Section 1 definition of "emergency planning zone" BEFORE amended by BC Reg 204/2013, effective October 1, 2014.
"emergency planning zone" means a geographical area
(a) that surrounds a well or facility, either of which contains one or more hazardous materials, and
(b) within which, in the event of a release of a hazardous material from the well or facility, there could reasonably be expected to be that material in a quantity or concentration that could pose an immediate danger to the life or health of a person;
Section 1 definition of "API" BEFORE repealed by BC Reg 159/2015, effective July 30, 2015.
"API" means the American Petroleum Institute;
Section 1 definitions of ""daily gas allowable" or "DGA"", "gas processing plant" and "unadjusted daily oil allowable", BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
"daily gas allowable" or "DGA" means the volume of natural gas determined by multiplying the unadjusted daily gas allowable by any applicable adjustment factors;
"gas processing plant" means a facility for the extraction from natural gas of hydrogen sulphide, carbon dioxide, helium, ethane, natural gas liquids or other substances, but does not include a facility that
(a) has a processing capacity less than 150 000 m3/day, and
(b) uses a non-regenerative system for the removal of hydrogen sulphide or carbon dioxide;
"unadjusted daily oil allowable" or UDOA means the volume of oil determined in accordance with section 54 (2);
Section 1 definitions of "ASME Standard B31.3, "CSA Standard Z341", "CSA Standard Z662", "CSA Standard Z741", "oil and gas road", "unadjusted daily gas allowable" or "UDGA" and "unused equipment" were added by BC Reg 159/2015, effective July 30, 2015.
Section 1 definitions of "Enform" and "workover" BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
"Enform" means the non-profit organization of Canadian petroleum industry trade associations which provides certification, training and health and safety services to the oil and gas industry;
"workover" means
(a) any operation that changes the configuration or producing characteristics of a well or zone,
(b) the installation or removal of equipment from a wellbore,
(c) stimulation operations, and
Section 1 definitions of "deep groundwater", "groundwater", "integrity management program", "safety equipment" and "usable groundwater" were added by BC Reg 146/2017, effective June 1, 2017.
Section 1 definition of "Enform" BEFORE repealed by BC Reg 103/2019, effective May 17, 2019.
"Enform" means the non-profit organization of Canadian petroleum industry trade associations that provides certification, training and health and safety services to the oil and gas industry;
Section 1 definition of "accepted safety training organization" was added by BC Reg 103/2019, effective May 17, 2019.
Section 1 definition of "unused equipment" BEFORE repealed by BC Reg 103/2019, effective May 17, 2019.
"unused equipment" means equipment, at an oil and gas activity site, that
(a) is related to a decommissioned activity,
(b) is dismantled or partially dismantled to render the equipment inadequate for use,
(c) is in a derelict condition, or
(d) has been inactive for 10 years or longer;
Section 1 definition of "wellhead" was added by BC Reg 103/2019, effective May 17, 2019.
Section 1 (1) definition of "facility" BEFORE amended by BC Reg 48/2021, effective March 4, 2021.
"facility" does not include an LNG facility within the meaning of the Liquefied Natural Gas Facility Regulation;
Section 1 (1) definitions of "gas processing plant" and "natural gas liquids" BEFORE repealed by BC Reg 48/2021, effective March 4, 2021.
"gas processing plant" means a facility for the extraction from natural gas of hydrogen sulphide, carbon dioxide, helium, ethane, natural gas liquids or other substances, but does not include a facility that
(a) uses, for the exclusive purpose of processing low-volume fuel gas,
(i) a regenerative system for the removal of hydrogen sulphide or carbon dioxide and emits less than 2 tonnes/day of sulphur, or
(ii) a liquid extraction process such as refrigeration to extract hydrocarbon liquids from a gas stream, or
(b) uses a non-regenerative system for the removal of hydrogen sulphide or carbon dioxide;
"natural gas liquids" means ethane, propane, butanes or pentanes and any other condensates, or any combination of them, recovered from natural gas;
Section 1 definitions of "Act" and "qualified professional" BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
"Act" means the Oil and Gas Activities Act;
"qualified professional" means a person who is licensed or registered as either a professional engineer or a professional geoscientist under the Engineers and Geoscientists Act;
Section 1 definition of "oil and gas road" BEFORE repealed by BC Reg 202/2023, effective September 1, 2023.
"oil and gas road" has the same meaning as in the Oil and Gas Road Regulation;
Section 1 definition of "facility" BEFORE repealed by BC Reg 78/2023, effective January 1, 2024.
"facility" does not include the following:
(a) a processing facility within the meaning of the Oil and Gas Processing Facility Regulation;
(b) an LNG facility within the meaning of the Liquefied Natural Gas Facility Regulation;
Section 1 definition of "production tank" was added by BC Reg 78/2023, effective January 1, 2024.
Section 1 definition of "CSA" BEFORE amended by BC Reg 26/2025, effective April 1, 2025.
"CSA" means the Canadian Standards Association;
Section 1 definition of "qualified professional" BEFORE amended by BC Reg 26/2025, effective April 1, 2025.
"qualified professional" means a person who is licensed or registered as either a professional engineer or a professional geoscientist under the Professional Governance Act;
Section 1.1 (part) BEFORE amended by BC Reg 26/2025, effective April 1, 2025.
Application
1.1 Subject to section 22 of the Oil and Gas Processing Facility Regulation, this regulation does not apply in relation to the following:
Section 1.1 (a) BEFORE amended by BC Reg 26/2025, effective April 1, 2025.
(a) a processing facility as defined in section 1 of the Oil and Gas Processing Facility Regulation;
Section 2 (6) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(6) An official may designate a well or a portion of a well as a special data well if the well permit holder submits to the commission
Section 4 (1) (g) and (k) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(g) section 26 (a);
(k) section 34 (1) and (7);
Section 4 (1) (z.1) was added by BC Reg 241/2012, effective August 14, 2012.
Section 4 (1) (k) and (m) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
Section 4 (1) (d), (g), (o) and (z.1) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
Section 4 (1) (z.01) was added by BC Reg 146/2017, effective June 1, 2017.
Section 4 (1) (c.1) was added by BC Reg 103/2019, effective May 17, 2019.
Section 4 (1) (z.01) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
Section 4 (1) (m) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
Section 4 (1) (o.1), (o.2), (o.3), (o.4) and (o.5) were added by BC Reg 256/2024, effective January 1, 2025.
Section 8 (1) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) A well permit holder must notify the commission, in electronic form, of the following actions taken by the permit holder:
Section 10 (2) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(2) At the request of an official, a well permit holder's contractor or rig crew, when it is safe to do so, must test the operation and effectiveness of the blowout prevention equipment installed on the permit holder's well in accordance with the Well Control Procedure placard issued by the Canadian Association of Oilwell Drilling Contractors or the Enform Blowout Prevention Manual.
Section 13 (2), (3) and (4) (part) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) A driller of a well being drilled or tested during drilling operations must
(a) be trained in blowout prevention,
(b) have a valid first line supervisor's blowout certificate or a valid second-line supervisor's well control certificate issued by Enform, and
(c) provide evidence of his or her qualifications to an official on the official's request.
(3) A rig manager and the permit holder's representative at the well site where a well is being drilled or tested during drilling operations must
(a) be trained in blowout prevention,
(b) have a valid second-line supervisor's certificate issued by Enform, and
(c) provide evidence of his or her qualifications to an official on the official's request.
(4) The following people must possess, during well servicing operation, a valid well service blowout prevention certificate issued by Enform and provide evidence of their qualifications to an official on the official's request:
Section 13 (2) (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(b) have a valid first line supervisor's blowout certificate or a valid second-line supervisor's well control certificate issued by Enform or an equivalent certification acceptable to an official, and
Section 13 (3) (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(b) have a valid second-line supervisor's certificate issued by Enform or an equivalent certification acceptable to an official, and
Section 13 (4) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(4) The following people must possess, during servicing operation on a well other than a well that is drilled to access usable groundwater, a valid well service blowout prevention certificate issued by Enform or an equivalent certification acceptable to an official and provide evidence of their qualifications to an official on the official's request:
Section 13 (2) (c) BEFORE amended by BC Reg 37/2024, effective March 1, 2024.
(c) provide evidence of his or her qualifications to an official on the official's request.
Section 13 (3) (c) BEFORE amended by BC Reg 37/2024, effective March 1, 2024.
(c) provide evidence of his or her qualifications to an official on the official's request.
Section 15 (1) (d), (e) and (f) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(d) if the well may produce flammable gas, a flammable gas symbol from the Schedule;
(e) if the well may produce gas containing 100 ppm or greater of hydrogen sulphide, a poisonous gas symbol from the Schedule;
(f) after March 1, 2011, if the well may produce gas containing 10 ppm or greater of hydrogen sulphide, a poisonous gas symbol from the Schedule.
Section 15 (1) (b) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(b) emergency notification information, including a telephone number;
Section 15 (3) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(3) A well permit holder must ensure
Section 15 (3) (a) and (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(a) that the well site is maintained in a condition so as to minimize hazards, including but not limited to hazards associated with pits, holes, storage of materials and equipment, and
(b) that the well site is free of garbage, debris and unused equipment.
