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B.C. Reg. 204/2013
Oil and Gas Commission
Deposited September 26, 2013
effective October 1, 2014

Oil and Gas Activities Act

Emergency Management Regulation

Note: Check the Cumulative Regulation Bulletin 2015 and 2016
for any non-consolidated amendments to this regulation that may be in effect.

Contents
Part 1 — Definitions and Application
1Definitions
2Application
Part 2 — Information Requirements
3Obligation to provide information
Part 3 — Programs and Plans
4Emergency response program
5Hazard planning distances
6Response contingency plans required
7Preparation of plans
8Preparation of supplementary plans
9Access to plans
10Review and update of plans
11Submission of plans
12Classification of incidents
13Implementation of plans
14Evaluation of response to emergencies
15Emergency response map
16Emergency communication system
17Information in writing
18Exemptions
Part 4 — Transition
19Transition
Schedule A
Schedule B
Schedule C
Schedule D

Part 1 — Definitions and Application

Definitions

1  In this regulation:

"Act" means the Oil and Gas Activities Act;

"applicant" means a person who intends to submit or has submitted an application under section 24 of the Act for a permit to carry out an oil and gas activity to which this regulation applies;

"arterial highway" has the same meaning as in section 1 of the Transportation Act;

"contact information" means

(a) a telephone number at which a person can be contacted, and

(b) an email address at which a person can be contacted, unless the person does not have such an address;

"emergency" means an incident classified in accordance with section 12 as a level 1, 2 or 3 incident that requires action by the permit holder to protect persons, property or the environment;

"emergency planning zone" means a geographical area that encompasses all the hazard planning zones for an oil and gas activity that is the subject of a plan;

"hazard planning distance" means a hazard planning distance within the meaning of section 5;

"hazard planning zone" means a geographical area

(a) determined by using the hazard planning distance as a radius, and

(b) within which persons, property or the environment may be affected by an emergency;

"incident" means a present or imminent event or circumstance, resulting from an oil and gas activity that is the subject of a plan, that

(a) is outside the scope of normal operations, and

(b) may or may not be an emergency;

"local authority" has the same meaning as in section 1 of the Consultation and Notification Regulation, B.C. Reg. 279/2010;

"municipal highway" has the same meaning as in section 1 of the Transportation Act;

"oil and gas road" has the same meaning as in the Oil and Gas Road Regulation, B.C. Reg. 56/2013;

"plan" means a response contingency plan within the meaning of section 7 and includes, except in sections 7 and 8, a supplementary plan;

"program" means an emergency response program within the meaning of section 4;

"rights holder" has the same meaning as in section 1 of the Consultation and Notification Regulation;

"supplementary plan" means a supplementary response contingency plan within the meaning of section 8.

Application

2  This regulation does not apply to permit holders carrying out the following oil and gas activities:

(a) geophysical exploration;

(b) the drilling, operation or abandonment of a water source well;

(c) the construction or maintenance of an oil and gas road;

(d) the construction, operation or maintenance of a liquefied natural gas facility.

Part 2 — Information Requirements

Obligation to provide information

3  (1) Before submitting a plan to the commission, an applicant or permit holder must give the information set out in subsection (2) to the following persons or other entities:

(a) a person who occupies land within the emergency planning zone;

(b) a local authority, if any part of the emergency planning zone is located within the local authority;

(c) the government of Canada, if an existing building or structure owned by the government of Canada is within the emergency planning zone;

(d) a First Nation, if all or a portion of the First Nation's Indian reserve is located within the emergency planning zone;

(e) a rights holder, if an area subject to a right of the rights holder is located within the emergency planning zone;

(f) the ministry of the minister responsible for the administration of the Transportation Act and the municipal council, if any part of the emergency planning zone is located within a municipality and within the right of way of an arterial highway or municipal highway.

(2) The information given under subsection (1) must include all of the following:

(a) the name and contact information of the applicant or permit holder;

(b) a map that shows the location of the emergency planning zone in relation to roads, including oil and gas roads, dwellings, schools and public facilities;

(c) a description of

(i) the site-specific hazards and risks of the oil and gas activity that is the subject of the plan,

(ii) how the applicant's or permit holder's response to an emergency may affect the person or other entity receiving the information,

(iii) how the applicant or permit holder will notify the person or other entity receiving the information if and when the applicant or permit holder thinks the person or other entity should shelter in place or evacuate in an emergency, and

(iv) how the person or other entity receiving the information can get to safety in an emergency;

(d) a statement requesting that the person or other entity receiving the information provide to the applicant or permit holder

(i) the name and contact information of a contact person, and

(ii) a description of how the person or other entity may be affected by an emergency.

