Alberta Regulation 32/2002

Government Organization Act

BOILERS DELEGATED ADMINISTRATION REGULATION

Filed: March 6, 2002

Made by the Lieutenant Governor in Council (O.C. 88/2002) on March 6, 2002

pursuant to

Schedule 10,

section 2 of the Government Organization Act.

Table of Contents

Definitions 1

Delegation 2

Authorization to assess and collect fees and charges 3

Use of money collected 4

Limitation of liability 5

Appeals 6

Records 7

Advice to the Minister 8

Repeal 9

Expiry 10

Coming into force 11

Definitions

1 In this Regulation,

(a) "Act" means the Government Organization Act;

(b) "Administration Agreement" means the written agreement made

between the Minister and the Association, entitled the "Administration

Agreement" (as amended, if applicable);

(c) "Administrator" means an Administrator as defined in the Safety

Codes Act;

(d) "Association" means the Alberta Boilers Safety Association

incorporated under the Societies Act;

(e) "Freedom of Information and Protection of Privacy Coordinator"

means an employee of the Government designated by the Deputy Minister as a

Freedom of Information and Protection of Privacy Coordinator;

(f) "Minister" means the Minister designated with the

responsibility for the administration of the Safety Codes Act and "Deputy

Minister" means the Deputy of that Minister;

(g) "pressure equipment" means pressure equipment within the

meaning of the Safety Codes Act;

(h) "safety codes officer" means a safety codes officer as defined

in the Safety Codes Act.

Delegation

2(1) The powers, duties and functions of a safety codes officer are

delegated to the Association with respect to the following:

(

a) the Pressure Welders' Regulations (AR 229/75);

(

b) the Design, Construction and Installation of Boilers and

Pressure Vessels Regulations (AR 227/75);

(

c) the Engineers' Regulations (AR 319/75);

(

d) section 8 of the Boilers and Pressure Vessels Regulation (AR

293/94);

(

e) sections 34, 35, 38, 44, 46, 48, 49 and 56(1) of the Safety

Codes Act in respect of pressure equipment;

(

f) sections 4 and 5 of the Administration and Information Systems

Regulation (AR 55/95).

(2) The delegation of powers, duties and functions under this

section is

subject to the following conditions:

(

a) the Association must comply with this Regulation;

(

b) the Association may only exercise the powers, and must perform

the duties and functions, delegated to it by this Regulation in accordance

with the Administration Agreement;

(

c) all computer software and software systems used or developed by

the Association, the information on them and anything generated or capable

of generation by them for carrying out the Association's powers, duties and

functions under this Regulation or the Administration Agreement is owned by

the Government;

(

d) all money received by the Association under the authority of

this Regulation must be recorded and accounted for in accordance with

generally accepted accounting principles, and receipts for the money

received must be provided on the request of the person paying the money.

Authorization to assess and collect fees and charges

3 The Association is authorized

(

a) to impose assessments, fees and charges with the approval of

the Minister, and

(

b) to collect money from the levy of the assessments, fees and

charges,

with respect to the powers, duties and functions delegated to it by this

Regulation, on persons who apply for or are provided with services,

materials or programs, including but not limited to providing information,

issuing a permit, certificate or other thing or on notifying, filing with

or registering anything with the Association.

Use of money collected

4 The Association is authorized to use the money collected by it under

this Regulation to pay costs incurred in carrying out its powers, duties

and functions under this Regulation.

Limitation of liability

5(1) No action lies against the Association or against its directors,

officers, agents or employees or any of them individually for anything done

or not done in good faith in the carrying out of powers, duties or

functions under this Regulation.

(2) The Association and its directors, officers, employees and agents and

any of them individually are not liable for any damage caused by a decision

or the failure to make a decision related to the system of inspections,

examinations, evaluations and investigations, including but not limited to

a decision relating to their frequency and how they are carried out.

Appeals

6(1) Pursuant to

section 2(1)(

e) of

Schedule 10 to the Act, a person

affected by a decision made or the failure to make a decision, or any other

action taken or the failure to take an action, by the Association or any of

its agents, directors, officers or employees respecting a matter related to

this Regulation or the Administration Agreement may appeal the decision,

other action or the failure to make the decision or take the action, in

writing, to the Minister if the matter is not governed by

section 50 of the

Safety Codes Act.

(2) The Minister may decide whether to hear an appeal under subsection

(1).

(3) On hearing an appeal the Minister may confirm, vary or revoke the

action or decision that is the subject-matter of the appeal.

(4) A decision made by the Minister with respect to an appeal under this

section is final.

Records

7(1) All records in the custody or under the control of the Association

that are required in the carrying out of its powers, duties and functions

under this Regulation must be managed, maintained and destroyed in

accordance with subsection (2) and the Records Management Regulation (AR

224/2001).

(2) The following conditions apply to the records described in subsection

(1):

(

a) the records must be managed under the direction of a senior

records officer to whom a deputy head, within the meaning of the Records

Management Regulation (AR 224/2001), has assigned powers and duties under

that Regulation;

(

b) the Association must designate a person to be responsible for

records management and freedom of information and protection of privacy

matters;

(

c) all records created or maintained in the carrying out of

powers, duties and functions under this Regulation become and remain the

property of the Crown in right of Alberta and must be managed in accordance

with the Freedom of Information and Protection of Privacy Act;

(

d) a request for access to information made under the Freedom of

Information and Protection of Privacy Act to the Association must be

directed to the Freedom of Information and Protection of Privacy

Coordinator for the processing of the request;

(

e) the Association must provide any records that are required by

the Freedom of Information and Protection of Privacy Coordinator for the

processing of the request, within the time period set out in the

Administration Agreement;

(

f) the Association must comply with

section 63 of the Safety Codes

Act.

(3) The Association shall maintain records with respect to pressure

equipment that include the following:

(

a) the registration, de-registration and recording, as applicable,

(

i) designs and the approval of designs for new

pressure equipment,

(ii) obsolete designs of pressure equipment,

(iii) unsafe designs of pressure equipment,

(iv) permitted procedures, including repairs and

alterations to existing pressure equipment,

(

v) inspection reports concerning the construction,

installation, repair or maintenance of pressure equipment,

(vi) permitted welding procedures,

(vii) refusals to register designs,

(viii) refusals to permit procedures,

(ix) the location, ownership and inspection records of

pressure equipment, and

(

x) the maintenance of pressure equipment;

(

b) the registration of, testing for and issuance of certificates

of competency under the Engineers' Regulations (AR 319/75) and the Pressure

Welders' Regulations (AR 229/75);

(

c) the registration of organizations that have quality control

programs and that are permitted to carry out activities related to pressure

equipment under the Safety Codes Act;

(

d) recording reports of accidents and unsafe conditions involving

pressure equipment and information on their investigation;

(

e) recording the issuance of orders related to pressure equipment;

(

f) recording the issuance of variances related to pressure

equipment;

(

g) recording notices of appeals related to the carrying out of

powers, duties and functions under this Regulation;

(

h) any other matter related to pressure equipment that is

requested by the Minister.

