately unless equipment used in the hole and at surface is adequate for the conditions.

Note:

A closed chamber drill stem test will prevent fluid flow at surface during a sour test. IRP 4.2 Well Testing, provides additional recommendations about handling sour fluids using surface well testing equipment.

4.1.5.5

Sour Hydrocarbon Recovery

IRP

All sour gas shall be flared. Install a constant pilot light or ignition device in the flare stack to ensure combustion of all gas sent to the flare stack. Refer to Provincial Regulations regarding flaring.

IRP

Sour liquid recovery shall be reversed to a certified pressurized tank with a flare stack.

4.1.5.6

Neutralizing H2S During Trip Out of Hole

IRP

When pulling drill stem test tools out of the hole, use a mixture of aquaammonia and water to neutralize any H2S in vapour phase. Use caution when putting the mixture down the test string. A small amount of fluid may unload due to displacement from the ammonia. Ammonia is available from safety service companies.

Section 4.1

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WELL TESTING AND FLUID HANDLING

Appendix I Recommended Drill Stem Testing Services Inspection Checklist Worksite Owner ______________________

Drilling Company___________________

Lease Location And LSD ________________

Critical Sour Well(Y/N)_______________

DST Service Company _________________

Service Company Rep_______________

Inspected By ___________________

Date 20____ ____ ____ Time:_________Hrs Yr Mo Day 24 Hr Clock Well Activity _____________________________________________________________ Mark A Check If "Adequate Or Inadequate" Of ' - ' If Not Applicable (Note: Any "Inadequate" Must Have An Explanation And be corrected)

A.

INADEQ

____ ____ ____ ____ ____

____ ____ ____ ____ ____

____ ____ ____ ____ ____ ____ ____

____ ____ ____ ____ ____ ____ ____

____ ____ ____ ____ ____ ____ ____ ____ ____ ____

____ ____ ____ ____ ____ ____ ____ ____ ____ ____

SIGNS 01 02 03 04 05

B.

ADEQ

No Smoking Designated Smoking Area No Vehicles or Unauthorised Persons Danger High Pressure H2S (if required)

PERSONAL SAFETY 06 07 08 09 10 11 12 13

14 15 16 17 18 19

Section 4.1

Emergency Response Plan complete Pre-start up Safety Meeting Hard hats (CSA approved) Safety footwear Eye Protection Ear Protection First Aid supplies Certificates a) H2S b) WHMIS c) First Aid d) Transportation of Dangerous Goods Fire retardant clothing Facial hair Fire Extinguishers H2S gas detector (manual) Back packs checked Air supply checked

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WELL TESTING AND FLUID HANDLING

ADEQ C.

INADEQ

GENERAL 20 21 22 23 24 25 26 27 28 29 30 31 32 33

Motor kills checked Motor exhaust water manifolds operational Safety valve connection checked Control valve actuated Flowline including lead to manifold to flare line, pressure tested B.O.P. operation tests Well kill fluid adequate Pumping/tripping practices observed according to Government regulations Emergency lighting Rig floor ventilation system Equipment integrity for H2S Manifold valves set for flow Flare pit properly dug 50 m from wellbore Flare ignition system

____ ____ ____ ____

____ ____ ____ ____

____ ____ ____

____ ____ ____

____ ____ ____ ____ ____ ____ ____

____ ____ ____ ____ ____ ____ ____

COMMENTS / EXPLANATIONS

Note: 1. If separation equipment and oil storage is used, refer to production testing inspection list in Section 4.2. 2. For rig safety, refer to drilling rig inspection checklist in ARP 2.0 Owner Representative ________________________

Signature _________________

Drilling Company Representative________________

Signature__________________

DST Service Company Representative ____________

Signature__________________

Section 4.1

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4.2

WELL TESTING

4.2.1.

Scope The Original ARP’s (Alberta Recommended Practices) for Well Testing were developed by the Well Testing and Fluid Handling Subcommittee of the Drilling and Completions Committee (DACC) in 1987 to establish recommended practices for equipment, procedures and workers for the safe handling of fluids associated with Well Testing. These IRP’s (Industry Recommended Practices) incorporate, update and replace the Alberta Recommended Practices (ARP) Volume 4 “Well Testing and Fluid Handling”, Section 4.2 entitled “Well Testing”. These IRP’s were developed through 1998 and 1999 with planned implementation in 1999. The recommendations in this IRP are somewhat unique in that it is meant to encompass Well Testing and similar operations where Well Testing companies perform the work. Certain recommendations (including but not limited to a recommendation on the number of workers required) are more stringent than would be required for work where Well Testing companies are not involved. Wellsite Owners are expected to use their own safe operating practices when testing wells with their own workers and to refer to the complete IRP Volume 4 document when well testing and fluids handling operations are being conducted.

4.2.2

Wellhead Control

4.2.2.1

General

IRP

Well testing operations should be conducted with a wellhead installed, or with a temporary wellhead as per IRP 4.2.2.3.6

4.2.2.2

Standard

IRP

Wellheads should be selected, designed and manufactured in accordance with the applicable portions of: API 6A, Specification for Wellhead and Christmas Tree Equipment or the relevant parts of the ASME/ANSI Series: • B16.4, Pipe Flanges and Flanged Fittings. • B16.9, Wrought Steel Buttwelding Fittings • B16.11, Forged Steel Fittings, Socket-Welding and Threaded • B16.34, Valves-Flanged, Threaded and Welded End or "Registered Fittings" as defined in the Provincial Regulatory Agency or IRP Volume 5.0 Wellheads or A combination of the above, so that wellhead components meet recognized standards.

Section 4.2

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WELL TESTING AND FLUID HANDLING Note:

Auxiliary documents should be applied where applicable: NACE MR 01-75 LATEST EDITION - Sulfide Stress Cracking Resistance Metallic Materials For Oilfield Equipment. ARP 2.0, Alberta Recommended Practices for Completing and Servicing Critical Sour Wells. Provincial regulations Wellhead components should be manufactured by suppliers with an appropriate quality program. Shop and field welding quality programs are also required to ensure that welding meets the requirements of ASME Section IX, Welding and Brazing Qualifications.

4.2.2.3

Wellhead Minimum Requirements

4.2.2.3.1

Pressure Rating

IRP

All wellhead components should have a working pressure rating that is at least equal to the lesser of the bottom hole pressure of the producing zone or 1.3 x SITHP.

Note:

In Alberta, AEUB Regulation 7.050 calls for wellhead components to be not less than the bottom hole pressure of the producing formation for wells with greater than 50 moles / kmol H2S (5%).

Note:

In British Columbia (WCB Regulation 23.69(7)): when flow piping exceeds 3500kPa (500 psi), connections must be welded, flanged or hammer unions. If there is only a threaded connection available at the wellhead, special precautions must be taken.

4.2.2.3.2

Master Valves

IRP

Where practicle, all well tests must be performed using wellheads with a master valve. Master valves should be of the full bore, round opening type. Wells where the H2S content of the wellbore effluent is 50 moles/kilomole (5%) or greater require 2 master valves. Master valves for Critical Sour wells should be API 6A flanged.

Note:

Master valves are used to allow the servicing of the wing valve and to allow the connection of treatment lines, lubricators and other temporary connections. Master valves are used to isolate other components, and should not be used to initiate or shut off flow.

4.2.2.3.3

Flow Tee and Flow Cross

IRP

All wells must be provided with a flow tee or cross above the master valve, to connect wing valves to the master valve(s). Critical Sour wells must be provided with an API 6A flanged flow tee. A top connector should be considered where applicable.

Section 4.2

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4.2.2.3.4

Wing Valve

IRP

A wing valve must be attached to the flow or cross tee. Critical sour wells must have API 6A flanged wing valves.

Note:

The wing valve is used to initiate or shut off flow. The flow sequence is always: open the lower master valve (if applicable), then the upper master valve, the wing valve. The shut off sequence is the reverse.

Note:

Consideration must be given to the use of Emergency Shutdown Valves (ESD’s) on all wells classed as sour (above 10ppm). In Alberta, all wells to be flowed having a surface pressure greater than 1379kPa and an H2S content greater than 1% requires an ESD.

4.2.2.3.5

Pressure Testing

IRP

All primary and secondary seals in the wellhead must be hydrostatically tested upon installation. All wellhead components should be pressure tested to a pressure that is at least equal to the lesser of the bottom hole pressure of the producing zone or 1.3 x SITHP. Check with the wellhead maufacturer for maximum test values between the primary and secondary seals.

Note:

In Alberta, AEUB Regulation 7.050 calls for wellhead components to be not less than the bottom hole pressure of the producing formation for wells with greater than 50 moles / kmol H2S (5%).

Note:

In British Columbia (WCB Regulation 23.69(7)): when flow piping exceeds 3500kPa (500 psi), connections must be welded, flanged or hammer unions. If there is only a threaded connection available at the wellhead, special precautions must be taken.

Note:

The minimum stabilization criteria is that detailed in API 6A Appendix F, which is a change rate of no more than 5% of the testing pressure per hour (10 minute minimum) or 3500 kPa/hour (500 Psig/hour) whichever is less.

4.2.2.3.6

Temporary Wellheads

IRP

Temporary wellheads used in well testing, such as drilling or servicing Blowout Preventers, Tree Savers and Frac Heads must be designed with control systems that are essentially that of 4.2.2.3.1 through 4.2.2.3.4.. BOP rams are not considered to be master valves.

Section 4.2

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4.2.3

Well Testing Equipment Capacities And Pressure Ratings

4.2.3.1

Capacities

4.2.3.1.1

General

IRP

Equipment flow capacities should be sized for the flow rates of the program, and need not be sized for the maximum capacity of the well. Flow capacities may be derived from detailed calculations, nomographs and experience.

IRP

Pop valves and burst heads must be piped to a system to take discharged product away from the vessel and workers in the immediate area.

IRP

Unrestricted access to the wellhead wing valve and master valve must be ensured.

IRP

Pressure relief devices as defined by the provincial regulatory agency must protect pressure vessels and piping.