(3) If an applicant or permit holder receives a response to a request under subsection (2) (d) (ii) before submitting a plan to the commission, the applicant or permit holder must consider the response in the preparation of the plan.

Part 3 — Programs and Plans

Emergency response program

4  (1) A program is prescribed for the purposes of section 38 (1) (b) of the Act.

(2) A permit holder must prepare and maintain a program that

(a) coordinates the permit holder's plans,

(b) requires the permit holder to conduct training and emergency response exercise programs for all emergency response staff to whom powers and duties are assigned in accordance with the emergency management system set out in section 7 (3) (d), and

(c) requires the permit holder to evaluate the response to an emergency in accordance with section 14.

(3) A permit holder must ensure a program coordinator implements the program.

(4) A permit holder must submit to the commission the name and contact information of the program coordinator referred to in subsection (3).

(5) If there is any change in the information referred to in subsection (4), the permit holder must submit updated information to the commission as soon as possible.

(6) A permit holder must review and, if necessary, update the program

(a) at least once every 3 years,

(b) after a significant change occurs in the types of hazards and risks arising from the permit holder's oil and gas activities that are the subject of the plans, and

(c) after an evaluation of the response to a level 3 incident is completed under section 14.

(7) A permit holder must maintain written records of the permit holder's program until the permit holder ceases to carry out any oil and gas activities for which a plan is required.

(8) The records referred to in subsection (7) are prescribed for the purposes of section 38 (1) (a) of the Act.

Hazard planning distances

5  (1) For the purpose of this regulation, hazard planning distances are

(a) horizontal distances, and

(b) measured from the site of an oil and gas activity that is the subject of a plan.

(2) An applicant or permit holder must determine the hazard planning distance

(a) for fluids containing hydrogen sulphide, in accordance with Schedule A, B or C, as applicable, or

(b) for hazards other than hydrogen sulphide, by taking into consideration the types of hazards and risks arising from the oil and gas activity that is the subject of the plan.

Response contingency plans required

6  A permit holder must not carry out an oil and gas activity that is the subject of a plan unless the permit holder has, in respect of the plan,

(a) determined that there is no emergency planning zone, or

(b) complied with section 7 or 8.

Preparation of plans

7  (1) A plan is prescribed for the purposes of section 38 (1) (b) of the Act.

(2) An applicant or permit holder must prepare a plan for each of the applicant's or permit holder's oil and gas activities to which this regulation applies, unless

(a) the site-specific hazards and risks of each oil and gas activity that is the subject of a plan are the same, and

(b) the emergency planning zones for each oil and gas activity that is the subject of a plan overlap,

in which case, an applicant or permit holder may prepare a single plan for more than one of the applicant's or permit holder's oil and gas activities to which this regulation applies.

(3) The following information must be included in the plan:

(a) the name and contact information of the applicant or permit holder;

(b) a description of

(i) the oil and gas activity that is the subject of the plan, and

(ii) the site-specific hazards and risks of the oil and gas activity that is the subject of the plan, identified in an all-hazard risk assessment;

(c) an emergency response map, as set out in section 15;

(d) an emergency management system for control, command and coordination of the emergency response that

(i) describes the powers and duties of the emergency response roles, and

(ii) assigns emergency response staff to the emergency response roles;

(e) a list and description of the applicant's or permit holder's emergency response resources, for deployment in an emergency;

(f) a description of the emergency communication system, as set out in section 16 (1), and a requirement that the permit holder must test the emergency communication system in accordance with section 16 (2);

(g) a description of how the applicant or permit holder will

(i) deploy and monitor the emergency response resources referred to in paragraph (e) in an emergency,

(ii) notify those persons and other entities who may be affected by an emergency, and

(iii) provide information to those persons and other entities referred to in subparagraph (ii) regarding an emergency, including shelter in place or evacuation decisions, if applicable.

Preparation of supplementary plans

8  (1) A supplementary plan is prescribed for the purposes of section 38 (1) (b) of the Act.

(2) An applicant or permit holder who previously submitted a copy of a plan to the commission may prepare a supplementary plan for a subsequent oil and gas activity to which this regulation applies, if the site-specific hazards and risks of the subsequent oil and gas activity are such that the applicant's or permit holder's existing plan can be applied, with only minor adjustments, to the subsequent oil and gas activity.