Advice to the Minister

8 The Association is authorized, with the consent of the Minister, to

provide advice to the Minister on the powers, duties and functions

delegated under this Regulation.

Repeal

9 The Boilers Delegated Administration Regulation (AR 54/95) is repealed.

Expiry

10 For the purpose of ensuring that this Regulation is reviewed for

ongoing relevancy and necessity, with the option that it may be repassed in

its present or an amended form following a review, this Regulation expires

on March 30, 2007.

Coming into force

11 This Regulation comes into force on March 31, 2002.

Alberta Regulation 33/2002

Apprenticeship and Industry Training Act

ELECTRONIC TECHNICIAN TRADE AMENDMENT REGULATION

Filed: March 7, 2002

Made by the Alberta Apprenticeship and Industry Training Board on January

30, 2002 pursuant to

section 33(2) of the Apprenticeship and Industry

Training Act and approved by the Minister of Learning on February 28, 2002.

1 The Electronic Technician Trade Regulation (AR 275/2000) is amended by

this Regulation.

Section 5(2) is amended by striking out "one apprentice" and

substituting "2 apprentices".

------------------------------

Alberta Regulation 34/2002

Apprenticeship and Industry Training Act

STRUCTURAL STEEL AND PLATE FITTER TRADE

AMENDMENT REGULATION

Filed: March 7, 2002

Made by the Alberta Apprenticeship and Industry Training Board on January

30, 2002 pursuant to

section 33(2) of the Apprenticeship and Industry

Training Act and approved by the Minister of Learning on February 28, 2002.

1 The Structural Steel and Plate Fitter Trade Regulation (AR 306/2000) is

amended by this Regulation.

Section 1(c)(ix) is amended by striking out "miscellaneous steel" and

substituting "miscellaneous metals".

Section 2(

c) is repealed and the following is substituted:

(

c) revisions to structures.

Section 3(

d) is amended by adding "synthetic slings," after "wire

rope,".

Alberta Regulation 35/2002

Financial Administration Act

INDEMNITY AUTHORIZATION AMENDMENT REGULATION

Filed: March 13, 2002

Made by the Lieutenant Governor in Council (O.C. 103/2002) on March 12,

2002 pursuant to

section 71 of the Financial Administration Act.

1 The Indemnity Authorization Regulation (AR 22/97) is amended by this

Regulation.

Section 5.1(1)(

b) is amended by adding "or

section 1 of the Northland

School Division Act" after "Act".

------------------------------

Alberta Regulation 36/2002

Oil and Gas Conservation Act

OIL AND GAS CONSERVATION AMENDMENT REGULATION

Filed: March 14, 2002

Made by the Alberta Energy and Utilities Board on March 5, 2002 pursuant to

section 10 of the Oil and Gas Conservation Act.

1 The Oil and Gas Conservation Regulations (AR 151/71) are amended by

this Regulation.

Section 1.020(2) is amended

(

a) by adding the following after clause 12:

12.1. "oilfield waste" means an unwanted substance or mixture

of substances that results from the construction, operation, abandonment or

reclamation of a facility, well site or pipeline, but does not include an

unwanted substance or mixture of substances from such a source that is

received for storage, treatment, disposal or recycling at a facility that

is regulated by the Department of Environment;

12.2. "oilfield waste management facility" means a facility,

the operation of which is approved by the Board, including, without

limitation, a waste processing facility, a waste storage facility, a waste

transfer station, a surface facility associated with a disposal well, a

biodegradation facility, an oilfield landfill, a thermal treatment facility

and any other facility for the processing, treatment, storage, disposal or

recycling of oilfield waste;

(

b) in clause 14 by striking out "plant" and substituting

"facility";

(

c) by repealing clause 31.

Section 5.150(2) is repealed and the following is substituted:

(2) An application for an order for the establishment of a project

shall contain a statement verifying that the lands being included in the

project are of common ownership.

Section 6.020 is amended

(

a) by repealing subsection (1);

(

b) by repealing subsection (2) and substituting the following:

(2) This

section applies to all wells and facilities and to LPG

facilities and oil loading and unloading terminals as if they were

facilities.

Section 6.021 is repealed and the following is substituted:

6.021 On commencement of the drilling of a well, other than a well

of the kind referred to in

section 2.030 or 2.040(1)(d), the licensee

shall, within 12 hours or as otherwise arranged with the Board, advise the

appropriate field centre of the Board.

Section 6.030(2) is repealed.

Section 6.070 is amended by striking out "cirucmstance" and

substituting "circumstance".

Section 6.100(4) is repealed and the following is substituted:

(4) The Board may exempt a well from the requirements of this

section if the well pressures are such that annulus vents are not

necessary, or if special circumstances require the vents to remain closed

except when checking for pressure in the surface casing.

Section 6.101(4) is repealed.

10 The heading preceding

section 7.001 is amended by striking out

"Batteries" and substituting "Facilities".

Section 7.001 is repealed and the following is substituted:

7.001 No person shall commence construction of or modification to a

battery (other than a battery receiving production from a single well which

produces gas containing less than 0.01 moles per kilomole of hydrogen

sulphide), an oilfield waste management facility or a compressor station,

unless the Board has, on application, approved the location and

construction of or modification to the battery, oilfield waste management

facility or compressor station.

Section 7.002(2) is amended by striking out "a waste management

facility" and substituting "an oilfield waste management facility".

Section 7.003 is repealed and the following is substituted:

7.003 An approval or licence for the location, construction or

modification of a battery, oilfield waste management facility or compressor

station shall be subject to any conditions set out in the approval.

Section 7.020 is repealed and the following is substituted:

7.020 Where production from more than one well is received at a

battery, the production from each well or each zone in each well, as the

case may be, shall be carried to the battery in a separate flow line unless

a test measurement of the oil, gas and water production can be made at any

time without separate flow lines.

Section 7.030 is amended

(

a) by repealing subsection (1) and substituting the following:

7.030(1) Unless the Board stipulates otherwise, where the

production of wells is commingled before measurement, the operator of the

battery shall test each well in accordance with this

section and

Schedule

(

b) by repealing subsections (2) and (4);

(

c) by repealing subsection (5) and substituting the following:

(5) An application to reduce the test frequency of a well or

wells must set out the reasons why a lesser standard should be accepted.

Section 7.040 is amended

(

a) by repealing subsection (1) and substituting the following:

7.040(1) No person shall burn, and no licensee of a well or

operator of a facility shall cause or permit to be burned, any oil, gas,

oily waste or other material produced or used at a well or in the

operation of a scheme, except under conditions of controlled combustion

where there is no significant or visible emission of smoke.

(1.1) Subsection (1) does not apply where the Board or its

authorized representative approves the burning.

(

b) in subsection (2) by striking out "well or plant effluent" and

substituting "effluent from a well or facility".