Section 15 (1) (c) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(c) the location of the surface site of the well as specified in the well permit;
Section 16 (1) (a) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(a) that all tools or equipment used in well operations are installed and operated in accordance with the manufacturer's specifications and accepted industry practices or sound engineering practices, and
Section 16 (2) (b) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(b) ensure that the space between tubing and the outer steel casing is filled with a corrosion inhibiting fluid.
Section 16 (3) (b) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(b) maintain a record of the tests and repairs carried out under paragraph (a).
Section 16 (1) (b) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(b) that all production from or injection into a well, except production of gas containing less than 5 mole percent of hydrogen sulphide or injection of fresh water, is through tubing.
Section 16 (2) (part) and (3) (part) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) Before injecting a fluid other than fresh water into a subsurface formation through tubing in a well, a well permit holder must
Section 16 (1) (a) and (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(a) that all tools and equipment used in well operations are installed and operated in accordance with the manufacturer's specifications or sound engineering practices, and
(b) that all production from or injection into a well is through tubing, except during a well operation, the production of fluids containing less than 5 mole percent of hydrogen sulphide or the injection of fresh water.
Section 16 (1) (c) was added by BC Reg 103/2019, effective May 17, 2019.
Section 16 (2) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(2) Except during a well operation, before injecting a fluid other than fresh water or fluids containing less than 5 mole percent of hydrogen sulphide into an injection or disposal well, a well permit holder must
Section 16 (3) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) submit a report of the annual segregation test and any repairs completed under paragraph (a) to the commission within 30 days of completing the test.
Section 18 (2), (4) and (7) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) A well permit holder must use non-toxic drilling fluids during the drilling of a well until, in the opinion of a qualified professional, all porous strata that
(a) are less than 600 m below ground level, and
(b) contain non-saline groundwater that is usable for domestic or agricultural purposes
have been isolated from the drilling fluid.
(4) A well permit holder, with respect to a well drilled after this regulation came into force, must ensure that the next casing string is cemented full length if surface casing for the well is not set below the base of all porous strata that contain usable groundwater or to a minimum depth of 600 m.
(7) If there is any reason to doubt the effectiveness of casing cementation, a well permit holder must ensure that a survey is made to evaluate the cement integrity and that remedial measures are taken if necessary.
Section 18 (9) (a) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(a) the surface and intermediate casing annulus can freely vent,
Section 18 (8) (a) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(a) notify the commission about the leak or failure without delay, and
Section 18 (9) (a) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(a) the surface casing annulus can freely vent,
Section 18 (10) was added by BC Reg 256/2024, effective January 1, 2025.
Section 21.1 (2) BEFORE amended by BC Reg 165/2015, effective August 7, 2015.
(2) If a well is identified by the well permit holder or the commission as being responsible for a seismic event that has a magnitude of 4.0 or greater, the well permit holder must suspend fracturing and disposal operations on the well immediately.
Section 21.1 BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
Induced seismicity
21.1 (1) During fracturing or disposal operations on a well, the well permit holder must immediately report to the commission any seismic event within a 3 km radius of the drilling pad that is recorded by the well permit holder or reported to the well permit holder by any source available, if
(a) the seismic event has a magnitude of 4.0 or greater, or
(b) a ground motion is felt on the surface by any individual within the 3 km radius.
(2) If a well is identified by the well permit holder or the commission as being responsible for a seismic event that has a magnitude of 4.0 or greater, the well permit holder must suspend fracturing and disposal operations on the well immediately.
(3) Fracturing and disposal operations suspended under subsection (2) may continue once the well permit holder has implemented operational changes satisfactory to the commission to reduce or eliminate the initiation of additional induced seismic events.
[en. B.C. Reg. 159/2015, s. 5; am. B.C. Reg. 165/2015.]
Section 21.1 (1) (part), (2) and (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) During fracturing, injection or disposal operations on a well, the well permit holder must immediately report to the commission any seismic event within a 3 km radius of the drilling pad that is recorded by the well permit holder or reported to the well permit holder by any source available, if
(2) If a well is identified by the well permit holder or the commission as being responsible for a seismic event that has a magnitude of 4.0 or greater, the well permit holder must suspend fracturing, injection and disposal operations on the well immediately.
(3) Fracturing, injection and disposal operations suspended under subsection (2) may continue once the well permit holder has implemented operational changes satisfactory to the commission to reduce or eliminate the initiation of additional induced seismic events.
Section 23 (1) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(1) A well permit holder must not complete a well for commingled production from more than one pool or zone unless the completion is permitted by the well permit or is authorized under section 75 of the Act.
Section 23 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder respecting a multi-zone well who has permission or authorization for commingled production must, within 30 days of beginning production from a commingled well, submit to the commission a notification of the commingled well production.
Section 25 (1) definition of "active", paragraph (c) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(c) reservoir pressure observation;
Section 25 (1) definition of "active", paragraph (b) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
Section 25 (5) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(5) The well permit holder of an inactive well, within 60 days of the well becoming inactive, must suspend the well in a manner that ensures the ongoing integrity of the well.
Section 25 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) The well permit holder of an inactive well must submit a report to the commission within 30 days of the suspension of a well.
Section 26 (d) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(d) the permit holder must do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation.
Section 26 (c) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(c) an abandonment report, in chronological format, detailing all significant operations, treatments, tests and resulting well behaviour, and including a downhole schematic diagram, must be submitted to the commission in duplicate within 30 days of the completion of abandonment operations;
Section 26 was renumbered as subsection (1), and subsection (2) was added by BC Reg 146/2017, effective June 1, 2017.
Section 26 (0.1) was added by BC Reg 103/2019, effective May 17, 2019.
Section 26 (1) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(1) The following requirements are prescribed for the purposes of section 40 (e) of the Act with respect to a well permit under which a well has been drilled:
Section 26 (1) (d) BEFORE repealed by BC Reg 48/2021, effective March 4, 2021.
(d) the permit holder, for a well drilled on Crown land, must do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation.
Section 26 (1) (a) and (c) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(a) for cased wells, a notice of operations and a plugging program must be submitted to the commission at least 7 days before commencement of operations;
(c) an abandonment report, in chronological format, detailing all significant operations, treatments, tests and resulting well behaviour, and including a downhole schematic diagram, must be submitted to the commission within 30 days of the completion of abandonment operations;
Section 29 (1) (a) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(a) take a series of drill cuttings samples at depth intervals of 5 m beginning at a point determined by the permit holder to be 50 m measured depth above the shallowest potential reservoir zone expected in the well and continuing to the total depth of the well,
Section 29 (1) (a.1) was added by BC Reg 241/2012, effective August 14, 2012.
Section 29 (2) (a) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(a) as soon as practicable after collecting a core sample, remove the core sample from the core barrel and store it in book fashion in one or more wooden core boxes,
Section 29 (3) and (4) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(3) A well permit holder must ensure that wooden core boxes are of adequate construction, the sides of the boxes project above the level of the contained cores, lids are securely fixed to ensure safe transit and the boxes have an inside length of 80 cm.
(4) When submitting a core that has been slabbed, a well permit holder must ensure that the 1/3 slab is either placed in the wooden core box with the corresponding 2/3 slab, or, with the approval of an official, preserved as a viewing slab and submitted in cardboard boxes of adequate construction.
Section 29 (1) (d) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(d) deliver 2 sets of the drill cuttings samples, carriage prepaid, to the commission not later than 14 days after the date of rig release.
Section 29 (2) (d) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(d) forward the core to the commission, carriage prepaid, not later than 14 days after the date of rig release.
Section 30 (2) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(2) Within 30 days after completion of a core analysis, a well permit holder must submit to the commission, in duplicate, the result of the core analysis, including digital core analysis data.
Section 30 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) Within 30 days after completion of a core analysis, a well permit holder must submit to the commission a report of the result of the core analysis, including digital core analysis data and photographs, if any.
Section 31 (4) (c) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(c) submit two copies of any laboratory analysis conducted on the core to the commission within 30 days of completing the analysis,
Section 31 (3) BEFORE amended by BC Reg 8/2014, effective February 6, 2014.
(3) With the approval of an official and subject to subsection (4), a person, on payment of a fee of $300 per well, may remove a well core from the core lab for the purpose of laboratory investigations and analysis that cannot be performed at the core lab.
Section 31 (5) BEFORE repealed by BC Reg 8/2014, effective February 6, 2014.
(5) Core and drill cuttings may be examined at the core lab on payment of the following fees:
(a) $30 per day to examine drill cuttings;
(b) $40 per well to examine well cores.
Section 31 (3) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(3) With the approval of an official and subject to subsection (4), a person, on payment of the fees set out in section 19 of the Fee, Levy and Security Regulation, may remove a well core from the core lab for the purpose of laboratory investigations and analysis that cannot be performed at the core lab.