Note:

Conventional safety valves are designed for block in pressure protection and to operate without allowing the relieving pressure to rise greater than 10% over the set pressure of the PSV. ASME Section VIII Division 1 requirements are that the safety valve cannot be set greater than the vessel’s Maximum Allowable Working Pressure (MAWP) and must have adequate capacity to ensure that the maximum rise of pressure after the valve opens is limited to 10% of the MAWP. Backpressure on a safety valve is not a function of its operation to relieve pressure but is a function of any external produced pressures on the outlet side of the safety valve. If this backpressure is constant then the conventional safety valve can be cold set at a lower pressure, set to compensate for the backpressure.If the backpressure is variable a pilot or balanced bellows safety valve is required to maintain constant pop pressure. If the safety valve is installed to prevent overpressure due to thermal (fire) exposure only and there is no source of external pressure that would cause the vessel to exceed its MAWP, a thermal relief valve can be installed. This safety valve can be set at 110% of the vessel MAWP and pressure rise to maximum 25% over the MAWP is allowed. A pressure shutdown devise is not an acceptable means of overpressure protection for pressure vessels – a safety relief valve is required.

4.2.3.1.2

Separator Systems

IRP

Separator capacities should be at planned operating pressures and should be sized for all well effluent phases.

Section 4.2

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4.2.3.1.3

Heat Requirements

IRP

Heat requirements should consider hydrate inhibition, inhibition of solid deposition, and reduction of solution gas at the liquid storage stage.

4.2.3.1.4

Liquid Storage

IRP

The upstream system and the liquid storage stage must be designed to reduce or eliminate or control the escape of vapors to the environment.

4.2.3.2

Pressure Ratings

4.2.3.2.1

Pressure Vessels

Note:

Refer to the “Definitions” section in this IRP for clarification on certified versus non-certified vessels.

IRP

Pressure vessels are defined by the Provincial Regulatory Agency. All pressure vessels must be designed and registered to their requirements. All certified vessels must have a CRN registered for the province where the vessel is used. Pressure vessels or pressurized tanks used for flow back or storage of fluids produced from a sour well must be manufactured under a quality program to ensure conformance with design specifications utilizing materials meeting the requirements of NACE MR 01-75 LATEST EDITION.

4.2.3.2.2

Pressure Piping

IRP

ASME B31.3 Pressure Piping should be used as the design pressure standard for pressure piping. Appendix 1, Section 4.0.8.13 summarizes the maximum allowable working pressure calculation and nominal dimensions of common carbon and low alloy steels. Section 4.2.6 must be considered for the inspection of all pressure retaining equipment.

Note:

The pressure rating table of Appendix 1, Section 4.0.8.13 has no corrosion allowance. It is the Well Testing Company’s responsibility to ensure that piping systems are derated or replaced when pipe wall thickness is reduced below 0.875 multiplied by the nominal pipe thickness.

Note:

In British Columbia (WCB Regulation 23.69(7)): when flow piping exceeds 3500kPa (500 psi), connections must be welded, flanged or hammer unions. If there is only a threaded connection available at the wellhead, special precautions must be taken.

Note:

Consideration must be given to the use of Emergency Shutdown Valves (ESD’s) on all wells with H2S concentrations exceeding 10ppm. In Alberta, all wells to be flowed having a surface pressure greater than 1379kPa and an H2S content greater than 1% requires an ESD.

Section 4.2

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4.2.3.2.3

Flanges

IRP

ASME flanges have the pressure rating defined in ASME B16.5 Pipe Flanges and Flanged Fittings. Also refer to CSA Z245.12. Unless higher temperatures are encountered, the nominal pressure rating is that at 38 degrees C (100 degrees F). API flanges have the pressure rating stamped on the flange. API 6H fitting use the same class designation as ANSI B16.5 however the pressure / temperature ratings are different.

4.2.3.2.4

Other Connections

IRP

Other connections that are not defined by standards such as ASME, API, CSA, etc. are acceptable (e.g. Hammer unions, Unibolt connections, etc.) provided that: -

The Working Pressure vs Temperature rating is clearly stated by the manufacturer

-

The manufacturer has established the Working Pressure according to proper engineering standards

-

Materials shall be as listed in ASME, API or CSA

-

Fabricated components shall be welded using welding procedures qualified per ASME Section IX. Inspection and testing shall be per ASME B31.3 normal (sweet) or severe cyclic (sour) requirements.

Note:

In British Columbia, documentation regarding working pressure must be available on site.

4.2.3.2.5

Flexible Piping

IRP

Flexible pressure piping (e.g. swivel joints, pressure hose, etc.) should not be used where well effluent internal pressure could exceed 103.4 kPa (15 Psig) in well testing operations.

Note:

Where lines of 33 mm (1") or less are normally filled with a stable fluid (e.g. pressure gauge lines filled with methanol), flexible lines are acceptable.

4.2.3.2.6

Welding of Pipe and Fittings

IRP

Pipe and fitting welding should be to the requirements of ASME Section IX. Post-weld stress relieving is required for H2S service systems (as defined in 4.2.4.1.2) unless special hardness control procedures as defined in NACE MR 01-75 LATEST EDITION are observed. Radiography to ASME B31.3 is recommended.

4.2.3.2.7

Pipe and Fitting Threading

IRP

Line pipe threading should not be used above 17.2 MPa (2500 Psig), for pipe sizes above 33 mm (1" nominal). At a maximum, the line pipe threading ratings of API 6A shall apply, provided that the thread depth ratings of Appendix I are not exceeded.

Section 4.2

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WELL TESTING AND FLUID HANDLING Pipe / Fitting Size To 21 mm (1/2") 27 mm (3/4") - 60 mm (2") 73 mm (2 ½ ") - 168 mm (6") EUE Tubing Threads

Working Pressure 68.9 MPa (10,000 psig) 34.5 MPa (5,000 psig) 20.7 MPa (3,000 psig) 34.5 MPa (5,000 psig)

Refer to the formula for pressure rating seamless pipe on Appendix I, Section 4.0.8.13. 4.2.4

H2s Service Equipment Requirements

4.2.4.1

Metallic Materials

4.2.4.1.1

General

IRP

Metallic equipment in H2S service must be designed to prevent Sulfide Stress Cracking (SSC). NACE MR 01-75 LATEST EDITION, Sulfide Stress Cracking Resistant Metallic Materials for Oilfield Equipment, defines the requirements as a minimum standard. The "Sour Gas" definition of an H2S environment is encouraged (although "Sour Oil and Multiphases" may be used where applicable). An H2S environment exists when the H2S Partial Pressure exceeds .35 kPa (.05 Psia), and the total pressure exceeds 448 kPa (65 psia). H2S Partial Pressure = Mole Fraction H2S x Maximum Operating Pressure.

Note:

Owners and Service Companies should note that this definition of Partial Pressure is not related to definitions of "Sour" by any provincial regulatory body and that Partial Pressure introduces an additional planning consideration.

4.2.4.1.2

Welding of Carbon and Low Alloy Steels

IRP

Post weld stress relieving is mandatory for low alloy steels, and mandatory for carbon steels unless a weld procedure qualification ensures HRC 22 maximum throughout the weld. Radiography to ASME B31.3 is recommended where applicable.

4.2.4.1.3

Exceptions

IRP

Production lines to tanks, flare lines and vent lines may be exempted from complete conformance toNACE MR 01-75 LATEST EDITION if: -

Section 4.2

The lines will not normally be exposed to pressures in excess of 448 kPa (65 psia), and the lines have an adequate pressure rating for short term abnormal service.

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4.2.4.2

Elastomers

IRP

Elastomers for H2S service must be chosen by a combination of manufacturers' recommendations and industry experience, with regard for other products in the well effluent that may degrade elastomers.

Note:

Elastomers are not addressed by NACE MR 01-75 LATEST EDITION, but are required to be chosen carefully to contain well effluents. A reference for elastomer selection is ARP 2.11 Guidelines for Selecting Elastomeric Seals or NACE TM 0187-87 (Standard Method for Evaluating Elastomeric Materials in Sour Gas Environments).

4.2.4.3

Internal Trims of Valves, Controllers, Etc.

IRP

Valves, controllers, etc. should be examined to analyze the possibility of H2S sulfide stress cracking (SSC). (e.g. components in tension are generally subject to SSC, components in compression are generally not). Secondly, the consequences of an SSC failure should be analyzed for the item. If an SSC failure would compromise workers or environmental safety, replacement trims should meet the requirements of NACE MR 01-75 , LATEST EDITION. The following equipment items must have internal trims that meet the requirements of NACE MR 01-75, LATEST EDITION, regardless: -

Wellhead Emergency Shut Down Valves (ESD's)

-

Pressure Vessel Pressure Relief Devices

-

Sleeve or Disc-type Chokes.

Note:

The internal trims of some components exposed to H2S have a much higher possibility of compromising safety and control when they are subject to erosive well products. These components include level control valves, meters, and block / bypass valves. Contractors should carefully consider the practical details of the equipment service.

4.2.5

Well Testing Equipment Material Conformance

4.2.5.1

General

IRP

Equipment fabrication standards must conformance to Sections 4.2.3 and 4.2.4.

Note:

Per Section 4.0.8.5, it is the Well Testing Company’s responsibility to meet pressure ratings and H2S requirements when the Owner has given the proper information; therefore, the Well Testing Company warrants material conformance to the Owner. IRP’s 4.2.3 through 4.2.6 are minimum standards for material identification. More rigid identification systems are appropriate, and are sometimes specified by the Owner.

Section 4.2

be

sufficient

to

ensure

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4.2.5.2

Pressure Vessels

IRP

The manufacturer's tag shall be affixed to the pressure vessel. The Manufacturer's Data Report shall be on file along with the latest Provincial Regulatory Agency inspection certificate and latest pressure safety valve record.

4.2.5.3

Pipe, Forging and Fittings

IRP

Forgings and fittings should be identifiable by API, ANSI, CSA and Original Equipment Manufacturer (OEM) markings. Pipe should be identifiable by fabrication standards, drawings, or purchase orders. Pipe marking by low stress dies is discretionary.

4.2.5.4

Valves, Controllers Meters, Etc.

IRP

Such components should be identifiable through API, ANSI, CSA and OEM markings, or catalogues of OEM products if such catalogues uniquely identify and are traceable to the component.

4.2.5.5

Connections (Hammer Unions, Flanges, Etc.)

IRP

Such components should be identifiable through O.E.M. markings, or catalogues of O.E.M. products if such catalogues uniquely identify and are traceable to the component.

4.2.6

Equipment Inspections

4.2.6.1

General

IRP

Well Testing Companies should establish a routine equipment inspection program, structured to reject or repair service related defects and improper field replacements. The following should be replaced or repaired: -

Components severely worn or damaged (so that they cannot safely perform their operating function)

-

Welds weakened by fatigue cracking or sulfide stress cracking

-

Components subjected to uncontrolled field repairs

-

Components that compromise the pressure rating

-

Components that compromise the H2S service rating.