Section 7.050 is amended by adding the following after subsection (7):

(7.1) The licensee of a well shall ensure that the wellhead is

conspicuously marked or fenced in a manner that makes it visible in all

seasons.

(7.2) The licensee and operator of a well shall ensure that no

vehicles operate within a 3-metre radius of the wellhead, except vehicles

that are specifically required to do so as part of an operation being

performed on a well.

(7.3) A licensee of a pumping well that has the potential to flow to

atmosphere at sustained rates of at least 8 m3 per day of liquids and has a

hydrogen sulphide content of 10 moles per kilomole or greater in the gas

phase shall ensure that the well is equipped with a full opening master

valve, a hydraulic rod blowout preventer and an environmental blowout

preventer.

(7.4) The licensee of a pumping well referred to in subsection

(7.3) that was completed before March 1, 1998 shall ensure that the well is

brought into compliance with that subsection at the first workover during

which the Christmas tree is removed and that occurs after the coming into

force of this subsection.

Section 7.055 is repealed and the following is substituted:

7.055(1) Where gas

(

a) from a well producing gas containing more than 50

moles per kilomole of hydrogen sulphide, or any higher or lower ratio

stipulated by the Board, or

(

b) produced from a well designated as a critical sour

well

is flared during any test, during any period of cleaning out the well

or during well servicing operations, the licensee shall obtain approval

from the Board of the method, stack height and equipment to be used to

flare the gas.

(2) An application submitted under subsection (1) must be in

accordance with Guide 60 "Upstream Petroleum Flaring".

Section 7.060 is amended

(

a) in subsection (1) by striking out "by order";

(

b) in subsection (4)(

c) by adding "sweet gas" before "pilot";

(

c) in subsection (7) by striking out "an approved flare stack" and

substituting "a flare stack that meets the requirements of subsection

(4)(a), (

b) and (c)";

(

d) by repealing subsection (8) and substituting the following:

(8) Unless the licensee of a well equips and operates the well so

that the maximum operating flow line gauge pressure cannot exceed 1400

kilopascals, the licensee shall install on the wellhead a mechanism that

halts the flow of oil or gas in the event of an uncontrolled drop in

pressure or an equipment failure.

Section 7.070 is amended

(

a) in subsections (1) and (3) by striking out "battery" and

substituting "facility";

(

b) in subsection (4)

(

i) in clause (

a) by striking out "Minister of

Environment" and substituting "Department of Environment";

(ii) in clause (

b) by striking out "battery" and

substituting "facility";

(

c) in subsection (6) by striking out "battery" and substituting

"facility".

Section 8.010 is amended by striking out "or water produced from a

well or associated facility" and substituting ", produced water, process

water or oilfield wastes (other than drilling wastes) produced from a well

or facility".

Section 8.030 is repealed and the following is substituted:

8.030(1) Materials that are used, produced or generated at a well

site or facility, other than fresh water and inert solids, shall be stored

in accordance with the requirements of Guide 55, "Storage Requirements for

the Upstream Petroleum Industry".

(2) Aboveground tanks, underground tanks, containers, lined earthen

excavations and bulk pads shall meet the requirements for integrity

verification, secondary containment, leak detection and weather protection

that are set out in Guide 55, "Storage Requirements for the Upstream

Petroleum Industry".

(3) The Board on application may approve storage methods, systems or

devices alternative to those set out in Guide 55, "Storage Requirements for

the Upstream Petroleum Industry" if in the Board's opinion the level of

environmental protection provided is at least equal to that outlined in

Guide 55.

(4) Tanks or batteries of tanks containing fluids other than fresh

water at a well or facility shall be located so that the distance from the

outer perimeter of the dike to any surface improvement other than a public

roadway is not less than 60 metres or a lesser distance permitted by the

Board.

Section 8.040 is repealed and the following is substituted:

8.040 All water produced at a well or facility shall be disposed of

in accordance with a scheme approved by the Board pursuant to

section 39 of

the Act.

24 The heading "Control of Oil and Salt Water Spills" preceding

section

8.050 is repealed and the heading "Control of Spills" is substituted.

Section 8.050 is repealed and the following is substituted:

8.050(1) When oil, water or unrefined product is spilled or released

from a break or leak in a wellhead, tank, separator, treater or process

vessel, the licensee of the well or operator of the facility from which the

spill or release occurred shall immediately take reasonable steps to

contain and clean up the spill or release and shall ensure that the spilled

or released material is processed in the operator's facilities, if

appropriate, or is treated or disposed of, or both, in accordance with

Guide 58, "Oilfield Waste Management Requirements for the Upstream

Petroleum Industry".

(2) Where a spill or release referred to in subsection (1)

(

a) is not confined to the site of the well or facility

from which the spill or release occurred,

(

b) is on-site and is in excess of 2 cubic metres, or

(

c) is on-site and of a size that may cause, is causing

or has caused an adverse effect as defined in the Environmental Protection

and Enhancement Act,

the licensee or operator shall immediately orally report the size and

location of the spill to the appropriate field centre of the Board.

(3) When so directed by the Board, a report made pursuant to

subsection (2) shall be confirmed in a written report to the Board and be

supplemented with at least the following additional information:

(

a) the time the spill or release occurred;

(

b) a description of the circumstances leading to the

spill or release;

(

c) a discussion of the spill or release containment

and recovery procedures;

(

d) a discussion of steps to be taken to prevent

similar future spills or releases;

(

e) any other information that the Board may require.

Section 8.051 is repealed and the following is substituted:

8.051 Where oil, water or unrefined product is spilled while being

transported, otherwise than by pipeline, from a well, pipeline or other

facility over which the Board has jurisdiction to any other like facility,

the licensee of a well or pipeline or operator of the facility and the

owner of the transportation facility shall immediately

(

a) report the spill to the appropriate field centre of

the Board and to Alberta Environment,

(

b) take reasonable steps to contain and clean up the

spill material, and

(

c) ensure that the spill material is treated or

disposed of in accordance with Guide 58, "Oilfield Waste Management

Requirements for the Upstream Petroleum Industry", unless otherwise

approved by the Board.

Section 8.052 is repealed and the following is substituted:

8.052(1) Where any salt water disposal well, oil well, liquid

pipeline or facility poses an environmental hazard to a water body, the

licensee or operator shall file with the Board on request a contingency

plan encompassing production and pipeline facilities and trucking routes.

(2) The licensee or operator is not required to file a contingency

plan under subsection (1) if the licensee or operator is a member of an oil

spill co-operative.

(3) A licensee or operator that is not a member of an oil spill

co-operative shall submit a contingency plan and purchase spill clean-up

equipment to satisfy the Board that no environmental hazard to a water body

exists.

(4) A licensee and operator shall co-operate with the Board and

officials of the Department of Environment through

(

a) participation in spill equipment deployment

training exercises,

(

b) ensuring ready access to equipment and materials

that will enable containment and recovery of spilled substances, and

(

c) the maintenance and updating of manuals.