Section 31 (4) (c) and (d) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(c) submit a report, including photographs, if any, of any laboratory analysis conducted on the core to the commission within 30 days of completing the analysis,
(d) submit any thin sections cut from core to the commission in adequate boxes labelled with the unique well identifier, well permit number and well name,
Section 32 (1) (b), (c) and (d) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) if a kick occurs during drilling operations, notify the commission immediately and submit a written kick report to the commission within one day of the incident,
(c) submit a copy of the daily drilling report (tour sheet) to the commission within 30 days of rig release,
(d) submit a summary report of drilling operations to the commission within 4 days of the following:
Section 32 (2) and (e) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(e) full details of all formation tests, unless the details are submitted on a confidential report form provided by the commission;
Section 33 (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(3) A well permit holder must submit to the commission within 14 days of rig release the results of the directional survey under subsection (2).
Section 34 (1) (part) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(1) Subject to subsection (2), before a well is completed, suspended or abandoned, a well permit holder must ensure that
Section 34 (1) (c) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(c) a resistivity and porosity log is taken from the base of the surface casing of the well to the total depth of the well.
Section 34 (3), and (5) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(3) Within 30 days after the date on which a log was run, the well permit holder must submit to the commission 2 copies of the log, including any computer enhanced logs, and
(a) one copy of the log must be on paper and one copy of the log must be in a digital format, and
(b) all copies must be clearly labelled with the well permit number and well name.
(5) If drill stem tests, wire line tests or initial production tests from a well allow good sampling, the well permit holder must submit to the commission, within 30 days of analysis completion, 2 copies of all analyses made of any oil, gas or formation water recovered from each formation.
Section 34 (2.1) was added by BC Reg 241/2012, effective August 14, 2012.
Section 34 (5) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(5) If drill stem tests, wire line tests or initial production tests from a well allow good sampling, the well permit holder must submit to the commission, within 30 days of analysis completion, a report of all analyses made of any oil, gas or formation water recovered from each formation.
Section 34 (6.1) was added by BC Reg 159/2015, effective July 30, 2015.
Section 34 (6) BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
(6) On obtaining the data and results of a bottom-hole sample analysis or other pressure-volume-temperature analysis, the well permit holder must submit the data and results to the commission within 30 days of analysis completion.
Section 34 (7) BEFORE repealed by BC Reg 48/2021, effective March 4, 2021.
(7) The permit holder of a gas processing plant must, on or before January 31 of each year, submit analyses, representative of the operations for the preceding year, of
(a) the fluids entering the plant, if practical separately, for each pool delivering gas to the plant, and
Section 34 (3), (4) (part), (5) (part) and (6) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(3) Within 30 days after the date on which a log was run, the well permit holder must submit a copy of the log to the commission.
(4) A well permit holder must submit to the commission
(5) A well permit holder must submit the following to the commission within 30 days of analysis completion:
(6) On obtaining the data and results of a bottom hole sample analysis or other pressure-volume-temperature analysis, the well permit holder must submit the data and results to the commission within 30 days of analysis completion.
Section 34 (6.1) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) submit an analysis of the isotope data samples captured under paragraph (a) to the commission within 30 days of analysis completion.
Section 35 was renumbered as 35 (2) by BC Reg 103/2019, effective May 17, 2019.
Section 35 (1) was added by BC Reg 103/2019, effective May 17, 2019.
Section 35 (1) (part) and (2) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) Within 14 days after the date of rig release of the drilling rig, a well permit holder must submit to the commission the final as-drilled survey plan, showing the surface location and bottom hole location of the well and including the following for each:
(2) Within 60 days after the date of rig release of the drilling rig, a well permit holder must submit to the commission a wellsite geology report
Section 36 (1) and (2) BEFORE amended by BC Reg 241/2012, effective January 1, 2012.
(1) For each separate completion or workover operation on a well, a well permit holder must submit to the commission in duplicate, within 30 days of the end of each completion or workover operation, a report, in chronological format, detailing all significant operations, treatments and resulting well behaviour, and including a downhole schematic diagram.
(2) A report under subsection (1) is not required for routine maintenance operations, including injection of corrosion inhibitors, scale removal, pressure testing operations, or removal of tubing plugs.
Section 36 (2) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) A report under subsection (1) is not required for routine maintenance operations, including injection of corrosion inhibitors, scale removal or pressure testing operations.
Section 36 (1) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) For each separate completion or workover operation on a well, a well permit holder must submit to the commission, within 30 days of the end of each completion or workover operation, a report, in chronological format, detailing all significant operations, treatments and resulting well behaviour, and including a downhole schematic diagram.
Section 37 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder must submit to the commission the records referred to in subsection (1) within 30 days after the completion of the well.
Section 38 (2) BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
(2) A permit holder must keep for not less than 72 months records of supporting information, methodologies and data associated with the records referred to in subsection (1).
Section 39 (2), (4), (5) and (6) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(2) A permit holder of a completed well or facility must equip each well or facility with a system to detect and control leaks as quickly as practicable.
(4) Subject to subsection (10), if an uncontrolled flow of oil or gas from a completed well, other than a well suspended in accordance with section 25, could produce a hydrogen sulphide concentration greater than 100 ppm in atmosphere within 50 metres of the well, the permit holder of the well must install and maintain
(a) an automated system to isolate the well in the event of an uncontrolled flow of oil or gas, and
(b) if the well is located within 1600 m of a populated area, a hydrogen sulphide detection and alarm system that is continuously monitored and is capable of activating the automated system referred to in paragraph (a).
(5) Subject to subsection (10), if an uncontrolled flow of oil or gas from a facility could produce a hydrogen sulphide concentration greater than 100 ppm in atmosphere at the facility boundary, the permit holder of the facility must install and maintain
(a) an automated system to isolate the facility in the event of an uncontrolled flow of oil or gas, and
(b) if the facility is located within 1600 m of a populated area, a hydrogen sulphide detection and alarm system which is continuously monitored and is capable of activating the automated system referred to in paragraph (a).
(6) The permit holder of a completed well or facility where the hydrogen sulphide content of the gas exceeds 5 mole percent must do all of the following if a populated area or a numbered highway is within the emergency planning zone for the well or facility:
(a) for a completed well not produced by artificial lift,
(i) equip the well with 2 master valves,
(ii) install a production packer set as closely above the producing formation as is practicable and fill the annular space between the tubing and production casing with a suitable corrosion inhibiting liquid,
(iii) install wellhead equipment for which the working pressure rating is not less than the bottom-hole pressure of the producing formation, but with a minimum rating of 14 000 kPa,
(iv) if a hot oil circulating string is used inside the production casing of a well, install a check valve in the injection line and automatic shutoff valve on the return line,
(v) if a well is equipped with a production packer as required under subparagraph (ii), conduct annual segregation tests and, if the test fails, complete repairs without unreasonable delay, and
(vi) maintain a record of the tests and repairs referred to in subparagraph (v);
(b) for a flowing well that is located within 800 m of a populated area or within 8 km of a city, town or village and that has the potential to produce more than 30 000 m3 of gas per day, install at least 30 m below the surface a downhole safety valve in the tubing that closes automatically in the event of an uncontrolled flow of oil or gas or a failure in the system which operates the valve.
Section 39 (9) BEFORE repealed by BC Reg 204/2013, effective October 1, 2014.
(9) For each well or facility, a permit holder must
(a) develop and maintain an adequate emergency response plan,
(b) submit the emergency response plan to the commission before beginning operations at the well or facility, and
(c) respond to an emergency at the well or facility in accordance with the emergency response plan.
Section 39 (7) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(7) If a well completed after the date this regulation came into force is produced by artificial lift and the hydrogen sulphide content of the gas exceeds 100 ppm, the well permit holder must
(a) install on the stuffing box an automatic shutdown device that will shut down the pumping unit in the event of a stuffing box failure and effectively seal off the well in the event of a polish rod failure, and
(b) install an automatic vibration shutdown system that will safely shut down the pumping unit.
Section 39 (6) (a) (vi) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(vi) maintain a record of the tests and repairs referred to in subparagraph (v);
Section 39 (6) (a) (iii) BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
(iii) install wellhead equipment for which the working pressure rating is not less than the bottom-hole pressure of the producing formation, but with a minimum rating of 14 000 kPa,
Section 39 (3) (a) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(a) the well or facility is located within 800 m of a populated area, or
Section 39 (6) (c) was added by BC Reg 103/2019, effective May 17, 2019.
Section 39 (7) (a) (i) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(i) install on the stuffing box a device that will seal off the well in the event of a polish rod failure, and
Section 39 (8) BEFORE repealed by BC Reg 103/2019, effective May 17, 2019.
(8) A permit holder must ensure that buildings of wood construction do not house production equipment at a well or facility.
Section 40.1 (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
Invasive plant compliance record
40.1 A person who carries out oil and gas activities within an operating area must prepare and maintain an invasive plant compliance record that describes the activities carried out for the purpose of complying with the obligations described in section 15 of the Environmental Protection and Management Regulation, including all of the following:
Section 41 (3), (4) and (6) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(3) On discovery, a well permit holder must report to the commission without delay a surface casing vent flow that presents an immediate safety or environmental hazard or an occurrence of gas migration.
