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     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,
of

               (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.


2   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.


2   Section 1(c)(ix) is amended by striking out "miscellaneous steel" and
substituting "miscellaneous metals".


3   Section 2(c) is repealed and the following is substituted:

     (c)  revisions to structures.


4   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.


2   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. 


2   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.


3   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.


4   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.


5   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.


6   Section 6.030(2) is repealed.


7   Section 6.070 is amended by striking out "cirucmstance" and
substituting "circumstance".


8   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.


9   Section 6.101(4) is repealed.


10   The heading preceding section 7.001 is amended by striking out
"Batteries" and substituting "Facilities". 


11   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.


12   Section 7.002(2) is amended by striking out "a waste management
facility" and substituting "an oilfield waste management facility".


13   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. 


14   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.


15   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
16. 

     (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.


16   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". 


17   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.


18   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".


19   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.


20   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".


21   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". 


22   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. 


23   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.


25   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. 


26   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.


27   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. 


28   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. 


29   Section 8.070 is amended by striking out "battery" wherever it occurs
and substituting "facility".


30   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. 


31   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".


32   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.


33   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
8; 

               (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. 


34   Section 8.130(3) is amended by striking out "Class I and" and
substituting "Class I, Class IA or". 


35   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, 


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


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


38   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.


39   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.


40   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. 


41   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)". 


42   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. 


43   Section 8.145(5) is amended by striking out "Classes I and II" and
substituting "Classes I, II and IIA".


44   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,".


45   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.
     

46   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).


49   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. 


53   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.


54   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.


55   Section 10.270 is amended by adding ", in accordance with the
Allowables Handbook G-7-1 and Interim Directive 99-2" after "production".


56   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.


57   Section 10.290 is repealed.


58   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).


59   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.


61   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.


62   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
of

               (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.


63   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.


64   Section 12.130 is repealed.


65   Section 12.150(3)(a) is amended by striking out "12.130" and
substituting "12.120".


66   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.


67   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.


68   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.


69   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".


70   Section 14.100(3) is amended by striking out "manual gauging or oil
meter" and substituting "gauging, a weight scale or an oil meter".


71   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.


72   Section 14.150(2) is amended by striking out "is less than" and
substituting "does not exceed".


73   Section 14.160(2) and (3) are amended by striking out "is less than"
and substituting "does not exceed".


74   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).


76   Section 15.130 is repealed.


77   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.


82   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%

      1%


(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


      5%

     10%
     20%


(iii)  Total battery water

More than 50 cubic metres per month
Less than or equal to 50 cubic metres per month


      5%
     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


      5%

     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


      5%

     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


      
      3%

      5%



      5%
     20%


(iv)   Flare gas

(v)    Acid gas

(vi)   Dilution gas
     20%

     10%

      5%


(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


      5%
     10%
     15%


(viii)  Total water

(ix)  Well water

      5%

     10%


C  Injection Systems

(i)    Total gas

(ii)   Well gas

(iii)  Total water

(iv)  Well water


      5%

     10%

      3%

     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.