(5) Where contingency plans are submitted by each operator or

licensee or jointly by 2 or more operators or licensees or by a spill

co-operative acting on behalf of one or more operators or licensees, the

plan shall be kept up to date at all times and shall contain the following:

(

a) a description of initial emergency procedures and

response action;

(

b) the licensee or operator contacts, government

contacts and notification procedures;

(

c) topographical maps showing designated spill control

points, access roads, urban centres, bodies of water and streams, water

supply intakes for municipal and industrial operations, pipelines, wells

and other licensee or operator facilities;

(

d) a map index;

(

e) a description of all control points in the area;

(

f) river hydrology information;

(

g) spill containment and recovery equipment locations

and inventory;

(

h) spill containment and recovery and clean-up

procedures effective for the conditions and spills that may be expected in

the area the plans encompass;

(

i) policies for worker safety at an oil spill

containment site;

(

j) job descriptions of the various personnel positions

in the training exercise.

(6) Where spill equipment deployment training exercises referred to

in subsection (4)(

a) are conducted, a notification of the exercise must be

given at least 30 days in advance of the exercise

(

a) to the appropriate Board area office,

(

b) to the Fish and Wildlife Division, Sustainable

Resource Development, and

(

c) when the exercise requires access to Crown lands,

to the appropriate Public Lands or Forest Area office in order to obtain an

access agreement.

(7) A notification referred to in subsection (6) shall contain the

following:

(

a) the type of training exercise to be conducted, the

date on which it will be conducted and the legal description of the land on

which it will be conducted;

(

b) a map showing the general topography and location

of and the access routes to the deployment area and the location of any

municipal water intakes within 3 kilometres of the deployment area;

(

c) the proposed spill material and volume to be used,

if any;

(

d) comments on the public use of the area, collection

and disposal of garbage and a statement indicating the extent, if any, of

anticipated surface disturbance to stream banks or shorelines at the test

site;

(

e) the name of the landowner on whose land the

training exercise will be held and a statement indicating that the

landowner has no objection to the exercise proceeding at the proposed test

site.

(8) Within 30 days after completion of the training exercise the

licensee or operator shall prepare a report summarizing the training

exercise, and the licensee or operator shall

(

a) keep the report for at least 3 years after it was

completed, and

(

b) make the report available to the Board on request.

(9) If the training exercise is a co-operative training exercise,

the report shall list co-operative membership and delinquent membership

attendance at the exercise and shall contain a discussion of the general

effectiveness of the exercise, recovery of oil and any observed adverse

environmental effects resulting from the training exercise.

(10) Oil spill treating agents are not approved for use in Alberta.

(11) The Board may, on application, exempt a licensee or operator

from any provision of this

section where, in the opinion of the Board, the

nature of production, the remoteness of the area or any other circumstance

warrants the exemption.

Section 8.060 is repealed and the following is substituted:

8.060 Where a well or facility is located closer than 100 metres to

the normal high water mark of a body of water or permanent stream or is in

a location such that in the opinion of the Board a spill or leak may reach

the water, the licensee or operator shall

(

a) where a well is not on pump, install on the well

head a valve which closes automatically to shut off an uncontrolled flow of

effluent from the well in the event of a failure of the well head, surface

facilities or gathering line,

(

b) at the direction of the Board, install in the well

a packer and a subsurface valve to shut off automatically an uncontrolled

flow of effluent from the well in the event of a failure of the well head

or production casing,

(

c) construct pits, dikes, trenches or other structures

or installations to contain effluent or spill material, and

(

d) submit, at the request of the Board, a plan to

limit the spread of effluent or spill material and to recover effluent or

spill material from the surface of the water in the event of a leak or

spill, such plan to include details of procedures, materials and equipment

proposed to be used.

Section 8.070 is amended by striking out "battery" wherever it occurs

and substituting "facility".

Section 8.080 is repealed and the following is substituted:

8.080(1) The licensee of a well or the operator of a facility or oil

sands scheme shall burn any significant volume of gas that is vented to the

atmosphere.

(2) Vented gas shall not be flared to an earthen pit at a well or

facility that was constructed after July 1, 1996.

(3) The licensee or operator shall

(

a) safeguard all flare pits constructed before July 1,

1996, and

(

b) construct and safeguard all ends of flare lines

so that no hazard to public property or forest cover will be created

and so that they are not located closer than 100 metres to a surface

improvement, except a surveyed roadway, but the Board, where, in its

opinion, special circumstances exist, may prescribe a greater or lesser

distance.

(4) The licensee of a well or operator of a facility that was

constructed before July 1, 1996 and on which vented gas is flared to an

earthen pit shall prevent produced liquids from entering the pit by

installing appropriate flow shut-off and emergency containment devices.

(5) No flare pit or open end of a flare line shall be located or

remain within 50 metres of a well or oil storage tank, or within 25 metres

of any oil or gas processing equipment, but the Board, having regard to the

volume and nature of the gas and the flash point and other characteristics

of the oil being produced, may suspend the application in a field or pool

of the requirement of this subsection respecting the distance of a flare

pit or open end of a flare line from a well, and in such case,

notwithstanding subsection (1), gas vented from the flare line shall not be

burned.

Section 8.090 is amended

(

a) in subsection (8) by striking out "Electrical Protection Act"

and substituting "Safety Codes Act";

(

b) in subsection (10) by striking out "battery or other".

Section 8.120(3) is repealed and the following is substituted:

(3) Where a person contravenes subsection (1), the licensee and the

contractor referred to in subsection (2) who is the employer of that person

are in contravention of subsection (2) regardless of whether they had

knowledge of the smoking or took steps to guard against the smoking.

Section 8.129 is amended by adding the following after subsection (6):

(7) Prior to making application for a well licence, the licensee

shall

(

a) research offset well records to determine maximum

pore pressures and hole problems which may be encountered while drilling

the proposed well, and

(

b) incorporate the information determined under clause

(

a) into the well design.

(8) A licensee shall make the information determined under

subsection (7)(

a) available to the Board on request.

(9) In subsection (10), "high hazard area" means the land located in

Townships 19 to 24, in Ranges 5 to 10, West of the 4th Meridian in Alberta.

(10) The licensee of a well being drilled to the Mannville Formation

or deeper in the high hazard area shall comply with the following

requirements, in addition to the requirements of sections 8.130 and 8.143:

(

a) surface casing shall be run to a minimum depth of

180 m;

(

b) where fluid turns or high-pressure flexible hose

exists in the

section of choke line between the blowout preventer stack and

the choke manifold, an extra flare line for emergency purposes shall be

installed;

(

c) the line referred to in clause (

b) shall be

installed upstream of the first fluid turn or high-pressure flexible hose

and shall extend directly to the flare pit or tank as set out in

Schedule

(

d) the line referred to in clause (

b) shall

(

i) up to and including the last valve in

the line, consist of an arrangement of valves and steel line that has a

working pressure equal to the working pressure of the blowout preventer

stack,

(ii) be equal in diameter to the main

flareline extending from the choke manifold,

(iii) contain only straight pipe or 1.57

radian (90-degree) bends constructed of tees and crosses blocked on fluid

turns, and

(iv) be securely tied down;

(

e) after penetration of the Mannville Formation, the

drilling fluid density shall be adequate to exert a minimum overbalance

pressure of 1400 kilopascals at the Mannville Formation prior to tripping

pipe out of the hole.

