GEOTHERMAL RESOURCE DEVELOPMENT RULES
For information only: Made by the Alberta Energy Regulator on May 19, 2022
pursuant to section 26 of the Geothermal Resource Development Act.
Table of Contents
Part 1
Interpretation
1 Interpretation
2 Resident defined
3 Directives
Part 2
Applications, Licences,
Security and Variances
4 Application for approval or discharge of agent
5 Exemption from requirement to appoint agent
6 Licence eligibility requirements
7 Application for well licence
8 Application for facility licence
9 Application to change authorized purpose of well
10 Transfer of licence
11 Security for wells and facilities
12 Directives re licensee assessment, licensee
management, liability and security
13 Variances
Part 3
Geothermal Operations
Drilling, Completing, Servicing
and Other Operations
14 Approval of certain operations
15 Emergency variation or departure from program
16 Approval of injection or disposal
17 Approval of commingling of formation fluids
18 Advising field centre on commencement of drilling
19 Deviation and directional surveys
20 Removal of rig
21 Control of encountered fluids
22 Licence specifications
23 Minimum casing requirements
24 Surface casing requirements
25 Intermediate casing
26 Hydraulic fracturing operations
27 Use of high vapour pressure hydrocarbons
28 Casing cementing requirement
29 Annulus between casing
30 Tubing requirement
31 Recovered casing
32 Use of isolation packer
33 Surface and subsurface equipment
34 Testing, reports and repair requirements
35 Risk assessment, monitoring, mitigation and response
Drilling and Operations
Near Underground Mines
36 Drilling within 3 km of underground mine
37 Requirement for pillar in coal seam
38 Hole diameter requirements in coal seam
39 Decision of Regulator final
Signage
40 Posting of licence and amendments
41 Posting of entrance and wellhead signs
Emergency Preparedness and Response
42 Definitions
43 Preparation of corporate ERP
44 Preparation of ERP in respect of sour well
45 ERP update, training and emergency response
Storage
46 Use of earthen structures or excavations
47 Storage of materials
48 Venting of relief devices to open tank
Prevention of Spills or Releases
49 Equipment
50 Control of spills or releases from well or facility
51 Spill during transport from well or facility
52 Spill response contingency plans and training
53 Wells or facilities closer than 100 m to water
54 Abandonment of source of serious water pollution
Air Emissions Management
55 Compliance with Directive 060
56 Burning at a well or facility
57 Equipping wells if samples > 50 mol/kmol H2S gas
58 Flaring at well producing H2S gas
59 Wells where > 10 mol/kmol H2S gas present
60 Facilities where > 10 mol/kmol H2S gas present
61 Pumping well with potential to flow H2S to atmosphere
Waste
62 Management of oilfield waste
63 Management of drilling waste
64 Alternative management of waste
Blowout Prevention
65 Blowout prevention requirements
66 Drilling and servicing inspections
Fire Hazards, Exhaust and Smoking
67 Fire risks
68 Operation of vehicles near wellhead
69 Smoking
Fencing
70 Fencing of facility
71 Marking and fencing of well
Miscellaneous
72 Conservation
73 Detection of hydrocarbons in production fluids
74 Noise
75 Participant involvement
Part 4
Well Sampling, Testing,
Records and Reports
Sampling and Submission of Well Data
76 Submission of well data
77 Well tests, analyses, surveys, reports and logs
78 Analysis of reservoir fluids
79 Drillstem tests
80 Samples of drill cuttings
81 Core samples
82 Submission of core reports
83 Submission of well logs
Measurement
84 Calibration of instruments
85 Metering errors
86 Measurement of injection wells
87 Measurement requirements in Directive 089
Record, Reports and Confidentiality
88 Records and reports of well operations
89 Records of status of well
90 Record of production
91 Records under Directive 076
92 Report of fire
93 Report of casing leak or failure
94 Financial information
95 Confidentiality
Part 5
Suspension, Abandonment and Closure
96 Suspension of wells
97 Abandoned wells
98 Abandonment operations
99 Closure quotas
100 Regulator request for closure plans
101 Eligible requesters request for closure plan
102 Application for determination of costs
103 Abandonment of well drilled through coal
Part 6
General
104 Fees
105 Service of notice of garnishment
106 Forwarding garnished money or revenue
107 Service of notices
108 Expiry
109 Coming into force
Schedules
Part 1
Interpretation
Interpretation
1(1) In these Rules
(a) "applicant" means an applicant for a licence for a well or a
facility under the Act;
(b) "closed-loop well" means a well that is expected to have zero
fluid injection and zero fluid production from a zone when
fluids are circulated within the wellbore;
(c) "closure" means the phase of the energy resource
development life cycle that involves the permanent end of
operations including the abandonment and reclamation of
wells, facilities, well sites and facility sites;
(d) "Designated Information Submission System" means the
online data submission process established by the Regulator;
(e) "drilling waste" means the mud and cuttings generated from
drilling a well;
(f) "energy resource" means energy resource as defined in the
Responsible Energy Development Act;
(g) "observation well" means a well used to monitor downhole
temperature or pressure;
(h) "OGCA facility" means a facility licensed under the Oil and
Gas Conservation Act;
(i) "OGCA well" means a well licensed under the Oil and Gas
Conservation Act;
(j) "oilfield waste" means an unwanted substance or mixture of
substances that results from the construction, operation,
abandonment or reclamation of a well, facility, well site or
facility site, 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 and Parks;
(k) "open-loop well" means a well that is used to inject fluids
into a zone or produce fluids from a zone;
(l) "underground mine" means an excavation and the associated
infrastructure used to extract a mineral from the subsurface
without removing the overburden.
(2) A decision of the Regulator is final as to whether a definition in
subsection (1) is applicable in a particular case.
Resident defined
2 For the purposes of section 20 of the Act and these Rules,
(a) a licensee who is an individual is resident in a jurisdiction if
the individual makes the individual's home in and is
ordinarily present in that jurisdiction, and
(b) a licensee that is a corporation is resident in a jurisdiction if a
director or officer of the corporation or a person employed or
retained to provide services to the corporation makes their
home in that jurisdiction, is ordinarily present in that
jurisdiction and is authorized to
(i) make decisions respecting a licence for a well or facility
issued by
(A) the regulatory authority in that jurisdiction, or
(B) in the case of Alberta, the Regulator,
(ii) operate the well or facility, and
(iii) implement directions from the regulatory authority or,
in the case of Alberta, the Regulator, relating to the well
or facility.
Directives
3 In these Rules a reference to one of the following directives means
a reference to that directive as published by the Regulator and
amended from time to time:
(a) Directive 001: Requirements for Site Specific Liability
Assessments in Support of the ERCB's Liability
Management Programs;
(b) Directive 007: Volumetric and Infrastructure Requirements;
(c) Directive 008: Surface Casing Depth Requirements;
(d) Directive 009: Casing Cementing Minimum Requirements;
(e) Directive 010: Minimum Casing Design Requirements;
(f) Directive 013: Suspension Requirements for Wells;
(g) Directive 017: Measure Requirements for Oil and Gas
Operations;
(h) Directive 020: Well Abandonment;
(i) Directive 036: Drilling Blowout Prevention Requirements
and Procedures;
(j) Directive 037: Service Rig Inspection Manual;
(k) Directive 038: Noise Control;
(l) Directive 040: Pressure and Deliverability Testing Oil and
Gas Wells;
(m) Directive 050: Drilling Waste Management;
(n) Directive 055: Storage Requirements for the Upstream
Petroleum Industry;
(o) Directive 058: Oilfield Waste Management Requirements for
the Upstream Petroleum Industry;
(p) Directive 059: Well Drilling and Completion Data Filing
Requirements;
(q) Directive 060: Upstream Petroleum Industry Flaring,
Incinerating and Venting;
(r) Directive 67: Eligibility Requirements for Acquiring and
Holding Energy Licences and Approvals;
(s) Directive 068: ERCB Security Deposits;
(t) Directive 071: Emergency Preparedness and Response
Requirements for the Petroleum Industry;
(u) Directive 076: Operator Declaration Regarding Measurement
and Reporting Requirements;
(v) Directive 079: Surface Development in Proximity to
Abandoned Wells;
(w) Directive 080: Well Logging;
(x) Directive 083: Hydraulic Fracturing - Subsurface Integrity;
(y) Directive 087: Well Integrity Management;
(z) Directive 089: Requirements for Geothermal Resource
Development.
Part 2
Applications, Licences,
Security and Variances
Application for approval or discharge of agent
4 An application for the approval of an agent or for consent to
discharge an agent must be made in the form established for that
purpose by, and obtainable from, the Regulator.
Exemption from requirement to appoint agent
5(1) In this section, "mutual recognition agreement" means a valid
and subsisting agreement made between the Minister and a regulatory
authority of another jurisdiction for the purpose of recognizing
substantial regulatory equivalency and enabling reciprocity between
Alberta and that jurisdiction.
(2) The Regulator, on application, may grant an exemption from the
requirement under section 20 of the Act to appoint an agent if the
licensee applying for the exemption
(a) is resident in a jurisdiction outside Alberta that is a party to a
mutual recognition agreement and is subject to the authority
of the regulatory authority in that jurisdiction,
(b) is in compliance with all applicable legislation in Alberta and
in the jurisdiction in which the licensee is resident and all
applicable directives, orders, decisions, directions and other
instruments of the regulatory authority referred to in clause
(a) and of the Regulator,
(c) provides evidence satisfactory to the Regulator that the
licensee meets, and during the time the licence or approval is
in effect will continue to meet, the requirements set out in
subsection (3), and
(d) agrees to attorn to the jurisdiction of Alberta with respect to
all matters, obligations and liabilities pertaining to licences
and approvals issued by the Regulator.
