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Copyright (c) Queen's Printer, IMPORTANT INFORMATION Victoria, British Columbia, Canada. B.C. Reg. 282/2010 Oil and Gas Commission Deposited September 24, 2010 effective October 4, 2010
Oil and Gas Activities Act Drilling and Production Regulation
Note: Check the Cumulative Regulation Bulletin 2012 and 2013 for any non-consolidated amendments to this regulation that may be in effect. [includes amendments up to B.C. Reg. 242/2012, August 14, 2012] Contents Part 1 — Definitions 1 Definitions Part 2 — Well Permits and Exemptions 2 Well classifications 3 Display of well permit 4 Exemptions for particular sites and installations from specified provisions Part 3 — Well Position, Spacing and Target Areas 5 Position of wells 6 Spacing and target areas for oil wells 7 Spacing and target areas for gas wells Part 4 — Well Operations Division 1 — Notification 8 Notification of well construction and drilling operations Division 2 — Blowout Prevention 9 Well control equipment 10 Testing of well control equipment 11 Drilling fluid system 12 Well control 13 Personnel 14 Records Division 3 — General Well Equipment 15 Protection from hazards 16 Tools, casing, equipment and materials 17 Wellhead requirements 18 Casing requirements 19 Surface and subsurface equipment Division 4 — Procedures 20 Management of substances 21 Fracturing operations 22 Hydraulic isolation 23 Multi-zone or commingled wells
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24 Alterations of wells 25 Inactive or suspended wells Part 5 — Abandoning, Plugging and Restoring Wells 26 Plugging requirements for wells 27 Pulling casing 28 Surface restoration of wells and associated sites Part 6 — Well and Other Data 29 Well samples and cores 30 Submission of core analysis data 31 Examination of cores 32 Daily drilling reports 33 Deviation and directional surveys 34 Tests, analyses, surveys and logs 35 Wellsite geology reports 36 Completion and workover reports 37 Fracturing fluids records 38 Production data Part 7 — Safety, Security and Pollution Prevention 39 Safety and pollution prevention 40 Noise 41 Venting and fugitive emissions 42 Flaring limits 43 Flaring notification and reporting 44 Flaring performance requirements 45 Fire precautions 46 Drill stem test recovery 47 Fire prevention 48 Position of tanks and production equipment 49 Emergency shutdown devices 50 Prevention of losses 51 Storage and disposal of wastes 52 Seals Part 8 — Production Operations Division 1 — Measurements 53 Measurements Division 2 — Oil 54 Daily oil allowable 55 Restriction of oil production 56 Test period allowable 57 Measurement of total oil production 58 Production test of oil wells 59 Calculation of oil production 60 Underproduction of oil 61 Overproduction of oil 62 Oil production analyses Division 3 — Gas 63 Gas well tests 64 Metering and measurement of gas
65 Restriction of gas production 66 Overproduction of gas 67 Gas production analyses Division 4 — Water 68 Measurement of water production 69 Water produced at oil wells 70 Water produced at gas wells 71 Water analysis 72 Operation of a water source well Division 5 — Pressure Measurement 73 Reservoir pressure measurements Division 6 — Injection and Disposal 74 Measurement of fluids injected 75 Reporting of injection and disposal Division 7 — Production Facilities 76 Notification 77 Signs for facilities 78 Production facilities 79 Obligations on cancellation or cessation of operations Division 8 — Storage Reservoirs 80 Storage reservoirs Schedule 1 Schedule 2 Part 1 — Definitions Definitions 1 In this regulation: "abandon" , in relation to a well, means permanently to plug the well in accordance with Part 5; "Act" means the Oil and Gas Activities Act; "annual gas allowable" means, for any production period, the volume of natural gas determined by multiplying the daily gas allowable by either (a) the number of days from November 1 to October 31 inclusive, or (b) in the initial production year, the number of days from the date production began to October 31 inclusive; "API" means the American Petroleum Institute; "ASME" means the American Society of Mechanical Engineers; "barrier" means any fluid, plug or seal that prevents gas or oil or any other fluid from flowing unintentionally from a well or from a formation into another formation; "battery" means a system or arrangement of tanks or other surface equipment receiving the effluents of one or more wells prior to delivery to market or other disposition, and may include equipment or devices for separating the effluents into petroleum, natural gas or water and for measurement; "completed" , in relation to a well or zone, means a well or zone that is physically able to permit (a) the production of fluids from the well or zone, (b) the observation of the performance of a reservoir, or (c) the injection or disposal of fluids into a zone;
http://www. butanes or pentanes and any other condensates. the amount by which petroleum production during the test period exceeds the test period allowable.. "natural gas liquids" means ethane. "daily gas allowable" or "DGA" means the volume of natural gas determined by multiplying the unadjusted daily gas allowable by any applicable adjustment factors. "Enform" means the non-profit organization of Canadian petroleum industry trade associations which provides certification. "CSA" means the Canadian Standards Association. for any month. "production target" means. and (b) within which.ca/EPLibraries/bclaws_new/document/ID/freeside/. sulphur and substances other than marketable natural gas that are recovered from raw natural gas by processing or normal two-phase field separation. "facility permit holder" means a permit holder of a facility permit. the sum of the daily oil allowables for each day from the beginning of the
. the volume of petroleum determined by multiplying the daily oil allowable by the number of days in the month. either of which contains one or more hazardous materials. "flaring" means the disposal by combustion of natural gas or gas derived from petroleum. and on any succeeding day means the amount by which the actual production from the beginning of the production period exceeds the production target. "producing well" means a completed well that has been placed on regular production. at the end of any day. "gas processing plant" means a facility for the extraction from natural gas of hydrogen sulphide. helium. recovered from natural gas.bclaws. "natural gas by-products" means natural gas liquids. 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. "observation well" means a well or a portion of a well designated as an observation well under section 2 (7). "facility permit" means a permit that includes permission to construct or operate a facility. "production period" means a period beginning on the day following the test period to the following October 31 and thereafter means a 12 month period ending on October 31 each year. ethane. carbon dioxide.
"concurrent production" means the controlled. or any combination of them. "natural boundary" has the same meaning as in section 1 of the Land Act. "flare stack" means a vertical pipe in which natural gas or gas derived from petroleum is combusted at the tip.. "daily production limit" means a volume equal to 125% of the daily oil allowable or daily gas allowable. "daily oil allowable" or "DOA" means the volume of petroleum determined in accordance with section 54. "monthly oil allowable" means. at the end of the test period. propane. natural gas liquids or other substances. but does not include a facility that (a) has a processing capacity less than 150 000 m3/day. "emergency planning zone" means a geographical area (a) that surrounds a well or facility. "incinerator" means a device designed to dispose of natural gas or gas derived from petroleum by combusting the gas inside a chamber of the device. simultaneous production from a pool of petroleum and natural gas at a gas-oil ratio that exceeds the solution gas-oil ratio. "initial oil production" means the first production after the release of the drilling rig and after the recovery of a volume of petroleum equal to the volume of the completion petroleum. and (b) uses a non-regenerative system for the removal of hydrogen sulphide or carbon dioxide. in the event of a release of a hazardous material from the well or facility. training and health and safety services to the oil and gas industry. "overproduction of oil" means. "core lab" means the facility for the storage and examination of well samples and cores.
. "underproduction of oil" means. re-entering.1 of the Act.