Section 8.130(3) is amended by striking out "Class I and" and

substituting "Class I, Class IA or".

Section 8.131 is amended by adding the following after clause (a):

(a.1) Class IA: a well that will produce crude oil or crude bitumen

with a density of 920 kg/m3 or greater and in respect of which a reduction

in conventional surface casing depth could be or has been approved by the

Board,

Section 8.133(1) is amended by adding "and Class IA" after "Class I".

Section 8.134(1) is amended by adding "and Class IA" after "Class I".

Section 8.135 is amended by adding the following after subsection (4):

(4.1) The bleed-off system for wells in Class IA shall consist of

(

a) a minimum 152 mm full opening remotely activated

valve, and

(

b) a 152 mm bleed-off line.

(4.2) If the bleed-off line referred to in subsection

(4.1) terminates in a flare tank, the Board may on application reduce the length

of the line from 50 m to 25 m.

Section 8.137 is amended by adding the following after subsection (3):

(4) If a potential hydrocarbon bearing zone has been penetrated,

either a bottoms-up circulation shall be conducted or a weighted tripping

pill shall be pumped prior to pulling pipe from the well.

(5) A 5-minute flow check shall be conducted and recorded in the

drilling log book at the following stages during trips:

(

a) during a trip-out,

(

i) after pulling the first 5% of the drill

pipe from the hole,

(ii) at the mid-point depth of the well

bore,

(iii) prior to pulling the first stand of

drill collars from the hole, and

(iv) after all of the drill string is pulled

out of the hole;

(

b) during a trip-in,

(

i) on reaching the surface casing shoe

with the drill string, and

(ii) at the mid-point depth of the wellbore.

(6) In the case of Class III wells, the trip tank design must be

such that a change in level of 25 mm equals a volume change of not more

than 0.075 m3, equating to a maximum surface area of 3.0 m2.

(7) Notwithstanding subsection (6), a trip tank with larger surface

areas is permitted if equipped with an electronic trip tank monitoring

device capable of showing volume changes of 0.03 m3 or less, in the

oversized tank.

(8) Unless an electronic pit volume totalizer is installed and

operating, the driller shall at all times know the normal fluid level in

the mud tanks as indicated by the pit level indicator.

Section 8.141 is amended

(

a) by adding the following after subsection (5):

(5.1) In the case of a Class IA well,

(

a) a daily function test must be conducted on the

annular preventer,

(

b) the full-opening valve on each well must be

function tested at least once, and

(

c) pressure tests under this

section are not required.

(

b) by adding the following after subsection (7):

(8) Prior to assembly, all connections between the choke manifold

and mud gas separator and between the choke manifold and the end of the

flare line shall be visually inspected.

(9) After assembly of the connections, an inspection shall be

conducted to ensure proper make-up.

(10) The results of the inspections under subsections (8) and

(9) shall be recorded in the drilling log book.

Section 8.142 is amended

(

a) in subsection (1) by adding the following after clause (c):

(c.1) except for wells in Class I, Class IA and Class II,

if hydrocarbon-bearing zones have been penetrated, either the Rig Manager

or the Licensee Wellsite Representative

(

i) shall be on site during tripping in or

out of the well, and

(ii) shall possess a valid "Second Line

Supervisor's" well control certificate,

(

b) by adding the following after subsection (1):

(1.1) Notwithstanding subsection (1)(c.1)(i), if it is necessary to

make an unscheduled trip when neither of the persons referred to in

subsection (1)(c.1) is present, the trip may commence immediately after

contacting one of those persons and, in that case, the person shall return

to the wellsite immediately on being contacted.

(

c) in subsection (2) by striking out "subsection (1), clauses (

b) and (c)" and substituting "subsection 1(b), (

c) and (c.1)".

Section 8.144 is amended

(

a) in subsection (1)

(

i) in clause (a)(ii) by striking out "940" and

substituting "920";

(ii) by striking out "and" at the end of clause (

b) and

by adding the following after clause (b):

(b.1) Class IIA: a well that produces heavy

oil with a density greater than 920 kilograms per cubic metre and has a

gas-oil ratio of less than 70 cubic metres per cubic metre, a maximum

potential hydrogen sulphide release rate of less than 0.001 m3/second and

an expected bottom hole pressure of less than 21 000 kilopascals, and

(

b) by adding the following after subsection (3):

(4) Notwithstanding that a rig pump, tank or circulation manifold is

not required during servicing operations on a Class IIA heavy oil or oil

sands well, return fluids must be contained, and if a rig tank is used it

must be located a minimum of 15 metres from the well.

Section 8.145(5) is amended by striking out "Classes I and II" and

substituting "Classes I, II and IIA".

Section 8.146(2) is amended

(

a) by striking out "Classes II and III" and substituting "Classes

II, IIA and III";

(

b) in clause (

b) by striking out "section 8.144, subsection (2),

clause (c)" and substituting "section 8.144(2)";

(

c) in clause (

c) by adding "except for Class IIA wells," after

"tank,".

Section 8.147 is amended by adding the following after subsection (1):

(1.01) The first well of a servicing program for Class IIA and Class

III wells shall have the blowout prevention system components pressure

tested as specified in subsection (1).

(1.02) Blowout prevention system components in Class IIA and Class

III wells must be pressure tested as specified in subsection (1)

(

a) every 7 days after the testing referred to in

subsection (1.01) in the case of a secondary recovery well servicing

program, and

(

b) every 30 days after the testing referred to in

subsection (1.01) in the case of a primary recovery well servicing program.

(1.03) Each blowout prevention system component in a well in a

secondary recovery servicing program must be pressure tested as specified

in subsection (1) for at least 2 minutes before the well is serviced.

Section 8.148 is amended by adding the following after subsection (6):

(7) Bailing operations on a heavy oil or oil sands well may be

conducted to an open tank adjacent to the well, but the tank must be

removed as soon as bailing operations are completed.

(8) A blowout preventer that is capable of closing on the rod string

is required while tripping rods on a secondary recovery heavy oil or oil

sands well.

(9) The blowout preventer must be hydraulically operated with the

control located no closer to the well than the driller's control panel.

(10) If the blowout preventer is operated using service rig

hydraulics, an alternative method to operate the preventer must be

provided, with the controls located at least 7 metres from the well.

47 The heading preceding

section 8.150 and sections 8.150 and 8.160 are

repealed and the following is substituted:

Waste Management at Well and Facility Sites

8.150(1) In this section, "oilfield waste" does not include drilling

mud and cuttings.