(3) An exemption under subsection (2) is subject to the condition that,
in substitution for the requirements of section 20(2) of the Act, the
licensee must have
(a) sufficient numbers of individuals who are trained and
competent to
(i) carry out operations relating to a well or facility, as the
case may be, in compliance with the requirements of all
applicable legislation and all applicable directives,
orders, decisions, directions and other instruments of the
Regulator, and
(ii) respond sufficiently to incidents and emergencies,
and
(b) representatives at a well site during any drilling, completion,
stimulation, servicing and abandonment operations at the
well site who are authorized to make decisions respecting all
aspects of those operations.
(4) An exemption under subsection (2) ceases to have effect
immediately on
(a) the licensee ceasing to meet a requirement referred to in
subsection (2)(a), (b) or (d), or
(b) the Regulator determining that it is no longer satisfied that
the licensee meets or will continue to meet the requirements
set out in subsection (3).
Licence eligibility requirements
6(1) No person may acquire or hold a licence unless the person meets
the licence eligibility requirements set out in Directive 067 and
Directive 089, and in the case of a corporation, is
(a) registered, with an active status, under the Business
Corporations Act,
(b) incorporated by or under an Act of the Legislature, other than
the Business Corporations Act, and approved by the
Regulator as a corporation that may acquire or hold a licence,
(c) incorporated under the Bank Act (Canada),
(d) a railway company incorporated under an Act of the
Parliament of Canada,
(e) registered under the Loan and Trust Corporations Act, or
(f) an insurer licensed under the Insurance Act.
(2) If an applicant meets the licence eligibility requirements of
Directive 067 and Directive 089 to the satisfaction of the Regulator,
the Regulator may grant licence eligibility subject to any restrictions,
terms or conditions the Regulator considers appropriate.
(3) If an applicant does not meet the licence eligibility requirements of
Directive 067 and Directive 089 to the satisfaction of the Regulator,
the Regulator may refuse to grant licence eligibility.
(4) The Regulator may revoke or restrict the licence eligibility of an
applicant if the applicant fails to acquire licences under the Act within
a year of the day of the licence eligibility being granted by the
Regulator.
(5) A licensee must continue to meet the licence eligibility
requirements of Directive 067 and Directive 089 to the satisfaction of
the Regulator.
(6) The Regulator may restrict a licensee's eligibility to hold a licence
if the licensee does not meet the licence eligibility requirements of
Directive 067 to the satisfaction of the Regulator.
Application for well licence
7 An application for a licence for a well, or amendment of a licence
for a well, must be made in accordance with Directive 089.
Application for facility licence
8 An application for a licence for a facility, or for an amendment to a
licence for a facility, must be made in accordance with Directive 089.
Application to change authorized purpose of well
9(1) If a licensee intends to change the authorized purpose of the
licensee's well under this Act to a purpose authorized under the
Oil and Gas Conservation Act, the licensee must apply to the
Regulator to amend the licence to change the authorized purpose of the
well.
(2) An application to amend a licence to change the authorized
purpose of the well must be made in accordance with Directive 089
and as directed by the Regulator.
Transfer of licence
10(1) A transfer of a licence is not effective unless this section is
complied with.
(2) An application for a transfer of a licence must be made in
accordance with Directive 089 and submitted through the Designated
Information Submission System.
(3) If the Regulator directs the transfer of a licence under section 9(5)
of the Act, the person to whom the licence is so transferred must pay
the Regulator the fee set out in Schedule 1.
(4) If a licensee of one or more wells changes its name or
amalgamates with another company that results in a change of name,
the licensee must submit certificates of proof satisfactory to the
Regulator.
Security for wells and facilities
11(1) The Regulator may require an applicant for a licence or for an
amendment of a licence to provide a security deposit before issuing or
amending the licence.
(2) The Regulator may require a licensee, or an applicant for a transfer
of a licence who is not a licensee, to provide a security deposit
(a) before approving a transfer of a licence,
(b) at any time where the Regulator considers it appropriate to do
so to offset the estimated costs of suspending, abandoning or
reclaiming a well, facility, well site or facility site,
(c) at any time where the Regulator considers it appropriate to do
so to offset the estimated costs of providing care and custody
for a well, facility, well site or facility site, and
(d) at any time where the Regulator considers it appropriate to do
so to offset the estimated costs of carrying out any other
activities necessary to ensure the protection of the public and
the environment.
(3) The Regulator may require a security deposit to be provided, and
may administer a security deposit, on either of the following bases and
may convert a security deposit from one basis to the other:
(a) relative to a particular well, facility, well site or facility site;
(b) relative to the operations of the licensee generally.
(4) If the Regulator determines that a security deposit currently held
by the Regulator is inadequate for the purposes provided for in
subsection (2), the Regulator may require the licensee to provide any
additional amounts that the Regulator considers necessary.
(5) A security deposit must be in one of the following forms, as
determined by the Regulator:
(a) cash;
(b) an irrevocable letter of credit in a form acceptable to the
Regulator;
(c) another form of security acceptable to the Regulator.
(6) The Regulator may require that a security deposit be provided in
one payment or in portions in the amounts and at the times specified by
the Regulator.
(7) If a licensee fails to meet an obligation or carry out an activity in
respect of which the security deposit was provided, the Regulator may,
(a) in the case of a cash security deposit, apply all or part of the
security deposit held in the name of the licensee and any
earned interest towards the costs required to meet the
obligation or carry out the activity,
(b) in the case of a security deposit in the form of a irrevocable
letter of credit, cash the irrevocable letter of credit and apply
any or all of the cash towards the costs required to meet the
obligation or carry out the activity, or
(c) in the case of another form of security, call on the security
and apply any or all of the funds towards the costs required to
meet the obligation or carry out the activity.
(8) If a person other than the licensee does anything for the purposes
of meeting the obligation or carrying out the activity in respect of
which the security deposit was provided, the Regulator may distribute
any or all of the security deposit to that person for that purpose.
(9) On the request of a licensee, the Regulator must return a security
deposit, together with any earned interest, where the Regulator is
satisfied that the licensee
(a) has fully met all of the obligations and carried out all of the
activities in respect of which the security deposit was
provided, and
(b) has met the other eligibility requirements of the Regulator for
a full refund of the security deposit.
(10) On the request of a licensee, the Regulator may return part of a
security deposit where the Regulator is satisfied that the licensee
(a) has partially met the obligations and carried out the activities
in respect of which the security deposit was required, and
(b) has met the other eligibility requirements of the Regulator for
a partial refund of the security deposit.
Directives re licensee assessment, licensee
management, liability and security
12(1) A licensee must comply with information requirements set out
in Directive 089 in respect of licensee assessments and licensee
management.
(2) A licensee must comply with the requirements set out in Directive
001 and Directive 089 in respect of liability assessments and Directive
068 and Directive 089 in respect of security deposits, as applicable.
Variances
13(1) An applicant or licensee may, in accordance with Directive 089,
apply for a variance from a requirement in these Rules related to
licences, wells or facilities that is specified in that Directive.
(2) The Regulator may approve the variance, with any conditions the
Regulator considers appropriate.
Part 3
Geothermal Operations
Drilling, Completing, Servicing and Other Operations
Approval of certain operations
14(1) The licensee of a well must apply for and obtain the permission
of the Regulator before performing any of the following operations, or
causing or permitting them to be performed:
(a) suspend normal drilling operations;
(b) resume drilling operations after a previous completion,
suspension or abandonment of the well;
(c) abandon or plug back the well with a mechanical well bore
problem;
(d) undertake remedial operations for the purposes of eliminating
a vent flow or gas migration in accordance with Directive
087;
(e) undertake remedial operations for the purposes of eliminating
a leaking, open-hole abandonment.
(2) An application under subsection (1) must be made in the manner
directed by the Regulator.
(3) The Regulator may vary a program approved or alter a condition
prescribed in an approval granted under this section.
(4) If an operation approved under this section will deepen a well
beyond the formation authorized by the well licence, the Regulator
must amend the licence accordingly.
(5) The Regulator may first give orally an approval required under this
section.
Emergency variation or departure from program
15 In case of an emergency in which an immediate departure from or
variation in a program of operations approved or prescribed by the
Regulator is necessary, the departure or variation may be made to the
extent that it is necessary, and the licensee must immediately advise
the Regulator by the quickest effective means and must further report
to the Regulator as directed.
Approval of injection or disposal
16(1) No scheme for the injection or disposal of any fluid or other
substance to an underground formation through a well may be
proceeded with unless the Regulator has approved the scheme under
Directive 065 on any terms and conditions that the Regulator
prescribes.
(2) All fluid produced at a well or facility must be injected or disposed
of in accordance with a scheme approved by the Regulator under
subsection (1).
(3) A licensee may not inject reservoir fluids into a formation that is
different from the formation from which the reservoir fluids were
produced unless approved by the Regulator.
Approval of commingling of formation fluids
17(1) Unless approved by the Regulator, a licensee may not inject
into, or produce fluids out of, multiple formations without segregation
in the well bore.
(2) The Regulator may, on application, approve injection or
production without segregation in the well bore, where the Regulator is
satisfied that it is appropriate in the circumstances.
(3) An application for commingling of formation fluids must be made
as directed by the Regulator.
