S-34.1, r. 2 - Regulation respecting petroleum exploration, production and storage on land

Section 192 Disposition versions

2018-09-20

192. The fracturing technical program must contain

(1)  the name and contact information of the engineer responsible for the technical program;

(2)  the name, profession and functions of the persons who prepared or revised the program;

(3)  the name and contact information of the enterprises charged with carrying out the work;

(4)  a chronological and detailed description of the work to be carried out;

(5)  the classification of the well determined according to Schedule 1;

(6)  a lateral section of the well indicating the technical elements;

(7)  an interpreted logging of the quality of the cement bond or any other equivalent analysis of the evaluation of the production tubing or the intermediate casing, from the shallowest zone targeted containing petroleum to the top of the cement, that shows that the hydraulic isolation has been obtained;

(8)  the list of well logs planned;

(9)  the list of pressure and leak tests and any other tests planned;

(10)  the list of fracturing tests planned, or the reasons why they are not required;

(11)  the type of service rig, equipment, components and casings to be used and their specifications;

(12)  an evaluation of well integrity compliant with the Industry Recommended Practice, IRP: #24, Fracture Stimulation, published by the Drilling and Completions Committee indicating, in particular,

(a)  the identification of the primary protective barrier and, if applicable, the secondary protective barrier;

(b)  the maximum pressure to be used to avoid compromising the integrity of the well; and

(c)  that the equipment, components and casings may withstand the conditions, forces and stresses to which they will be submitted;

(13)  a description of the fracturing intervals expected, in particular, the location of the perforations, in true vertical depth and measured depth;

(14)  the number of planned stages;

(15)  the nature and total volume of the fracturing fluids anticipated at each step;

(16)  the pressures and fluid flows anticipated for pumping at each step;

(17)  the type of fractures;

(18)  the quantity of energy used for pumping at each fracturing step;

(19)  a fracturing parameter monitoring program including, in particular,

(a)  the surface injection pressure;

(b)  the fluid flow;

(c)  the concentration of proppant; and

(d)  if applicable, the pressure in the annular space between the primary and secondary protective barriers;

(20)  a well integrity monitoring program including, in particular,

(a)  the changes in the well characteristics likely to indicate a weakness of the casings or any other aspect of the well integrity necessary for the isolation of the usable groundwater;

(b)  a well casing corrosion monitoring program; and

(c)  the analyses to be carried out concerning the flows of the surface casing vent and the migration of the gas;

(21)  the following information concerning the fracturing fluids used:

(a)  the commercial name of all the additives and their function;

(b)  the maximum concentration of each additive and of each additive in the fracturing fluid;

(22)  an evaluation of the risks related to the presence of additives in the fracturing fluids and the practices and operational audits provided for the management of the risks and including, in particular,

(a)  the physical, chemical and toxicological properties of the additives in the fracturing fluid;

(b)  the classification of the additives based on their chemical ingredients and their potential impact on the safety and health of persons;

(c)  the identification of the additives for which specific verifications or practices are required to reduce the risks on the safety and health of persons and on the environment; and

(d)  the nature of the specific verifications and practices planned;

(23)  an evaluation of the propagation of the fractures including, in particular, an analysis of the communication potential between the stimulated well and the adjacent drilling holes carried out in compliance with the Industry Recommended Practice, IRP: #24, Fracture Stimulation, published by the Drilling and Completions Committee, by using the relevant data to which the holder has access;

(24)  an evaluation of the capacity of the geological formations located between the petroleum zone and the base of the usable groundwater aquifer to act as a confining layer and contain the effects of the fracturing, or the reasons why it is not required; if applicable, the evaluation must contain, in particular,

(a)  an analysis of the mobility of the fracturing fluid in the zone located between the fracturing intervals planned and the base of the usable groundwater aquifer;

(b)  a simulation of the fracture pattern and the location of the faults; and

(c)  an analysis distance covering double the half length of the fracture planned on the entire depth of the wellbore;

(25)  a seismicity analysis based, in particular, on

(a)  the normal local and regional seismic activity determined from the historical data available;

(b)  the pre-existing geological constraints near the fracturing work contemplated;