(3) The supplementary plan must include the information set out in section 7 (3) (b), (c) and (e) that is different from the information included in the existing plan.

Access to plans

9  An applicant or permit holder must have a copy of the plan, in paper or electronic form, accessible

(a) to the applicant's or permit holder's emergency response staff, and

(b) at the applicant's or permit holder's head office.

Review and update of plans

10  (1) A permit holder must review and, if necessary, update the information included in a plan

(a) at least once a year,

(b) after an evaluation of the response to an emergency is completed under section 14, and

(c) if the site-specific hazards and risks of the oil and gas activity that is the subject of the plan change significantly.

(2) As part of the review referred to in subsection (1), a permit holder must

(a) review the information included in the plan,

(b) make reasonable efforts to determine whether the persons or other entities referred to in section 3 (1) (a) to (f) have changed, and

(c) consider any responses to requests under section 3 (2) (d) (ii) received after the plan or updated information was submitted to the commission.

(3) If, as a result of reviewing the plan, the permit holder determines that the persons or other entities referred to in section 3 (1) (a) to (f) have changed, the permit holder must give the information set out in section 3 (2) respecting the plan to the persons or other entities not previously given the information as soon as possible.

(4) If, as a result of updating the plan, the information given under section 3 (2) has changed, the permit holder must provide updated information to those persons or other entities referred to in section 3 (1) (a) to (f) who are affected by the change as soon as possible.

Submission of plans

11  An applicant or permit holder must submit to the commission in writing and in both paper and electronic form

(a) a copy of the plan, and

(b) if applicable, a copy of any updated information under section 10 (1).

Classification of incidents

12  A permit holder must classify an incident according to the Incident Classification Matrix, set out in Schedule D, immediately after the permit holder becomes aware of the incident.

Implementation of plans

13  (1) When an emergency occurs a permit holder must

(a) implement the plan immediately,

(b) take such other actions as necessary to respond effectively and adequately to the emergency, and

(c) notify the commission as soon as the circumstances permit.

(2) A permit holder must ensure that the plan is implemented in accordance with the following order of priorities:

(a) protection of emergency response staff;

(b) protection of the permit holder's employees;

(c) protection of the public;

(d) protection of property;

(e) protection of the environment.

Evaluation of response to emergencies

14  (1) A permit holder must evaluate the response to an emergency as soon as the circumstances permit.

(2) A report of the results of an evaluation under subsection (1) must be prepared and maintained until the permit for the oil and gas activity that is the subject of the plan is cancelled or is declared to be spent.

(3) The report under subsection (2) must include

(a) a description of the emergency, including the cause or suspected cause,

(b) a description of the permit holder's response to the emergency, and

(c) an assessment of the permit holder's response.

(4) The report under subsection (2) is prescribed for the purposes of section 38 (1) (a) of the Act.

Emergency response map

15  (1) An emergency response map required by section 7 (3) (c) must show all of the applicable of the following information:

(a) the location of the oil and gas activity that is the subject of the plan;

(b) the emergency planning zone;

(c) the location of roads, including oil and gas roads, within the emergency planning zone.

(2) An emergency response map must show all of the following information if the area, feature, structure or location may be affected by an emergency or may affect the response to an emergency:

(a) the area adjacent to the emergency planning zone;

(b) surface and environmental features and structures, including stream crossings and lakes within the emergency planning zone;

(c) the location of commercial or industrial operations within the emergency planning zone;

(d) the location of a registered trapline, guiding territory or Crown range within the emergency planning zone;

(e) the location of any other areas within the emergency planning zone that may be used by the public, including, without limitation, dwellings, schools, public facilities, campgrounds and recreation areas.

Emergency communication system

16  (1) An emergency communication system required by section 7 (3) (f) must be capable of enabling communications among the applicable of the following:

(a) the permit holder;

(b) the emergency response staff;

(c) the public;

(d) employees of the permit holder conducting air monitoring;

(e) the commission;

(f) government agencies and authorities.

(2) The emergency communication system must be tested annually to confirm the equipment is functional.

Information in writing

17  Information required to be given or submitted under this regulation, other than the information required by section 11, must be given or submitted in writing and may be in either paper or electronic form.

Exemptions

18  (1) An official may exempt an applicant or permit holder from complying with one or more provisions of this regulation if the official is satisfied that, in the circumstances,

(a) compliance with the provision or provisions is not reasonably practicable, or

(b) the exemption is in the public interest.