4.2.6.2

Inspection Guidelines

IRP

Annual or regularly scheduled equipment inspection should consist of the following:

Section 4.2

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WELL TESTING AND FLUID HANDLING -

detailed visual internal and external inspection, where possible

-

random thickness tests on pressure vessels and piping components focused on areas most likely to erode, corrode or deteriorate -

at least one Weld Flaw Detection per pressure specification

-

repair / replacement of rejected components

-

hydrostatic testing of each pressure component to 1.5 times working pressure.

Note: Several inspection frequency processes are available, for example on a calendar or usage basis. Well testing work can subject equipment to exceptional short term corrosion and erosion, which may necessitate additional inspection. Exceptional corrosion can be caused by acids, solvents, high chloride content, and CO2 with H2S. Where exceptional corrosion could be expected, programs should be modified to eliminate as many system elements as possible (without compromising safety). Exceptional erosion can be caused by any well debris, and is common with frac sand returns. Programs in high erosive situations should be modified to include elements of the following: -

Reduce the rate to minimize erosion

-

Direct well flow to a 2-choke manifold, followed by a combination separator / storage vessel with large cleanout openings: extra methanol injection may be required for hydrate inhibition

-

Direct well flow to a solids separator or filter.

Equipment should be designed, fabricated, inspected and tested to the intended most severe service to minimize the effects of corrosion, erosion cracking, etc. Use of treated (cobalt cased) or coated components should be evaluated to minimize the effects of erosion. 4.2.7

Well Testing Equipment Spacing

IRP

The schematics of the Appendices should be used as general guidelines to meet spacing requirements and provincial regulations. If the spacing cannot be met, it is the Owners responsibility to obtain permission from the local authority for changes. Some spacing requirements are listed below.

Note:

The water tank solution gas hazard should be evaluated before reducing the distances. The appendices are intended to specify minimum spacing and not equipment layout or piping details. IRP 4.3 must be referenced when well testing is combined with other flow back operations.

Note:

The Provi nce of British Columbia, Drilling and Production Regulation on Fire Control s. 62 (c) specifies the required distance from a separator to a flare stack to be 50 meters versus 25 meters in other jurisdictions. As a recommended practice, it suggests that all equipment should be 50 meters from the flare stack for safety and fire considerations.

Section 4.2

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4.2.7.1

Equipment Spacing For Propane Tanks

IRP

Distances for placement of skid mounted or free standing propane storage vessels are not regulated. The following shall be considered before placing this equipment. -

When in use with a vaporizer the equipment placement distance must meet the minimum distance requirement of the local authority for open flame equipment from the wellhead. Consideration must be given to all other potential sources of vapor when selecting a site to position the vaporizer ( to prevent a fire or explosion)

-

Propane tanks must not be located within any tank dyke

-

The vaporizer must be a minimum 25 meters from the propane storage tank(s)

-

It is recommended the interconnecting pipe from the propane storage tanks to the vaporizor be hard-piped and the interconnecting material must be manufacturered to maintain integrity for short periods in a fire

-

The vaporizer should be inspected and cleaned regularly by a certified propane equipment supplier

-

filling of propane tanks above 85% capacity is not allowed (80% in British Columbia)

-

Position of supply and filling lines to be outside of high traffic areas, i.e. foot and vehicular

-

Tarping propane vessels for use with external heat sources to vaporize liquid propane during cold weather operations is not recommended

-

Valved ports on the propane storage tanks should be plugged prior to transport.

Note:

Reference the appropriate Provincial Department of Transport for guidance when transporting oilfield skid mounted propane tanks with product in the tanks.

4.2.7.2

Equipment Spacing For More Than One Certified Pressurized Tank

IRP

Where two or more certified pressurized tanks are used as either a primary flow vessel or for storage of fluids, the tanks must be a minimum of 25 meters from the wellhead and can be placed side-byside.

Note:

Provincial jurisdictions may vary in the distance requirement. Refer to the appropriate regulatory agency for clarification.

4.2.7.3

Equipment Spacing For Non-Certified, Non-Registered Vessels Or Pressure Tanks

IRP

All non-registered non-certified vessels or pressure tanks must be at least 50 meters from the wellhead and 50 meters from the flare stack or any open flame.

Section 4.2

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4.2.8

Pre-Test Equipment Check And Pressure Test

IRP

The following pre-test checks should be performed: -

Ensure that an inspection check list is followed

-

Ensure that all connections are tightened

-

Ensure the wellhead flowline is adequately secured to restrict movement of the line in the event of failure

-

Ensure gas flaring lines and fluid production lines are adequately secured

-

Ensure the wellhead ESD (if applicable) is function tested

-

Ensure the purging is completed per 4.0.8.26

-

Ensure the safety meeting has been completed per 4.0.8.17.

Note:

An Inspection Check List is included in the Appendices, developed by the UPITFOS Implementation Committee (1990). Applicable details of the checklist are recommended.

4.2.8.1

Pressure Testing in Daylight/Darkness

IRP

Following the rig in of test equipment and associated flowlines, pressure testing of the lines and equipment using a gaseous medium must be conducted in daylight hours only. If the integrity of the piping system has been broken at anytime after the initial pressure test, subsequent pressure tests using a gaseous medium must be in daylight hours only.

IRP

Hydraulic pressure testing may be conducted at night provided the conditions of section 4.2.9 are met.

Note:

See Section 4.2.9, Operational Safety, for night time start up procedures.

Note:

In British Columbia hydraulic pressure testing is a requirement on all high pressure piping systems up to the first pressure control choke. The pressure test must be not less than 10% above the maximum anticipated operating pressure as determined by the well owner. When nitrogen is used in well stimulation, the piping system may be pressure tested with nitrogen. See British Columbia WCB regulation Section 23.72 for more detail.

4.2.8.2

Wellhead to Choke

IRP

It is the Owners responsibility to specify the pressure test medium. Hydraulic testing is recommended over the use of wellhead gas or pressurized vapor (CO2 or N2). The test must be to the maximum of expected wellhead shut-in pressure. No leaks are to be tolerated. Pressure testing with a gaseous medium must be conducted in daylight hours only.

Section 4.2

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4.2.8.3

Pressure Testing on Critical Sour Wells

IRP

On wells defined as Critical Sour the flowline from the Wellhead to the Choke must be hydraulically pressure tested to a minimum of the expected Shut in Tubing Head Pressure (SITHP).

4.2.8.4

Downstream of Choke

IRP

An inert medium or wellhead gas should be used to pressure test vessels to a minimum of planned operating pressure and a maximum of 90% of pressure relief device set pressure. Any interconnecting piping must be included. No leaks are to be tolerated. Where water is used for a hydrotest, ensure a product to negate ice build up is used in sub-zero operations.

4.2.8.5

Open Ended Piping and Production Tanks

IRP

Open ended piping (flarelines, vent lines) and production tanks should not be isolated by valves and pressured tested. Closed valves should not be in the system. Instead, leak tests of open ended piping and production tanks must be part of initial operational checks after start up. Visual inspection of connections is an alternative.

4.2.9

Operational Safety

4.2.9.1

Start Up at Night

IRP

If required through necessity to start up at night, after a daylight pressure test was conducted, or a night time hydraulic pressure test was conducted, the following conditions must be met: -

Provisions are in place for lease lighting of a capacity to maintain safety of the site workers, allow the worker to perform his routine duties safely and to ensure visibility for the worker to safely exit an area in an emergency

-

A hazard assessment has been conducted and documented

-

The hazard assessment deems the start up safe for the worker

-

All non-essential workers are vacated from the immediate area of the testing equipment, flowlines and wellhead. These workers shall not return to the area until cleared to do so by the Owners Wellsite representative after consultation with the Well Testing Supervisor/ Manager

-

The crew is well rested.

4.2.9.2

General Start Up Procedure

IRP

The following generalized start up sequence should be performed: -

Section 4.2

all non-essential workers must vacate the surrounding area of the testing equipment, flowlines and wellhead. These workers shall not return to the area until cleared to do so by the Owners Wellsite Page 67

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-

representative after consultation with the Well Test Supervisor/ Manager The use of an ESD valve has been considered. In Alberta, all wells with a pressure greater than 1379 kPa and an H2S content greater than 1% require an ESD valve on the wellhead

-

With wing valve closed, open the master valve and record pressures

-

Close the choke (if applicable) and open the wing valve to the choke. Perform a detailed leak check

-

Open the choke slowly to the pressure vessel. Set operating pressures immediately, and set liquid levels as soon as possible

-

Begin vessel leak checks immediately, closely followed by downstream checks. For sour wells, those performing detailed leak checks must wear respiratory equipment

-

Check H2S concentration as soon as possible, and at regular intervals thereafter. Shut in the well if additional equipment or workers are required

-

Check equipment capacities. If pressures or rates exceed capacity, decrease the rate or shut in the well.

Note:

A rate preceding the actual test is appropriate to cleanup the well and to reevaluate the programmed well performance.

4.2.9.3

Test Performance

IRP

The test should be performed according to the following generalized guidelines : -

Perform and record measurements according to the program and provincial guidelines

-

Continuously monitor safety systems and equipment

-

Continuously monitor air entrainment in tanks (per 4.0.8.26)

-

Utilize the Safety Standby Method for all hazardous operations, and utilize a 2nd back-up worker during sour hazardous operations

-

Monitor flare rates and volumes according to the flare permit (if applicable)

-

Monitor and act on new or unanticipated hazards

-

Hold complete de-briefing sessions at shift changes per 4.0.8.17.

IRP

If the equipment or the procedure cannot safely accommodate the flow, the Well Testing Company’s supervisor of the shift has the ultimate authority to reduce the flow or shut in the well, after consultation with the well owners representative. If the representative is not available, the well testing supervisor will assume the responsibility to reduce the flow or shut the well in.

4.2.9.4

Shut In And Post-Test Procedures

IRP

The following generalized procedures should be followed: -

Section 4.2

shut in by closing the choke followed by the wing valve Page 68

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monitor shut in wellhead pressures per the program

-

shut in master valve(s)

-

displace all produced fluids to storage (or pipeline)

-

for sour or toxic wells, purge the sour or toxic vapors to flare

-

shut down flares

-

rig out and remove equipment from location

-

chain and lock wellhead valves

-

it is recommended all solid bullplugs in the wellhead be replaced with tapped plugs with a needle valve to check for pressure leakage past all wellhead valves. Ensure the pressure rating of the fittings exceed the wellhead shut in pressure

-

inform well operator of status of stored fluids still on location

-

remove debris and garbage from location.