Advising field centre on commencement of drilling
18 On commencement of the drilling of a well the licensee must,
within 12 hours or as otherwise arranged with the Regulator, advise the
appropriate field centre of the Regulator.
Deviation and directional surveys
19(1) Unless the Regulator otherwise directs in writing, the licensee
of a well must make tests during drilling or cause tests to be made
during drilling at depth intervals not exceeding 150 m, for the purpose
of ascertaining to what extent the well deviates from the vertical.
(2) The licensee must, immediately on making a directional survey,
send to the Regulator the report of the survey.
(3) The Regulator may order the licensee to make any further
deviation or directional surveys that the Regulator considers necessary,
and may give directions as to the manner in which such tests or
surveys must be made.
Removal of rig
20(1) The licensee of a well may not remove or cause or permit to be
removed the rig, derrick or other equipment from a well without first
obtaining written approval of the Regulator, unless the licensee has
(a) completed the well in accordance with the licence, or
(b) suspended operations or abandoned the well in accordance
with the approval of the Regulator under section 14.
(2) The Regulator may first give orally an approval required by this
section.
Control of encountered fluids
21 The licensee of a well must, at all times during which the well is
being drilled, tested, completed or reconditioned,
(a) conduct operations, and
(b) maintain casing and control equipment
so that any oil, gas or water encountered is effectively controlled.
Licence specifications
22 The licensee of a well must comply with any specifications
stipulated in the licence for the well and with any further equipment
specifications that the Regulator, after consultation with the licensee,
may from time to time stipulate.
Minimum casing requirements
23(1) The licensee of a well must case it in a manner prescribed by
the Regulator in Directive 010 and Directive 089.
(2) Notwithstanding subsection (1), the Regulator may, on application
by the licensee of a well,
(a) consider and approve the use of a casing engineered to an
alternative standard, or
(b) if the Regulator is satisfied that in the particular
circumstances casing is not required, dispense with the
requirement to case the well.
Surface casing requirements
24(1) The licensee must set surface casing and meet requirements as
prescribed in Directive 008 and Directive 089.
(2) Where the required surface casing setting depth is less than
(a) 180 m, or
(b) the base of groundwater protection depth,
the casing string next to the surface casing must be cemented full
length.
(3) Notwithstanding any other provision, for any specific well or area,
the Regulator may prescribe and require the licensee of the well to
ensure that the surface casing is installed at any greater or lesser depth
that the Regulator considers appropriate in the circumstances.
(4) The licensee must ensure that the surface casing is cemented full
length before drilling more than 10 m beyond the casing setting depth.
(5) Notwithstanding the surface casing exemptions set out in Directive
008, the licensee of a closed-loop well must have the surface casing
completed to the base of ground water protection.
Intermediate casing
25 The licensee of a well may not drill beyond a depth of 3600 m
without first setting intermediate casing unless the Regulator is
satisfied that the casing is not required.
Hydraulic fracturing operations
26 If a well is hydraulically fractured, the licensee of the well must
comply with Directive 083 and Directive 089.
Use of high vapour pressure hydrocarbons
27(1) In this section "high vapour pressure hydrocarbon" means any
hydrocarbon and stabilized hydrocarbon mixture with a Reid vapour
pressure greater than 14 kPa.
(2) Where the licensee of a well uses a high vapour pressure
hydrocarbon in an operation at a well other than in the hydraulic
fracturing of a formation, the licensee must comply with the following:
(a) no open tanks may be used for storing, gauging or measuring the
pumping rate;
(b) a minimum distance of 50 m must be maintained between the
wellhead and the storage tank;
(c) positive shut-off valves must be installed between the tank
and the pump and between the pump and the wellhead;
(d) a check valve must be installed between the pump and the
well to prevent backflow from the well;
(e) all surface lines downstream from the pump must be pressure
tested to 10 000 kPa above the anticipated maximum
pressure to be encountered;
(f) no significant wastage may occur.
(3) Unless approved by the Regulator, high vapour pressure
hydrocarbons must not be used for the purpose of hydraulically
fracturing a formation.
Casing cementing requirement
28 The licensee must cement casing as required by Directive 009
unless the Regulator
(a) exempts the licensee from the requirements, or
(b) prescribes another method for cementing the casing
for a particular well or area.
Annulus between casing
29(1) The licensee of a well must leave the annulus between the 2nd
casing string and the surface casing open to the atmosphere in the
manner described in subsection (2).
(2) Subject to any other specifications that the Regulator may
prescribe in a particular case, the licensee of a well must vent the
annulus by a line that
(a) has a minimum diameter of 50 mm,
(b) extends at least 60 cm above ground level,
(c) terminates so that any flow is directed either in a downward
direction or parallel to the ground, and
(d) is equipped with a valve where the hydrogen sulphide
concentration in a representative sample of gas from the well
is found to exceed 50 mol/kmol.
(3) The working pressure rating in kPa of all parts of the surface
casing vent must be at least 25 times the numerical equivalent of the
surface casing depth in metres required.
(4) The Regulator may exempt a well from the requirements of this
section in accordance with Directive 087 where, in the opinion of the
Regulator, the circumstances warrant the exemption.
(5) Wells that are exempt from surface casing requirements under
Directive 008 are exempt from the requirements of subsections (1) to
(3).
Tubing requirement
30(1) All production from or injection to a well, except for a closed-
loop well, must be through tubing.
(2) The Regulator may, on application by the licensee, exempt a well
from the requirements of subsection (1) where, in the opinion of the
Regulator, the circumstances warrant the exemption.
(3) A licensee applying for an exemption under subsection (2) must
demonstrate that the measures the licensee has taken to reduce the risk
of escape of fluids resulting from corroded materials are adequate.
Recovered casing
31 No casing recovered from a well may be run as intermediate or
production casing unless it has been tested in a manner satisfactory to
the Regulator and shown to meet the Regulator's requirements.
Use of isolation packer
32(1) Before any fluid other than potable water is injected to a
subsurface formation through a well the licensee must
(a) set an isolation packer in the well as closely above the
injection interval as is practicable, and
(b) fill the space between the tubing and outer steel casing with a
non-corrosive, corrosion-inhibited liquid,
but the Regulator, on application and in writing, may relieve the
licensee from any requirement of this subsection.
(2) If a well is equipped with an isolation packer as required by
subsection (1), the licensee must report test results in accordance with
Directive 087.
(3) If requested by the Regulator, the licensee must submit
(a) evidence to show, to the satisfaction of the Regulator, that the
liquid between the tubing and casing is isolated from the
fluid being injected, and
(b) the data that substantiates the isolation.
Surface and subsurface equipment
33(1) The surface and subsurface equipment of a completed well must
be arranged so as to permit the ready measurement of the tubing
pressure, production casing pressure, surface casing pressure and
bottom hole pressure, and permit any reasonable test required by the
Regulator except insofar as a completion technique approved by the
Regulator precludes such measurement or test.
(2) The surface equipment must include such valve connections as are
necessary to sample the fluids produced except insofar as a completion
technique approved by the Regulator precludes such connections.
(3) The licensee of a well, on completion of the well and on any
subsequent alteration, must keep and make readily available to the
Regulator an accurate and detailed description of all subsurface
equipment and its location in the well.
Testing, reports and repair requirements
34(1) A licensee must test, report and repair packer isolation, vent
flows, gas migrations and casing failures for all open-loop wells in
accordance with Directive 087.
(2) A licensee must test, report and repair vent flows, gas migrations
and casing failures in accordance with Directive 087 for all closed-
loop and observation wells.
Risk assessment, monitoring, mitigation and response
35 A licensee must meet the requirements in Directive 089 related to
risk assessment, monitoring, mitigation and response.
Drilling and Operations
Near Underground Mines
Drilling within 3 km of underground mine
36(1) Subject to subsection (2), no person may drill within 3 km of an
underground mine that is not abandoned or within 400 m of an
underground mine that is abandoned unless the person complies with
sections 37 and 38.
(2) The Regulator may, in writing,
(a) grant relief from any of the provisions of sections 37 and 38,
or
(b) direct, in a particular case, a change in any of the provisions
of section 37.
(3) The Regulator, in a particular case, may require compliance with
sections 37 and 38 by a person drilling at a greater distance than
stipulated in subsection (1) from an underground mine, and in such a
case sections 37 and 38 are deemed to apply to such a drilling
operation.
Requirement for pillar in coal seam
37 No person may drill a well through a coal seam in which
subsurface mining has been undertaken unless there can be left
surrounding the well bore a pillar of coal of a radius measured from the
well bore of 400 m, unless permission in writing is obtained from the
Regulator, subject to whatever direction the Regulator makes for the
drilling, completion and abandonment of the well.
Hole diameter requirements in coal seam
38(1) If a well is drilled through a seam of coal within 3 km of an
underground mine that is not abandoned or within 400 m of an
abandoned underground mine, the diameter of the hole to a depth of at
least 50 m below the base of the lowest workable coal seam must be at
least 90 mm larger than the diameter of the first casing string to be set
through the coal.
(2) The first casing string in the well to be set through the coal must
be
(a) new,
(b) equipped with suitable float equipment and a positive means
of insuring that the cement in the casing is not displaced from
the bottom 10 m of the casing string,
(c) assembled with the lowest 2 lengths of casing fastened
together by a suitable thread bonding material or other
equivalent means,
(d) run and set at a point at least 50 m below the base of the
lowest workable coal seam, and
(e) equipped with suitably located centralizers and scratchers on
the lowest length of casing and both above and below each
coal seam.
(3) If the distance between coal seams is less than 15 m, not more than
one centralizer and 3 scratchers are required for each 15 m of casing.