. (a) at the time the well permit is issued. "water body" means a natural water course or source of water supply. "water supply well" has the same meaning as in the Ground Water Protection Regulation. Reg.Drilling and Production Regulation
http://www. [am. at the end of the test period. (a) it is to be located less than 7 km from an oil or gas pool designated under section 49. or (b) the well has been designated as a discovery well. it is to be located not nearer than 7 km to an oil or gas pool designated under section 49. "well permit" means a permit that includes permission to drill or operate a well. 241/2012.
production period plus any underproduction or less any overproduction carried forward from the test period or a preceding production period.1 of the Act. B. "well control" means control of the movement of fluids into or from a well. commencing with the day of initial oil production. Reg. (a) it is to be located in a spacing area that is in or contiguous to an oil or gas pool designated under section 49. suspending or abandoning a well. "unadjusted daily oil allowable" or UDOA means the volume of oil determined in accordance with section 54 (2). completing.ca/EPLibraries/bclaws_new/document/ID/freeside/. at the time the well permit is issued. at the time the well permit is issued. "water production" means the flowing of water from a water source well. the lesser of either 90 producing days or the time required to produce the test period allowable. water volume and natural gas volume produced from the wells are measured at the battery outlet and are then allocated to each well based on test results. the amount by which petroleum production during the test period is less than the test period allowable and. B. at the end of any succeeding day.] Part 2 — Well Permits and Exemptions Well classifications 2 (1) A well is classified as a development well if. 1. 299/2004.. whether usually containing water or not. and (b) it is not a development well.C. (b) the installation or removal of equipment from a wellbore.bclaws.C. s.1 of the Act. recompleting. means the amount by which the actual production from the beginning of the production period is less than the production target. but does not include muskeg. carrying out a workover. intervening. (3) A well is classified as an exploratory wildcat well if. "proration battery" means a battery that gathers from more than one well and where the petroleum volume. "well operation" means the operation of drilling. and (b) if an objective formation is not in a deeper geological formation than the designated oil or gas pool. "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. (c) stimulation operations. "test period" means. (2) A well is classified as an exploratory outpost well if. and (d) maintenance operations. "workover" means (a) any operation that changes the configuration or producing characteristics of a well or zone.
241/2012.ca/EPLibraries/bclaws_new/document/ID/freeside/. that correspond to the interval from which the cores referred to in subparagraph (i) are collected. (2. (o) section 51 (3). (n) section 45 (3) (b). (7) An official may designate a well as an observation well if (a) the well is being used to monitor reservoir pressures or to obtain other formation information. and (b) the well is not used to produce from. (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 (a) a report respecting monitoring of hydraulic fracturing operations in the well. (n. Reg.] Display of well permit 3 A well permit holder must keep a copy of the well permit at the well site during drilling operations.. (f) section 25 (5). (5) An official may designate a well or a portion of a well as a discovery well if a new oil or gas pool has been designated as a result of data obtained from the well. (l) section 39. (m) section 41 (6). B. (ii) at least 3 specialty petro-physical logs. (i) section 31. [am. (d) section 16 (1)(b). 2. (2) and (4). run over an interval of not less than 200 metres..
(4) If a well permit is amended to give permission to deepen a well. the new portion of the well is classified in accordance with subsections (1) to (3). (n. (k) section 34 (1). (j) section 33 (1).
. Exemptions for particular sites and installations from specified provisions 4 (1) An official may grant to a permit holder an exemption in writing from the application of any or all of the following: (a) section 5 (2) (a).Drilling and Production Regulation
http://www. (c) section 7 (3). or (b) both of the following: (i) at least 9 metres of full diameter core from the well or 20 rotary sidewall cores from the well. (g) section 26 (a) and (d).C. (p) section 54 (2) and (6).1) section 47 (c). a formation being monitored. (e) section 18. (b) section 6 (4).1) and (7). (h) section 29.bclaws.2) section 48. or inject or dispose of fluids into. s.
given the topography or other relevant factors. Regs.C.1) section 79 (b). (t) section 60 (2). (y) section 71 (1). an official may impose any conditions on the exemption the official considers necessary. (b) 100 m of a permanent building. but not nearer than 100 m to the sides of. or (b) 100 m or more from the natural boundary of a water body. (c) 100 m of a place of public concourse. 3. 94/2011. the off-target penalty factor for an oil well completed outside the oil well target area is: d1d2 FOTP = 12 x
. the target area for an oil well in a normal spacing area at any depth is the area inside. (4) For the purposes of section 54. or surface-control measures have been taken. or (d) 100 m of a reservation for national defence.] Part 3 — Well Position. (v) section 63 (1). the permit holder must ensure surface-control features are in place. (z. (s) section 59 (2). (2) A permit holder must not drill a well within (a) 40 m of the right of way or easement of any road allowance or public utility. (2) If the boundary of a location does not coincide with the side of a normal oil well spacing area. but situated so that. (2) In granting an exemption under subsection (1). (x) section 67 (1).. to contain escaping fluids.
(q) section 55. B.. s. the oil well target area must have sides not nearer than 100 m to the boundary. installation or works. Spacing and target areas for oil wells 6 (1) In each pool.bclaws. (u) section 62 (1). [am. 241/2012. brine or another fluid may reach the water body. (z) section 73 (1) and (2).Drilling and Production Regulation
http://www. it is likely that an uncontrolled flow of oil. gas.ca/EPLibraries/bclaws_new/document/ID/freeside/. (w) section 65 (4) and (5). (3) A permit holder may complete one oil well in each normal spacing area on a location that contains more than one normal spacing area if each well is located not nearer than 100 m to the boundary of the location. Spacing and Target Areas Position of wells 5 (1) If a well or facility is (a) closer than 100 m to the natural boundary of a water body. the spacing area. (r) section 58 (1).
(6) A well permit holder may not produce from a well in an unconventional zone listed in Schedule 2 if a completed portion of the wellbore is located closer than the distance listed in Schedule 2 for that zone to land with respect to which the well permit holder (a) is not the owner of the petroleum and natural gas rights or the holder of the location. (b) a well drilled and completed before May 2. = the distance east or west.]
A where FOTP = off target penalty factor. whichever is closer. the spacing area. Reg. B. from the closest point of the well bore within the productive zone to the side of the spacing area. 1958. = the area of the spacing area. (5) Subsections (1) to (3) do not apply to the completed portion of a well producing from an unconventional zone listed in Schedule 2. d1 d2 A = the distance north or south. 4. (b) a well drilled and completed before May 2. [am. (c) an off-target oil well located not nearer than 100 m to the boundary of the location. 241/2012. the off-target penalty factor for a gas well completed outside the gas well target area is: d1d2 FOTP = 8 x A where FOTP = off target penalty factor. whichever is closer.
(4) Subsection (3) does not apply to any of the following: (a) the discovery well of a gas pool. (2) A permit holder may complete one gas well in each normal spacing area on a location that contains more than one normal spacing area if each well is located not nearer than 250 m to the boundary of the location. from the closest point of the well bore within the productive zone to the side of the spacing area. or (b) does not have an agreement with the owner or holder respecting the production. whichever is closer. s. but not nearer than 250 m to the sides of. the target area for a gas well in a normal spacing area at any depth is the area inside.
(5) Subsection (4) does not apply to any of the following: (a) the discovery well of an oil pool. Spacing and target areas for gas wells 7 (1) In each pool. 1958.bclaws. from the closest point of the well bore within the productive zone to the side of the spacing area. (c) an off-target gas well located not nearer than 250 m to the boundary of the location. whichever is closer.C. from the closest point of the well bore within the productive zone to the side of the spacing area. d1 d2 A = the distance north or south. = the distance east or west. = the area of the spacing area. (3) For the purposes of section 65..Drilling and Production Regulation
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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. prevent blow-outs and safely carry out all well operations. (2) If well control is lost or compromised. the well permit holder must ensure that all actions necessary to rectify the situation are taken without delay.Drilling and Production Regulation
http://www.. (c) releasing a rig. Division 2 — Blowout Prevention Well control equipment 9 (1) A well permit holder must ensure that. during all well operations. to ensure safe drilling operations and. if drilling is completed or temporarily suspended. to provide an effective barrier against formation pressure. for 60 days from the date of rig release. and (b) the indicators and alarms associated with the monitoring equipment are located at appropriate locations on the drilling rig to alert onsite personnel of well conditions that could lead to a loss of well control. (2) If a well barrier fails. Personnel
. (2) At the request of an official. operated and maintained to allow for proper well evaluation. a record of the results of tests required under subsection (1) (a). (2) The notice under subsection (1) (a) must be sent at least 2 days before construction is to begin. of the following actions taken by the permit holder: (a) beginning the construction of a well. (3) A well permit holder must maintain. Drilling fluid system 11 A well permit holder must ensure that (a) the drilling fluid system and associated monitoring equipment is designed. and is able to operate. (c) or (d) must be sent within 24 hours of the action being taken. when it is safe to do so. the blowout prevention equipment. and (b) the rig crew conducting the well operation has an adequate understanding of.bclaws. (d) resuming drilling operations after a temporary suspension. and a notice under subsection (1) (b).. (b) beginning the drilling of a well. other than those intended to restore or replace the barrier. except when drilling underbalanced. Well control 12 (1) A well permit holder must take all reasonable measures to minimize the risk of loss of well control. the well permit holder must ensure that no other activities. reliably operating well control equipment is installed to control kicks. take place in the well. Testing of well control equipment 10 (1) A well permit holder must ensure that (a) pressure-control equipment associated with well operations is pressure-tested on installation and as often as necessary during well operations to ensure the continued safe operation of the equipment.