4.2.10

Well Testing Workers

IRP

The Owner of the well must ensure there are an adequate number of qualified well testing workers on the wellsite at all times to conduct operations safely. The following identifies key situations and recommends a minimum number of workers required to conduct the operation safely and efficiently.

4.2.10.1

Recommended Minimum Well Testing Workers on a Wellsite During Testing Operations

IRP

All Owners and Well Testing Companies must exercise caution and good safety judgement in the selection of well testing equipment components and the number of qualified well testing workers. Gas/liquid deliverability, pressure and toxic vapors such as H2S must be considered. Test equipment should be selected which reduces the risk of workers being exposed to toxic vapors. Pressurized storage for the liquid phase is one method of significantly reducing the toxic vapor hazard. Per 4.2.3.2, vessels for pressurized storage must meet the requirements of Provincial Regulatory Agencies. Unregistered noncertified vessels must have adequately sized pressure relief devices to prevent bursting.

IRP

For well testing, a minimum of two (working) qualified test workers per shift are recommended. If an Owner chooses to conduct a continuously manned testing operation without the services of a well testing company, the minimum worker recommendations still apply.

4.2.10.2

One Qualified Well Testing Worker Per Shift One qualified well testing person per shift may be used on sweet or sour wells in the following circumstances: -

Section 4.2

The individual has the knowledge and qualifications to perform as required

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The individual is in a supervisory capacity only, supervising two (2) other workers at the site, in non-flowing operations such as swabbing, circulating, venting or bleeding off a well directly to a certified registered pressurized tank

-

The workers at the site assigned to the well testing supervisor are willing and capable of operating well testing equipment as instructed

-

The well is not flowed continuously to establish gas or fluid rates

-

Where equipment rigged in a sour inline mode is automated and remotely controlled, the well Owner may summon one (1) qualified representative from the Well Testing Company to the location for consultation or calibration of equipment as long as a qualified Owning Company representative is present on the location at the same time

-

Where the well tester is installing electronic data gathering equipment on existing facilities.

4.2.10.3

Two Qualified Well Testing Workers Per Shift

IRP

Regardless of well parameters, consideration must be given to the amount of equipment the crew is expected to operate effectively and safely. The workers ability to maintain a safe work environment and efficient operations is the prime consideration. A minimum of two qualified well testing workers per shift are recommended in the following circumstances:

Section 4.2

-

All sweet wells flowed through test equipment

-

The operation is a sour inline test, with all measured well effluents at the separator diverted back to the pipeline

-

A sour operation with essentially no inflow from the producing zone, such as the servicing of a hydraulically killed well, or where the formation is mechanically isolated

-

A sour operation where the final sour liquid storage stage for produced fluids is a certified registered pressurized vessel or tank and the pressure vessel or tank is not preceded by more than one (1) separation stage

-

A sour operation where the final liquid storage vessel is a nonregistered non-certified vessel preceded by a certified registered vessel or tank, provided the operating pressure of the non-certified non-registered vessel or tank does not exceed 50% of the design pressure

-

A sour operation where the final sour liquid storage stage is an atmospheric tank system where; the tank(s) and thief hatches are designed for a maximum of 7 kPa working pressure, and there is a maximum of two (2) atmospheric tanks, and •

The operating pressure at the atmospheric tank system does not exceed 50% of the design pressure, and

•

The atmospheric tank system is not preceded by more than two (2) separation stages including a gas boot, and Page 70

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4.2.10.4 IRP

•

The atmospheric tank system is gauged only at shift changes where more than two (2) workers are present, and

•

The H2S concentration does not exceed 5% (50 moles per kilomole)

Three Qualified Well Testing Workers Per Shift Regardless of well parameters, consideration must be given to the amount of equipment the crew is expected to operate effectively and safely. The workers ability to maintain a safe work environment and efficient operations is the prime consideration. Additional procedures such as tank gauging, circulating fluids, operating line heaters, use of tank-farms and operation of choke manifolds in erosive environments will require additional personnel. Consideration must be given having an adequate number of workers to effectively respond to any emergencies that may arise. If the conditions in Section 4.2.10.3 cannot be met, a minimum of three qualified well testing workers per shift are recommended.

Note:

If maintaining the atmospheric tank pressure below 50% of the thief hatch operating pressure becomes a problem, excess solution gas may be reduced by some or all of the following methods: -

Use of pressurized tanks

-

Reducing the well effluent flow rate (i.e. reduce choke,

-

Reducing the operating pressure of the separation stage(s) upstream of the tanks

-

Adding heat upstream of the last separation stage

-

Increasing the tank vent line and tank vent line flame arrestor size.

If such operation cannot rapidly eliminate excess toxic vapors, the well must be shut in and additional equipment and/or workers called out. Note:

When storage stage gas is flared, additional precautions to prevent air entrainment are required, per Section 4.0.8.26.

4.2.10.5

Minimum Well Testing Worker Qualifications The following is the minimum qualifications Well Testing workers must possess in training, certification and competence. PSAC Standards of Competence have been developed for Supervisory job classifications. These standards are registered with the Petroleum Industry Training Service (PITS) and are recognized by the Petroleum Services Association of Canada (PSAC). Well Testing companies should consider these Standards of Competence when qualifying their workers.

IRP

Workers must have the listed minimum qualifications. Assistant Operator (Reports to Shift Leader): -

Section 4.2

Individual must have H2S Alive (or equivalent) and First Aid Certificates Page 71

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Individual must have WHMIS and TDG training

-

Individual must be able to drive and perform routine repairs on service vehicles

-

Individual must have basic knowledge of employers safety policies and emergency procedures

-

Individual must understand IRP 4.0 as it applies to the individual's job function

-

Individual must have basic knowledge of equipment functions.

Shift Foreman/Operator/Shift Supervisor (Leads One Shift And Reports to Test or Job Supervisor/ Project Manager) (In addition to Assistant Operator qualification) -

Individual must have command of basic testing skills (in order to be able to lead a shift with minimum supervision)

-

Individual must have thorough knowledge of employers safety policies and emergency procedures

-

Individual must know pressure ratings of system elements

-

Individual must be thoroughly trained in use of safety equipment Individual must be able to identify dangerous conditions and act accordingly

-

Individual must understand safety responsibilities of assistants.

Test or Job Supervisor/ Project Manager (Well Testing Company’s Overall Supervisor) (In addition to Shift Foreman/Operator/Shift Supervisor qualifications):

Section 4.2

-

Individual must be able to command entire test with no supervision

-

Individual must be able to coordinate test with well owner

-

Individual must be able to train assistants, and monitor progress/ deficiencies

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Appendix II Lease Layout Schematics

Section 4.2

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Section 4.2

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Section 4.2

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Section 4.2

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Section 4.2

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Section 4.2

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Section 4.2

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Appendix II - Production Testing Services Inspection Checklist

CONTRACTOR: _____________________________

OPERATOR: ___________________________________

LEASE LOCATION AND LSD: ___________________

CRITICAL SOUR WELL (Y/N): ______________________

SERVICE COMPANY : _________________________

SERVICE COMPANY REP.: _______________________

INSPECTED BY: _____________________________

DATE: 20__ ___ ___ TIME: _____Hrs. yr. mo. day 24 hr. clock

WELL ACITIVITY: _____________________________________________________________________________ Mark a check if "adequate or inadequate" or "-" if not applicable (Note: Any "INADEQUATE" must have an explanation and be corrected) A.

Signs

01

No Smoking

30 Remote Shutdowns (OST)

02

Designated Smoking Area

31 Gauge in place

03

D.

04

No Vehicles or Unauthorized Persons Danger High Pressure

05

H2S (if required)

06 B.

Sign with Operator name or phone # Personal Safety

07

Emergency Response Plan complete

E.

08

Pre-start up Safety Meeting

09

Hard hats (CSA approved)

36 Pipe schedule ______________ 37 Working pressure _____MPA

10

Safety footwear

38 Pressure Tested (Hydro)

11

Ear Protection

39 Secured

12

Eye Protection

40 Blocked Level

13

First aid supplies

F.

14

Certificates:

41 Secured

a) H2S

42 Blocked Level

b) First Aid

G. Pop Line

c) WHMIS

43 Pipe Size _____ 44 Secured

15

d) Transportation of Dangerous Goods Fire retardant clothing

16

Facial Hair

46 Pop Riser Pilot in place

17

Fire Extinguishers #____

18

Floor Lights

19

H2S gas detector (manual)

Section 4.2

ADEQ

# ____

/ INADEQ

ADEQ / INADEQ

Flowline

32 Pipe schedule ______________ 33 Working pressure _____MPA 34 Pressure Tested (Hydro) 35 Blocked Level Deadweight Line

Gas, Oil and Waterline

45 Blocked Level 47 Riser Secured H.

Other

48 Check valve in place on pipeline

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WELL TESTING AND FLUID HANDLING Appendix III - Production Testing Inspection Checklist - Page 2 20

Work masks worn outside

21

Side packs checked

22

Back packs checked

49 plant operators notified of procedure 50 Flame arrestors in place _____ 51 Flame arrestor __________in.

23

Air supply checked

52 Flame arrestor checked

24

Two air lines reach tanks

25

Wind direction indicators

C.

Wellhead

26

Clean

53 Purge system in place for tank trucks 54 H2S Scrubber in place for 400bbl tanks 55 H2S Scrubber in place on Tank trucks 56 Tank lines checked

27

Working Pressure ___MPA

57 Tank manifold checked

28

All valves seal

58 Tank manifold Bonded to tanks

29 I.

ESD Valve Working Pressure ___ MPA Shipping Line

M. Spacing

59

Bonded to Tank

103 Wellhead to Separator 25m

60

Length ___m

104 Separator to Tank 25m Min

61

Blocked Level

105 Separator to Stack 25m Min

62

Drip Pail

106 Wellhead to Tanks 50m

63

Valve

107 Tanks to Flare 50m

64

Truck Bonding

108 Flare to Wellhead 50m

65

Fire Extinguisher

J.

Propane Line

66

Hard pipe to vaporizor

67

Blocked Level

68

Bonded

K.