(4) On discovery, a well permit holder, without unreasonable delay, must test the flow rate and buildup pressure of a surface casing vent flow that is not required to be reported under subsection (3) and maintain a record of those tests.
(6) A permit holder of a well drilled or facility constructed after the date this regulation came into force must not use gas containing hydrogen sulphide for pneumatic instrumentation or to provide motive force to pumps.
Section 41 (3) BEFORE amended by BC Reg 242/2012, effective August 14, 2012.
(3) On discovery of a surface casing vent flow that presents an immediate safety or environmental hazard or an occurrence of gas migration, a well permit holder must
(a) immediately take steps to eliminate the hazard or gas migration, and
(b) submit to the commission without delay a report respecting the surface casing vent flow and the steps taken under paragraph (a).
Section 41 (3) (part) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(3) On discovery of a surface casing vent flow that presents an immediate safety or environmental hazard or an occurrence of gas migration, a well permit holder must
Section 41 (3) (a) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(a) immediately take steps to eliminate the hazard or gas migration,
Section 41 (4) (b) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(b) submit to the commission within 30 days of the discovery a record of the test.
Section 41 (4.1) was added by BC Reg 159/2015, effective July 30, 2015.
Section 41 (2) (a), (b) and (c) BEFORE repealed by BC Reg 146/2017, effective June 1, 2017.
(a) during initial completion of the well,
(b) as routine maintenance throughout the life of the well, and
(c) during abandonment of the well.
Section 41 (2) (d), (e) and (f) were added by BC Reg 146/2017, effective June 1, 2017.
Section 41 (2) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(2) A well permit holder must check each well for evidence of a surface casing vent flow
Section 41 (2) (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
Section 41 (5) BEFORE repealed by BC Reg 286/2018, effective January 1, 2020.
(5) A facility permit holder must have an adequate fugitive emissions management program.
Section 41 (2) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder must check each well for evidence of a surface casing vent flow, and submit the results of the check to the commission,
Section 41 (3) (b) and (c) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) immediately notify the commission of the surface casing vent flow, and
(c) submit to the commission without delay a report respecting the surface casing vent flow and the steps taken under paragraph (a).
Section 41 (4) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) submit a surface casing vent flow report to the commission within 30 days of the discovery of the surface casing vent flow.
Section 41 (4.1) (a) and (c) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(a) immediately notify the commission of the gas migration,
(c) submit to the commission without delay a report respecting the evaluation and risk assessment completed under paragraph (b).
Section 41 (1.1), (2.1), (4.02), (4.03), (4.04) and (4.05) were added by BC Reg 256/2024, effective January 1, 2025.
Section 41 (4.01) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(4.01) A well permit holder must ensure that the emissions of gas from a surface casing vent flow do not exceed 100 m3 per day.
Section 41.1 (1) definition of "water source well" was added by BC Reg 78/2023, effective January 1, 2024.
Section 41.1 (2) to (7) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(2) A facility permit holder who operates a facility must, in accordance with subsection (4), carry out at least the following surveys of the facility, including, without limitation, any pneumatic devices at the facility:
(a) three comprehensive surveys per year, if the facility is
(iii) a multi-well battery, or
(iv) a single-well battery that includes a controlled storage tank;
(b) one comprehensive survey per year, if the facility is
(i) a custom treating facility,
(ii) an injection and disposal facility,
(iii) a single-well battery not described in paragraph (a) (iv), or
(iv) a facility that includes a storage tank, other than a facility described in paragraph (a);
(c) in any other case, one screening survey per year.
(3) A well permit holder who operates a well must, in accordance with subsection (4), carry out at least the following surveys of the well:
(a) one comprehensive survey per year, if the well
(ii) is producing from an unconventional zone listed in Schedule 2;
(b) in any other case, one screening survey per year.
(4) A survey required under this section must be carried out at least the following interval after the previous required survey:
(a) in the case of a facility described in subsection (2) (a), 60 days;
(b) in the case of a facility described in subsection (2) (b) or (c) or a well described in subsection (3) (a) or (b), 9 months.
(5) If a leak is detected at a facility during a survey required under this section, the facility permit holder who operates the facility must repair the leak
(a) within 30 days of detection, or
(b) if the repair requires the facility to be shut down, at the next turnaround for the facility.
(6) If a leak is detected at a well during a survey required under this section, the well permit holder who operates the well must repair the leak within 30 days of detection.
(7) A permit holder who operates a facility or well must maintain a record of the surveys of the facility or well that are carried out to meet a requirement under this section that includes the following information for each survey:
(a) the date of the survey and the method used;
(b) any leaks that are detected and, for each leak detected,
(ii) if the leak is repaired, the date of the repair.
Section 41.1 (8) to (16) were added by BC Reg 78/2023, effective January 1, 2024.
Section 41.1 (2) (part), (5) (part), (6) (part), (9), (10) and (13) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(2) Subject to subsections (7) to (9), a facility permit holder must, each calendar year, carry out at least the following surveys of the facility, including, without limitation, any pneumatic devices at the facility:
(5) Subject to subsections (7) to (9), the well permit holder of a well, other than a water source well, a water injection well or a water disposal well, that is pressurized 91 days or more in a calendar year must carry out at least the following surveys of the well in the calendar year:
(6) Subject to subsections (7) to (9), a survey required under this section must be carried out no sooner than the following interval after the previous required survey:
(9) A requirement for a permit holder to carry out a screening survey of a facility or well under this section is met if the permit holder carries out a comprehensive survey of the facility or well.
(10) If a leak is detected at a facility or well during a comprehensive survey required under this section, the permit holder of the facility or well must measure the leak unless
(a) it is unsafe to measure the leak,
(b) the leak is inaccessible, or
(c) the leak flow rate is outside the range of the measurement device.
(13) A well permit holder must repair a leak detected at a well during a survey required under this section within 30 days of detection.
Section 41.1 (2) (b) (vi) was added by BC Reg 256/2024, effective January 1, 2025.
Section 41.1 (2) (c) BEFORE repealed by BC Reg 256/2024, effective January 1, 2025.
(c) one screening survey, if the facility is a gas sales meter facility and is pressurized 91 days or more in the calendar year.
Section 41.1 (3) table BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
| Column 1 Days pressurized per calendar year | Column 2 Surveys required per calendar year |
| 0 – 30 | 0 |
| 31 – 121 | 1 |
| 122 – 243 | 2 |
| 244 – 365 | 3 |
Section 41.1 (4) (b) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(b) submit the record to the commission by March 31 of the calendar year after the calendar year to which the record relates.
Section 41.1 (5.1), (5.2), (5.3), (7.1), (17), (18), (19) and (20) were added by BC Reg 256/2024, effective January 1, 2025.
Section 41.1 (6) (b) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(b) in the case of a facility described in subsection (2) (b) or (c) or a well described in subsection (5) (a) or (b), 9 months.
Section 41.1 (8) and (11) BEFORE repealed by BC Reg 256/2024, effective January 1, 2025.
(8) A permit holder who carries out a screening survey of a facility referred to in subsection (2) (c) must at the same time carry out a screening survey of each other facility, and each well, of the permit holder that is located at the same site.
(11) If a leak referred to in subsection (10) cannot be measured, the permit holder must quantify the leak rate using an engineering estimate or by applying an emission factor.
Section 41.1 (14) (b) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(b) submit the report to the commission by March 31 of the calendar year after the calendar year to which the report relates.
Section 41.1 (15) (a) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(a) the site identification number provided to the permit holder by the commission;
Section 41.1 (15) (i) (i), (vii) and (viii) BEFORE repealed by BC Reg 256/2024, effective January 1, 2025.
(vii) if the leak rate was measured, the make and model of the device used to measure the leak;
(viii) if the leak rate was quantified using an engineering estimate or by applying an emission factor, the reason that the leak was not measured;
Section 42 (4) (b) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(b) the cumulative quantity of flared gas during the initial completion of the well does not exceed
(i) 400 000 m3, if the well is classified as a development well, and
(ii) 600 000 m3, if the well is classified as an exploratory outpost well or an exploratory wildcat well.
Section 42 (2) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(2) Subject to subsections (3) to (5), a permit holder must not flare gas unless flaring is required for emergency purposes or for drilling operations.
Section 42 (4) BEFORE repealed by BC Reg 159/2015, effective July 30, 2015.
(4) A holder of permit that was, immediately before section 116 of the Act came into force, an authorization referred to in that section may flare gas for the purposes of well clean up and testing if
(a) the well is not completed before the date this regulation comes into force, and
(b) the cumulative quantity of flared gas does not exceed
(i) 400 000 m3, if the well is classified as a development well, and
(ii) 600 000 m3, if the well is classified as an exploratory outpost well or an exploratory wildcat well.
Section 43 (4) BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
(4) When gas is flared at a well, the permit holder with respect to the well must report to the commission, within 60 days after completing the operation, the quantity of gas flared.
Section 43 (1), (2) and (4) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) A permit holder must notify the commission at least 24 hours before a planned flaring event if the quantity of gas to be flared exceeds 10 000 m3.