(2) In granting an exemption under subsection (1), an official may impose any conditions on the exemption the official considers necessary.

Part 4 — Transition

Transition

19  (1) A plan submitted to the commission before this regulation comes into force is deemed to have been submitted under section 11.

(2) For the purpose of section 10, a plan under subsection (1) of this section must be reviewed on or before the earlier of the following:

(a) one year after the permit holder's last review of the plan;

(b) one year after the date on which this regulation comes into force.

Schedule A

(section 5)

Facility Distances

Hazard planning distances for facilities are determined by reference to the maximum potential hydrogen sulphide release volume from any pipeline entering or leaving the facility, calculated in accordance with the applicable of the following equations. The hazard planning distance for facilities is the distance indicated on the vertical axis of Chart A that corresponds to the release volume indicated on the horizontal axis of the chart, as indicated by the graphline on the chart.

Equations

Gas pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a gas pipeline is as follows:

V = 2.232 x 10-6D2L (P + 101.325) H

Z(T + 273)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
D  =  internal diameter of pipeline in millimetres (mm);
L  =  length of pipeline between emergency shutdown valves in kilometres (km);
P  =  licensed maximum operating pressure in kilopascals (kPa);
H  =  licensed H2S content (moles/kilomole) for the pipeline;
Z  =  compressibility factor at reduced pressure and reduced temperature;
T  =  pipeline minimum operating temperature in degrees Celsius (°C).

Sour liquid multiphase pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a sour liquid multiphase pipeline is as follows:

V = (GLR x GVF) x Vpl x H

1 000(GLR + GVF)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
GLR  =  produced gas-liquid ratio at maximum operating pressure (MOP) (m3/m3);
GVF  =  ratio of produced gas volume at standard conditions to the volume of gas at MOP (m3/m3);
Vpl  =  volume of the pipeline in cubic metres (m3);
H  =  licensed H2S content (moles/kilomole) for the pipeline.

Gas multiphase pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a gas multiphase pipeline is as follows:

V = 0.785 x 10-6D2L (GLR x GVF) x H

(GLR + GVF)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
D  =  internal diameter of pipeline in millimetres (mm);
L  =  length of pipeline between emergency shutdown valves in kilometres (km);
GLR  =  produced gas-liquid ratio at maximum operating pressure (MOP) (m3/m3);
GVF  =  ratio of produced gas volume at standard conditions to the volume of gas at MOP (m3/m3);
H  =  licensed H2S content (moles/kilomole) for the pipeline.

Chart A: Facility Distances

Schedule B

(section 5)

Well Distances

Hazard planning distances for wells are determined by reference to the maximum potential hydrogen sulphide release rates from a well during drilling, completion, re-completion or production operations.

H2S Release Rates

Drilling operations

The maximum potential H2S release rates during drilling operations must be determined as follows:

1 For a proposed well, the maximum gas rate (AOF) values and maximum H2S concentrations for each H2S-bearing formation must be determined for each of at least 5 wells drilled and tested in an analogous geological area or pool within 5 km of the proposed well.

2 The H2S release rates for all potential H2S-bearing formations in the proposed well must be determined based on the highest AOF and highest H2S concentration for each formation and the sum of the H2S release rates for all the formations that will be open to the well bore during drilling operations.

3 If appropriate data does not exist or is otherwise inadequate, the hazard planning distance is 3 km.

Completion or re-completion operations

For completion or re-completion operations in an existing well, data from the appropriate formation in the well must be used to determine H2S release rates, but if the appropriate data does not exist or is otherwise inadequate, H2S release rates must be determined in accordance with the equations and notes set out below for production operations.

Production operations

The maximum potential H2S release rates during production operations must be determined in accordance with the following equation and the notes that follow:

H2S Release Rate = H2S% x AOF

8 640 000
  where
H2S%  =  volume of H2S expressed as a percentage of the total volume of gas;
AOF  =  maximum gas rate (m3/d).

Notes:

1 For gas wells, if an AOF test has been conducted and value determined for a formation in a well, that value must be used. If an AOF test value has not been determined, a theoretical AOF must be calculated using the following formula:

AOF = Gas Test Rate x Pr2

(Pr2 - Pf2)
  where
AOF  =  maximum gas rate (m3/d);
Gas Test Rate  =  gas flow rate during testing (m3/d);
Pf  =  flowing bottom hole pressure (kPa);
Pr  =  reservoir pressure (kPa).