(2) The licensee of a well or pipeline and the operator of a

facility generating oilfield waste shall

(

a) properly characterize and classify oilfield wastes,

(

b) use appropriate oilfield waste storage, treatment

and disposal practices,

(

c) understand the capabilities and limitations of the

methods selected for the treatment and disposal of oilfield wastes that are

generated,

(

d) complete and maintain accurate oilfield waste

documentation and records,

(

e) disclose to waste carriers and receivers the

characteristics and classification of the oilfield wastes, and

(

f) ensure that waste operational requirements have

been satisfied and, if applicable, approvals are in place for on-site

oilfield waste handling, treatment, and disposal methods

in accordance with the requirements outlined in Guide 58, "Oilfield

Waste Management Requirements for the Upstream Petroleum Industry", and any

other requirements as directed by the Board.

(3) The operator of a facility receiving oilfield waste shall

(

a) ensure that all required approvals are in place and

operational requirements have been satisfied for all oilfield waste

storage, handling, treatment and disposal methods,

(

b) understand the capabilities and limitations of the

treatment and disposal methods of the facility and communicate those

capabilities and limitations to oilfield waste generators,

(

c) accept only those oilfield wastes that the facility

is approved to receive,

(

d) maintain accurate and complete oilfield waste

documentation and records,

(

e) operate the facility in compliance with required

licences and approvals, and

(

f) upgrade equipment and operating practices as

necessary to comply with changes in regulatory requirements,

in accordance with the requirements outlined in Guide 58, "Oilfield

Waste Management Requirements for the Upstream Petroleum Industry", and any

other requirements as directed by the Board.

(4) The licensee of a well or pipeline and the operator of a

facility shall maintain the well, pipeline or facility in a clean condition

and shall ensure that oilfield wastes do not create or constitute a safety

hazard or nuisance or adversely affect air, soil, surface water or

groundwater.

8.151(1) In this section, "drilling waste" means the mud and

cuttings generated from drilling a well.

(2) A licensee of a well shall ensure that an earthen excavation at

a well site used to store drilling waste

(

a) is so located and constructed that it will not

collect natural run-off water, and

(

b) is so located and constructed that it will not

allow contaminants from the drilling waste to migrate beyond the pit walls

and bottom.

(3) Where the surface topography or soil conditions are such that a

satisfactory storage pit of sufficient design and capacity cannot be

constructed, the licensee of the well shall contain drilling waste in tanks

and shall dispose of the waste without undue delay.

(4) All drilling waste shall be treated and disposed of in

accordance with

(

a) the requirements in Guide 50, "Drilling Waste

Management",

(

b) the requirements in Guide 58, "Oilfield Waste

Management Requirements for the Upstream Petroleum Industry", or

(

c) other requirements approved by the Board.

8.152 The Board may, on application, approve alternative storage,

treatment and disposal methods to those prescribed in sections 8.150 and

8.151 if the Board is satisfied that those alternative methods will not

adversely affect air, soil, surface water or groundwater.

48 The following is added after

section 8.170:

8.171 If the Board considers that a facility, other than a battery,

may, due to its location or nature, constitute a serious hazard to the

general public, the Board may require that the facility be fenced in

accordance with

section 8.170(2).

Section 10.020(2) is repealed.

50 Sections 10.030 and 10.040 are repealed.

51 The heading "Proration, Distribution and Allowables" preceding

section

10.070 and sections 10.070 to 10.090 are repealed.

52 The heading "Gas Base Allowables" is added before

section 10.095.

Section 10.095 is repealed and the following is substituted:

10.095 The gas base allowable of a well shall be its Qmax as shown

in the subsisting gas allowable order.

Section 10.200 is repealed and the following is substituted:

10.200 In sections 10.220 to 10.280, "overproduction" means the

production of oil or gas in excess of the oil or gas allowable or control

well rate determined in accordance with a subsisting order or directive of

the Board.

Section 10.270 is amended by adding ", in accordance with the

Allowables Handbook G-7-1 and Interim Directive 99-2" after "production".

Section 10.280 is repealed and the following is substituted:

10.280(1) Cumulative overproduction of an allowable or control well

rate at a production entity for oil shall be dealt with in accordance with

the Allowables Handbook G-7-1 and Interim Directive 99-2.

(2) Where the cumulative overproduction of an allowable at a

production entity for gas at the end of an allowable period is 20% or more

of the gas allowable for the allowable period, the Board, without further

notice, may restrict the gas allowable in the next succeeding period to an

amount equivalent to the gas allowable that the production entity would

otherwise have less an amount equal to 0.50 times the cumulative

overproduction in excess of 10% of the gas allowable for the period ending.

(3) Notwithstanding subsections (1) and (2), where a well is

overproduced and, after notice, the well continues to be overproduced, the

Board may take such measures as may be necessary to remedy the

overproduction status, including shutting in the well.

Section 10.290 is repealed.

Section 10.300(1) is amended

(

a) in clause (

a) by striking out "section 11.130" and substituting

"Guide G-40";

(

b) by striking out "or" at the end of clause (b).

Section 10.330(1) is amended by adding "group" before "measurement".

60 The heading "Proration of Battery Injection" preceding

section 10.340

and

section 10.340 are repealed.

Section 11.150(2)(

b) and (

c) are repealed and the following are

substituted:

(

b) notify a Board representative at the appropriate field centre

at least 3 days in advance of any segregation test at the well,

(

c) retain the data that substantiate segregation in the well and

the analysis and

interpretation verifying segregation in the well for a

period of 5 years from the date of each segregation test, and

(

d) make the data, analysis and

interpretation available to the

Board on request.

Section 12.111 is repealed and the following is substituted:

12.111(1) The operator of an oilfield waste management facility

where crude oil is recovered shall supply to the Board monthly statements

(

a) oilfield wastes received, including place of

origin,

(

b) inventory, and

(

c) disposition of all separated streams including

recovered oil, waste water and residual solids.

(2) The operator of an oilfield waste management facility shall keep

records and submit reports to the Board

(

a) as specified in Guide 58, "Oilfield Waste

Management Requirements for the Upstream Petroleum Industry" and in the

facility approval, and

(

b) as otherwise directed by the Board.

Section 12.120 is repealed and the following is substituted:

12.120 Unless otherwise directed by the Board, the operator of a

scheme for enhanced recovery of oil shall file reports with the Board in

accordance with the terms of any order, approval or written request of the

Board.

Section 12.130 is repealed.

Section 12.150(3)(

a) is amended by striking out "12.130" and

substituting "12.120".

Section 14.020 is amended by renumbering it as

section 14.020(1) and

by adding the following after subsection (1):

(2) A record or report of any measurement of liquid required by the

Act or these Regulations shall be made in units of cubic metres to one

decimal place.

Section 14.040 is amended

(

a) in subsection (1) by striking out "The" and substituting

"Subject to subsection (2), the";

(

b) by repealing subsection (2) and substituting the following:

(2) The Board, on its own motion or on application in writing,

may relieve the licensee of the requirement of subsection (1), subject to

the condition that the licensee supply to the Board satisfactory estimates

of the volumes of gas produced.