(4) The licensee must
(a) cement the well's first casing string to be set through the coal
as required by subsection (2) from bottom to top by the
circulation method with cement containing a proportion of
accelerator of not more than 0.04 t per t or other proportion
as the Regulator may approve for a particular well or area,
(b) have a survey made before the shoe of the casing is drilled
out, if cement returns are not received at the surface, to
determine to the satisfaction of the Regulator the position of
the top of the cement, and
(c) take such action following a survey under clause (b) to re-
cement as the Regulator may require.
(5) The cement at the shoe of the casing string set through the coal
may not be drilled out until 24 hours after the completion of cementing
or such longer length of time as the Regulator may require in a
particular case.
(6) If the lowest workable coal seam is below prudent surface casing
depth, the Regulator may require that the surface casing be set at a
shallower depth and that
(a) an intermediate string be run, to which subsections (1) to (5)
must apply, or
(b) subsections (1) to (4) must apply to the part of the hole and
the production casing extending from the shoe of the first
casing string to 50 m below the base of lowest workable coal
seam.
(7) If a subsequent string of casing is run
(a) its equipment must include an approved type of float shoe or
collar and an adequate program of centralizers and
scratchers,
(b) it must be cemented in compliance with the conditions
prescribed by the Regulator,
(c) the upper 150 m of cement around the casing must contain
not more than 0.03 t per t additives and the remainder of the
cement must develop not less than the minimum 24-hour
strength specified by the Regulator,
(d) the licensee must, before any testing or producing of the well,
have a temperature or other approved survey made to
determine the fill up of cement that, if it is a temperature
survey, must be made within 24 hours of the placement of
cement,
(e) if the cement does not reach the required level, the licensee
immediately must advise the Regulator and take such action
to re-cement as the Regulator may require, and
(f) the cement may not be drilled out until at least 24 hours after
the completion of cementing.
(8) The licensee must notify the Regulator through its appropriate area
office of an intention to cement any casing string or to run plugs at
least 12 hours before commencing such operations and may not
proceed with such operations until a representative of the Regulator is
present to inspect the casing and witness the cementing.
(9) If in the Regulator's opinion special circumstances are present, the
Regulator may alter the requirements of subsections (1) to (7) or
specify other requirements or provisions that the Regulator considers
necessary.
Decision of Regulator final
39 For the purposes of sections 36 to 38, the decision of the
Regulator as to
(a) whether an underground mine is or is not abandoned, or
(b) whether a coal seam is workable
is final.
Signage
Posting of licence and amendments
40 During drilling operations, the licensee of a well must post and
keep prominently displayed at the well site a duplicate of the licence
for the well, together with a duplicate of any amendments to the
licence.
Posting of entrance and wellhead signs
41(1) The licensee of a well must identify a well and the licensee of a
facility must identify a facility by the use of a conspicuous sign erected
at the primary entrance to the well or facility that indicates
(a) the name and telephone number of the licensee, and
(b) the legal description of the surface location of the well or
facility.
(2) Subsection (1) does not apply to a licensee of a well during drilling
and initial completion operations.
(3) A licensee must maintain a sign that is erected pursuant to
subsection (1) in a manner that is satisfactory to the Regulator.
(4) A licensee who operates more than one facility at a facility site
may erect one sign to identify all of the facilities at that site.
(5) A licensee who drills more than one well from one surface location
must identify the bottom hole location of each well on a sign affixed to
the wellhead.
(6) The licensee of a well or facility must post the following
categories of warning symbol, as applicable:
(a) Category I: Flammable (gas or liquid); Class 3;
(b) Category II: Poison Gas; Class 2.
(7) A Category II warning symbol must be used in the following
cases:
(a) where a facility handles or a well may produce gas
containing 0.01 mol/kmol of hydrogen sulphide or greater;
(b) where the Regulator so directs,
and a Category I warning symbol must be used in all other cases.
(8) Warning symbols must be of the size, design and colour shown in
Schedule 2.
(9) Warning symbols must be posted adjacent to all entrances to the
developed area of wells and facilities or, for wells and facilities that
have no access roads or developed areas, warning symbols must be
posted at the wellhead or facility.
(10) A warning symbol may be posted on a sign that is erected at the
primary entrance to a well or facility pursuant to subsection (1).
(11) No licensee may
(a) post warning symbols if a hazard does not exist, or
(b) post warning symbols that are not in compliance with this
section and Schedule 2.
Emergency Preparedness and Response
Definitions
42 In this section and sections 43 to 45
(a) "corporate ERP" means an ERP that applies to all wells and
facilities of a licensee;
(b) "emergency" means a present or imminent event, outside the
scope of normal operations, that requires prompt
coordination of resources to protect the health, safety or
welfare of people or to limit damage to property and the
environment;
(c) "ERP" means a comprehensive emergency response plan to
protect the public that includes criteria for assessing an
emergency and procedures to mobilize response personnel
and agencies and to establish communications and ensure
coordination of the emergency response;
(d) "sour gas" means any incidental formation gas containing
hydrogen sulphide;
(e) "sour well" means a well expected to encounter sour gas
bearing formations during drilling or any well incidentally
capable of producing sour gas.
Preparation of corporate ERP
43(1) A licensee of a well or facility must prepare a corporate ERP in
accordance with Directive 071.
(2) A licensee must on request file the corporate ERP referred to in
subsection (1) with the Regulator for review by the Regulator.
Preparation of ERP in respect of sour well
44(1) A licensee of a sour well must prepare a site-specific ERP for
each sour well in accordance with Directive 071.
(2) A licensee referred to in subsection (1) must submit a site-specific
ERP for each sour well to the Regulator for approval as required by
Directive 071.
ERP update, training and emergency response
45 A licensee referred to in section 43 or 44 must
(a) update the ERP and undertake training exercises, and
(b) in the case of an emergency, report the emergency to the
Regulator and implement the ERP
in accordance with Directive 071.
Storage
Use of earthen structures or excavations
46 Earthen structures or excavations may not be used as receptacles
for operational fluids, hydrocarbons, process chemicals, produced
water, process water or oilfield wastes (other than drilling wastes)
produced from a well or facility, either by design or normal operating
practice, without the written approval of the Regulator.
Storage of materials
47(1) Materials that are used, produced or generated at a well site or
facility, other than fresh water and inert solids, must be stored in
accordance with the requirements of Directive 055.
(2) Aboveground tanks, underground tanks, containers, lined earthen
excavations, bulk pads and any other storage device or system referred
to in Directive 055 must meet the requirements in Directive 055.
(3) The Regulator, on application, may approve storage methods,
systems or devices alternative to those set out in Directive 055 if in the
Regulator's opinion the level of environmental protection provided is
at least equal to that outlined in the Directive.
(4) Tanks or batteries of tanks containing fluids other than fresh water
at a well or facility must 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 m or a lesser distance permitted by the
Regulator.
Venting of relief devices to open tank
48(1) Notwithstanding section 59(5) and subject to subsection (2),
where a pressure relief valve, rupture disk or burst plate is installed on
a separator, treater or other pressure vessel that receives production
from a well, the licensee must connect the valve, rupture disk or burst
plate fitting by suitable piping to an open tank to contain the liquids.
(2) The Regulator, on application, may allow a licensee to use a
system of automatic controls or other method of avoiding spills if it is
satisfied that the degree of protection provided is equivalent to or
better than the venting of relief devices to an open tank.
Prevention of Spills or Releases
Equipment
49 A licensee must install equipment that will provide for the
protection of the environment from spills or uncontrolled releases of
fluids from the site.
Control of spills or releases from well or facility
50(1) If operating fluid, oilfield waste, water or hydrocarbon is spilled
or released from a break or leak in a wellhead, tank, separator, treater
or process vessel, the licensee of the well or the facility from which the
spill or release occurred must immediately take reasonable steps to
contain and clean up the spill or release and must ensure that the
spilled or released material is processed in the licensee's facility, if
appropriate, or is treated or disposed of, or both, in accordance with
Directive 058.
(2) If 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 m3, 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 must immediately report the spill or release to the
Regulator as required by this section, section 51 and Directive 089.
(3) When so directed by the Regulator, a report made under subsection
(2) must be confirmed in a written report to the Regulator 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 description of the spill or release containment and recovery
procedures;
(d) a description of steps to be taken to prevent similar future
spills or releases;
(e) the location of the spill or release;
(f) any other information that the Regulator may require.
Spill during transport from well or facility
51 If operating fluid, oilfield waste, water or hydrocarbon is spilled
while being transported, otherwise than by pipeline, from a well or
facility to the intended destination, the licensee of the well or facility
must immediately
(a) report the spill or release to the Regulator as required by
Directive 089,
(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 Directive 058, unless otherwise approved by
the Regulator.
Spill response contingency plans and training
52(1) A licensee of a well or facility must
(a) prepare a spill response contingency plan, and
(b) conduct spill training exercises and complete a training
exercise report
in accordance with Directive 071.
(2) If in the opinion of the Regulator a well or facility is a risk to a
water body due to its location near the water body, the Regulator may
require the licensee of the well or facility to demonstrate that the
licensee has the equipment and the ability to implement a spill
response contingency plan.
Wells or facilities closer than 100 m to water
53 If a well or facility is located closer than 100 m to the normal
high-water mark of a body of water or permanent stream, or is in a
location where in the opinion of the Regulator a spill or leak may reach
the water, the licensee must
(a) install on the wellhead, if the well is not on pump, a valve
that closes automatically to shut off an uncontrolled flow of
effluent from the well in the event of a failure of the
wellhead, surface facilities or gathering line,
(b) install in the well, at the direction of the Regulator, 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 wellhead 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 Regulator, 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, which includes details of procedures, materials
and equipment proposed to be used.