Tanks

69

Bonded to Wellhead

109 Certified Ptank to Wellhead 25m 110 Non-certified Ptank to Wellhead 50m 111 Vaporizer to Propane Tanks 25m N. Circulating Pump & System 112 Check Valve Working Press. ___MPA 113 Storm Choke Working Press. ___MPA 114 Reservoir Full

70

On Planks

115 Flowlines Blocked

71

Level

116 Heater Checked

72

Valves Work

73

Valves Set

117 Upper coil schedule _______

74

Tank Stairs

75

Thief Hatch Seal

118 Upper coil working prs. ____MPA 119 Stack Gasket Checked

Section 4.2

O. Heater

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Gas Blanket

120 Bath full

77

Tanks Purged

121 Choke Inspected

78

Vertical line _________in.

122 Supply Gas Checked

79

Flame arrestor _______in.

123 Pilot Checked

80

Flame Arrestor Checked

124 Main Burner Checked

81

Block Valve

125 Flame Arrestor Checked

82

Vertical line secured

126 Heater preheated

83

Drain At Low Point

84

Stack Line Clear

85

Vertical line bonded

127 Separator working prs. _____MPA 128 Relief Valve Checked

86

Berm Checked

129 Pressure Tested

87

Pressure Alarm Set

130 Valves Operational

L.

Stack

131 Lines Clear

(Dia.___mm. x m.___ )

P.

Separator

88

Lines Clear

132 Instrument Supply System Checked 133 BP Valve Stroked and Set

89

Pilot Checked

134 Front Manifold Set

90

Shooter Tube Checked

135 Inside Valves Set

91

Flare Catcher Checked

136 Deadweight Manifold Set

92

Igniter checked

137 Deadweight Line Full

93

No. Guy Wires

138 Methanol Barrel Safe

94

0-15 meters Wires (3)

139 Liquid meters by-passed

95

15-35 meters Wires (3 minimum)

140 Floats Checked

96

35-60 meters Wires (6 minimum)

141 Dump Controllers Set

97

Correct Angles Flagged

142 Hi-Low's Checked

98

3 Clamps/Cable (1" apart)

99

Clamps Correct Position

100 Shackles tight 101 Stack Straight 102 Fire Hazard Checked Q.

Lease Trailer Light Plant

R.

General

158 Flash Lights C1-D1

143 Safety Board

159 Test Program Available

144 Portable Water

160 Chemical clothing

145 Safety Binder

161 Mobile Phone good working order 162 Test Kits Checked

146 WHMIS Labeling 147 Emergency Response Plan Posted 148 Safety Meeting Posted

163 Purging Complete

149 Flare Permit Posted

165 Flaring permit obtained

150 Fire Extinguisher

166 Area residents notified

Section 4.2

164 Government Notified

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WELL TESTING AND FLUID HANDLING Appendix III - Production Testing Inspection Checklist - Page 4 151 Fire Blanket 152 Furnace lit 153 Office area clean 154 Lockers Clean 155 Bench Area Clean 156 Floor Clean 157 Step Level

S.

Comments/Explanations

Owner Representative: ____________________________

Signature: _______________________________

Contractor Representative: ________________________

Signature: _______________________________

Service Company Representative: ____________________

Signature: _______________________________

Section 4.2

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Appendix IV - Logic Chart

Section 4.2

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4.3

OTHER FLOWBACKS

4.3.1

Scope The Other Flowbacks IRP was developed by the Well Testing and Fluid Handling Subcommittee of the Drilling and Completion Committee (DACC to establish minimum recommended practices for equipment requirements, procedures and workers. The safe handling of fluids associated with well killing, coiled tubing unit (CTU) operations, and stimulation (swabbing, fracturing, etc) operations are emphasized on sweet well flowbacks utilizing open tank systems. Criteria are included for monitoring explosive mixtures on sweet and sour well flowbacks using closed tank systems. Criteria are provided for pumping of High Vapour Pressure (HVP) hydrocarbons with a Reid Vapour Pressure greater than 14 kPa or 50 API gravity. It is recognized by the Committee that some of the recommendations of this IRP are onerous to “shallow gas well projects” and projects involving multi-well operations such as “rod jobs”. The IRP does not intend to cause undo operational and economic hardship to any owner/operator in the use of these IRP’s on shallow gas and multi-well projects. In specific circumstances where the IRP’s do cause operational and economic hardship on these type of projects, the owner/operator may apply commom practices currently in place by the owner/operator that meet the intent of this IRP and Occupational Health and Safety Standards - to provide a standard of safety for the worker, the equipment and the general public.

4.3.2

Flowing, Pumping Or Circulating A Well To An Open Tank System

Note:

See Section 4.3.5.4 for IRP’s on Monitoring and Supervision of Open Tank Systems.

IRP

In operations where wellsite personnel or nearby residents have the potential to be exposed to sour gas or fluids (>10ppm), the fluids must be contained in a closed system.

IRP

In operations where gas vapours are expected from produced fluid, the hazards to on-site workers, equipment and the public must be assessed and deemed safe before proceeding. Hold and document a hazard assessment meeting on the site with all personnel prior to beginning operations. The meeting should include discussion of procedures, sources of ignition, personal protective equipment and identification of harardous atmospheres. The report must be posted on the site.

Note:

The Canadian Association of Oilwell Drilling Contractors (CAODC) has a standard hazard assessment form for use in daily operations.

Section 4.3

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All open tanks shall be positioned a minimum of 50 meters from the wellhead and 50 meters from any open flame sources.

IRP

A “safety zone” of 50 meters in all directions from the open tank must be established and relayed to all persons on the site, when flowing, circulating or pumping to an open tank system.

IRP

No worker(s) shall enter the “safety zone” while flowing, circulating or pumping to an open tank system. An exception is the pump operator who must be in the zone to operate the pump if fluid transfer or circulation is required. Precautions must be taken to ensure the safety of the pump operator, such as wind direction flags visible to the pump operator and H2S/LEL monitoring between the pump and the open tank system.

Note:

The use of an external gauge on the tank will aid in monitoring tank levels from outside the “safety zone”.

IRP

A minimum of one person per shift must be trained and competent in the use of an explosive monitoring device, (LEL meter). The LEL meter must be calibrated to propane.

IRP

All workers involved with flowing, circulating or pumping operations to open tank systems shall wear appropriate fire retardant workwear.

IRP

All sources of ignition possible.

IRP

No smoking is allowed anywhere on location while flowing, circulating or pumping to open tank systems.

IRP

Wind indicators must be placed near and around the open tanks. Consideration of wind speed and direction shall be considered prior to start up.

IRP

The operation shall be shutdown where excessive flows are encountered and before fluids are splashed or flowed over the sides of the open tank system.

IRP

Flowing or startup after dark is permitted only where absolutely necessary. Adequate lighting must be available.

IRP

All flows must be controlled using a choking device other than the wellhead wing valve.

IRP

The piping system must be designed to accommodate pressure, H2S, erosion and any other products that may compromise the integrity of the piping system. The line must be set up with a tee such that if there is no fluid being recovered, the gas can be diverted to a flare stack or riser to be vented or burned. The piping system must be properly secured to restrict movement of the line.

Section 4.3

must be eliminated and locked out where

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Physical gauging of open tank systems will only be done once the area is proved safe by the LEL meter.

IRP

Any loading/unloading of fluids from open tank systems shall be done with the well shut in and only after the area has been checked with an LEL meter and H22 detector.

IRP

While flowing, circulating or pumping wells to an open tank system where gas vapors are vented to atmosphere signage indicating “gas vapors are venting to atmosphere” must be positioned to impede entrance to the wellsite by all vehicles.

IRP

After the flowing, pumping or circulating operation to an open tank system is complete or shutdown, no person(s) shall enter the “safety zone” until an H2S detector and explosive detection device indicates the area is safe for entry. These readings must be recorded in a daily log or safety report. Proper PPE must be worn while operating a gas detection meter in the hazardous environment.

4.3.3

Wellhead Control

IRP

4.3.4

Well control equipment should be selected having regard for Section 4.2.2 , Well Testing. Location Of The Rig Pump

IRP

The rig pump should be located a minimum of 7 m from the rig tank. Ensure that the rig pump is not located downwind of the rig tank and if so, extend the separation to 14 m. IRP 4.3.5.6 provides additional recommendations regarding potential ignition sources.

4.3.5

Procedures

4.3.5.1

Well Killing Operations

IRP

During well killing operations, where possible, the well should be flowed into the facility pipeline or production facility. If the facility pipeline is utilized, the backpressure imposed by the line-pac should be considered. If production facilities are used, the pump rate should not impart a pressure exceeding the burst rating of the system.

Note:

The use of a pipeline, production facility or a pressure tank is an alternative to reduce explosion hazards. Flowlines, pressurized tanks or atmospheric tanks equipped with suitable vapour gathering - flaring/scrubbing systems are alternatives to eliminate any H2S releases to atmosphere (nuisance odours and public or personal safety). In Alberta, AEUB inspection policies regarding the handling of sour effluent are included in AEUB Guide G-37 Service Rig Inspection Manual.

Section 4.3

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In British Columbia, the Oil and Gas Waste Regulation of the Waste Management Act, Section 3 states, “ The owner or operator of a piece of equipment or a facility referred to in section 4 or 6 (1) must ensure that the one hour average ambient ground level concentration of hydrogen sulphide due to the discharge of air contaminants from that equipment or facility does not, at the perimeter property on which the equipment or facility is located, exceed 10 parts per billion by volume.” The Oil and Gas Waste Regulation also in section 4 (g) authorizes discharges to the air of contaminants by owners or operators of “equipment or facilities that vent to the air, for the purpose of maintenance of the equipment or facilities, (i) natural gas that contains less than 230 milligrams of total sulphur per cubic meter of natural gas, or (ii) natural gas that contains at least 230 milligrams of total sulphur per cubic meter of natural gas if the natural gas is combusted in a flare or equivalent.”

4.3.5.2

Coiled Tubing Unit (CTU) Operations Using Air Air is sometimes used in coiled tubing clean outs in shallow gas wells with low formation pressure, where no condensate or H2S is present in the formation fluid, and there is a low flow rate expectation from the well.

Note:

Nitrogen gas is recommended for higher risk wells.

IRP

A safe operating procedure should be followed. A written procedure including a hazard assessment should be available on-site with consideration given to the following: -

Recommendations from IRP 7.0 Coiled Tubing Operations for Drilling and Servicing

-

Wind direction

-

Proper grounding of equipment

-

Safe and effective control and handling of well effluent

-

Ensure that all the air has been displaced from the well, after the job, before shutting in or producing the well.

4.3.5.3

Operations at Night

IRP

Where possible, flowback, swabbing, and coiled tubing operations should be conducted during daylight hours. Adequate lighting must be provided if it is necessary to continue operations into the night.