Section 14.070 is amended

(

a) by repealing subsection (3) and substituting the following:

(3) The licensee of an oil well at which gas is produced shall

use for the metering of gas production a 24-hour chart drive unless

(

a) the Board has otherwise identified conditions where

a slower chart drive will be acceptable, or

(

b) on application and on being satisfied that gas

production can be accurately determined, the Board permits the use of a

slower chart drive.

(

b) by repealing subsection (7) and substituting the following:

(7) Unless otherwise required by the Board, the computation period

for the gas volumes measured shall be for the period of the chart rotation.

Section 14.090(3) is amended by striking out "A" and substituting

"Unless the Board has stipulated an alternate calibration method for the

purposes of subsection (2), a".

Section 14.100(3) is amended by striking out "manual gauging or oil

meter" and substituting "gauging, a weight scale or an oil meter".

Section 14.140(1) is repealed and the following is substituted:

14.140(1) A measurement of water required by the Act or a regulation

or order made under the Act shall be made at a temperature of between -5øC

and 50øC and the water volume so determined shall be computed as the number

of cubic metres it would occupy at a temperature of 15øC.

Section 14.150(2) is amended by striking out "is less than" and

substituting "does not exceed".

Section 14.160(2) and (3) are amended by striking out "is less than"

and substituting "does not exceed".

Section 14.190 is amended by striking out "lesser testing frequency"

and substituting "reduced calibration frequency".

75 The heading "Water Disposal" preceding

section 15.070 and

section

15.070 are repealed and the following is substituted:

Disposal of Fluid or Other Substance

15.070(1) An application under

section 39(1)(

d) of the Act for

approval of a scheme for the storage or disposal of any fluid or other

substance to an underground formation through a well shall be made in

accordance with Guide 65, "Resources Applications for Conventional Oil and

Gas Reservoirs".

(2) The Board may require any other information in relation to the

application referred to in subsection (1).

Section 15.130 is repealed.

Section 15.140(3) is amended by striking out "300 m3 per day" and

substituting "the volume prescribed by the Board for the purposes of this

subsection".

78 The heading "Battery Construction" preceding

section 15.210 is struck

out and the heading "Facility Construction" is substituted.

79 The heading "Waste Processing and Disposal Facility" preceding

section

15.212 and

section 15.212 are repealed and the following is substituted:

Oilfield Waste Management Facility

15.212 An application under

section 7.002 for approval of a new

oilfield waste management facility or for approval of a modification to an

existing oilfield waste management facility shall include

(

a) information to appropriately address the

application requirements outlined in Guide 58, "Oilfield Waste Management

Requirements for the Upstream Petroleum Industry", and

(

b) any other information the Board may require.

80 The heading "Flaring of Sour Gas" preceding

section 15.240 and

section

15.240 are repealed.

81 Schedules 8, 9, 10 and 11 are repealed and Schedules 8, 9, 10 and 11

to this Regulation are substituted.

Schedule 16 to this Regulation is added after

Schedule 15.

SCHEDULE 8 Page 1 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

BLOWOUT PREVENTION SYSTEMS

EQUIPMENT CODE

R single ram type preventer with one set of rams, either blank or for

pipe

A annular-type blowout preventer

S drilling spool with flanged side outlet connections for bleed-off and

kill lines

METRIC SYMBOLS

m metre mm millimetre kPa Kilopascal

EQUIPMENT SYMBOLS

Note:

1. A double gate blowout preventer may replace a single gate preventer

but the lowest ram in any stack shall be a pipe ram.

SCHEDULE 8 Page 2 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS - CLASS I

FOR WELLS WITHOUT SURFACE CASING SET

NOTE:

1. See Page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 3 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS

- CLASS IA

FOR HEAVY OIL AND OIL SANDS

Note:

1. Flanged or welded connections are not mandatory.

2. A manifold is not required.

3. Hydraulic control system as per Class I system

SCHEDULE 8 Page 4 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS

CLASS II

FOR WELLS NOT EXCEEDING A DEPTH OF 750 m

Minimum pressure rating 14 000 kPa

Note:

1. Bleed-off system shall be minimum nominal 75 mm diameter throughout

except for lines through chokes and to mud system which may be 50 mm.

2. Flanged pipe connections from the drilling spool down to and

including the connection to the choke manifold, remainder of manifold may

contain threaded fittings.

3. See page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 5 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS - CLASS III

FOR WELLS NOT EXCEEDING A DEPTH OF 1800 m

Minimum pressure rating 14 000 kPa

Note:

1. Bleed-off system shall be minimum normal 75 mm diameter throughout

except for lines through chokes and to mud system which may be 50 mm.

2. Flanged pipe connections from the drilling spool down to and

including the connection to the choke manifold, remainder of manifold may

contain threaded fittings.

3. See note on page 1 of 9 of

Schedule 8 for double gate preventers.

4. A second drilling spool may be installed between the lower pipe ram

and casing bowl, in which case a valve on the casing bowl is not required.

5. See page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 6 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS - CLASS IV

FOR WELLS NOT EXCEEDING A DEPTH OF 3600 m

Minimum pressure rating 21 000 kPa

Note:

1. Bleed-off system shall be minimum nominal 75 mm diameter throughout

except for lines through chokes and to mud system which may be 50 mm.

2. Flanged pipe connections from the drilling spool to the last valve on

the manifold, inclusive.

3. A second drilling spool may be installed between the lower pipe ram

and casing bowl, in which case a valve in the casing bowl is not required.

4. See page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 7 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS - CLASS V

FOR WELLS NOT EXCEEDING A DEPTH OF 6000 m

Minimum pressure rating 34 000 kPa

Note:

1. Kill and bleed-off 75 mm minimum nominal diameter throughout.

2. Flanged pipe connections from the drilling spool to the last valve on

the manifold, inclusive.

3. The lower drilling spool may be installed on the casing bowl provided

the lower pipe ram is installed immediately below the blind ram. A casing

bowl valve is not required in this case.

4. See page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 8 of 9

referred to in sections 8.131 of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION SYSTEMS - CLASS VI

FOR WELLS EXCEEDING A DEPTH OF 6000 m

Minimum pressure rating 69 000 kPa

Note:

1. Kill and bleed-off systems 75 mm minimum nominal diameter

throughout.

2. Flanged pipe connections from the drilling spool to the last

valve on the manifold, inclusive.

3. The lower drilling spool may be installed on the casing bowl

provided the lower pipe ram is then installed immediately below the blind

ram. A casing bowl valve is not required in this case.

4. See page 1 of 9 of

Schedule 8 for equipment symbols.

SCHEDULE 8 Page 9 of 9

referred to in sections 8.129(4) of the Oil and

Gas Conservation Regulations

DRILLING BLOWOUT PREVENTION CONFIGURATION

SPECIFIC HIGH HAZARD AREA

OF SOUTHEASTERN ALBERTA

Note:

1. Refer to Interim Directive 92-1 "Drilling Blowout Prevention

Modification.