Part 4 — Well Operations Division 1 — Notification Notification of well construction and drilling operations 8 (1) A well permit holder must notify the commission. installed.ca/EPLibraries/bclaws_new/document/ID/freeside/. a well permit holder's contractor or rig crew. in electronic form.
(2) A driller of a well being drilled or tested during drilling operations must (a) be trained in blowout prevention. and that sign must show all of the following: (a) the name of the well permit holder. and (c) provide evidence of his or her qualifications to an official on the official's request. (3) A well permit holder must ensure (a) that the well site is maintained in a condition so as to minimize hazards. including but not limited to hazards associated with pits. (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. a flammable gas symbol from Schedule 1 (e) if the well may produce gas containing 100 ppm or greater of hydrogen sulphide.ca/EPLibraries/bclaws_new/document/ID/freeside/. and
. Records 14 (1) For each well operation. (b) emergency notification information. including a telephone number. (b) have a valid second-line supervisor's certificate issued by Enform.Drilling and Production Regulation
http://www. (2) A well permit holder must not post warning symbols where no hazard exists. (b) the rig manager. a valid well service blowout prevention certificate issued by Enform and provide evidence of their qualifications to an official on the official's request: (a) the driller on tour. (b) have a valid first line supervisor's blowout certificate or a valid second-line supervisor's well control certificate issued by Enform. storage of materials and equipment. a well permit holder must ensure that a permanently legible and conspicuous sign is displayed and maintained at each well. and (c) provide evidence of his or her qualifications to an official on the official's request. Division 3 — General Well Equipment Protection from hazards 15 (1) Until the well is abandoned. and (b) any operational procedure that is a hazard to safety or the environment is corrected and all affected persons are informed of the alteration. during well servicing operation. a poisonous gas symbol from Schedule 1.bclaws.. (d) if the well may produce flammable gas.
13 (1) A well permit holder must ensure that (a) there is a sufficient number of trained and competent individuals carrying out well operations for those operations to be carried out safely and without causing pollution. (c) the well permit holder's representative. 2011. a well permit holder must maintain a record of the well control equipment and an assessment of the adequacy of the well control equipment for 6 months following the completion of the well operation. if the well may produce gas containing 10 ppm or greater of hydrogen sulphide. a poisonous gas symbol from Schedule 1.. (4) The following people must possess. holes. (c) the location of the surface site of the well as specified in the well permit. (2) A well permit holder must maintain records of the policies and procedures used to ensure the safe conduct of well operations. (f) after March 1.
5. s.. and (b) maintain a record of the tests and repairs carried out under paragraph (a). (3) A well permit holder must ensure that surface casing for a well conforms to the following requirements: (a) surface casing must be set in a competent formation at a depth sufficient to provide a competent anchor for blowout prevention equipment and to ensure control of anticipated well pressures. including valves.] Tools. in the opinion of a qualified professional.. (5) A well permit holder must ensure that surface casing cement is not drilled out until sufficient compressive strength has been reached to allow the safe conduct of drilling operations.
. equipment and materials 16 (1) A well permit holder must ensure (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. (3) A well permit holder must (a) conduct an annual segregation test of any of the holder's wells with a production packer. and (b) the cement is not drilled out until sufficient compressive strength has been reached to allow the safe conduct of drilling operations. 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.C. and (b) that all production from or injection into a well. with respect to a well drilled after this regulation came into force. 241/2012. (6) A well permit holder must ensure that (a) all reasonable measures are taken to cement all intermediate and production casing to the surface or a minimum of 200 m above the shoe of the previous casing string. is through tubing. (b) the annulus must be filled with cement to the surface. all porous strata that (a) are less than 600 m below ground level.
(b) that the well site is free of garbage. Casing requirements 18 (1) A well permit holder must ensure that casing is designed so that it will not fail if subjected to the maximum loads and service conditions that can reasonably be anticipated during the expected service life of the well. (2) A well permit holder must use non-toxic drilling fluids during the drilling of a well until. except production of gas containing less than 5 mole percent of hydrogen sulphide or injection of fresh water. and (b) contain non-saline groundwater that is usable for domestic or agricultural purposes have been isolated from the drilling fluid. Wellhead requirements 17 A well permit holder must ensure that the wellhead equipment. (4) A well permit holder.bclaws.Drilling and Production Regulation
http://www. (2) Before injecting a fluid other than fresh water into a subsurface formation through tubing in a well. complete repairs without unreasonable delay. B.ca/EPLibraries/bclaws_new/document/ID/freeside/. if the test fails. debris and unused equipment. [am. is designed to operate safely under the conditions anticipated during the life of the well and that the wellhead is not subjected to excessive force. Reg. and (b) ensure that the space between tubing and the outer steel casing is filled with a corrosion inhibiting fluid. a well permit holder must (a) set a production packer in the well as near as is practical above the injection interval. casing. and.
and (b) in the case of a gas well.. production casing pressure and surface casing pressure.. Fracturing operations 21 A well permit holder must not conduct a fracturing operation at a depth less than 600 m below ground level unless the operations are permitted by the well permit. (3) A well permit holder respecting a multi-zone well. facilities for determining the wellhead fluid temperature. and (c) the surface casing is equipped with an open valve. submit to the commission a notification of the commingled well production. completes. Hydraulic isolation 22 A well permit holder must establish and maintain hydraulic isolation between all porous zones in a well. formation water. and waste. must (a) once every calendar year and immediately after a change of subsurface equipment or the completion of any operation that may have disturbed or exerted an abnormal differential pressure on equipment. drilling fluid. who does not have permission for commingled production for more than one pool or zone.
(7) If there is any reason to doubt the effectiveness of casing cementation. complete repairs without unreasonable delay. except for zones in which commingled production is permitted or authorized as described in section 23. Surface and subsurface equipment 19 (1) The well permit holder of a completed oil or gas well must ensure that the surface and subsurface equipment of the well is arranged to permit the ready measurement of the tubing pressure. (8) On detection of a casing leak or failure. completion fluid. within 30 days of beginning production from a commingled well. conduct segregation tests. (3) The well permit holder of a well must keep a detailed record of all subsurface equipment in the well at all times prior to abandonment. a well permit holder must ensure that a survey is made to evaluate the cement integrity and that remedial measures are taken if necessary. (2) A well permit holder respecting a multi-zone well who has permission or authorization for commingled production must. plugs or begins production from a well. gas. and (b) repair the leak without unreasonable delay. chemical substances. (b) excessive pressure cannot occur at the surface casing shoe. a well permit holder must (a) notify the commission about the leak or failure without delay. (b) if the tests referred to in paragraph (a) fail. Division 4 — Procedures Management of substances 20 Before a well permit holder drills. (9) A well permit holder must ensure that a well is configured such that (a) the surface and intermediate casing annulus can freely vent. the well permit holder must ensure that adequate provision is made for the management of any oil.Drilling and Production Regulation
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. gas or water produced. (2) The well permit holder of a completed well must ensure that the surface equipment at the well site includes (a) the valve connections necessary to sample the oil. Multi-zone or commingled wells 23 (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.bclaws.
must suspend the well in a manner that ensures the ongoing integrity of the well. tubing.. including plugs. 241/2012. in relation to a well. has not been active for 6 consecutive months.bclaws. (b) the permit holder must plug the well in a manner that ensures (i) adequate hydraulic isolation is established between porous zones. packers. (d) install. and (c) with respect to a well designated under section 2 (7).