Abandonment of source of serious water pollution
54 If, in the opinion of the Regulator, the location or condition of a
well or facility is such that the well or facility may become a source of
serious water pollution, the Regulator may require that the well or
facility be abandoned.
Air Emissions Management
Compliance with Directive 060
55 The licensee of a well or facility must comply with the
requirements of Directive 060.
Burning at a well or facility
56(1) No person may burn, and no licensee, in the case of a well or
facility, may cause or permit to be burned, any oil, gas, oily waste or
other material produced or used at a well or facility except under
conditions of controlled combustion where there is no significant or
visible emission of smoke.
(2) Subsection (1) does not apply where the Regulator approves the
burning.
(3) Notwithstanding subsection (1), burning of effluent from a well or
facility is permissible under emergency conditions and due to
equipment failure, but the burning must be immediately reported to the
Regulator.
Equipping wells if samples > 50 mol/kmol H2S gas
57(1) This section applies to a well at which the hydrogen sulphide
concentration in a representative sample of gas from the well is found
to exceed 50 mol/kmol, or a higher or lower ratio that the Regulator
may stipulate with respect to any well or group of wells in an area,
having regard to pressures, nature of production, remoteness of the
area and other circumstances.
(2) Unless the well is produced by artificial lift, the licensee must
equip the well with
(a) 2 master valves,
(b) in the case of an open-loop well, an isolation packer, set as
closely above the producing formation as is practicable, with
the annular space between the tubing and production casing
filled with a suitable non-corrosive, corrosion-inhibited
liquid, and
(c) a wellhead with a working pressure rating that is not less than
the bottom hole pressure of the producing formation, except
for the surface casing vent, which must have a working
pressure rating in accordance with section 29(3).
(3) If a well is equipped with an isolation packer, as required by
subsection (2)(b), the licensee must report test results in accordance
with Directive 087.
(4) If requested by the Regulator, the licensee must submit
(a) evidence to show, to the satisfaction of the Regulator, that the
liquid between the tubing and casing is isolated from the
fluid being injected, and
(b) the data that substantiates the isolation.
(5) Stimulation treatments employing maximum pressures in excess of
75% of the minimum internal yield pressure of the production casing
must be carried out through the tubing and below a packer seated as
near to the production formation as is practicable.
(6) If the Regulator so directs, the licensee of a well must install in the
tubing of the well, at a minimum depth of 30 m below the surface, or
such other depth that the Regulator may prescribe, a valve that may be
controlled from the surface that will close automatically in the event of
an uncontrolled flow of fluids or gas, or a failure in the system that
operates the valve.
(7) The Regulator may, on application, exempt from any provision of
this section a well or group of wells in an area where, in the opinion of
the Regulator, the pressures, nature of production, remoteness of the
area or other circumstances warrant the exemption.
Flaring at well producing H2S gas
58(1) If gas
(a) from a well producing gas containing more than 50 mol/kmol of
hydrogen sulphide, or any higher or lower ratio stipulated by the
Regulator, 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 must obtain approval
from the Regulator of the method, stack height and equipment to be
used to flare the gas.
(2) An application for approval under subsection (1) must be in
accordance with Directive 060.
Wells where > 10 mol/kmol H2S gas present
59(1) This section applies to any well that produces gas containing
more than 10 mol/kmol hydrogen sulphide, or a higher or lower ratio
that the Regulator may stipulate with respect to any well or group of
wells in an area, having regard to pressures, nature of production,
remoteness of the area and other circumstances.
(2) The licensee of a well may not discharge or permit to be
discharged to the atmosphere any vapours or gas from process
equipment, tanks or the well, unless they are burned so that essentially
all sulphur compounds are converted to sulphur dioxide, but the
Regulator on written application may approve another method of
disposal.
(3) If no gas analysis has been taken from the well within the
preceding 12-month period, gas from the formation produced at the
well must be tested at the commencement of flaring to determine the
hydrogen sulphide content.
(4) If a flare stack is to be installed at a well for burning gas produced
during normal depressurizing operations or other routine flaring, the
licensee must install a flare stack constructed in accordance with the
specifications for a flare stack set out in subsection (8).
(5) If a pressure relief valve, rupture disk or burst plate is installed on
a separator or other pressure vessel that receives production from a
well, the valve, rupture disk or burst plate fitting must be connected to
the flare stack required by subsection (4).
(6) If a pressure relief valve, rupture disk or burst plate is installed on
a separator, treater or other pressure vessel that receives production
from a well, the vessel must be equipped with pressure and liquid level
sensors that cause a valve installed on the inlet to close and isolate the
vessel from the flow stream.
(7) The Regulator may, on application, exempt a licensee from the
requirements of subsection (6) and permit the use of a tank referred to
in section 48 where, in the opinion of the Regulator, the nature of the
production, the remoteness of the area or any other circumstance
warrants the exemption.
(8) If gas is produced from any well to the atmosphere during a
drillstem test, the licensee must burn the gas through a flare stack,
which must
(a) terminate with a vertical riser of at least 12 m or any greater
or lesser height that the Regulator directs in a particular case,
(b) be provided with a suitable guard to prevent the wind from
extinguishing the flame,
(c) be provided with a sweet gas pilot or ignition device, if the
gas flow may be intermittent, to ensure continuous ignition of
any vented gas, and
(d) be provided with a suitable vessel to separate and collect any
liquids to prevent the liquids from reaching the flame.
(9) If hydrocarbon liquids are produced from a well during any test,
during any period of cleaning out the well or during well-servicing
operations, the liquids must be separated and piped to a storage tank
and all gas must be discharged to a flare stack that meets the
requirements of subsection (8)(a), (b) and (c).
(10) Unless the licensee of a well equips and operates the well so that
the maximum operating flow line gauge pressure cannot exceed 1400
kPa, the licensee must install on the wellhead a mechanism that halts
the flow of fluids or gas in the event of an uncontrolled drop in
pressure or an equipment failure.
(11) The licensee of the well must, when requested to do so by the
Regulator, file with the Regulator an outline of emergency procedures
to ensure public safety that will be followed by the licensee in the
event of an uncontrolled emission of fluids or gas.
(12) The Regulator may exempt a well or group of wells in an area
from any provision of this section where, in the opinion of the
Regulator, the pressure, nature of production, remoteness of area or
other circumstances warrant the exemption.
Facilities where > 10 mol/kmol H2S gas present
60(1) This section applies to any facility that receives fluids
containing more than 10 mol/kmol of hydrogen sulphide in the gas
phase, or a higher or lower ratio as the Regulator may stipulate having
regard to the nature of production, the remoteness of the area and other
circumstances.
(2) The licensee of a facility may not discharge or permit to be
discharged to the atmosphere any vapours or gas from process
equipment, tanks or the facility, unless it is burned so that essentially
all sulphur compounds are converted to sulphur dioxide, but the
Regulator on written application may approve another method of
disposal.
(3) Gas burned or disposed of by a method approved under subsection
(2) must be burned or disposed of so as to ensure that the
concentrations of hydrogen sulphide and sulphur dioxide do not exceed
(a) the maximum permissible concentrations set out in the
Alberta Ambient Air Quality Objectives and Guidelines
Summary as established and amended from time to time by
the Department of Environment and Parks,
(b) standards to which the facility is subject under the
Environmental Protection and Enhancement Act, and
(c) standards specified by the Regulator.
(4) Gas that is required under subsection (2) to be burned must be
discharged from a flare stack that is in accordance with the
specifications outlined in section 59(8).
(5) The Regulator may, on application, exempt a facility from any
provision of this section where, in the opinion of the Regulator, the
nature of production, the remoteness of the area or any other
circumstance warrants the exemption.
Pumping well with potential to flow H2S to atmosphere
61 A licensee of a pumping well that has the potential to flow to
atmosphere at sustained rates of at least 8 m3/day of fluids and has a
hydrogen sulphide content of 10 mol/kmol or greater in the gas phase
must ensure that the well is equipped with a full opening master valve,
a hydraulic rod blowout preventer and an environmental blowout
preventer.
Waste
Management of oilfield waste
62(1) In this section, "oilfield waste" includes waste generated from
the development of geothermal resources but does not include drilling
waste.
(2) The licensee of a well or facility generating oilfield waste must
(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 management
in accordance with the requirements outlined in Directive 058 and any
other requirements as directed by the Regulator.
(3) The licensee of a well or facility must maintain the well or facility
in a clean condition and must ensure that oilfield wastes do not create
or constitute a safety hazard or nuisance or adversely affect air, soil,
surface water or groundwater.
Management of drilling waste
63(1) A licensee of a well must ensure that an earthen excavation at a
well site used to store drilling waste
(a) is located and constructed so that it will not collect natural
run-off water, and
(b) is located and constructed so that it will not allow
contaminants from the drilling waste to migrate beyond the
pit walls and bottom.
(2) If 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 must contain drilling waste in
tanks and must dispose of the waste without undue delay.
(3) The licensee of a well must ensure that all drilling waste is treated
and disposed of in accordance with
(a) the requirements in Directive 050,
(b) the requirements in Directive 058, or
(c) other requirements approved by the Regulator.