IRP

Operations that will involve the bleeding of gas to open systems under the cover of darkness must proceed only where absolutely necessary. This will include flowback, swabbing and coiled tubing operations.

Note:

Reference the “Definitions” in this IRP on adequate lighting.

Section 4.3

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4.3.5.4

Monitoring and Supervision of Open System Rig Tank

IRP

Where the Owner does not have a site representative, the Owner shall ensure a gas detection meter is available to the site workers. See Section 4.0.8.1.

IRP

The Owners on-site representative shall have training and competence in the operation of an LEL meter. The Owners representative shall possess or ensure availability of an LEL meter on all sites where vapors are expected to be vented to atmosphere.

IRP

No worker shall enter the 50 meter “safety zone” around an open tank system where gas vapors have been vented to atmosphere until cleared to do so by the Owners site representative or the worker who is responsible for monitoring the area with a gas detection meter.

IRP

Where an Owners representative is assigned to the site, the representative must be present during all operations were a well is flowed, pumped or circulated to an open tank system where gas vapors are not contained. Where an Owners representative is not assigned, the contractor must provide a supervisor during these procedures involving open tank systems.

IRP

Before commencing bleed-off, flowback, swabbing, pumping or well killing operations, all non-essential workers must vacate the surrounding area of the tanks, flowlines and wellhead. These workers shall not return to the area until cleared to do so by the Owners wellsite representative after consultation with the Rig Supervisor.

Note:

Well killing/circulating/flowbacks are critical and technical procedures. The Owners representative and/or the rig manager, being the most experienced in both technical and practical aspects, must be on location during these operations to provide supervision and to judge proper responses to fluid handling, explosion monitoring, equipment utilization, and safety procedures. In particular, workers not necessary to the operation are to be vacated from the immediate area.

4.3.5.5

Swabbing

IRP

A check valve and an additional shut-off valve must be installed on the flow tee outlet. The shut-off valve must be closed while running in the hole. Check valves do not always seal 100%. The manual shut-off valve is a backup for the check valve. Consideration should be given to using a purge medium to follow swab cups while running in the hole.

Note:

The purpose of this procedure is to prevent drawing air or the flame from the flare into the production tank or into the tubing when running the swab cup back into the well. The introduction of air into the system can lead to a combustible mixture. IRP 4.2, Well Testing, Section 4.0.8.27 (Air Entrainment) details other considerations for the prevention of air entrainment. Where gases produced are being flared, consideration should be given to maintaining a positive pressure and flow to the flare stack.

Section 4.3

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WELL TESTING AND FLUID HANDLING 4.3.5.6

Control of Potential Ignition Sources

IRP

Shut down of potential ignition sources on location, for example the rig pump, boiler and heaters, if not required for the operation, must be considered during the flowback of volatile hydrocarbons.

IRP

All vehicular access to the well site should be restricted during well killing and flow back operations to minimize the potential for inadvertent ignition of any combustible vapours present on the lease.

IRP

While flowing, circulating or pumping wells to an open tank system where gas vapors are vented to atmosphere signage indicating gas vapors are venting to atmosphere must be positioned to impede entrance to the wellsite by all vehicles.

Note:

Improved wellsite security will ensure that individuals who are required to use vehicles in proximity to the wellbore, open system rig and storage tanks will only be able to under the supervision of the Owners representative and/or the rig manager.

4.3.5.7

Safety Checklists

IRP

A safety checklist should be utilized when planning and undertaking an operation involving the pumping into and flow back of fluids from a well.

Note:

The Upstream Petroleum Industry Taskforce on Safety (UPITFOS) developed a series of checklists for a variety of operations. They are available through the industry associations, for example Petroleum Services Association of Canada (PSAC). An outline is shown in IRP 4.2 Well Testing, Appendix Section.

4.3.6

Well Site Workers

4.3.6.1

Minimum Workers and Training Requirements

IRP

The Owner of the well must ensure there are an adequate number of qualified workers on the wellsite at all times to conduct operations safely. The following identifies key situations and recommends a minimum number of workers required to conduct the operation safely and efficiently.

IRP

On non-critical sour wells where well testing workers are not employed, a minimum of two (2) people are required to directly monitor flowback operations. Where well testing workers are not employed the Owners representative or the rig manager must supervise the operation and the two workers.

Section 4.3

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For critical sour wells, IRP 2, Completing and Servicing, Section 2.15 Well Site Worker Training and Experience, and IRP 4.2, Well Testing, must be adhered to.

IRP

On non-critical sour wells, a minimum of two (2) people at the well site involved in flowback operations shall have valid first aid certificates and H2S training.

Note:

Standard St. John First Aid or equivalent.

IRP

All persons expected to control pressure rated equipment used during flowback, swabbing, coiled tubing or well killing operations, should have training in the operation of pressure vessels and pressure rated equipment.

Section 4.3

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4.4

LOADING, UNLOADING AND TRANSPORTATION OF FLUIDS

4.4.1

Scope The Original ARP’s (Alberta Recommended Practices) for the loading and transportation of fluids were developed by the Well Testing and Fluid Handling Subcommittee of the Drilling and Completions Committee (DACC) in 1987 to establish minimum recommended practices for the loading, unloading and transportation of wellsite fluids. The IRP’s (Industry Recommended Practices) incorporate, update and replace the Alberta Recommended Practices (ARP Volume 4 “Well Testing and Fluid Handling”, Section 4.4 entitled “Loading, Unloading and Transportation of Fluids”). These IRP’s were developed through 1998 and scheduled for approval and implementation in 1999. These IRP’s outline procedures to minimize the likelihood of tank explosions during loading or unloading for both temporary wellsite production testing and subsequent production facility operations, as well as to control H2S emissions. The procedures can also be utilized for the safe handling of High Vapor Pressure (HVP) hydrocarbons.

4.4.2

Fluid Hauling Company Procedures

IRP

Section 4.4

Fluid Hauling companies must adhere to the following procedures and practices. -

Stop at the entrance to all sites before entering to check for the possibility of gas vapors venting to the atmosphere where the vehicle is intending to drive

-

Ensure the consignor (shipper/owner) has provided appropriately completed shipping documents and placarding as required by law

-

Ensure that tank specification is acceptable for fluid characteristics defined in shipping documents. The design and construction of the tank must be capable of handling the sour fluid to be hauled

-

Ensure drivers are properly trained and educated to the handling of flammable and / or sour fluids

-

Provide proper safety equipment which is maintained in good working order (i.e. Personal protective equipment (hardhat, footwear, eyewear, clothing, H2S monitor, SCBA, etc.), fire extinguishers, and radio or telephone)

-

All trucks should be equipped with a 30 minute Self-contained Breathing Apparatus (SCBA)

-

treat sweet fluids being hauled immediately after a sour load as a sour load with respect to worker safety

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4.4.3

-

list all necessary H2S equipment on a pre-trip check list

-

maintain all equipment valves, fittings, hoses and hatch seals in good working order

-

ensure trucks with diesel engines have intake air shut-offs

-

maintain a contingency plan including procedures for truckingrelated spills.

Fluid Charactaristics

IRP

The properties of any fluids to be loaded, unloaded or transported are to be evaluated for the following hazards from information in the shipping documents: -

Toxicity Flammability Corrosive effects Environmental impact of escaped fluids Flashability

IRP

Well Owners and transporters of fluid must make or have available Material Safety Data Sheets (MSDS) to workers. Refer to Section 4.0.8 Produced fluids for more information.

Note:

Material Safety Data Sheet and Transportation of Dangerous Goods information may provide valuable information to assess any toxicological or flammability hazards. Other sources of produced fluid properties information includes well testing and reservoir fluid analysis, regulatory production reports or custody transfer (point of sale) measurements. Properties that should be considered include: explosive limits, flash point, boiling point, Reid Vapor Pressure, chemical composition, and toxicity information.

4.4.4

Loading, Unloading and Transportation Practices

4.4.4.1

Closed Systems The use of a closed system (pressurized tanks or atmospheric tanks equipped with suitable vapor gathering – flaring / scrubbing systems) may be necessary to eliminate any H2S releases to atmosphere (nuisance odorous and public or personal safety). The duration of operation, proximity to, and notification of area residents, should be considered. Inspection policies regarding the handling of sour effluent in Alberta are included in Alberta Energy and Utilities Board Guide G-37, Service Rig Inspection Manual.

Section 4.4

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WELL TESTING AND FLUID HANDLING Closed systems can also be utilized to enhance the safe handling of high vapor pressure hydrocarbons on the wellsite. 4.4.4.2

Tank Truck Loading and Unloading Operations – Sweet and Sour Fluids

IRP

Atmospheric tank trucks should only be used to haul sweet and sour fluids where the fluid is non-gaseous and there is minimal possibility of vapour breakout due to agitation or ambient temperature increases. An H2S scrubber must be used while loading, unloading and transporting sour fluids where an atmospheric tank truck is used to haul sour fluids.

IRP

Where ammonia type scrubbers are used, the ammonia must be kept fresh and must be able to handle the concentrations and volume of H2S vapour. Refer to Section 4.0.8 H2S Scrubbers.

IRP

Where there is the possibility of vapour breakout and pressure build up on the tank truck due to agitation or increased ambient temperature, the sour fluid must be transported in a pressure certified tank truck. The tank must be constructed using a quality program certified by the Provincial pressure vessels authority and from materials meeting the requirements of NACE MR 01-75 LATEST EDITION for the expected pressure and H2S concentration.

Note:

ARP 2.10 Quality Programs for Pressure Containing Equipment includes basic information regarding quality programs. NACE MR 01-75 LATEST EDITION, Sulphide Stress Cracking Resistant Metallic Materials for Oilfield Equipment has a 350 kPa (50 psi) pressure limit below which the requirements do not apply.

4.4.4.2.1

Using Atmospheric or Pressure Certified Tank Trucks

IRP

A well must not be flowed directly to a tank truck.

IRP

To haul sour gaseous fluids the tank truck must arrive at the wellsite with a purge in the tank or be equipped to be purged at the wellsite.

IRP

All vents must be closed while transporting the fluid.

IRP

Tank trucks may be vented to a flare stack only when:

Section 4.4

Temporary Production Testing

-

The tank has been purged and been tested with an LEL meter to determine the oxygen content in the tank

-

Tthe tank truck is able to maintain the purge in a sealed tank

-

There is a positive flow of gas to the flare stack to produce a venturi on the vent line from the tank truck

-

There is a minimum of one (1) flame arrestor in the vent line to the stack

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The system, including the tank truck and the tanks being emptied will not allow air in through a vacuum apparatus

-

The truck driver has H2S training certification

-

The truck driver has TDG certification.