(c) maintain records of the tests and repairs referred to in paragraphs (a) and (b).] Part 5 — Abandoning. remove or repair wellbore equipment. (3) The well permit holder of a suspended well must establish a program of inspections sufficient to ensure the ongoing integrity of the well. (b) perform a workover on a well. Plugging and Restoring Wells Plugging requirements for wells 26 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: (a) for cased wells. s. Inactive or suspended wells 25 (1) In this section: "active" means (a) production. [am. completion or workover operations. (c) an abandonment report. (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. or (b) if the well is classified as a special sour well. artificial lift or subsurface safety valves. means a well that has not been abandoned but (a) has not been active for 12 consecutive months. (iii) excessive pressure will not build up within any portion of the well. (ii) fluids will not leak from the well. tests and resulting well
. B. (c) perform remedial work on a well. (e) plug a portion of a well. "inactive" . (4) The well permit holder of a suspended well must maintain records of the inspections referred to in subsection (3).. and (iv) the long-term integrity of the wellbore is maintained.C.Drilling and Production Regulation
http://www. injection or disposal of fluids. (5) The well permit holder of an inactive well. monitoring reservoir pressure or obtaining other formation information. a notice of operations and a plugging program must be submitted to the commission at least 7 days before commencement of operations. 6. within 60 days of the well becoming inactive. detailing all significant operations. in chronological format. Reg.ca/EPLibraries/bclaws_new/document/ID/freeside/. casing. treatments. (b) drilling. Alterations of wells 24 A well permit holder must submit a notice of operations to the commission at least one business day before beginning work to do any of the following: (a) complete or recomplete a well.
carriage prepaid. the sides of the boxes project above the
. the surface location of the well.. [am..
behaviour.1) for horizontal wells drilled from a common drilling pad location and to be completed in a zone listed in Schedule 2.bclaws. Reg. (c) protect boxes containing the cores from theft. not later than 14 days after the date of rig release. the core number and interval and the length of the core recovered. a well permit holder must restore the ground surface of those areas of the well site and associated remote sumps and camp sites that will not be required for future operations to a state that eliminates hazards. 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. misplacement or exposure to the weather. (b) collect. (d) the permit holder. 241/2012. arranged in trays of adequate construction. the well name. (b) accurately label on the end of the box body. (a. Part 6 — Well and Other Data Well samples and cores 29 (1) A well permit holder must (a) unless paragraph (a.ca/EPLibraries/bclaws_new/document/ID/freeside/. (3) A well permit holder must ensure that wooden core boxes are of adequate construction. s. but not the box lid.1) applies. to the commission not later than 14 days after the date of rig release. dry. B.C. at 5 m intervals 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 point at which the drilling of the horizontal portion of the well is begun. take drilling cutting samples as follows: (i) for a minimum of one horizontal well on the pad location. the well permit number. (c) clearly and accurately label the vials and trays with the name and location of the well and the sample depths represented and. remove the core sample from the core barrel and store it in book fashion in one or more wooden core boxes. (ii) for a minimum of one well on the pad location in each dominant direction of the horizontal portion of the well for each zone listed in Schedule 2. and including a downhole schematic diagram. wash. must be submitted to the commission in duplicate within 30 days of the completion of abandonment operations. and identify the top and bottom of the core on the core box. identify the leg from which the cuttings originated. (2) A well permit holder must (a) as soon as practicable after collecting a core sample. and (d) forward the core to the commission. and (d) deliver 2 sets of the drill cuttings samples.Drilling and Production Regulation
http://www. if the well is a multi-leg well. or as soon after cessation as weather and ground conditions permit. or (b) to the prevention of inter-zonal communication. 7. must do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation. carriage prepaid. Surface restoration of wells and associated sites 28 Immediately after ceasing drilling or workover operations. for a well drilled on Crown land. sort and preserve 2 complete sets of drill cuttings samples in vials. at 10 m intervals beginning at the point at which the drilling of the horizontal portion of the well is begun and continuing to the total depth of the well. enables control of weeds and runoff and prevents erosion.] Pulling casing 27 A well permit holder must ensure that casing or other equipment is not removed from the well permit holder's well if the casing or equipment is essential (a) to the proper control of the well.
] Daily drilling reports 32 (1) A well permit holder of well being drilled or otherwise worked on must (a) ensure that a daily drilling report (tour sheet) is kept at the well site. on payment of a fee of $300 per well. [am. 9. (4) When submitting a core that has been slabbed. if any.Drilling and Production Regulation
http://www. (2) A person must ensure that breakage of core during examination at the core lab is minimized and that core is not destroyed.C. 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. 8.. 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. (b) take every reasonable precaution to prevent damage to or mixing of the core in core boxes.] Examination of cores 31 (1) A person must ensure that core declared by an official as being representative of a type section is not broken or chipped. [am. Reg.C. lids are securely fixed to ensure safe transit and the boxes have an inside length of 80 cm. (3) With the approval of an official and subject to subsection (4).C. (d) submit any thin sections cut from core to the commission in adequate boxes labelled with the unique well identifier. s. with the approval of an official. the well permit holder must complete core analysis of the core without unreasonable delay. Reg. (b) if a kick occurs during drilling operations. including photographs.
level of the contained cores. (4) A person who removes a well core from the core lab must (a) return the core within 90 days. B. well permit number and well name.bclaws. a person. 241/2012.. if any. s. broken or sampled without approval of an official. notify the commission immediately and submit a written kick report to the commission within one day of the incident.ca/EPLibraries/bclaws_new/document/ID/freeside/. [am. preserved as a viewing slab and submitted in cardboard boxes of adequate construction. s. 241/2012. (2) Within 30 days after completion of a core analysis. (d) submit a summary report of drilling operations to the commission within 4 days of the following:
. B. 241/2012. Reg. of any laboratory analysis conducted on the core to the commission within 30 days of completing the analysis. a well permit holder must submit to the commission a report of the result of the core analysis. (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. and (g) return the core immediately on the request of an official. (e) label individual thin sections with the well permit number and depth. (c) submit a report. including digital core analysis data and photographs. (c) submit a copy of the daily drilling report (tour sheet) to the commission within 30 days of rig release. (b) $40 per well to examine well cores. B. 10. (f) test cores in a manner acceptable to an official.] Submission of core analysis data 30 (1) If a well permit holder has submitted core from a well under section 2 (6) and the well has been designated as a special data well.
(4) A permit holder must not drill a well. (d) a report of any tests made. (ii) drilling operations have ceased with the intention of resuming drilling at a later date. (b) the surface position of the well is outside its target area.1). including blowout prevention system function tests. (c) particulars of cementing. surveys and logs 34 (1) Subject to subsections (2) and (2. (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). unless the details are submitted on a confidential report form provided by the commission. including size. other than a relief well. and (e) maintain all data recorded by the electronic drilling recorder for at least 30 days from the date of rig release.ca/EPLibraries/bclaws_new/document/ID/freeside/. (2) A well permit holder must ensure that a directional survey of a well to total depth is made if (a) the surface position of the well is nearer to the boundary of its target area than 2% of the measured depth of the well. whether new or used and the depth at which the casing is set. or (ii) the lowest point in the vertical portion of one horizontal well beyond which the logging tool cannot be lowered by gravity. (f) details of any loss of drilling fluid into the formation. (k) the results of all deviation surveys. (b) all casing data. in which case a survey may be omitted. (b) a neutron log is taken from 25 m below ground level to the base of the surface casing. and (c) a resistivity and porosity log is taken from the base of the surface casing to (i) the total depth of the well of a vertical pilot hole.. type. in the
. including but not limited to the following: (a) the depth at the beginning and end of each tour. if one exists.
(i) the rig is released. Tests. analyses. grade. (2) A daily drilling report (tour sheet) under subsection (1) (a) must set out complete data on all operations performed during the day. or (c) the well is directionally drilled. (2) Subsection (1) (b) applies only to wells the drilling of which begins after the date this regulation came into force.1) If more than one well has been drilled or has been permitted to be drilled from a common drilling pad location in an unconventional zone listed in Schedule 2. the logs referred to in subsection (1) must be taken in at least one of the wells and. before a well is completed.bclaws. (2. unless there are significant wellbore stability problems. so that it intersects with an existing well. (j) details of any casing bowl welding. a well permit holder must ensure that (a) a gamma ray log is taken from ground level of the well to total depth. (i) the spud and rig release dates. (e) full details of all formation tests.Drilling and Production Regulation
http://www. Deviation and directional surveys 33 (1) A well permit holder must ensure that deviation surveys are made during drilling at intervals not exceeding 150 m in depth. suspended or abandoned. (g) the allocation of time to each operation. (h) the name of the drilling contractor or service company and rig number. weight..