Alternative management of waste
64 The Regulator may, on application made in accordance with
Directive 050, Directive 055 or Directive 058, approve alternative
storage, treatment and disposal methods to those prescribed in sections
47, 62 and 63 if the Regulator is satisfied that those alternative
methods will not adversely affect air, soil, surface water or
groundwater.
Blowout Prevention
Blowout prevention requirements
65(1) The requirements of Directive 036 and Directive 037 apply to
any well that is being drilled, tested, abandoned, completed,
reconditioned or serviced.
(2) A licensee of a well referred to in subsection (1) must comply with
Directive 036, Directive 037 and with any other requirements as
directed by the Regulator.
(3) The Regulator may, on its own initiative or on application, vary or
specify the blowout prevention requirements that apply to any well or
wells.
(4) The Regulator may, on its own initiative or on application, vary a
classification set out in Directive 036 or Directive 037 for any well or
wells.
(5) The Regulator may, on its own initiative or on application, vary
the design or requirements for any classification set out in Directive
036 or Directive 037.
(6) Prior to making application for a well licence, the licensee must
(a) research offset well records to determine maximum pore
pressures and hole problems that may be encountered while
drilling the proposed well, and
(b) incorporate the information determined under clause (a) into
the well design.
(7) A licensee must make the information determined under
subsection (6)(a) available to the Regulator on request.
Drilling and servicing inspections
66(1) The Regulator may make a direction requiring the licensee of
the well to
(a) test the operation and effectiveness of blowout prevention
equipment required by Directive 036 and Directive 037,
(b) conduct a pressure test of the blowout prevention equipment
referred to in clause (a), using where necessary a hanger plug
or casing packer, and
(c) perform a blowout prevention drill.
(2) On a direction made by the Regulator and if the licensee believes it
is safe to do so, the licensee of a well must suspend or cause to be
suspended any operation or service being performed at a well until any
test required to be made, under subsection (1), has been completed.
(3) Any direction made by the Regulator under subsection (1) may be
made to the licensee of the well or to any contractor or other person
performing an operation or service referred to in subsection (2).
Fire Hazards, Exhaust and Smoking
Fire risks
67(1) In this section,
(a) "fire" means any open or enclosed flame or other source of
ignition except
(i) an open or enclosed flame from a flare stack or
incinerator, or
(ii) a source of ignition associated with the installation and
operation of electrical equipment;
(b) "flame-type equipment" means any fired equipment using an
open or enclosed flame and includes, without limitation, a
space heater, torch, heated process vessel, boiler, open-flame
welder and thermoelectric generator, but does not include a
flare stack or incinerator;
(c) "process vessel" means a heater, separator, treater or any
vessel used in the processing or conversion of geothermal
heat.
(2) No person may create or cause to be created any fire within 50 m of a
well or any source of ignitable vapour at a well or facility.
(3) No oil storage tank may be placed or remain within 50 m of any
well, but the Regulator may prescribe a distance of less than 50 m but
not less than 15 m in any field or at any well, having regard to the
products of the well.
(4) No flame-type equipment may be placed or operated within 25 m
of a well or any source of ignitable vapour except
(a) where the well is a water supply well,
(b) where the well is a water injection well equipped with a
suitable packer and with the surface casing annulus vented
outside any building,
(c) where the equipment is required to be used for emergency
work and the wellhead valves and the blowout preventer, if
one is installed, are closed, or
(d) where extenuating circumstances exist and the Regulator has
suspended the application of this subsection in the area.
(5) No flame-type equipment may be placed or operated within 25 m
of any process vessels unless the flame-type equipment is fitted with
an adequate flame arrestor.
(6) No flame-type equipment may be located in the same building as
any process vessel or other source of ignitable vapour, unless
(a) the air intakes and flues of all burners are located outside the
building,
(b) relief valves, safety heads and other sources of ignitable
vapours are vented outside the building and discharged above
roof level, and
(c) the building is adequately cross ventilated.
(7) All process vessels and equipment from which any ignitable
vapour may issue must be safely vented to the atmosphere, and all vent
lines from oil storage tanks that are vented to flare pits or flare stacks
must be provided with flame arrestors or other equivalent safety
devices.
(8) All installations at or near any well, process vessel or a source of
ignitable vapour must be made in compliance with regulations made
under the Safety Codes Act and the Occupational Health and Safety
Act.
(9) An exhaust pipe from an internal combustion engine, located
within 25 m of any well, process vessel or other source of ignitable
vapour, must be constructed so that
(a) any emergence of flame along its length or at its end is
prevented, and
(b) the end is not closer than 6 m to the vertical centre line of the
well, is projected upward and is directed away from the well.
(10) Each licensee of a well or facility at which there is located a
source of ignitable vapour must enforce the provisions of this section.
Operation of vehicles near wellhead
68 The licensee of a well must ensure that no vehicles operate within
a 3 m radius of the wellhead, except vehicles that are specifically
required to do so as part of an operation being performed on a well.
Smoking
69(1) No person may smoke within 25 m of a well, separator, oil
storage tank or other unprotected source of ignitable vapour, or on a rig
or derrick, at a well site.
(2) Each licensee of a well and each contractor who has contracted to
manage or perform any operation at a well must enforce the provisions
of subsection (1) at the well site.
(3) If 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.
Fencing
Fencing of facility
70(1) If the Regulator considers that a facility may, due to its location
or nature, constitute a serious hazard to the general public, the
Regulator may require the licensee of the facility to construct and
maintain an adequate fence around the facility.
(2) For the purpose of subsection (1), a fence must be considered
adequate if,
(a) where a facility is within 800 m of an occupied dwelling, a
school or a location developed for camping, picnic or day use
by the public, the fence
(i) is at least 2 m high,
(ii) is small mesh industrial type,
(iii) completely encloses the facility, and
(iv) is equipped with a gate that is locked when the facility
is unattended,
and
(b) where a facility is located elsewhere, it is a cattle-type fence
with a minimum of 4 strands of barbed wire and either a gate
or a cattle guard.
Marking and fencing of well
71(1) In this section, "unrestricted country development" means any
collection of permanent dwellings situated outside of an urban centre
and having more than 8 permanent dwellings per quarter section.
(2) The licensee of a well must ensure that the wellhead is
conspicuously marked or fenced in a manner that makes it visible in all
seasons.
(3) The licensee of a well that is equipped with a pumping unit and
located in or within 800 m of
(a) the boundaries of a city, town, new town, village, summer
village, hamlet or other incorporated centre,
(b) an unrestricted country development,
(c) a public facility,
(d) an occupied dwelling,
(e) a school, or
(f) a location developed for camping, picnic or day use by the
public
must enclose the well and pumping unit with a fence suitable for
preventing access to or tampering with the well and pumping unit.
(4) A fence required by subsection (3) must be
(a) of steel mesh, with the mesh not greater than 130 cm2,
(b) not less than 2 m high,
(c) placed around the entire pumping unit, wellhead and cellar,
and
(d) equipped with a gate that is locked when the well is
unattended.
(5) If, in the opinion of the Regulator, the location of a well that is
equipped with a pumping unit is or may become a serious hazard to the
general public, the Regulator may require that the well be fenced in
accordance with subsection (4).
(6) The Regulator may, on application, exempt the licensee from or
vary any of the requirements of this section where, in the opinion of
the Regulator, circumstances warrant the exemption or variation.
Miscellaneous
Conservation
72 A licensee may not waste energy resources.
Detection of hydrocarbons in production fluids
73(1) If production fluids from a well contain any incidental
hydrocarbons, the licensee of the well must
(a) cease operations, unless they have the right to produce the
hydrocarbons,
(b) immediately notify the Regulator, and
(c) apply to amend the licence, if directed to do so by the
Regulator, to change the authorized purpose of the well in
accordance with section 9.
(2) If the licensee has the right to produce the hydrocarbons and has
not been directed by the Regulator to apply to amend the licence, the
licensee must
(a) meet the hydrocarbon-related measurement requirements in
Directive 017, and
(b) report the production in accordance with Directive 007.
Noise
74 The licensee of a well or facility must meet the noise control
requirements in Directive 038.
Participant involvement
75 The licensee of a well or facility must meet the participant
involvement requirements in Directive 089.
Part 4
Well Sampling, Testing,
Records and Reports
Sampling and Submission of Well Data
Submission of well data
76 If a licensee of a well conducts or obtains well tests, analyses,
surveys, reports or logs, the licensee must submit all results to the
Regulator within the time period specified by the Regulator.
Well tests, analyses, surveys, reports and logs
77 The Regulator may require the licensee of a well to conduct or run
any reasonable or conventional test, analysis, survey or log or perform
any instrument calibration and to submit to the Regulator the
information so obtained.
Analysis of reservoir fluids
78 The licensee of a well must conduct initial and annual sampling
and analysis of reservoir fluids in accordance with Directive 089 and
must submit the analysis in accordance with Directive 040 and
Directive 089.
Drillstem tests
79 The licensee of a well must submit any drillstem tests that are
conducted at the well site to the Regulator in accordance with
Directive 040 and Directive 089.
Samples of drill cuttings
80(1) The licensee of a well must take samples of drill cuttings in
accordance with Directive 089.
(2) Within 2 weeks of the finished drilling date of a well, the licensee
must deliver the samples at the licensee's expense to the Regulator's
Core Research Centre, 3545 Research Way N.W., Calgary, Alberta
T2L 1Y7.
(3) Samples submitted under subsection (2) must meet the following
requirements:
(a) the samples are washed and dried;
(b) the samples are in 2 dram (19 mm x 48 mm) plastic vials;
(c) the vial caps are round and of low density polyethylene;
(d) the vial labels are 16 mm x 63 mm of latex laser sheet label
quality;
(e) the information on the label includes the unique well
identifier and the depth from which the sample was taken;
(f) the vials are packaged and submitted in lidded sample trays.