IRP

The facility where the fluids will be off-loaded should be equipped with a purge gas make-up system so as to purge the tank while fluid is being pumped off, allowing the tank truck to have a purge on board when returning to the wellsite.

IRP

When loading and unloading fluids from pressurized flowback or atmospheric storage tanks, precautions must be taken in the placement of the truck relative to the tank(s) location on the wellsite.

IRP

When loading and unloading fluids from a pressurized flowback or storage tank that a live well is flowing to, the following precautions must be taken: -

The tank truck to be loaded or unloaded must be parked 25 meters from the pressurized flowback or storage tank

-

A fluid head must be maintained in the pressurized flowback or storage tank at all times – gas must not be allowed to escape to the tank truck being loaded or unloaded

-

The pressure of the pressurized flowback or storage tank system must be reduced to the minimum pressure required to transfer the fluid to the tank truck

-

The pressure capabilities of the piping and hose system to the tank truck must not be exceeded

-

Where a certified pressurized tank truck is used, the pressure capabilities of the tank on the truck must not be exceeded.

Note:

Where possible, shut-off the truck while loading. The pressure on the flowback or storage tank will transfer the fluid to the tank truck. The use of a pump will also agitate fluids resulting in additional gas vapor from the fluid.

IRP

When loading fluids produced from a sour well where testing operations are in progress the following procedures must be adhered to:

Section 4.4

1.

Where an atmospheric tank truck is used, connect the trucks atmospheric tank vent line to an adequately sized H2S scrubber. The scrubber may be truck mounted or a stand alone skid mounted unit.

2.

Where a truck equipped with a pressurized tank is used, ensure the tank specification including pressure rating is sufficient for the nature of the fluids being loaded. See “Venting Tanks to Flare Stacks” below.

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The tank to be filled or unloaded should be separated (blocked) from any other tanks being used while the tank truck is loading or unloading. A gas blanket (positive pressure) must be maintained on closed system production tanks.

IRP

Tank trucks should be a minimum of 7m from the tank to be filled or unloaded.

IRP

Tank trucks should be electrically bonded to the tank to be filled or unloaded prior to and during fluid transfers. The wheels should be chocked while transferring the liquids.

IRP

Ensure the maximum working pressure (MAWP) of the pressurized truck tank is not less than the maximum working pressure (MAWP) of the production facility components being connected to.

4.4.4.2.2

Venting Tank Trucks to Flare Stacks

IRP

For the transportation of sour fluids, a fluid haulers tank must have a purge inside before venting to a flare stack during loading operations. The truck tank must have a purge on when it arrives at the worksite or a means to purge the tank on the worksite must be available.

IRP

The purge must be verified at the worksite, just prior to loading, with an LEL meter. The vent line from the tank to the stack must have a manual valve installed with a minimum of one (1) flame arrestor. A slip stream of gas injected downstream of the tank, to create a venturi, may be appropriate.

Note:

Consult the operator of the vent system to ensure to ensure proper valving and flame arrestor(s) are installed in the vent line to the flare stack.

4.4.4.3

Permanent Production Facilities – Sweet or Sour Fluids

IRP

A well must not be flowed directly into a tank truck.

IRP

When loading sour fluids, tank truck vapors may be directed into a flare system as long as the trucks tank contains no oxygen, otherwise tank truck vapors should be scrubbed through an ammonia scrubber and vented to atmosphere. Eliminating oxygen can be achieved by the following:

Section 4.4

-

An adequate positive pressure is maintained on the production tanks at a closed system multi-well facility where the fluid is to be unloaded

-

Ensure the maximum working pressure (MAWP) of the truck tank is not less than the maximum working pressure MAWP of the production facility components being connected to properly

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WELL TESTING AND FLUID HANDLING sized vent lines should be provided at the multi-well facility where the fluid is to be unloaded; this will allow the void left in the tank truck after unloading to be replaced with adequate gas vapors from the positive pressure production tanks -

Thief hatches on production tanks and trucks must be in good working condition.

IRP

A gas blanket (positive pressure) must be maintained on closed system production tanks.

IRP

Tank trucks must be a minimum of 7 m from the tank to be filled or unloaded.

IRP

A grounding line must be connected to a ground rod and load line of the tank.

IRP

The wheels of the tank truck should be chocked while transferring the liquids.

4.4.4.4

Transportation – Sour Fluids

IRP

Transportation of Dangerous Goods (TDG) legislation must be consulted for selecting equipment to transport sour fluids.

Note:

Refer to the “definitions” in this IRP for information relative to TDG legislation and tank construction.

IRP

Trucks transporting sour fluid must be equipped with a functional H2S scrubber to adequately control odor emissions or be a sealed tank.

IRP

The tank vent must be sealed during storage and during transport when the truck is empty.

Note:

In British Columbia, the Oil and Gas Regulations of the Waste Management Act, Section 5, s.s (3) states, “after May 31, 1997, (a) during transportation, tanks mounted on vehicles must be, (i) operated with control devices such that the concentration of hydrogen sulphide at any vents or outlets is less than 10 parts per million by volume.”

4.4.5

Fluid Hauling Company Worker Qualifications

IRP

Workers transporting sour fluids shall have valid H2S, WHMIS and TDG certificates.

IRP

Workers operating fluid hauling trucks must have a valid license for the province/territory of operation.

IRP

Workers must be trained in proper procedures and practices for operating vehicles while transporting fluids.

Section 4.4

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Workers must be properly trained in loading and unloading procedures and practices.

IRP

Workers must be properly trained in the use of safety equipment used in the course of the operation, including breathing equipment and explosive monitoring devices.

4.4.6

Tank Truck Requirements to Transport Hydrocarbon Fluids Containing Hydrogen Sulphide (H2s)

4.4.6.1

Transporting Fluid With 88 Ppm Hydrogen Sulphide Content or Less: (Not TDG Sub-Class 6.1 (I)) Well fluid with a hydrogen sulfide saturated vapor concentration (H2S content) of 0.088 moles / kilomole (88 ppm) or less is designated as SWEET for the purposes of transportation. Fabricating specifications for equipment used to haul sweet fluids are not as stringent as those required for fluids containing H2S. References/Links Transport Canada TDG Regs, Part 3 (Classification) Transport Canada TDG Regs, 7.33.1 (GrandFathering) CSA B621, Selection & Use for TDG

Note:

In British Columbia, the Oil and Gas Regulations of the Waste Management Act, Section 5, s.s (3) states, “after May 31, 1997, (a) during transportation, tanks mounted on vehicles must be, (i) operated with control devices such that the concentration of hydrogen sulphide at any vents or outlets is less than 10 parts per million by volume.”

4.4.6.2

Transporting Fluid With More Than 88 Ppm Hydrogen Sulphide 88 to 440 ppm H2S SVC: 440 to 4400 ppm H2S SVC: 4400 ppm or more H2S SVC:

TDG, Sub-Class 6.1, PG 111 TDG, Sub-Class 6.1, PG 11 TDG, Primary Class 6.1, PG 1

Well fluid with a hydrogen sulfide saturated vapor concentration (H2S SVC) of more than 0.088 moles / kilomole (88 ppm) is designated as SOUR for the purposes of transportation. Fabrication specifications and working pressures become more stringent for well fluids at 440 ppm and again at 4400 ppm H2S. References/Links Transport Canada TDG Regs, Schedule II List II Transport Canada TDG Regs, Part 3 Transport Canada TDG Regs, 7.33.1 (GrandFathering) CSA B621, Selection & Use for TDG Canadian Centre for Occupational Health & Safety (LC50 H2S)

Section 4.4

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WELL TESTING AND FLUID HANDLING Alberta Safety Codes Act Boilers & Pressure Vessel Exemption Order ASME Section VIII ASME B31.3 4.4.6.3

Hydrocarbon Transportation: Class & Packing Group (Boiling Point, Flash Point & Vapor Pressure) TDG Class 3, Flammable Liquids, Packing Group I: Hydrocarbon mixtures with an initial boiling point of 37.8o C (100o F) or less at an absolute pressure of 101.325 kPa (14.7 psi) are a Class 3, Packing Group I, flammable liquid for the purposes of transportation. TDG Class 2, Gasses Hydrocarbon mixtures with a Reid Vapor Pressure of 275 kPa (40 psi) or greater at 37.8o C (100o F) are gasses for the purposes of transportation.

Note:

Reid Vapor Pressure is determined in a laboratory test. API gravity can be readily measured in the field. C1-C7 content can also be indicative of flammability. Flammability increases with increasing C1-C7 content. Fluid analyses, if available, should be reviewed. Fluid and ambient temperatures should also be considered. References/Links Transport Canada TDG Regs, Part 3 Transport Canada TDG Regs, Schedule VI, Part I (Class 3, Flammable Liquids, Packing Group Test Methods) Transport Canada TDG Regs, Schedule VI, Part III (Class 2, Gases, Reid Vapor Pressure, Test Methods) CSA B621, Selection & Use for TDG Transport Canada TDG Regs, 7.33.1 (GrandFathering) Alberta Safety Codes Act Boilers & Pressure Vessel Exemption Order ASME Section VIII ASME B31.3

Section 4.4

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4.5

KEY WORDS AND PHRASES INDEX

4.5.1

Scope This section of IRP Volume 4, Well Testing and Fluid Handling, provides an alphabetical index to assist the user to find common words and phases used in this IRP.