(2) If an unplanned flaring event occurs and the quantity of flared gas exceeds 10 000 m3, the permit holder must notify the commission within 24 hours of the flaring event.
(4) When gas is flared at a well, the permit holder with respect to the well must report the quantity of gas flared to the commission no later than 20 days after the end of the month in which the flaring occurred.
Section 44 (b) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(b) that unsupervised flare stacks where intermittent flaring may occur are equipped with an adequate auto-ignition system;
Section 44 (1) (d) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(d) flare and incinerator systems installed after the date this regulation came into force are designed by and operated within the limits specified by a professional engineer licensed or registered under the Engineers and Geoscientists Act;
Section 44 BEFORE renumbered as 44 (1) by BC Reg 78/2023, effective January 1, 2024.
Flaring performance requirements
44 A permit holder of a well or facility must ensure all of the following:
(a) that flare stacks are adequately anchored;
(b) that unsupervised flare stacks where flaring may occur are equipped with an adequate auto-ignition system;
(c) if the hydrogen sulphide content of the gas to be flared exceeds one mole percent, that
(i) unsupervised flare stacks where continuous flaring will occur are equipped with a flame-out detection device with operation shut down capability that provides an immediate alarm to the permit holder, and
(ii) the minimum height of flare stacks is 12 m;
(c.1) that a flare pit is constructed only if the construction is specifically authorized in the well or facility permit;
(d) flare and incinerator systems installed after the date this regulation came into force are designed by and operated within the limits specified by a professional engineer licensed or registered under the Professional Governance Act;
(e) flaring does not result in the emission of black smoke.
[am. B.C. Regs. 159/2015, s. 11; 103/2019, s. 18; 202/2023, Sch. 2, s. 5.]
Section 44 (1) (b.1) was added by BC Reg 78/2023, effective January 1, 2024.
Section 44 (2) was added by BC Reg 78/2023, effective January 1, 2024.
Section 45 (3) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(3) If a pressure relief valve, rupture disc or burst plate is installed on a pressure vessel at a facility, the permit holder must ensure
(a) that the valve, disc or plate is connected by suitable piping to a tank if production is in the liquid phase,
(b) that the valve, disc or plate is connected to a flare system, if a flare system exists at the facility, or
(c) that a system of controls is installed to ensure safe operation and minimize venting.
Section 45 (4) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(4) A person carrying out an oil and gas activity must not smoke within 25 m of any well or facility.
Section 46 BEFORE repealed by BC Reg 103/2019, effective May 17, 2019.
Drill stem test recovery
46 (1) If a permit holder has recovered oil or gas during a drill stem test, the permit holder must ensure that the drill pipe is not pulled during hours of darkness, unless positive steps have been taken to ensure that there is no possibility of oil or gas being present in the drill pipe.
(2) A permit holder must ensure that gas produced to the atmosphere for a period exceeding 10 minutes during a drill stem test is flared.
Section 47 (e) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(e) a separator is not enclosed within the fire wall, dike or ditch surrounding a storage tank installation;
Section 47 (c) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(c) flares and incinerators are located at least 80 m from any public road, public utility, building, installation, works, place of public concourse or reservation for national defence;
Section 47 (c) (i) and (iii) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(i) a safe distance from any oil and gas road or resource road,
(iii) 100 m from any permanent building, installation or works that is not associated with an oil and gas activity, and
Section 48 BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
Position of tanks and production equipment
48 A permit holder must ensure that any petroleum storage tanks and production equipment for a well or facility for which the permit holder is responsible are located not less than 60 m from any right of way, easement, road allowance, public utility, building, installation, works, place of public concourse or reservation for national defence.
Section 48 (a) and (c) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(a) a safe distance from any oil and gas road or resource road,
(c) 100 m from any permanent building, installation or works that is not associated with an oil and gas activity, and
Section 49 BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
Emergency shut-down devices
49 A permit holder must not bypass or disable an alarm, monitoring or emergency shutdown device at a producing well or facility, unless
(a) the purpose of the bypass or disablement is to carry out maintenance or commissioning of the well or facility,
(b) the well or facility is continuously monitored,
(c) the permit holder has established and documented work procedures sufficient to ensure that the operation can be conducted safely, and
(d) the operation is conducted in accordance with the procedures referred to in paragraph (c).
Section 49 (1) (part) and (2) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(1) A permit holder must not bypass or disable an alarm, monitoring device, pressure relieving valve or emergency shutdown device at a producing well or facility, unless
(2) Subject to subsection (1), a permit holder must lock or car seal any valve or device that can bypass or disable a pressure relieving valve or device, or an emergency shutdown device, at a producing well or facility.
Section 49 (1) (part) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(1) A permit holder must not bypass or disable safety equipment at a producing well or facility, unless
Section 49 (2) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(2) Subject to subsection (1), a permit holder must lock or car seal any valve or device that can bypass or disable safety equipment at a producing well or facility.
Section 51 (3) (e) and (f) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(e) is filled to not more than one metre below the point of overflow at any given time, and
(f) is completely emptied and any excavation filled without unreasonable delay.
Section 51 (2) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(2) A well permit holder who deposits into an earthen pit drilling fluids that may be harmful to domestic livestock or big game must maintain the pit so as to prevent domestic livestock or big game from ingesting the fluids.
Section 51 (6) (d) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(d) the structure is located and constructed in a place and manner that ensures the contained fluids will not migrate beyond the lease boundary in the event of a containment failure,
Section 51 (4) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(4) Within 90 days of completing a drilling waste disposal, a well permit holder must submit to the commission a report of the drilling waste disposal.
Section 51 (6) (e) to (g) and (k) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(e) the commission is satisfied that the retaining walls of the structure are capable of withstanding the hydraulic pressure of the contents at full capacity,
(f) the installation of the liner system is completed to the satisfaction of the commission,
(g) the ground surface has been prepared to the satisfaction of the commission,
(k) any sign of leakage is reported to the commission within 24 hours of discovery, and
Section 51 (5) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) ensure that the earthen pit is designed by and installed under the supervision of a professional engineer licensed or registered under the Engineers and Geoscientists Act.
Section 52 (5) (a) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(a) in case of emergency, in which case the person must notify the commission of the removal without delay, or
Section 52.02 (1) (part) and (2) (part) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(1) A facility permit holder who operates a facility that uses hydrocarbon gas conservation equipment must ensure that
(2) A facility permit holder who operates a facility that uses hydrocarbon gas conservation equipment must maintain a record of the following for each piece of hydrocarbon gas conservation equipment:
Section 52.02 (1) (a) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(a) the equipment is operated continuously, except during a turnaround for the facility or while being maintained, cleaned, inspected or repaired,
Section 52.03 (1) to (4) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(1) A facility permit holder who operates a facility that began operations on or after January 1, 2022 must ensure that the emissions of natural gas from tanks at the facility are less than 1 250 m3 per month in total.
(2) Beginning on January 1, 2023, a facility permit holder who operates a facility that began operations before January 1, 2022 must ensure that the emissions of natural gas from tanks at the facility are less 9 000 m3 per month in total.
(3) Subject to subsection (4), a facility permit holder who operates a facility that includes an uncontrolled storage tank must maintain a record of the volume of natural gas emitted from the tank in each calendar month.
(4) Subsection (3) does not apply until January 1, 2023 in relation to a facility that began operations before January 1, 2022.
Section 52.03 BEFORE re-enacted by BC Reg 256/2024, effective January 1, 2025.
Tanks
52.03 (1) A facility permit holder of a facility that began operations on or after January 1, 2022 must ensure that the emissions of natural gas from uncontrolled production tanks at the facility are less than 1 250 m3 per month in total.
(2) Beginning on January 1, 2023, a facility permit holder of a facility that began operations before January 1, 2022 must ensure that the emissions of natural gas from uncontrolled production tanks at the facility are less 9 000 m3 per month in total.
(3) A facility permit holder of a facility that includes an uncontrolled production tank must
(a) maintain a record of the volume, in m3, of natural gas emitted from the production tank during each calendar month in each calendar year, and
(b) submit the record to the commission by March 31 of the calendar year after the calendar year to which the record relates.
(4) A facility permit holder of a facility that includes an uncontrolled production tank must maintain, for at least 7 years from the date a record is submitted under subsection (3), all records of equipment and methods used to quantify the volume of natural gas reported.
[en. B.C. Reg. 286/2018, s. 5 (b); am. B.C. Reg. 78/2023, Sch. 2, s. 10.]
Section 52.04 BEFORE re-enacted by BC Reg 78/2023, effective January 1, 2024.
Compressors
"high-output" means
(a) rated at 75 kW or more, or
(b) operated for 450 hours or more per year;
"provincial fleet", in relation to a facility permit holder, means all of the type B compressors used at facilities operated by the permit holder, whether or not under the same permit;
"type A compressor" means
(a) a reciprocating compressor that has 4 or more throws, and
(b) a high-output compressor, other than a type B compressor;
"type B compressor" means a high-output reciprocating compressor that
(a) was installed before January 1, 2021, or
(2) Subject to subsections (3) to (5), a facility permit holder who operates a facility that uses a type A compressor must ensure that the emissions of natural gas from the compressor are
(a) routed to hydrocarbon gas conservation equipment, or
(b) flared in accordance with sections 42 to 44.