(a) subsection (1) does not apply.. 12. (b) the fracture date. but not limited to (a) the well authorization number. (7) The permit holder of a gas processing plant must. of (a) the fluids entering the plant.bclaws. 241/2012. and (b) a report containing complete details on fluid recoveries for each drill stem test or wire line test taken on a well within 30 days of the date on which the test was made.] Fracturing fluids records 37 (1) A well permit holder must maintain detailed records of the composition of all fracturing fluids that are used in a well for which the well permit holder is responsible. (5) If drill stem tests. wire line tests or initial production tests from a well allow good sampling. Completion and workover reports 36 (1) For each separate completion or workover operation on a well. including injection of corrosion inhibitors. the well permit holder must submit to the commission. within 30 days of analysis completion. a report. (c) an identification of the fluid ingredients and a description of the purpose of each. if practical separately. representative of the operations for the preceding year. Reg. within 30 days of the end of each completion or workover operation. or (b) regardless of the well classification. treatments and resulting well behaviour. (6) On obtaining the data and results of a bottom-hole sample analysis or other pressure-volume-temperature analysis. submit analyses.ca/EPLibraries/bclaws_new/document/ID/freeside/. s. (d) an identification of the ingredient concentration in the additive and in the hydraulic fracturing fluid. (2) A report under subsection (1) is not required for routine maintenance operations.C.C. a well permit holder must submit to the commission a wellsite geology report (a) for a well or portion of a well classified exploratory outpost or exploratory wildcat.
case of the other well or wells. s. Reg. the well permit holder must submit the data and results to the commission within 30 days of analysis completion.. in chronological format. including. and including a downhole schematic diagram. and (b) a gamma ray log must be taken from the base of the surface casing of each well to the total depth of each well. on or before January 31 of each year. a report of all analyses made of any oil. detailing all significant operations. a well permit holder must submit to the commission.] Wellsite geology reports 35 Within 60 days after the date of rig release of the drilling rig. for each pool delivering gas to the plant. (e) the chemical abstract service number of each ingredient. scale removal or pressure testing operations.
. 241/2012. (3) Within 30 days after the date on which a log was run. [am. B. 11. the well permit holder must submit a copy of the log to the commission. and (b) each marketable product leaving the plant. (4) A well permit holder must submit to the commission (a) a pressure chart.Drilling and Production Regulation
http://www. [am. gas or formation water recovered from each formation. if a wellsite geological report has been compiled. B.
(f) an identification of the total volume of water injected with the ingredients. 249/2011. (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.bclaws. "populated area" means an occupied dwelling. methodologies and data associated with the records referred to in subsection (1). Security and Pollution Prevention Safety and pollution prevention 39 (1) In this section.] Production data 38 (1) A permit holder must keep.ca/EPLibraries/bclaws_new/document/ID/freeside/. a hydrogen sulphide detection and alarm system that is continuously monitored and is capable of activating the automated system referred to in paragraph (a). for not less than 72 months. (4) If an uncontrolled flow of oil or gas from a completed well. (3) The permit holder's accounting methods. (6) The permit holder of a completed well must do all of the following if the hydrogen sulphide content of the gas exceeds 5 mole percent or a populated area or a numbered highway is within the emergency planning zone for the well: (a) for a completed well not produced by artificial lift.Drilling and Production Regulation
http://www.C. 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 facility is located within 1600 m of a populated area. other than a well suspended in accordance with section 25. (2) A permit holder must keep for not less than 72 months records of supporting information.. school. (2) A permit holder of a completed well or facility must establish and maintain a system to detect and control leaks as quickly as practicable. refined. 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. purchased. (i) equip the well with 2 master valves. B. a hydrogen sulphide detection and alarm system which is continuously monitored and is capable of activating the automated system referred to in paragraph (a). (3) A permit holder of a completed well or facility must install and maintain fencing or take other access control measures to prevent unauthorized access to the well or facility if (a) the well or facility is located within 800 m of a populated area. accurate and complete. hydrocarbon liquids or natural gas liquids that are produced. picnic ground or other place of public concourse. acquired. transported. (5) 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. or (b) a populated area is within the emergency planning zone for the well or facility. complete. and (b) if the well is located within 1 600 m of a populated area. (4) The records referred to in subsection (1) must be adequate for production accounting purposes and the assessment of royalties under the Petroleum and Natural Gas Royalty and Freehold Production Tax Regulation. stored. [en. and (g) the trade name and supplier of each ingredient. processed or marketed by the permit holder. Reg.
. natural gas. Part 7 — Safety.. correct and accurate records of quantities of petroleum. sold. practices and record keeping as well as the measurement methods and practices associated with records referred to in subsection (1) must be sufficient to ensure that records of quantities are correct. (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. could produce a hydrogen sulphide concentration greater than 100 ppm in atmosphere within 50 metres of the well.
but with a minimum rating of 14 000 kPa. conduct annual segregation tests and. 282/2010. s. (b) for a flowing well that is located within 800 m of a populated area or within 8 km of a city. and (c) during abandonment of the well. (b) submit the emergency response plan to the commission before beginning operations at the well or facility. 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. volume or flow rate is insufficient to support stable combustion and (a) the venting is conducted in a manner that does not constitute a safety hazard. install a check valve in the injection line and automatic shutoff valve on the return line. and (b) install an automatic vibration shutdown system that will safely shut down the pumping unit. (10) Repealed. Venting and fugitive emissions 41 (1) A permit holder must not vent gas unless the gas heating value. 39 (11). (9) For each well or facility.Drilling and Production Regulation
http://www. (b) as routine maintenance throughout the life of the well.ca/EPLibraries/bclaws_new/document/ID/freeside/. (2) A well permit holder must check each well for evidence of a surface casing vent flow (a) during initial completion of the well. Reg. (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.C. (b) the venting does not cause off-site odours. complete repairs without unreasonable delay. Reg. if the test fails.C.] Noise 40 A permit holder must ensure that operations at a well or facility for which the permit holder is responsible do not cause excessive noise. 13. town or village and that has the potential to produce more than 30 000 m3 of gas per day. (8) A permit holder must ensure that buildings of wood construction do not house production equipment at a well or facility. and (c) respond to an emergency at the well or facility in accordance with the emergency response plan. B.. (v) if a well is equipped with a production packer as required under subparagraph (ii). a permit holder must (a) develop and maintain an adequate emergency response plan.bclaws. [B. (iv) if a hot oil circulating string is used inside the production casing of a well. 241/2012. [am. 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 (vi) maintain a record of the tests and repairs referred to in subparagraph (v). a well permit holder must
(iii) install wellhead equipment for which the working pressure rating is not less than the bottom-hole pressure of the producing formation. (3) On discovery of a surface casing vent flow that presents an immediate safety or environmental hazard or an occurrence of gas migration. and (d) the duration of venting is minimized.] (11) Spent. s.. (c) the quantity of vented gas is minimized.
within 60 days after completing the operation.bclaws.ca/EPLibraries/bclaws_new/document/ID/freeside/. B. (6) A permit holder of a well drilled or facility constructed after the date this regulation came into force may use gas containing hydrogen sulphide for pneumatic instrumentation or to provide motive force to pumps only if the gas contains no more than 20 parts per million of hydrogen sulphide. or (b) permission to flare is included in the facility permit. s. and (b) the cumulative quantity of flared gas does not exceed (i) 400 000 m3. the quantity of gas flared. 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. (5) A facility permit holder must have an adequate fugitive emissions management program.Drilling and Production Regulation
http://www. immediately before section 116 of the Act came into force. a well permit holder must (a) test the flow rate and buildup pressure of the surface casing vent flow. [am.] Flaring notification and reporting 43 (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. and (b) submit to the commission within 30 days of the discovery a record of the test. 14. if the well is classified as an exploratory outpost well or an exploratory wildcat well. if the well is classified as a development well. and (ii) 600 000 m3. the permit holder with respect to the well must report to the commission. 241/2012.C.