SCHEDULE 9

STANDARDS OF ACCURACY FOR

GAS AND LIQUID MEASUREMENT

A Oil Systems

Maximum Uncertainty of Monthly Volume

(

i) Total battery oil (delivery point measurement)

Delivery point measures more than 100 cubic metres per day

Delivery point measures less than or equal to 100 cubic metres per day

0.5%

(ii) Total battery gas, fuel gas or flare gas

More than 16.9 thousand cubic metres per day

More than 500 cubic metres per day but less than or equal to 16.9 thousand

cubic metres per day

Less than or equal to 500 cubic metres per day

10%

20%

(iii) Total battery water

More than 50 cubic metres per month

Less than or equal to 50 cubic metres per month

20%

(iv) Well oil (proration battery)

Class 1 (High), more than 30 cubic metres per day

Class 2 (Medium), more than 6 cubic metres per day but less than or equal

to 30 cubic metres per day

Class 3 (Low), more than 2 cubic metres per day but less than or equal to 6

cubic metres per day

Class 4 (Stripper), less than or equal to 2 cubic metres per day

10%

20%

40%

(

v) Well gas (measurement uncertainty only)

More than 16.9 thousand cubic metres per day

More than 500 cubic metres per day but less than or equal to 16.9 thousand

cubic metres per day

Less than or equal to 500 cubic metres per day

10%

20%

(vi) Well water (measurement uncertainty only)

10%

B Gas Systems

(

i) Gas deliveries

(ii) Plant inlet gas or group gas

(iii) Fuel gas

More than 500 cubic metres per day

Less than or equal to 500 cubic metres per day

20%

(iv) Flare gas

(

v) Acid gas

(vi) Dilution gas

20%

10%

(vii) Well gas

More than 16.9 thousand cubic metres per day

Less than or equal to 16.9 thousand cubic metres per day

Proration battery

10%

15%

(viii) Total water

(ix) Well water

10%

C Injection Systems

(

i) Total gas

(ii) Well gas

(iii) Total water

(iv) Well water

10%

10%

SCHEDULE 10 Page 1 of 4

referred to in sections 8.144 of the Oil and

Gas Conservation Regulations

SERVICING BLOWOUT PREVENTION SYSTEMS

CLASS I - RESERVOIR PRESSURE LESS

THAN 5500 kPa AND NO H2S PRESENT

Note: GAS WELL

1. Well is not killed.

2. A tubing and blind ram blowout preventer unit may be used in

lieu of an annular preventer (position of rams may be interchanged).

3. The tubing stripper may be located below the blowout

preventer(

s) provided it is an integral part of the wellhead.

4. Two flare lines - minimum diameter 50 mm or

One flare line - minimum diameter 75 mm, extending 50 m from

well.

Note: HEAVY OIL WELL

1. No bleed-off or kill line required.

2. Only applies to wells on primary production or in waterflood

schemes.

3. Oil density greater than 920 kg/m3 and gas-oil ratio less then

70 m3/m3.

SCHEDULE 10 Page 2 of 4

referred to in sections 8.144 of the Oil and

Gas Conservation Regulations

SERVICING BLOWOUT PREVENTION SYSTEMS

CLASS II - RATING OF PRODUCTION

CASING FLANGE IS LESS THAN OR

EQUAL TO 21 000 kPa

H2S CONTENT OF THE GAS IS LESS THAN

10 MOLES/KILOMOLE

Note:

1. Pressure rating of preventers is equal to or greater than the

production casing flange rating, or the formation pressure, whichever is

the lesser.

2. 50 mm lines throughout.

3. The positioning of the tubing and blind rams may be

interchanged.

4. Spool may have threaded side outlet (and valve) if wellhead has

threaded fittings.

5. A flanged blowout preventer port (and valve) below the lowest

set of rams may replace spool (valve may be threaded if wellhead has

threaded fittings).

SCHEDULE 10 Page 3 of 4

referred to in sections 8.144 of the Oil and

Gas Conservation Regulations

SERVICING BLOWOUT PREVENTION SYSTEMS - CLASS IIA

BOTTOMHOLE OR INJECTION PRESSURE LESS THAN

OR EQUAL TO 21 000 kPa

H2S RELEASE RATE IS LESS THAN 0.001 m3/s

Note:

1. Pressure rating of preventers is equal to or greater than

formation or injection pressure.

2. The positioning of tubing and blind rams may be interchanged.

3. The preventer connection to the wellhead may be threaded.

4. If spool installed, the valve connection to spool may be

threaded.

5. A flanged blowout preventer port (and valve) below the lowest

set of rams may replace spool (valve may be threaded) on primary wells.

6. All threaded connections to the working spool shall be

backwelded.

7. 50 mm kill line is required during the servicing of a secondary

recovery well.

SCHEDULE 10 Page 4 of 4

referred to in sections 8.144 of the Oil and

Gas Conservation Regulations

SERVICING BLOWOUT PREVENTION SYSTEMS - CLASS III

1. RATING OF PRODUCTION CASING FLANGE IS GREATER THAN 21 000 kPa, OR

2. RATING OF PRODUCTION CASING FLANGE IS LESS THAN OR EQUAL TO 21 000

kPa AND H2S CONTENT OF THE GAS IS EQUAL TO OR GREATER THAN 10

MOLES/KILOMOLE

Note:

1. Pressure rating of preventers is equal to or greater than the

production casing flange rating, or the formation pressure, whichever is

the lesser.

2. 50 mm lines throughout.

3. The positioning of the tubing and blind rams may be interchanged.

4. Spool may have threaded side outline (and valve) if wellhead has

threaded fittings.

5. A flanged blowout preventer port (and valve) below the lowest set of

rams may replace spool (valve may be threaded if wellhead has threaded

fittings).

SCHEDULE 11

referred to in sections 8.148 of the Oil and

Gas Conservation Regulations

EQUIPMENT SPACING FOR WELL SERVICING

Note:

1. The doghouse and light plant must be positioned in accordance

with smoking and open flame regulations, and regulations under the Safety

Codes Act.

2. All distances shown are minimum distances.

SCHEDULE 16

referred to in

section 7.030 of the Oil and

Gas Conservation Regulations

PRORATION TESTING REQUIREMENTS FOR

LIGHT AND MEDIUM DENSITY CRUDE OIL WELLS

Classa Name Oil Rate Minimum Minimum

No. m3/d Test Test

Frequency Duration (Hours)

1 High >30 3 per month 12

2 Medium >6 but ó30 2 per month 24

3 Low >2 but ó6 1 per month 24b

4 Stripper ó2 1 every quarter 24b

a Classification for each well shall be determined at least

semi-annually based on the average daily oil rate since the last

assessment. If a well experiences a large rate change, the operator shall

immediately change the classification.

b Operators should conduct longer duration tests for wells exhibiting

erratic rates.