(3) Subsection (2) does not apply until January 1, 2022 in relation to a centrifugal compressor that was installed before January 1, 2021.
(4) Subsection (2) does not apply in relation to a centrifugal compressor that was installed before January 1, 2021 if the emissions of natural gas from the compressor
(b) do not exceed 0.17 m3 per minute.
(5) Subsection (2) does not apply in relation to a centrifugal compressor that was installed on or after January 1, 2021 if the emissions of natural gas from the compressor
(b) do not exceed 0.057 m3 per minute.
(6) A facility permit holder who operates a facility that uses a type B compressor must ensure
(a) that the emissions of natural gas from the compressor do not exceed 5 m3 per hour per throw on that compressor, and
(b) beginning on January 1, 2022, that the emissions of natural gas from the permit holder's provincial fleet do not exceed 0.83 m3 per hour per throw on the compressors in the fleet that are in operation.
(7) Beginning on January 1, 2022, a facility permit holder who operates a facility that uses a type A compressor or a type B compressor must maintain a record of the following:
(a) whether the compressor is centrifugal or reciprocating;
(b) if applicable, the number of throws the compressor has;
(c) for each calendar year, the volume of natural gas emitted from the compressor during a period of 15 minutes that is representative of the normal operating conditions of the compressor.
[en. B.C. Reg. 286/2018, s. 5 (b).]
Section 52.04 (2) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(2) A facility permit holder of a facility that uses a reciprocating compressor described in paragraph (a) or (b) in the definition of "fleet of reciprocating compressors" in subsection (1) or a centrifugal compressor described in subsection (8) must, at least once each calendar year, measure the volume of natural gas emitted from each compressor seal during a 15-minute period that is representative of the normal operating conditions of the compressor.
Section 52.04 (2.1) and (4.1) were added by BC Reg 256/2024, effective January 1, 2025.
Section 52.04 (3) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(3) A facility permit holder of a facility that uses a reciprocating compressor described in subsection (4) must ensure that emissions of gas from the compressor seals
(a) are routed to hydrocarbon gas conservation equipment, or
(b) subject to sections 42 to 44, are flared.
Section 52.04 (5) (a) and (b) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(a) the venting of seal gas from each throw does not exceed 5 m3 per hour, and
(b) the average vent gas rate for the fleet for each calendar year does not exceed 0.83 m3 per hour per throw.
Section 52.04 (6) (b) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(b) submit the record to the commission by March 31 of the calendar year after the calendar year to which the record relates.
Section 52.04 (7) (a) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(a) the facility identification number provided to the permit holder by the commission;
Section 52.04 (10) (a) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(a) the facility identification number provided to the permit holder by the commission;
Section 52.04 (8.1), (8.2), (12) and (13) were added by BC Reg 256/2024, effective January 1, 2025.
Section 52.05 (4) (b) (i) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(i) the facility permit holder has a signed statement, from a professional engineer licensed or registered under the Engineers and Geoscientists Act, that
Section 52.05 (2), (3), (4) (part) and (5) (part) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(2) A facility permit holder who operates a facility that began operations on or after January 1, 2021 must not use at the facility a pneumatic device that emits natural gas.
(3) Beginning on January 1, 2022, a facility permit holder who operates a gas processing plant, or a large compressor station, that began operations before January 1, 2021 must not use at the facility a pneumatic device that emits natural gas.
(4) Beginning on January 1, 2022, a facility permit holder who operates a facility that began operations before January 1, 2021, other than a gas processing plant or a large compressor station, must not use at the facility a pneumatic device that emits natural gas unless
(5) Subject to subsection (6), a facility permit holder who operates a facility that uses a pneumatic device that emits natural gas must maintain a record of the following:
Section 52.05 (6) BEFORE repealed by BC Reg 78/2023, effective January 1, 2024.
(6) Subsection (5) does not apply until January 1, 2022 in relation to a facility that began operations before January 1, 2021.
Section 52.05 (7) to (10) were added by BC Reg 78/2023, effective January 1, 2024.
Section 52.05 (1) definition of "pneumatic device" BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
"pneumatic device" does not include a pneumatic pump or a pneumatic compressor starter.
Section 52.05 (4) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(4) A facility permit holder of a facility that began operations before January 1, 2021, other than a gas processing plant or a large compressor station, must not use at the facility a pneumatic device that emits natural gas unless
(a) the emissions of natural gas from the device do not exceed 0.17 m3 per hour, or
(b) all of the following requirements are met:
(i) the facility permit holder has a signed statement, from a professional engineer licensed or registered under the Professional Governance Act, that
(A) the device cannot be operated so as to meet the requirement in paragraph (a) without compromising the safe operation of the facility, and
(B) it is not practical to replace the device with a device that can be operated so as to meet those requirements;
(ii) the emissions of natural gas from the device are minimized to the extent consistent with efficient operation of the device and safe operation of the facility, and
(iii) the device is marked with a weatherproof and readily visible tag.
Section 52.05 (4.1), (4.2), (4.3) and (4.4) were added by BC Reg 256/2024, effective January 1, 2025.
Section 52.05 (5) (c) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(c) whether the device is being used under subsection (4) (b);
Section 52.05 (7), (8) and (9) BEFORE repealed by BC Reg 256/2024, effective January 1, 2025.
(7) A facility permit holder who uses, in accordance with the requirements set out in subsection (4) (b), a pneumatic device that emits natural gas must maintain a record of the signed statement referred to in subsection (4) (b) (i) for at least 7 years from the date of the statement.
(8) An official may grant to a permit holder an exemption in writing from the application of one or more of subsections (2), (3) or (4) 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.
(9) In granting an exemption under subsection (8), an official may impose any conditions on the exemption that the official considers necessary.
Section 52.06 (1) (part) and (2) (part) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(1) A facility permit holder who operates a facility must not use at the facility a pneumatic pump that emits natural gas unless the pump
(2) Beginning on January 1, 2021, a facility permit holder who operates a facility that uses a pneumatic pump that emits natural gas must maintain a record that contains
Section 52.06 (3) was added by BC Reg 78/2023, effective January 1, 2024.
Section 52.07 (1) (part) and (2) (part) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(1) Beginning on January 1, 2022, a facility permit holder who operates a facility that uses a pneumatic compressor starter must ensure that the emissions of natural gas from the compressor starter are
(2) Beginning on January 1, 2022, a permit holder who operates a facility that uses a pneumatic compressor starter that cannot be routed or flared as set out in subsection (1) must maintain a record that contains
Section 52.08 (3) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) submit the record to the commission by July 1 of the calendar year after the calendar year to which the record relates.
Section 52.08 (1), (2) and (3) (part) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(1) Subject to subsection (2), a facility permit holder who operates a facility that uses a glycol dehydrator that was installed on or after January 1, 2022 must ensure that the emissions of natural gas from the dehydrator are less than 25 tonnes per year.
(2) Beginning on January 1, 2023, a facility permit holder who operates a facility that uses a glycol dehydrator that was installed before January 1, 2022 must ensure that the emissions of natural gas from the dehydrator are less than 50 tonnes per year.
(3) A facility permit holder who operates a facility that uses a glycol dehydrator must
Section 52.08 (3) (b) BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
(b) submit the record to the regulator by July 1 of the calendar year after the calendar year to which the record relates.
Section 52.08 (0.1), (4), (5), (6), (7), (8) and (9) were added by BC Reg 256/2024, effective January 1, 2025.
Section 52.08 (1) and (2) BEFORE repealed by BC Reg 256/2024, effective January 1, 2025.
(1) Subject to subsection (2), a facility permit holder of a facility that uses a glycol dehydrator that was installed on or after January 1, 2022 must ensure that the emissions of natural gas from the dehydrator are less than 25 tonnes per year.
(2) Beginning on January 1, 2023, a facility permit holder of a facility that uses a glycol dehydrator that was installed before January 1, 2022 must ensure that the emissions of natural gas from the dehydrator are less than 50 tonnes per year.
Section 52.08 (3) BEFORE amended by BC Reg 256/2024, effective January 1, 2025.
(3) A facility permit holder of a facility that uses a glycol dehydrator must
(a) maintain a record of the volume of natural gas emitted from the dehydrator in each calendar year, and
(b) submit the record to the regulator by March 31 of the calendar year after the calendar year to which the record relates.
Section 52.12 BEFORE amended by BC Reg 78/2023, effective January 1, 2024.
Measurement equipment
52.12 A permit holder who operates a facility or well must ensure that the equipment and methods used to measure emissions at the facility or well are sufficient to measure
(a) the actual volumes and rates of emissions referred to in this Division, other than in section 52.04 (7) (c), and
(b) the volume of emissions referred to in section 52.04 (7) (c) to within 10% of the actual volume.
[en. B.C. Reg. 286/2018, s. 5 (b).]