(a) immediately take steps to eliminate the hazard or gas migration.] Flaring limits 42 (1) A permit holder must ensure that the duration of flaring and the quantity of gas that is flared is minimized. a permit holder must not flare gas unless flaring is required for emergency purposes or for drilling operations. (3) A well permit holder may flare gas at a well if (a) flaring is required for a workover or maintenance and the cumulative quantity of gas flared does not exceed 50 000 m3 in one year. (4) A holder of permit that was. (b) submit to the commission without delay a report respecting the surface casing vent flow and the steps taken under paragraph (a).C. (2) If an unplanned flaring event occurs and the quantity of flared gas exceeds 10 000 m3. 242/2012. 15. s. (2) Subject to subsections (3) to (5). [am. Regs. Flaring performance requirements
. or (b) permission to flare is included in the well permit.. (4) When gas is flared at a well.. (3) A permit holder must maintain a log of all flaring that occurs at each facility. Reg. 241/2012. (4) On discovery of a surface casing vent flow other than one referred to in subsection (3). the permit holder must notify the commission within 24 hours of the flaring event. (5) A facility permit holder may flare gas at a facility if (a) flaring is required for maintenance purposes. B.
. place of public concourse or reservation for national defence. disc or plate is connected by suitable piping to a tank if production is in the liquid phase. and (ii) the minimum height of flare stacks is 12 m. Drill stem test recovery 46 (1) If a permit holder has recovered oil or gas during a drill stem test. dike or ditch surrounding a storage tank installation. works. a well permit holder must not store gasoline or liquid fuel within 25 m of a well. 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. unless the installation is equipped with safety equipment designed to prevent fire. public utility. if engines are located at a wellsite. rupture disc or burst plate is installed on a pressure vessel at a facility. (d) all facility piping is arranged and provided with control valves to permit ready shut off of oil or gas in the event of fire at any facility installation.
44 A permit holder of a well or facility must ensure all of the following: (a) that flare stacks are adequately anchored.bclaws. Fire precautions 45 (1) A well permit holder must ensure that. if a flare system exists at the facility.. (b) that the valve. the permit holder must ensure that the drill pipe is not pulled during hours of darkness.ca/EPLibraries/bclaws_new/document/ID/freeside/. (c) if the hydrogen sulphide content of the gas to be flared exceeds one mole percent. (3) If a pressure relief valve. (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. disc or plate is connected to a flare system. explosions or exposure of personnel to hydrogen sulphide or other toxic or poisonous gases. (e) a separator is not enclosed within the fire wall. (c) flares and incinerators are located at least 80 m from any public road. (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. (b) that unsupervised flare stacks where intermittent flaring may occur are equipped with an adequate auto-ignition system. (e) flaring does not result in the emission of black smoke. and must ensure that drainage of gasoline or liquid fuel from the places where it is stored is in a direction away from a well location. (4) A person carrying out an oil and gas activity must not smoke within 25 m of any well or facility. installation. suitable safeguards are in place and tested to prevent a fire or explosion in the event of a release of flammable liquids or ignitable vapours.Drilling and Production Regulation
http://www. building. (f) all vessels and equipment from which ignitable vapours may issue are safely vented to the atmosphere. the permit holder must ensure (a) that the valve.. or (c) that a system of controls is installed to ensure safe operation and minimize venting. unless positive steps have been taken to ensure that there is no possibility of oil or gas being present in the drill pipe. Fire prevention 47 A permit holder must ensure all of the following: (a) fires and fired equipment are located a safe distance from flammable liquids or potential sources of ignitable vapours so that there is no undue risk of fire or explosion. (2) Except where gasoline or liquid fuel is held in fuel tanks actually connected to operating equipment. (b) all fires for any purpose are safeguarded by sufficient mechanical or other means so that no hazard to surrounding property is created.
(c) the permit holder has established and documented work procedures sufficient to ensure that the operation can be conducted safely. gas or water in drilling. wells. Reg. works. easement. (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. (h) a sufficient area beneath and around the flare stack is free of combustible materials and vegetation. usable aquifer or water body.C. completion fluid. (3) A well permit holder who uses an earthen pit to store liquid waste from a well drilling operation must ensure that the pit is (a) not located within 100 m of the natural boundary of a water body. (b) the well or facility is continuously monitored. B. over any water body that is frequented by fish or wildlife or that flows into any such water body. against damage or interference from unauthorized persons or activities. s. chemical substances or refuse from a well. waste. and (d) the operation is conducted in accordance with the procedures referred to in paragraph (c). Reg..
. (d) pass into or. (b) not located within 200 m of a water supply well.C.
(g) explosives of every kind and description are stored only in properly constructed magazines. unless (a) the purpose of the bypass or disablement is to carry out maintenance or commissioning of the well or facility. (c) run over.. oil. (3) A well permit holder must take every reasonable precaution to protect wells. s. 17. usable aquifer or water body or remain in a place from which it might contaminate any water supply well. producing and processing operations. [am. (b) run into or contaminate any water supply well. building. 241/2012. and that any dike or fire wall is maintained in good condition and the area encompassed by it is kept free from grass.ca/EPLibraries/bclaws_new/document/ID/freeside/. 241/2012.Drilling and Production Regulation
http://www.] 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. and. drilling fluid. B.bclaws. weeds or other combustible material. [am. Storage and disposal of wastes 51 (1) A well permit holder must ensure that formation water. road allowance.] Prevention of losses 50 (1) A permit holder must take every reasonable precaution to prevent loss or waste of oil. pressure relieving valve or emergency shutdown device at a producing well or facility. situated not less than 150 m from any place where any drilling. Emergency shutdown devices 49 A permit holder must not bypass or disable an alarm. production or processing operation is being undertaken. installation. tanks. in storing. monitoring device. pollute or damage any land or public road. oil or gas must not be used wastefully or allowed to leak or escape from natural reservoirs. on ice. whether connected to flow lines or not. (2) A facility permit holder must ensure that each storage tank or group of tanks at the permit holder's facility has secondary containment in accordance with the current edition of National Fire Protection Association Code 30: Flammable and Combustible Liquids Code. containers or pipes. piping or distributing. place of public concourse or reservation for national defence. public utility. tank or other facility do not do any of the following: (a) create a hazard to public health or safety. 16.
tank or other receptacle used for the storage or transportation of oil or other fluid produced or withdrawn from the well. natural gas liquids or natural gas byproducts are produced from a well or facility. and may remove or authorize the removal of such seals. (e) if natural gas. natural gas liquids or natural gas byproducts are not metered due to the failure of a meter. facilities and reservoirs. (d) located or ditched so that it will not collect natural run-off water. that the quantity error and the source of the quantity error are rectified immediately and a report of the corrected quantity for the period during which the quantity was incorrect is submitted by the next reporting cycle. facility or gathering system for which the permit holder is responsible are sufficient to determine the actual production of each product from (i) each zone in a well. (e) is filled to not more than one metre below the point of overflow at any given time. (d) if a quantity error is apparent or discovered. (iii) production accounting purposes. Part 8 — Production Operations Division 1 — Measurements Measurements 53 A permit holder must ensure all of the following: (a) that the measurement equipment for each well. (ii) the quantification of waste discharges. and
. (b) that the equipment and methods associated with the measurement of fluids are adequate for (i) the management of wells. an official.. a well permit holder must submit to the commission a report of the drilling waste disposal. petroleum. 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. petroleum. a permit holder may remove a seal affixed under subsection (1) (a) in case of emergency. (4) Within 90 days of completing a drilling waste disposal. (3) If notice under subsection (2) is given orally. (2) An official must notify the permit holder.Drilling and Production Regulation
http://www. must provide in writing the notice referred to in subsection (2). within 48 hours.bclaws. and (iv) the assessment of royalties under the Petroleum and Natural Gas Royalty and Freehold Production Tax Regulation. pipelines. chart recorder or other quantity device. (5) Despite subsection (4). (c) if quantities of natural gas. chart recorder or quantity device. and (ii) each product stream used for reporting purposes at a facility.