Core samples
81(1) When directed by the Regulator, the licensee of a well must
core each formation or part of a formation to which the direction
applies.
(2) Unless otherwise directed by the Regulator, the licensee may
remove and retain from any core recovered one longitudinal slab not
thicker than the lesser of 25 mm or 1/2 the thickness of the core.
(3) The licensee must
(a) place all core or parts of core remaining after the removal of
a slab in accordance with subsection (2) in cardboard core
boxes that fulfill the labelling and packaging requirements of
the Regulator, and
(b) forward the core intact at the licensee's expense, within 3
months of the finished drilling date of the well from which
the core was recovered, to the Regulator's Core Research
Center, 3545 Research Way N.W., Calgary, Alberta T2L
1Y7.
Submission of core reports
82 The licensee must submit to the Regulator, within one month of
the completion of any analyses made of the core involving
measurements of reservoir characteristics, 2 copies of reports of that
analyses.
Submission of well logs
83(1) The licensee must,
(a) before completion, abandonment or suspension of drilling
operations at a well, take well logs in accordance with
Directive 080,
(b) within one month of the rig release date of a well, submit to
the Regulator a copy of each log, survey or chart taken at the
well together with all pertinent data other than the check shot
calibrations made with reference to a velocity survey, and
(c) within one month of the run date, submit to the Regulator any
additional logs, including flow meter logs and related
analysis, taken at the well after the original logging
operation.
(2) Logs, surveys, charts and other data submitted under this section
must be in a format acceptable to the Regulator.
(3) The Regulator may on application allow substitution or grant relief
from the requirements of this section where special circumstances
warrant.
Measurement
Calibration of instruments
84 The licensee of a well must use instruments that meet the
following requirements:
(a) any dead weight gauge that is used to calibrate wire line
instruments for taking subsurface pressure measurements
must be certified annually by a calibration laboratory
accredited by the Standards Council of Canada through the
Calibration Laboratory Assessment Service of the National
Research Council of Canada or another calibration laboratory
certified as meeting ISO/IEC 17025 standards;
(b) the calibration must be obtained using an approved dead
weight gauge at a minimum of
(i) within 3 months prior to use in any survey,
(ii) twice after repairs or abnormal stresses, and
(iii) once annually under the necessary conditions to check
temperature sensitivity.
Metering errors
85 On the discovery of any metering error, the licensee must have the
meter corrected immediately and must report corrected production for
the period during which the meter measured incorrectly.
Measurement of injection wells
86 If gas, water or another substance is injected through a well to an
underground formation, it must be continuously measured by a method
satisfactory to the Regulator.
Measurement requirements in Directive 089
87 A licensee must meet the measurement requirements in Directive
089.
Records, Reports and Confidentiality
Records and reports of well operations
88 The licensee of a well must keep and file with the Regulator
records and reports relating to the operations of the well in accordance
with Directive 059 and Directive 089.
Records of status of well
89(1) The licensee of a well must, when required by Directive 007 or
Directive 089, keep a record relating to the status of a well and file the
record in accordance with that Directive.
(2) The licensee of a well must keep any other records relating to the
status of a well in addition to those described in subsection (1) and file
with the Regulator any other reports that the Regulator may require.
Record of production
90(1) The licensee of a well or a facility must, when required by
Directive 007 or Directive 089, keep records of any power, heat or
hydrocarbons encountered, and any water, air or other substances
produced, and file those records in accordance with those Directives.
(2) The licensee of a well or facility must keep a daily record of the
production operations of the well or facility in a form satisfactory to
the Regulator and keep the original recording of a measurement used
to determine the particulars for the record filed with the Regulator
under subsection (1).
(3) If a substance is received or delivered to a pipeline regulated under
the Pipeline Act, the licensee of the facility must, when required by
Directive 007 or Directive 089, keep records of the substance and file
the records with the Regulator in accordance with those Directives.
(4) The licensee of a well or facility must keep any other records
relating to production from a well or facility in addition to those
described in this section and file with the Regulator any other reports
that the Regulator may require.
Records under Directive 076
91 If Directive 076 applies to a well or facility, the licensee of the
well or facility must keep records in accordance with the requirements
of Directive 076 and provide copies of the records to the Regulator on
request.
Report of fire
92(1) The licensee of a well or facility must immediately report to the
Regulator any fire that occurs at a well or facility where the loss
exceeds 2 m3 of fluid or where damage to the wellhead occurs.
(2) Each report to the Regulator under subsection (1) must specify the
location of the well or facility.
Report of casing leak or failure
93 The licensee of a well must notify the Regulator immediately on
detection of a casing leak or failure and, if requested by a
representative of the Regulator, must provide a report assessing the
leak or failure, including a discussion of the cause, duration, damages,
proposed remedial program and measures to prevent future failures.
Financial information
94(1) A licensee must provide financial information to the Regulator
as and when directed by the Regulator for the purposes of
(a) assessing licensee eligibility,
(b) administering the liability management programs set out in
directives published by the Regulator, or
(c) to ensure the safe, orderly and environmentally responsible
development of energy resources in Alberta, including
closure.
(2) The information provided under this section must be kept
confidential by the Regulator for a period of 5 years.
Confidentiality
95(1) The following types of well data will remain confidential for
one year from the finished drilling date:
(a) any log and drillstem test data;
(b) wire line formation test data;
(c) pressure, temperature and flow test data;
(d) completion details;
(e) fluid analysis data;
(f) sample drill cuttings or core;
(g) core analysis data;
(h) hours on production and injection.
(2) The licensee may request extension of the period of
confidentiality, and if the licensee satisfies the Regulator that
continued confidentiality is warranted after the period referred to in
subsection (1), the Regulator may extend the confidentiality for a
further period that the Regulator considers appropriate.
(3) The Regulator, at any time, must make available to the public,
from records, reports or information submitted to or acquired by it,
(a) any application or submission of an applicant or intervener in
any proceedings before the Regulator under the Act or these
Rules and to which the Alberta Energy Regulator Rules of
Practice (AR 99/2013) apply, whether or not the proceeding
goes to a hearing or is otherwise disposed of, or any record,
report or information of an applicant or intervener filed by
the applicant or intervener in connection with the proceeding,
(b) the surface and bottom hole locations, elevation, current
depth, drilling status or casing and cementing data of a well,
(c) the monthly totals of each type of fluid injected into or
produced from a well, and
(d) any information submitted regarding hydraulic fracturing
fluids used in operations at any well.
(4) If interpretive data to determine the maximum hydrogen sulphide
release rate of a well that may encounter hydrogen sulphide are
submitted to and accepted by the Regulator as confidential, the
Regulator must make the data available to the public only with the
consent of the applicant or licensee.
(5) If any record, report or information submitted to or acquired by the
Regulator is not available to the public by reason of this section, the
Regulator may, with the consent in writing of the person by whom it
was submitted or from whom it was acquired, make the record, report
or information available to the public.
(6) Notwithstanding these Rules, the Regulator may make any data,
record, report or information available to a peace officer for the
purpose of enforcing the Criminal Code (Canada) or the laws of
Alberta.
(7) Nothing in this section requires the Regulator
(a) to obtain for the purpose of making it available any data it
otherwise does not have,
(b) to publish any data or make it available otherwise than on
request, or
(c) to make any data available otherwise than putting it on view
at the facilities provided for that purpose by the Regulator in
the ordinary routine observed in the Regulator's offices and
on payment of the Regulator's usual fees for such services.
(8) Notwithstanding anything in this section, the Regulator may make
any data, record, report or information submitted to the Regulator
available to the Minister of Energy for the purpose of calculating or
otherwise determining royalties on geothermal resources or other
substances receivable by or payable to the Crown in right of Alberta.
Part 5
Suspension, Abandonment
and Closure
Suspension of wells
96 A licensee must suspend a well when required by and in
accordance with Directive 013 and Directive 089, or as otherwise
directed by the Regulator.
Abandoned wells
97 A licensee must abandon a well or facility
(a) on the termination of the mineral lease or surface lease,
(b) where the licensee fails to obtain the necessary authorization
for the intended purpose of the well, if the licensee does not
hold the right to drill for and produce the geothermal
resource from the well,
(c) if the licensee has contravened an Act, a rule, a regulation or
an order or direction of the Regulator and the Regulator has
suspended or cancelled the licence,
(d) if the Regulator notifies the licensee that in the opinion of the
Regulator the well or facility may constitute an
environmental or a safety hazard,
(e) if the licensee is not or ceases to be a working interest
participant in the well or facility,
(f) if the licensee
(i) is not or ceases to be resident in Alberta,
(ii) has not appointed an agent in accordance with section
20 of the Act, and
(iii) does not hold a subsisting exemption under section 5
from the requirement to appoint an agent,
(g) if the licensee is
(i) a corporation registered, incorporated or continued
under the Business Corporations Act whose status is not
active or has been dissolved or if the corporate registry
status of the corporation is struck or rendered liable to
be struck under any legislation governing corporations,
or
(ii) an individual who is deceased,
(h) if the licensee has suspended the well in contravention of the
requirements established by the Regulator under section 96,
(i) when required by the Regulator under timelines set out in
directives related to closure published by the Regulator, or
(j) where otherwise ordered to do so by the Regulator.
Abandonment operations
98(1) Abandonment operations, including well abandonment, casing
removal, zone abandonments and plug backs, must be conducted in
accordance with Directive 020.