Section 52.13 (a) BEFORE renumbered as (a.1) by BC Reg 256/2024, effective January 1, 2025.
(a) a record or report required to be submitted or maintained under section 41.1;
Section 52.13 (a) was added by BC Reg 256/2024, effective January 1, 2025.
Section 53(e), (f) and (g) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(e) if natural gas, petroleum, natural gas liquids or natural gas byproducts are produced from a well or facility,
(i) the meter is maintained in good operating condition, and
(ii) the meter is suitably safeguarded from weather and from interference by unauthorized persons;
(f) if natural gas, petroleum, natural gas liquids or natural gas byproducts are produced from a well or facility and there is a bypass around a meter, that valves are installed that, when closed, will effectively stop all flow through the bypass;
(g) if natural gas, petroleum, natural gas liquids or natural gas byproducts are produced from a well or facility and a bypass around a meter is opened or if, for any other reason, the full production stream does not reach the meter, that a suitable entry is made on the meter chart or on the recordkeeping notations in the EFM system.
Section 53 (a) (i) and (ii) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(ii) each product stream used for reporting purposes at a facility;
Section 53 (a) (iii) was added by BC Reg 146/2017, effective June 1, 2017.
Section 53 (c), (e) (part), (f) and (g) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(c) if quantities of natural gas, petroleum, natural gas liquids or natural gas byproducts are not metered due to the failure of a meter, chart recorder or quantity device, that an engineering estimate of all un-metered production from the well or facility is included in the quantity computation for the reporting period for the meter, chart recorder or other quantity device;
(e) if natural gas, petroleum, natural gas liquids, natural gas byproducts or water are produced from or injected into a well or facility, that
(f) if natural gas, petroleum, natural gas liquids, natural gas byproducts or water are produced from or injected into a well or facility and there is a bypass around a meter, that valves are installed that, when closed, will effectively stop all flow through the bypass;
(g) if natural gas, petroleum, natural gas liquids, natural gas byproducts or water are produced from or injected into a well or facility and a bypass around a meter is opened or if, for any other reason, the full production stream does not reach the meter, that a suitable entry is made on the meter chart or on the recordkeeping notations in the electronic flow measurement (EFM) system.
Section 54 (2) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(2) The UDOA for an oil well, expressed in m3/day and rounded to one decimal place, is
(a) a minimum value of 10.0, if the well depth is less than 1 000 metres,
(b) a minimum value of the well depth of the well divided by 100, if the well depth is greater than 1 000 metres, or
(c) as specified in the well permit.
Section 55 BEFORE renumbered as subsection (1), and amended by BC Reg 146/2017, effective June 1, 2017.
Restriction of oil production
55 Subject to section 49.1 (1) (c) of the Act, the permit holder of
(b) a group of oil wells that have been designated a project UDOA under section 75 of the Act
must ensure that oil production from the well or group of wells in any one day does not exceed the daily production limit.
Section 55 (2) was added by BC Reg 146/2017, effective June 1, 2017.
Section 56 (2) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) Subsection (1) does not apply to a well subject to a designation under section 75 of the Act.
Section 59 (2) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) a production allowable report is submitted to the commission in time to be received on or before the 16th day of the month.
Section 61 (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(3) If a permit holder shuts in a well in accordance with this section, the commission must be notified in writing of the date on which the well is shut in, and the number of days calculated for the shut in period based on the daily oil allowable.
Section 62 (2) BEFORE repealed by BC Reg 146/2017, effective June 1, 2017.
(2) Subsection (1) applies only to producing formations in a well from which initial production occurs after the date this regulation came into force.
Section 62 (3) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(3) Within 60 days of the sampling referred to in subsection (1), the well permit holder must submit to the commission a report of the component analyses of the crude oil liquids.
Section 62 BEFORE re-enacted by BC Reg 103/2019, effective May 17, 2019.
Oil production analyses
62 (1) A well permit holder must take a representative crude oil sample from each producing formation from a well to which this subsection applies within 6 months of the initial production date.
(2) Repealed. [B.C. Reg. 146/2017, App. 1, s. 30 (a).]
(3) Within 60 days of the sampling referred to in subsection (1), the well permit holder must submit to the commission a report of the component analyses and physical properties of the crude oil liquids.
[am. B.C. Reg. 146/2017, App. 1, s. 30.]
Section 62 (2) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder must submit to the commission a report of the component analyses and physical properties of the oil and hydrocarbon liquids within 60 days of
Section 63 (1) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(1) Before 6 months have elapsed after a permit holder has first placed a gas well on production, the permit holder must flow test the well and determine the absolute open flow potential if
Section 63 (3) was added by BC Reg 241/2012, effective August 14, 2012.
Section 63 (2) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A permit holder must submit to the commission, within 60 days of the date on which the operation concluded, a detailed report of
Section 65 (2) (d) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(d) a gas well to which an off-target penalty factor applies.
Section 66 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A permit holder must submit to the commission a report of any accumulated overproduction for the period November 1 to October 31, and the submission must be made in time for it to be received on or before December 16 for each gas well or special project under section 75 of the Act.
Section 67 (2) and (3) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(2) Within 60 days of the sampling referred to in subsection (1), the well permit holder must submit to the commission a report of the component analyses of the natural gas and liquids.
(3) If any other natural gas sampling and analysis is performed on a well, the well permit holder must submit to the commission a report of the component analyses of the natural gas and liquids within 60 days of the sampling.
Section 67 BEFORE re-enacted by BC Reg 103/2019, effective May 17, 2019.
Gas production analyses
67 (1) A well permit holder must take a representative natural gas sample from each producing formation from a well within 6 months of the initial production date.
(2) Within 60 days of the sampling referred to in subsection (1), the well permit holder must submit to the commission a report of the component analyses and physical properties of the natural gas and hydrocarbon liquids.
(3) If any other natural gas sampling and analysis is performed on a well, the well permit holder must submit to the commission a report of the component analyses and physical properties of the natural gas and hydrocarbon liquids within 60 days of the sampling.
[am. B.C. Regs. 159/2015, s. 18; 146/2017, App. 1, s. 32.]
Section 67 (2) (part) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder must submit to the commission a report of the component analyses and physical properties of the natural gas and hydrocarbon liquids within 60 days of
Section 71 (1) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(1) If a zone in a well has produced sufficient water to allow representative sampling, the well permit holder of the well must collect a representative water sample from the zone and have it analyzed for mineral and ion content.
Section 71 (3) was added by BC Reg 146/2017, effective June 1, 2017.
Section 71 (2) and (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) Within 60 days of the sampling referred to in subsection (1), the well permit holder must submit to the commission a report of the analysis.
(3) Within 60 days of performing any other well water analysis, the well permit holder must submit to the commission a report of the analysis.
Section 72 (1) BEFORE repealed by BC Reg 146/2017, effective June 1, 2017.
(1) A permit holder must not operate a water source well in a manner that injuriously affects the use of the water source for domestic or agricultural purposes.
Section 72 (2) BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
(2) A well permit holder must report the quantity of water production from a water source well to the commission no later than 25 days after the end of the month in which the production occurred.
Section 72 (2) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(2) A well permit holder must report the quantity of water production from a water source well to the commission no later than 20 days after the end of the month in which the production occurred.
Section 73 (1) and (2) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(1) A well permit holder must ensure that the static bottom hole pressure of each completed zone of each of the permit holder's oil or gas wells is measured before initial oil or gas production.
(2) A well permit holder must ensure that the static bottom hole pressure of each of the permit holder's producing pools is measured annually.
Section 73 (5) and (6) were added by BC Reg 241/2012, effective August 14, 2012.
Section 73 BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
Reservoir pressure measurements
73 (1) Subject to subsection (5), a well permit holder must ensure that the static bottom hole pressure of each completed zone of each of the permit holder's oil or gas wells is measured before initial oil or gas production.
(2) Subject to subsection (6), a well permit holder must ensure that the static bottom hole pressure of each of the permit holder's producing pools and observation wells is measured once every calendar year.
(3) A well permit holder must report all static bottom hole pressures and the duration of the resulting shut-in period to the commission within 60 days after the date on which the pressures were measured.
(4) A well permit holder must ensure that, when static bottom hole pressures are measured, the surveyed wells remain shut-in until the reservoir pressure has been attained in the well bore or until sufficient data are available to permit the calculation of the reservoir pressure and, in the latter case, details of the reservoir pressure calculations are included in the report required under subsection (3).
(5) Subsection (1) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2 if the commission has released, under section 17 of the Oil and Gas Activities Act General Regulation, well reports and well data that include a static bottom hole pressure measurement from the same unconventional zone within a 4 km radius measured from the wellhead of the well.
(6) Subsection (2) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2.
[am. B.C. Reg. 241/2012, s. 20.]
Section 73 (5) and (6) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(5) Subsection (1) does not apply with respect to a gas well completed in an unconventional zone listed in Schedule 2 if the commission has released, under section 17 of the Oil and Gas Activities Act General Regulation, well reports and well data that include a static bottom hole pressure measurement from the same unconventional zone within a 4 km radius measured from the wellhead of the well.