(c) constructed of clay or other suitable impermeable material with the bottom of the pit above ground water level. (4) A permit holder must not remove or tamper with any seal affixed under subsection (1). Seals 52 (1) An official may seal or cause to be sealed any or all valves or meters installed at a well or on any pipeline. orally or in writing.. or (b) if the permit holder has not received notice as required under subsections (2) and (3).ca/EPLibraries/bclaws_new/document/ID/freeside/. (i) the meter is maintained in good operating condition. of the affixing of a seal under subsection (1) and of the reasons for taking that action. in which case the person must notify the commission of the removal without delay. and (f) is completely emptied and any excavation filled without unreasonable delay.
. "well depth" means the true vertical depth. (f) if natural gas. S = average separator pressure (kPa). (c) the average separator pressure is (i) for a single well. the average separator pressure for the month for the group of wells.
(ii) the meter is suitably safeguarded from weather and from interference by unauthorized persons. if the well depth is equal to or greater than 1 000 metres.. (g) if natural gas. (iii) if a project UDOA has been designated for a group of wells. (ii) if stage separation is used. if the well depth is less than 1 000 metres. (6) The DOA of an oil well or a group of oil wells that have been designated a project UDOA under section 75 of the Act is: DOA = UDOA X FGOR X FOTP where
. that a suitable entry is made on the meter chart or on the recordkeeping notations in the EFM system. and (iv) 400 kPa if no separator pressure is reported.0. (b) the well depth of the well divided by 100. the average separator pressure for the month. in metres.
(5) A calculation under subsection (4) must be made in accordance with the following: (a) the data used to make the calculation must be obtained from the last calendar month during which the oil well produced. will effectively stop all flow through the bypass. of the lowest producing perforation or open hole section in a zone. (3) For oil wells that are part of a special project under section 75 of the Act and have been assigned a project UDOA. Division 2 — Oil Daily oil allowable 54 (1) In this section. weighted by the volume of oil produced. is (a) 10. the full production stream does not reach the meter. GOR = net calculated gas-oil ratio (m3/m3).3 FGOR = GOR + 0. natural gas liquids or natural gas byproducts are produced from a well or facility and a bypass around a meter is opened or if. rounded to the second decimal place: 177. (b) for a gas reinjection project. that valves are installed that. (2) The UDOA for an oil well. the net calculated gas-oil ratio must be calculated using the net produced gas.bclaws. the average separator pressure of the lowest pressure stage for the month. natural gas liquids or natural gas byproducts are produced from a well or facility and there is a bypass around a meter. expressed in m3/day and rounded to one decimal place. (c) as specified in the well permit. for any other reason. petroleum. the project UDOA may be applied to the entire project area as though it were a single well. (4) The gas-oil ratio adjustment factor for the purposes of subsection (6) is the factor calculated in accordance with the following formula.0257 x S where FGOR = the gas-oil ratio adjustment factor. petroleum. or (d) as specified by an official.ca/EPLibraries/bclaws_new/document/ID/freeside/. when closed.Drilling and Production Regulation
or (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. (c) opening and closing meter readings. Production test of oil wells 58 (1) A permit holder must conduct at least 2 production quantity tests per month on each oil well whose production quantity is delivered to a proration battery. Reg. (b) be at least 22 hours in duration.ca/EPLibraries/bclaws_new/document/ID/freeside/. (3) A permit holder must keep records of production quantity tests conducted. and (d) allow sufficient purge time before the test to ensure that liquids from a previous quantity test are replaced by the fluids from the new well to be tested. (2) Subsection (1) does not apply to a well subject to a designation under section 75 of the Act. (2) A production quantity test referred to in subsection (1) must (a) measure the quantities of petroleum.
[am. a permit holder finds that a consistent meter factor is unattainable.bclaws.. (d) meter factor.
UDOA = the unadjusted daily oil allowable in m3/day. Measurement of total oil production 57 (1) If. B.] Restriction of oil production 55 Subject to section 49.. the permit holder of (a) an oil well.
UDOA = the unadjusted daily oil allowable in m3/day. (c) be adequately spaced throughout the month. 18.1 (1) (c) of the Act. during calibration of a meter. (2) A permit holder must maintain a record of the calibration of the oil meter installation. s.
= the daily oil allowable in m3/day. Test period allowable 56 (1) During the test period for an oil well. FGOR FOTP = the gas-oil ratio adjustment factor calculated in accordance with subsection (3). and the records must include the following. water and natural gas produced. (b) duration of the quantity test in hours. as applicable: (a) quantity test date.Drilling and Production Regulation
http://www. = the off-target penalty factor determined under section 6 (4).C. the permit holder must take corrective action without delay. 241/2012. the test period allowable is TPA = 90 x UDOA + 500 where TPA = the volume of oil that may be produced during the test period (m3).
or (b) the well is classified as an exploratory outpost well or exploratory wildcat well. (3) Within 60 days of the sampling referred to in subsection (1). the permit holder must shut in the oil well on or before the 16th day of the month. (2) If overproduction at the end of a production period is greater than 25% of the monthly oil allowable for October. for that month. the permit holder must flow test the well and determine the absolute open flow potential if (a) the well is producing from a pool with suspected water drive. (2) A permit holder must ensure that (a) the production target at the end of the month and the overproduction or underproduction at the beginning of the month for each producing oil well or group of oil wells for which the permit holder is responsible is calculated each month. and must keep it shut in until the overproduction is completely retired. and (b) a production allowable report is submitted to the commission in time to be received on or before the 16th day of the month.ca/EPLibraries/bclaws_new/document/ID/freeside/. before 6 months have elapsed after a permit holder has first placed a gas well on production. (2) A permit holder may not carry forward underproduction to the following production period. (i) petroleum density. the well permit holder must submit to the commission a report of the component analyses of the crude oil liquids. and the number of days calculated for the shut in period based on the daily oil allowable.
(e) percent of basic sediment and water. (h) net gas oil ratio. (f) quantities of petroleum. Underproduction of oil 60 (1) A permit holder may make up underproduction at any time within a production period at a rate not exceeding the daily production limit. a permit holder must use the test-to-test method of calculation. (2) Subsection (1) applies only to producing formations in a well from which initial production occurs after the date this regulation came into force. adjusted for any penalties. adjusted for any penalties. (g) average separator pressure over the time duration of the quantity test. the permit holder must carry the overproduction forward and must shut in the well on or before November 16 and must keep it shut in until the overproduction is completely retired. (4) To calculate the monthly estimated oil well quantity production that is to be reported for each oil well producing to a proration battery.bclaws. the commission must be notified in writing of the date on which the well is shut in. water and natural gas produced during the quantity test. Overproduction of oil 61 (1) If overproduction at the beginning of any month exceeds the monthly oil allowable.Drilling and Production Regulation
http://www. Calculation of oil production 59 (1) A well permit holder must determine the overproduction or underproduction of each of the permit holder's wells at the end of every month. Division 3 — Gas Gas well tests 63 (1) Subject to subsection (3). 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.
. (3) If a permit holder shuts in a well in accordance with this section...
Overproduction of gas 66 (1) A permit holder must determine the accumulated overproduction for the period November 1 to October 31 for each gas well or group of wells and. (3) For gas wells that are part of a special project designated under section 75 of the Act and that have been assigned a project DGA. a detailed report of (a) any gas well flow test. (2) A permit holder must submit to the commission a report of any accumulated overproduction for the period November 1 to October 31.