2 For oil wells, the AOF must be calculated using the following formula:

AOF = Oil Test Rate x GOR

[1 – 0.2 x (Pf/Pr) – 0.8 x (Pf/Pr)2]
  where
AOF  =  maximum gas rate (m3/d);
Oil Test Rate  =  oil flow rate during testing (m3/d);
GOR  =  gas-oil ratio from oil test rate well (m3/m3);
Pf  =  flowing bottom hole pressure (kPa);
Pr  =  reservoir pressure (kPa).

Determination of Well Distances

The hazard planning distance for wells is the distance indicated on the vertical axis of Chart B that corresponds to the release rate indicated on the horizontal axis of the chart, as indicated by the graphline on the chart.

Chart B: Well Distances

Schedule C

(section 5)

Pipeline Distances

Hazard planning distances for pipelines are determined by reference to the maximum potential hydrogen sulphide release volume from the pipeline, calculated in accordance with the applicable of the following equations. The hazard planning distance for pipelines is the distance indicated on the vertical axis of Chart C that corresponds to the release volume indicated on the horizontal axis of the chart, as indicated by the graphline on the chart.

Equations

Gas pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a pipeline is as follows:

V = 2.232 x 10-6D2L(P + 101.325) H

Z(T + 273)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
D  =  internal diameter of pipeline in millimetres (mm);
L  =  length of pipeline between emergency shutdown valves in kilometres (km);
P  =  licensed maximum operating pressure in kilopascals (kPa);
H  =  licensed H2S content (moles/kilomole) for the pipeline;
Z  =  compressibility factor at reduced pressure and reduced temperature;
T  =  pipeline minimum operating temperature in degrees Celsius (°C).

Sour liquid multiphase pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a sour liquid multiphase pipeline is as follows:

V = (GLR x GVF) x Vpl x H

1 000(GLR + GVF)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
GLR  =  produced gas-liquid ratio at maximum operating pressure (MOP) (m3/m3);
GVF  =  ratio of produced gas volume at standard conditions to the volume of gas at MOP (m3/m3);
Vpl  =  volume of the pipeline in cubic metres (m3);
H  =  licensed H2S content (moles/kilomole) for the pipeline.

Gas multiphase pipeline H2S release volume

The equation for calculating the maximum potential H2S release volume from a gas multiphase pipeline is as follows:

V = 0.785 x 10-6D2L (GLR x GVF) x H

(GLR + GVF)
  where
V  =  maximum potential H2S release volume at standard conditions in cubic metres (m3);
D  =  internal diameter of pipeline in millimetres (mm);
L  =  length of pipeline between emergency shutdown valves in kilometres (km);
GLR  =  produced gas-liquid ratio at maximum operating pressure (MOP) (m3/m3);
GVF  =  ratio of produced gas volume at standard conditions to the volume of gas at MOP (m3/m3);
H  =  licensed H2S content (moles/kilomole) for the pipeline.

Chart C: Pipeline Distances

Schedule D

(section 12)

Incident Classification Matrix

The classification of an incident is determined for each event or circumstance in the following matrix by identifying the probability of escalation or control of the event or circumstance.

    Probability
Item Event or Circumstance Escalation highly unlikely; controlled or imminent control Escalation unlikely; controlled or likely imminent control Escalation possible; under or imminent control Uncontrolled, with control unlikely in near term
1 • Moderate on site equipment damage
• Liquid spill or gas release on location
Minor Incident Minor Incident Level 1 Incident Level 1 Incident
2 • Emergency medical services for worker
• Major on site equipment damage
• Liquid spill or gas release potentially or beyond site, not affecting public safety, environment, or property
Minor Incident Level 1 Incident Level 1 Incident Level 2 Incident
3 • Worker hospitalized
• HAZMAT worker exposure exceeding allowable
• Major on site equipment failure
• Liquid spill or gas release beyond site, potentially affecting public safety, environment, or property
Level 1 Incident Level 1 Incident Level 2 Incident Level 3 Incident
4 • Fatality
• Major on site equipment or infrastructure loss
• Liquid spill beyond site, uncontained and affecting environment
• Gas release beyond site affecting public safety
Level 1 Incident Level 2 Incident Level 3 Incident Level 3 Incident

[Provisions relevant to the enactment of this regulation: Oil and Gas Activities Act, S.B.C. 2008, c. 36, sections 38, 106, 111 and 112]