(6) Subsection (2) does not apply with respect to a gas well completed in an unconventional zone listed in Schedule 2.
Section 73 (3) (part) and (5) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(3) A well permit holder must report the following measurements to the commission within 60 days of the date the measurements were taken:
(5) Subsection (1) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2 if the commission has released, under section 17 of the Oil and Gas Activities Act General Regulation, well reports and well data that include a static bottom hole pressure measurement from the same unconventional zone within a 4 km radius measured from the wellhead of the well.
Section 73 (5) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(5) Subsection (1) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2 if the regulator has released, under section 17 of the Oil and Gas Activities Act General Regulation, well reports and well data that include a static bottom hole pressure measurement from the same unconventional zone within a 4 km radius measured from the wellhead of the well.
Section 75 BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
Reporting of injection and disposal
75 If a well permit holder injects or disposes of water, gas, air or any other fluid into an underground formation, the well permit holder must submit a monthly injection or disposal statement, indicating the quantity of fluid injected or disposed of, to the commission no later than 25 days after the end of the month in which the activity occurred.
Section 75 BEFORE amended by BC Reg 174/2018, effective November 1, 2018.
Reporting of injection and disposal
75 If a well permit holder injects or disposes of water, gas, air or any other fluid into an underground formation, the well permit holder must submit a monthly injection or disposal statement, indicating the quantity of fluid injected or disposed of, the maximum wellhead injection or disposal pressure and the total monthly operating hours, to the commission no later than 25 days after the end of the month in which the activity occurred.
[am. B.C. Reg. 159/2015, s. 20.]
Section 75 BEFORE re-enacted by BC Reg 103/2019, effective May 17, 2019.
Reporting of injection and disposal
75 If a well permit holder injects or disposes of water, gas, air or any other fluid into an underground formation, the well permit holder must submit a monthly injection or disposal statement, indicating the quantity of fluid injected or disposed of, the maximum wellhead injection or disposal pressure and the total monthly operating hours, to the commission no later than 20 days after the end of the month in which the activity occurred.
[am. B.C. Regs. 159/2015, s. 20; 174/2018, s. 6.]
Section 75 (1) (part) and (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(1) If a well permit holder injects or disposes of water, gas, air or any other fluid into an underground formation, the well permit holder must submit to the commission a monthly injection or disposal statement indicating all of the following:
(3) In addition to the statement required under subsection (1), a well permit holder of an acid gas disposal well must submit to the commission a composition analysis of all disposed fluids, identifying the well location and disposal formation.
Section 77 (1) (d), (e) and (f) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(d) if the facility handles flammable gas, a flammable gas symbol from the Schedule,
(e) if the facility handles gas containing 100 ppm or greater of hydrogen sulphide, a poisonous gas symbol from the Schedule, and
(f) after March 1, 2011, if the facility handles gas containing 10 ppm or greater of hydrogen sulphide, a poisonous gas symbol from the Schedule.
Section 77(1)(b) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(b) emergency notification information, including a telephone number;
Section 78 (2), (3) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(2) A facility permit holder must construct and operate a piping system at a gas processing plant in accordance with ASME Standard B31.3, as amended from time to time, if construction begins after the date this regulation came into force.
(3) A facility permit holder must construct and operate a facility piping system at a facility other than a gas processing plant in accordance with CSA Standard Z 662, or ASME Standard B31.3, as amended from time to time, if construction begins after the date this regulation came into force.
Section 78 (3.1) and (5) were added by BC Reg 241/2012, effective August 14, 2012.
Section 78 (2) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(2) A facility permit holder must design and construct a piping system at a gas processing plant in accordance with ASME Standard B31.3, as amended from time to time, if construction begins after the date this regulation came into force.
Section 78 (3) (a) and (b) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(a) ASME Standard B31.3, as amended from time to time, or
(b) CSA Standard Z662, as amended from time to time.
Section 78 (3.1) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
(3.1) A facility permit holder referred to in subsection (1) must operate and maintain in accordance with the standard referred to in subsection (3) (b) any portions of the piping facility designed and constructed in accordance with that standard.
Section 78 (1.1) and (6) were added by BC Reg 159/2015, effective July 30, 2015.
Section 78 (4) and (5) BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
(4) A facility permit holder must submit to the commission all as-built drawings including piping and instrumentation diagrams, metering schematics and plot plans, signed and sealed by a professional engineer licensed or registered under the Engineers and Geoscientists Act, within 3 months of beginning production or completing permitted modifications, as applicable.
(5) The permit holder for a facility to which subsection (3) applies must indicate on the as-built drawings referred to in subsection (4) and on the piping of the facility the points at which the design and construction of the facility changes from one standard to the other, as applicable.
Section 78 (6) BEFORE amended by BC Reg 103/2019, effective May 17, 2019.
(6) A facility permit holder must ensure that
(a) the facility is maintained in a condition that minimizes hazards, including hazards associated with pits, holes, equipment and storage of materials, and
(b) the facility site is clean and free of garbage, debris and unused equipment.
Section 78 (3) (part) BEFORE amended by BC Reg 48/2021, effective March 4, 2021.
(3) A facility permit holder for a facility other than a gas processing plant must design and construct every portion of the piping system of the facility in accordance with either
Section 78 (4) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(4) A facility permit holder must submit to the commission all record drawings including piping and instrumentation diagrams, metering schematics and plot plans, signed and sealed by a professional engineer licensed or registered under the Engineers and Geoscientists Act, within 3 months of beginning production or completing permitted modifications, as applicable.
Section 78 (4) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(4) A facility permit holder must submit to the regulator all record drawings including piping and instrumentation diagrams, metering schematics and plot plans, signed and sealed by a professional engineer licensed or registered under the Engineers and Geoscientists Act, within 3 months of beginning production or completing permitted modifications, as applicable.
Section 78 (3.1) BEFORE amended by BC Reg 26/2025, effective April 1, 2025.
(3.1) A facility permit holder referred to in subsection (3) must operate and maintain in accordance with the standard referred to in subsection (3) (b) any portions of the piping facility designed and constructed in accordance with that standard.
Section 79 (b) BEFORE amended by BC Reg 241/2012, effective August 14, 2012.
(b) do everything referred to in section 19(1)(a) to (g) of the Environmental Protection and Management Regulation.
Section 79 BEFORE renumbered by BC Reg 146/2017, effective June 15, 2018.
Obligations on cancellation or cessation of operations
79 The following requirements are prescribed with respect to a facility permit for the purposes of section 40 (e) of the Act:
(a) remove the facility from the facility site;
(b) for a facility on Crown land, do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation.
[am. B.C. Reg. 241/2012, s. 23.]
Section 79 (2) and (3) were added by BC Reg 146/2017, effective June 15, 2018.
Section 79 (1) BEFORE amended by BC Reg 48/2021, effective March 4, 2021.
(1) The following requirements are prescribed with respect to a facility permit for the purposes of section 40 (e) of the Act:
(a) remove the facility from the facility site;
(b) for a facility on Crown land, do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation.
Section 79 (0.1) was added by BC Reg 266/2022, effective January 1, 2023.
Section 79 (2) BEFORE amended by BC Reg 266/2022, effective January 1, 2023.
(2) If a facility permit holder suspends operations at the facility, the facility permit holder must
(a) ensure that the suspension is carried out safely, and
(b) immediately notify the commission if the suspension continues for more than 12 consecutive months.
Section 79 (2) (b) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(b) within 60 days of the suspension of the facility, notify the commission of the suspension.
Section 79 (3) BEFORE amended by BC Reg 202/2023, effective September 1, 2023.
(3) A facility permit holder who has suspended operations at the facility must notify the commission at least 5 days before reactivating the facility.
Section 80 (1) and (2) BEFORE amended by BC Reg 159/2015, effective July 30, 2015.
Storage reservoirs
80 (1) A well permit holder of a well that is part of a special project for storage reservoirs designated under section 75 of the Act must construct and operate the well in accordance with CSA Standard Z341 as amended from time to time.
(2) A facility permit holder of a facility that is part of a special project for storage reservoirs designated under section 75 of the Act must construct and operate the facility in accordance with CSA Standard Z341 as amended from time to time.
Section 80 (3) was added by BC Reg 159/2015, effective July 30, 2015.
Schedule 2 BEFORE amended by BC Reg 146/2017, effective June 1, 2017.
[en. B.C. Reg. 241/2012, s. 24.]
Unconventional Zones
| Field | Zone Name | Distance (m) |
| Horn River | Muskwa-Otter Park | 100 |
| Horn River | Evie | 100 |
| Helmet | Muskwa-Otter Park | 100 |
| Helmet | Evie | 100 |
| Liard Basin | Besa River | 100 |
| Northern Montney | Montney | 150 |
| Northern Montney | Doig Phosphate-Montney | 150 |
| Heritage | Montney | 150 |
| Altares | Doig Phosphate-Montney | 150 |
| Town | Montney | 150 |
| Deep Basin | Cadomin | 150 |
| Deep Basin | Nikanassin | 150 |