4.5.2

Key Words And Phrases Index Key Word or Phrases adequate lighthing air entrainment air supply system API 6A

Page Number(s) A 7, 49, 86, 88 41, 43, 68, 71, 89 14 21-31, 55-57, 60

back packs bleed-off breathing equipment

B 14, 53, 81 7, 14, 89 14, 19, 98

calibration Canadian Petroleum Safety Council CAODC CAPP Caution(s) certified pressurized flowback tank checklist choke circulating closed system coiled tubing unit operations confined space contingency plan corrosion critical sour

Section 4.5

C 23, 70 2,4 2, 85 2 7, 10, 16, 19, 22, 34, 42, 48, 51, 52, 69, 86 95 8, 39, 40 48 ,53-54, 66, 80-81, 83, 90 13,24, 41, 48, 50, 62, 64, 66-68, 71, 81-82 6, 36, 39, 48, 70, 71, 81, 85, 86, 87, 89, 90 8, 35, 39, 85, 93-94, 96-97 8, 41, 88 8, 35 16, 93 7, 19, 26-27, 52, 59, 64 13, 19, 36, 39, 53, 57, 67, 80, 90-91

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Key Word or Phrases DACC darkness daylight definitions drill stem test Drilling and Completions Committee drilling company

Page Number(s) D 2, 4, 6, 55, 85, 92 49, 66, 88 48, 49, 66-67, 88 2, 7, 59, 61, 88, 97 2-5, 8, 10, 13, 17, 42, 46-53 2, 4, 6, 55, 92 8,53,54 E

egress packs elastomers emergency shutdown valve employer enclosed environment environmental protection equipment capacities erosion ESD explosive

14 37, 62 57, 59 1, 8, 9, 11, 13, 46, 72 9, 15 14 58, 68 27, 64, 86 9, 34, 57, 59, 62, 66, 68, 81 11, 16, 17, 20-23, 38, 41-42, 44, 51, 85-87, 93, 98 F

first aid certificate flammable limits flare pits flashback flowing

16, 71, 91 20 36 41 10, 13, 20, 24, 34, 36, 39, 70, 85, 87, 90, 95 2-4, 8-10, 20, 23, 35, 36, 38, 39, 40, 48, 85, 88, 89, 90, 91, 95 2-4, 6, 8-13, 15-1 8, 23, 25, 32, 35-39, 41, 42, 46-49, 51-52, 54, 55, 59-60, 65- 66, 69-71, 85-90, 92-99 2

flowback fluid

forward G gas

gas detection meter gas detection monitoring gas flares gas sensors

Section 4.5

1, 3-6, 8-11, 13-15, 17-24, 25, 33, 35-44, 48, 49, 51-53, 59, 61, 62, 64, 66, 67, 69-71, 80-82, 85-90, 92, 94- 99 15, 20, 87, 89 20 35, 36 21, 22

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Key Word or Phrases

Page Number(s) H

H2S

7-10, 12, 14, 16-19, 22, 24, 3334, 36, 39, 43, 46-47, 51-52, 3844, 48-49, 51-53, 59, 61-62, 64, 66-67, 69-71, 80-82, 85-90, 92, 94-99 8, 14, 22, 33, 36, 51, 59, 68, 70, 94 19, 22 8, 39, 94-95, 97 15 35, 67, 85, 88 7, 15-19, 32, 34, 36, 37, 38, 68, 85, 87, 93 9, 94 24, 25 39 23, 35, 87, 90 21, 22 9, 70 17, 18 24, 25, 89

H2S concentration H2S environments H2S scrubber hauling companies hazard assessment hazards high vapor pressure hydrocarbons hydrates hydrometers ignition source ignition temperature inline test inspections introduction J K L LEL (lower explosive limits) loading local authority

20, 21, 22, 86 2, 3, 16, 87, 92-98 36, 44, 48, 64, 65 M

master valves metallurgy monitoring MSDS sheets mud can

56, 57 19 10, 16, 20-21, 23, 85-86, 89, 98 93 48 N

NACE night time non-certified pressurized storage non-essential workers NORM (Naturally Occurring Radioactive Material

Section 4.5

7, 19, 39- 40, 51, 56, 59-62, 94, 66-67 66, 67 10, 39, 40 25, 44, 49, 67, 89 37

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Key Word or Phrases

Page Number(s) O

occupational exposure limit (OEL) oil

10, 15 3-5, 7-8, 10-11, 13, 20, 37, 41, 52, 54, 65, 81, 85, 88, 90-91, 93, 99 10, 88, 90 15, 20, 36, 37-38, 44, 85-87, 89, 90 3, 8, 10, 20, 36, 48, 85 8, 10-12, 14-16, 24, 35,3 9-40, 49-50, 66, 68,72,85,88,92 35 21, 22 34 44 94 96

open system open tank system other flowbacks owner owner representative oxygen P physically capable pipe tally PITS (Petroleum Industry Training Service) positive pressure PPE pre-job equipment checklist (see checklist) pre-job safety meeting pressure piping pressure rating pressure test pressure vessels pressurized tank truck procedures

produced fluids program of operations propane tanks PSAC pumping purge

17 18 50 6, 47 71 33, 96-97 11, 87 24, 32, 34 69, 60, 66 50, 56, 59-63, 69, 72, 95 3, 25, 48, 50, 54, 57, 66-67 58-59, 64, 91, 94 95 2-4, 12, 16, 22, 32, 34, 37, 42, 44, 46-47, 50-51, 55, 60, 66, 68, 71, 72, 85, 89, 92-93, 95, 97-98 37-38, 69-70 16 65 2, 4, 71, 90 10, 23, 36, 39, 85-87, 89, 90 25, 34-35, 41-45, 69, 89, 94-96

Q qualifications qualified well testing person qualified workers

Section 4.5

3, 11, 16, 46-47, 69, 71-72 69 15, 90

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Key Word or Phrases

Page Number(s) R

References regulatory requirements Reid vapor pressure responsibilities rig floor rig pump

2-4, 18, 21, 24, 46, 62, 64 3, 14, 32, 36 9, 37 17, 18, 34, 47, 49,72 49, 50 23, 87, 90 S

SABA – SCBA safety service company safety stairs safety standby method safety zone scope seamless pipe self-contained breathing apparatus service company service contractor shut in signage site representative SITHP sour

sour fluids sour gas sour service spacing spills standards start-up stimulation supervisor

Section 4.5

12, 14-15, 18, 33, 92 12, 17, 52 34 12, 33, 68 20, 86, 87, 89 2 25, 61 14, 33 11 14, 15, 41 9, 12, 68-69, 71, 87 15, 36, 87, 90 15, 20, 67, 89 12, 56-57, 67 1, 3-4, 12, 16-18, 21-23, 35-36, 38-38, 41, 44, 48-49, 51-52, 5760, 65, 68-70, 85-87, 90-97 38-39, 52, 92, 94, 96-97 18, 36, 39, 51-52, 85, 94 17-18, 51-52 40, 64 16, 93 2, 4, 32-34, 46, 55, 60, 62-63, 71 25, 45, 54, 66-67, 80, 86 4, 8, 10, 66, 85 15, 68, 70, 89

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Key Word or Phrases supplied air breathing apparatus swabbing

Page Number(s) 14, 33 10, 13, 39, 41, 45, 50, 70, 85, 8889, 91 42, 60, 69, 70, 85, 93-94, 98 50, 60

sweet swivel joint T tank truck tanks

48, 81, 94-97 3, 35,38-45, 59, 61, 65, 67-68, 70-71, 81, 86-87, 89, 90, 93, 9598 15, 32, 47, 71, 95, 97-99 49 48 2-4, 10-11, 14-15, 18-19, 22, 2425, 27, 34, 39, 41-42, 46-52, 5455, 57, 60, 64, 66-72, 90, 92-93, 95 4, 17, 20, 39, 48, 51, 72, 86, 92, 97-98 92

TDG test line test plug testing

trained transportation of fluids U UEL (upper explosive limits) unloading

21 3, 16, 87, 92, 94-98 V

vapor density vented to atmosphere

21 8, 10, 15, 20, 35-36, 38, 4, 87, 89, 90, 96 36 96

venting gas venting tank trucks W waste manifest water

15 12, 23-24, 33, 35, 37, 52, 54, 64, 67 18 10, 87, 89, 91 2-4, 10-11, 14,18-29, 24, 27, 34, 52, 55, 57, 60, 64, 68-71, 90, 93 18, 69-71, 90 55, 87 56, 57 14, 50 44, 56-58, 68, 86 18-19, 93 32,86

well designation well killing operations well testing well testing workers wellhead control wellheads wellsite owner wing valve worker safety workwear X Y

Section 4.5

Page 105

2000/02

WELL TESTING AND FLUID HANDLING Key Word or Phrases

Page Number(s) Z

Section 4.5

Page 106

Delta-P Test Corp. Safety Handbook Appendix G: Working Alone

19/06/01 38 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Delta-P Test Corp. Safety Handbook Appendix H: Safety Meeting Forms

19/06/01 39 C:\My Documents\Delta-P\Safety Programme\Safety Manual.doc

Testing Division

Pre-Job Safety Meeting - Checklist Drilling Co.

Date:

Location: Operating Company: Delta-P Rep:

Operating Co. Rep: (x) Check applicable items discussed

1. General Instructions Delta-P Safety Policy

Ropes, Chains & Cables

In Case of Injury

Power Driven Equipment

Safety Footwear

Use of Portable or Mobile in Restricted Areas

Emergency Plan

Respiratory Protective Equipment

Protective Clothing

Employee Responsibilities

Hoses & Cables

Reporting Accident/Incident

High Pressure/ Fittings

RX Hazard Glasses

Rotating Table / Packer Inflation

Hearing Protection

Smoking, Matches & Lighters

Hand Protection

Close Test Head Procedures

Eye and Face Protection

Open/Close Tool

Speed Limit

Mud Drop/Observation

Horseplay

Explosion Proof Flashlights

Leg Guards

Visitors

Vehicle Usage

Fire and Other Emergencies

Alcohol and Drugs

Compressed Air Hazard

Welding and Cutting

Loose Clothing

Grinding Tools

Unsafe Conditions

Parking Areas

Electrical Clearances

Improper Conduct

Ladders

Emergency Transportation

Static Electricity

Steam Hazards

Fire Prevention & Protection

Contact Lenses Hazard

Sandblasting

Handling and Lifting Materials

Painting

Safety Belts and Life Lines

Handling Pipes & Tool Handling

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2. Hazardous Product (Material Safety Data Sheet Manual)

Hydrogen Sulphide

Gasoline

Methyl Alcohol

Caustic

Propane or Butane

Glycols

Oils

Condensate

Oilfield Chemicals

Nitrogen

Acids

Others

Solvents

3. Fire and Safety Equipment Training Required

First Aid

Air Hood & Compressor

Portable or Wheeled Fire Extinguisher

TDG

Portable Combustible Gas Detection

O2 Indicator

Mechanical Ventilator

WHMIS

Cartridge and Dust Respirators

Confined Space

Hose Line Mask

Portable Toxic Gas Detection

H2S Alive

Others

4. Safety Equipment Received/Required

Health & Safety Rules Booklet for Contractors/Consultants

Hearing Protection

Protective Clothing (Neoprene)

Eye Protection

Explosion Proof Flashlight

Work Gloves

Neoprene Safety Boots

Leg Protection

Roll Bars on Appropriate Mobile Equipment

Fire Retardant Clothing

Hard Hat and Liner

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