(2) A permit holder must submit to the commission. (2) A permit holder may not produce from any of the following types of gas wells unless a DGA for the well has been established by the permit holder's permit or by a designation made under section 75 of the Act: (a) a producing well under a special project for concurrent production designated under section 75 of the Act. the well permit holder must submit to the commission a report of
. if a DGA has been established for a well by permit or a designation under section 75 of the Act... (5) A permit holder must not produce from a gas well that is in a gas cap. yet will also begin to significantly revapourize on some further reduction of pressure.325 kPa and 15°C. [am. (c) a producing well from a pool with suspected water drive. (2) A well permit holder must make provision to allow for proving taps to be used in conjunction with wet meter testing of gas wells. during the subsequent 3 months. (4) Subject to section 49.ca/EPLibraries/bclaws_new/document/ID/freeside/.1 (1) (c) of the Act. 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.bclaws. (b) any cleanup flow that results in burnable gas to the surface. or multiplied by the number of days from the date of initial production to the end of the production period. the permit holder must ensure that the production rate is adjusted so that all accumulated overproduction is retired by January 31. (2) Within 60 days of the sampling referred to in subsection (1). s. Restriction of gas production 65 (1) In this section. 19. the DGA may be applied to the entire project area as though it were a single well. (d) a gas well to which an off-target penalty factor applies. (b) a producing well from a retrograde condensate reservoir.C. B. 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.Drilling and Production Regulation
http://www.] Metering and measurement of gas 64 (1) A measurement of a volume of gas required by the Act or this regulation must be computed as the number of cubic metres it would occupy at standard conditions of 101. and (b) does not exceed the daily gas allowable multiplied by the number of days in the production period. Reg. "retrograde condensate" means any hydrocarbon fluid which exhibits an increased liquid volume fraction at pressures below the dew point. within 60 days of the date on which the operation concluded. the well permit holder must ensure that natural gas production from the well (a) does not in any one day exceed the daily production limit. 241/2012. (3) Subsection (1) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2. and (c) any underbalanced drilling that results in burnable gas to the surface.
bclaws. the well permit holder must submit to the commission a report of the analysis.
the component analyses of the natural gas and liquids.ca/EPLibraries/bclaws_new/document/ID/freeside/. as amended from time to time. Water produced at gas wells 70 A permit holder must ensure that water production that is separated at a gas well or central facility is metered to determine production or disposition quantities. in the American Petroleum Institute's Manual of Petroleum Measurement Standards. (5) If the total water production from a permit holder's oil well not grouped with others in a battery is less than 50 m3 per month. (2) If the water production from a permit holder's oil well is less than 100 m3/1 000 m3 of the total liquid production and no test treater facilities are available. Water produced at oil wells 69 (1) If the water production from a permit holder's oil well is 100 m3/1 000 m3 or more of the total liquid production and no test treater facilities are available. Operation of a water source well 72 (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. "Determination of Water and/or Sediment in Crude Oil by the Centrifuge Method". Division 4 — Water Measurement of water production 68 (1) A measurement of a quantity of water required by the Act or this regulation must be computed as the number of cubic metres it would occupy at standard conditions of 15°C. the permit holder must ensure that the water content of the oil is determined by (a) continuous proportional sampling of the produced liquids and accurate analysis of the sample. (2) Within 60 days of the sampling referred to in subsection (1). (4) If the total water production from a permit holder's multi-well battery is less than 50 m3 per month. the permit holder must ensure that water production is determined by totalling the calculated water production for each well based on its individual test rate. the battery or a central treating facility. or (b) a product analyzer. the permit holder must ensure that the water production is determined by centrifuging 3-spot or proportional samples taken at well spaced intervals during the month and averaging the results or by the method described in subsection (1). Division 5 — Pressure Measurement
.4. (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.. (3) If the total water production at a permit holder's oil well or battery exceeds 50 m3 per month and the water content exceeds 5 m3/1 000 m3 of the total liquid production. the permit holder must ensure that the water content of the oil is determined by centrifuging 2 samples taken at reasonable intervals during each test and averaging the results or by methods described in subsection (1). 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. (6) A permit holder must quantify sediment and water production in accordance with chapter 10..Drilling and Production Regulation
http://www. (2) A permit holder must meter the quantity and rate of water produced from the permit holder's water source well. the permit holder must ensure that the water is separated from the oil and accurately gauged or metered at the well. Water analysis 71 (1) If a zone in a well has produced sufficient water to allow representative sampling.
Signs for facilities 77 (1) A facility permit holder must ensure that a permanently legible and conspicuous sign is displayed and maintained at each facility. (e) if the facility handles gas containing 100 ppm or greater of hydrogen sulphide. the well permit holder must submit a monthly injection or disposal statement.C. (c) at least one day before beginning production operations at a facility.Drilling and Production Regulation
http://www. to the commission no later than 25 days after the end of the month in which the activity occurred.ca/EPLibraries/bclaws_new/document/ID/freeside/. a poisonous gas symbol from Schedule 1. s.. (b) at least 2 days before conducting a pressure test on process piping at a facility. indicating the quantity of fluid injected or disposed of. a flammable gas symbol from Schedule 1. 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. (c) the legal description of the site. Reg. (2) Subject to subsection (6). and (d) at least one day before putting new or modified equipment in service at a facility.] Division 6 — Injection and Disposal Measurement of fluids injected 74 A well permit holder must ensure that the quantity and rate of water.. (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.
Reservoir pressure measurements 73 (1) Subject to subsection (5). 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. details of the reservoir pressure calculations are included in the report required under subsection (3).
. gas. (4) A well permit holder must ensure that. B. gas. air or any other fluid into an underground formation. (b) emergency notification information. and the sign must show all of the following: (a) the name of the permit holder. when static bottom hole pressures are measured. 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. (d) if the facility handles flammable gas. in the latter case. 20. Division 7 — Production Facilities Notification 76 A facility permit holder must notify the commission (a) at least 2 days before beginning construction of a facility or beginning permitted modifications to a facility. air or any other fluid injected through a well to an underground formation is metered. Reporting of injection and disposal 75 If a well permit holder injects or disposes of water.bclaws. 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. [am. (6) Subsection (2) does not apply with respect to a well completed in an unconventional zone listed in Schedule 2. including a telephone number. 241/2012. (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.
s. B. Reg. if the facility handles gas containing 10 ppm or greater of hydrogen sulphide.C. 23. s. as amended from time to time. (b) for a facility on Crown land. [am. Reg. Reg. 2011. 24. 21. 241/2012.C. Reg. (2) A facility permit holder must design and construct a piping system at a gas processing plant in accordance with ASME Standard B31. (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. signed and sealed by a professional engineer licensed or registered under the Engineers and Geoscientists Act.bclaws. within 3 months of beginning production or completing permitted modifications. (2) A permit holder must not post warning symbols where no hazard exists..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. facilities and gathering systems. or (b) CSA Standard Z662. s.] [Sections 15 and 77]
.3. [am. as applicable. groups of wells. [am. do everything referred to in section 19 (1) (a) to (g) of the Environmental Protection and Management Regulation. s. (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 (a) ASME Standard B31. 22.C. as amended from time to time.ca/EPLibraries/bclaws_new/document/ID/freeside/. if construction begins after the date this regulation came into force. (4) A facility permit holder must submit to the commission all as-built drawings including piping and instrumentation diagrams.
(f) after March 1. metering schematics and plot plans. B. 241/2012.] 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.C. metering schematics and gathering schematics for all wells. (3.Drilling and Production Regulation
http://www. as applicable.
Schedule 1 [am. a poisonous gas symbol from Schedule 1..3.] Division 8 — Storage Reservoirs 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. as amended from time to time.] Production facilities 78 (1) A facility permit holder must maintain up-to-date and detailed flow diagrams. B. 241/2012. 241/2012. (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. B.
bclaws. B.. 241/2012.ca/EPLibraries/bclaws_new/document/ID/freeside/.Drilling and Production Regulation
Schedule 2 [en.. 24. Reg.C.] Unconventional Zones Field Horn River Horn River Helmet Helmet Zone Name Muskwa-Otter Park Evie Muskwa-Otter Park Evie Distance (m) 100 100 100 100
bclaws. Canada.ca/EPLibraries/bclaws_new/document/ID/freeside/. 2008. c.
100 150 150 150 150 150 150 150
Northern Montney Montney Northern Montney Doig Phosphate-Montney Heritage Altares Town Deep Basin Deep Basin Montney Doig Phosphate-Montney Montney Cadomin Nikanassin
[Provisions relevant to the enactment of this regulation: Oil and Gas Activities Act.B. S.
. 111 and 112] Copyright (c) Queen's Printer. 36.C.Drilling and Production Regulation
http://www. sections 106. British Columbia... Victoria.
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