(2) A licensee must comply with all of the requirements of Directive
079, including requirements for locating and testing wells that are
considered abandonment operations for the purposes of sections 14,
15, 16, 17 and 19 of the Act.
Closure quotas
99(1) The Regulator may establish closure quotas that are applicable
to some or all licensees with respect to the required amount of work or
the amount to be spent, or both, as directed by the Regulator and for
the period determined by the Regulator, with respect to the closure of
the licensee's wells and facilities.
(2) A licensee must comply with any closure quota applicable to it,
unless otherwise directed by the Regulator.
Regulator request for closure plans
100(1) When requested by the Regulator, a licensee must submit a
closure plan regarding some or all of its wells and facilities, in
accordance with any direction of the Regulator given under subsection
(3).
(2) A closure plan must contain the information required by the
Regulator and the plan must be approved by the Regulator subject to
any terms and conditions imposed by the Regulator.
(3) The Regulator may direct the timing and priority for performing
work with respect to the closure of the licensee's wells and facilities.
(4) A licensee must comply with any terms and conditions of the
licensee's approved closure plan.
Eligible requesters request for closure plan
101(1) For the purpose of this section, "eligible requester" means,
(a) in the case of a well or facility situated on private land, the
landowner,
(b) in the case of a well or facility situated on public land,
(i) the Minister, and
(ii) the holder, if any, of a disposition issued under Part 3 of
the Public Lands Administration Regulation
(AR 187/2011),
(c) in the case of a well or facility situated on an Indian reserve,
the reserve as represented by the council of the band as
defined in the Indian Act (Canada),
(d) in the case of a well or facility situated on a Metis settlement,
the Metis settlement, and
(e) in the case of a well or facility situated on land owned by a
municipality as defined in the Municipal Government Act,
the municipality.
(2) If
(a) a well or facility has remained in either an inactive or
abandoned state for 5 or more years, and
(b) a request for closure has been made to the Regulator by an
eligible requester,
unless otherwise directed by the Regulator, the licensee of the well or
facility must prepare a closure plan respecting the well or facility.
Application for determination of costs
102(1) An application under section 17(3) of the Act
(a) for a determination of the costs of providing reasonable care
and measures to prevent impairment or damage, suspension
costs, abandonment costs, remediation costs or reclamation
costs for a well, facility, well site or facility site, and
(b) for the allocation of the costs in clause (a) to each working
interest participant in accordance with each working interest
participant's proportionate share in the well or facility
made by a person who conducted the work where ordered or directed
by the Regulator must be made in accordance with this section.
(2) Unless otherwise directed by the Regulator, an application referred
to in subsection (1) must include
(a) the applicant's full legal name, business address, telephone
number, email address and the name of a contact person for
the applicant,
(b) the legal description and licence number of
(i) the well, facility, well site or facility site that has been
provided with reasonable care and measures to prevent
impairment or damage,
(ii) the well, facility, well site or facility site that has been
suspended or abandoned, or
(iii) the well site or facility site that has been remediated or
reclaimed,
(c) a complete list, totalling 100% of the working interest, of the
working interest participants in the well or facility at the time
the costs were incurred,
(d) each working interest participant's full legal name, last
known business address, telephone number and email
address, the name of a contact person for each working
interest participant and the proportionate share of the costs
for each working interest participant for which the
application is being made,
(e) a detailed description of the total costs incurred in the
provision of reasonable care and measures to prevent
impairment or damage or in the work of suspension,
abandonment, remediation or reclamation, supported by
receipts for the costs incurred and for salvage revenue, if any,
(f) in the case of a determination of costs for
(i) the provision of reasonable care and measures to
prevent impairment or damage, a statement that
(A) the provision of reasonable care and measures in
respect of the well, facility, well site or facility site
was carried out in accordance with these Rules and
other requirements, and
(B) the Regulator's records have been updated to
reflect the work performed,
(ii) suspension or abandonment, a statement that the
suspension or abandonment of the well, facility, well
site or facility site has been completed, was carried out
in accordance with these Rules and other requirements
and that the Regulator's records have been updated to
reflect the work performed,
(iii) remediation, a statement
(A) that an environmental site assessment has been
completed in accordance with the applicable
requirements and that the Regulator's records have
been updated to reflect the work performed, or
(B) that provides the number of the remediation
certificate issued for the well site or facility site,
or
(iv) reclamation, a statement that a reclamation certificate
has been issued for the well site or facility site and that
provides the number of the reclamation certificate
issued for the well site or facility site,
and
(g) any other information required by the Regulator.
(3) An application for a determination of costs under subsection
(2)(f)(ii) or (iii) may be made only after the abandonment or
remediation work is completed, unless otherwise permitted by the
Regulator.
Abandonment of well drilled through coal
103(1) The licensee of a well that has been drilled through coal may
not abandon the well unless the licensee has obtained the approval of
the Regulator under section 14.
(2) The Regulator may approve the abandonment of the well subject
to any conditions and specifications that the Regulator may direct.
(3) The licensee before the abandonment must carry out such works in
accordance with the conditions and specifications directed by the
Regulator.
(4) The licensee must notify the appropriate field centre of the
Regulator of the licensee's intention to abandon the well at least 12
hours before commencing the abandonment.
Part 6
General
Fees
104(1) The fees payable to the Regulator under these Rules are set
out in Schedule 1.
(2) The Regulator may vary or waive any fee in the Schedule if, in the
opinion of the Regulator, circumstances so warrant.
Service of notice of garnishment
105(1) A notice of garnishment may be served on the payor under
section 23 of the Act as follows:
(a) if the payor is an individual, by leaving the document with
the individual or by sending the document by registered mail
addressed
(i) to the individual at the individual's residence, or
(ii) to the name and address of any business of the
individual;
(b) if the payor is a partnership, on all members of the
partnership
(i) by leaving the document with one or more of the
general partners or a person having control or
management of the partnership business, or
(ii) by sending the document by registered mail addressed
to
(A) the partnership,
(B) any one or more of the general partners, or
(C) any person having control or management of the
partnership business
at the address of the partnership business;
(c) if the payor is a corporation other than a municipality,
(i) by leaving the document with an officer or director of
the corporation or person in charge of any office or
place of business of the corporation,
(ii) by leaving the document at, or by sending the document
by registered mail addressed to, the registered or head
office of the corporation, or
(iii) where the corporation has its registered or head office
outside of Alberta, by leaving the document with, or by
sending the document by registered mail addressed to,
its agent for service appointed under Part 21 of the
Business Corporations Act;
(d) on a municipal corporation, by leaving the document with, or
by sending the document by registered mail addressed to, the
principal office of the corporation or the chief administrative
officer of the corporation;
(e) on an association,
(i) by leaving the document with an officer of the
association, or
(ii) by sending the document by registered mail addressed
to an officer of the association at the address of the
officer.
(2) A notice of garnishment is deemed to have been served on and
received by a debtor under section 23 of the Act when
(a) it is delivered by registered mail or by courier service to the
last address of the debtor known to the Regulator,
(b) it is sent electronically to the last contact of the debtor known
to the Regulator, or
(c) it is served in accordance with section 107, if the debtor is a
licensee.
Forwarding garnished money or revenue
106 If the payor is required by section 23 of the Act to forward
money or revenue to the Regulator, the payor must forward the money
or revenue to the Regulator together with
(a) the notice number and date of the notice of garnishment,
(b) the name of the debtor, and
(c) an expected payment schedule setting out the following
information, if known by the payor:
(i) the date or dates on which the payor expects to have
money or revenue owing to the debtor;
(ii) the amount that is expected to be payable on each date
referred to in subclause (i);
(iii) the date or dates on which the payor will forward the
money or revenue referred to in subclause (i) to the
Regulator.
Service of notices
107 Any notice or order that the Regulator is required or may desire
to serve is deemed to have been served on a licensee
(a) on delivery of the notice or order at an address registered
under section 20 of the Act as the address of the licensee, the
address for service in Alberta of the licensee or the address of
the agent of the licensee,
(b) 7 days from the date of mailing to an address referred to in
clause (a) that is in Alberta, or
(c) subject to clause (b), 14 days from the date of mailing to an
address referred to in clause (a) that is in Canada.
(2) In the event of non-compliance with section 20 of the Act by a
licensee, all notices or orders required to be served or that the
Regulator desires to serve may be posted on the Regulator's website
and must be kept so posted for 24 hours, exclusive of Saturdays and
holidays, and on the expiration of that period are deemed to have been
served on the licensee.
Expiry
108 For the purpose of ensuring that these Rules are reviewed for
ongoing relevancy and necessity, with the option that it may be
repassed in their present or an amended form following a review, these
Rules expire on June 30, 2032.
Coming into force
109 These Rules come into force on June 30, 2022.
Schedule 1
1
Fee for application for a
Regulator-directed transfer of licence
$10 000
2
Fee for application for licence by an
applicant who has not held a licence
under these Rules
$10 000
3
Fee for submission of each of the
following data discrepancies that is not
corrected prior to the Regulator filing
deadline:
(a) facility imbalance error;
(b) facility metering difference error;
(c) well missing from a submission
$100
4
Fee for filing each of the following after
the filing deadline date:
(a) current month submissions;
(b) amendment required because of the
change to the disposition;
(c) amendment required because of the
change in a well or facility
infrastructure data
$500
5
Fee for follow-up when data or
information related to fluid analysis or
drillstem tests has not been supplied as
specified under Directive 089
$1000
Schedule 2