(c)  the evaluation of the risk of seismicity induced by the fracturing work; and

(d)  the evaluation of the probability that an earthquake of a 2.0 magnitude or more occurs;

(26)  the measures planned for the management of petroleum, formation fluids, drilling fluids, chemical substances and other discharges;

(27)  a summary of the results of any fracturing simulation or modelling carried out;

(28)  if applicable, the list of licences, certificates and other authorizations to be obtained;

(29)  the list of references used during the preparation of the technical program, in particular, the standards from recognized organizations and guidelines from other Canadian jurisdictions; and

(30)  any other information or document deemed necessary by the Minister.

Where the holder observes a probability of an induced seismicity of a 2.0 magnitude or more, the technical program must also contain a plan for the monitoring, mitigation and response to the induced seismicity including, in particular,

(1)  a quality and quantity monitoring plan that covers a radius of 10 km from the fracturing zone allowing the detection of an earthquake of a 2.0 magnitude or more including, in particular,

(a)  a map of the temporary or permanent seismic monitoring equipment stations;

(b)  the specifications of the seismic monitoring equipment, the data transmission method and their accuracy in measuring the location, depth and magnitude of a seismic activity;

(c)  the monitoring procedure, identification of the persons responsible and the speed of the detection and location of an earthquake and the communication of the information; and

(d)  a monitoring period comprised between the start of the work and the shortest of the following periods:

i.  60 days after the end of the fracturing work;

ii.  the end of the return of the flow-back water to the surface; and

(2)  the measures applicable if the recorded magnitude of the induced seismic activity exceeds those provided for in section 207.

Where work is planned in a temporarily closed well, the technical program must also contain the annual inspection worksheet provided for in Schedule 2.

The term “fracturing half-length” means the radial distance separating the well and the outer tip of a fracture propagated by fracturing.

O.C. 1252-2018, s. 192.

Not in force

In force: 2018-09-20

192. The fracturing technical program must contain

(1)  the name and contact information of the engineer responsible for the technical program;

(2)  the name, profession and functions of the persons who prepared or revised the program;

(3)  the name and contact information of the enterprises charged with carrying out the work;

(4)  a chronological and detailed description of the work to be carried out;

(5)  the classification of the well determined according to Schedule 1;

(6)  a lateral section of the well indicating the technical elements;

(7)  an interpreted logging of the quality of the cement bond or any other equivalent analysis of the evaluation of the production tubing or the intermediate casing, from the shallowest zone targeted containing petroleum to the top of the cement, that shows that the hydraulic isolation has been obtained;

(8)  the list of well logs planned;

(9)  the list of pressure and leak tests and any other tests planned;

(10)  the list of fracturing tests planned, or the reasons why they are not required;

(11)  the type of service rig, equipment, components and casings to be used and their specifications;

(12)  an evaluation of well integrity compliant with the Industry Recommended Practice, IRP: #24, Fracture Stimulation, published by the Drilling and Completions Committee indicating, in particular,

(a)  the identification of the primary protective barrier and, if applicable, the secondary protective barrier;

(b)  the maximum pressure to be used to avoid compromising the integrity of the well; and

(c)  that the equipment, components and casings may withstand the conditions, forces and stresses to which they will be submitted;

(13)  a description of the fracturing intervals expected, in particular, the location of the perforations, in true vertical depth and measured depth;

(14)  the number of planned stages;

(15)  the nature and total volume of the fracturing fluids anticipated at each step;

(16)  the pressures and fluid flows anticipated for pumping at each step;

(17)  the type of fractures;

(18)  the quantity of energy used for pumping at each fracturing step;

(19)  a fracturing parameter monitoring program including, in particular,

(a)  the surface injection pressure;

(b)  the fluid flow;

(c)  the concentration of proppant; and

(d)  if applicable, the pressure in the annular space between the primary and secondary protective barriers;

(20)  a well integrity monitoring program including, in particular,

(a)  the changes in the well characteristics likely to indicate a weakness of the casings or any other aspect of the well integrity necessary for the isolation of the usable groundwater;

(b)  a well casing corrosion monitoring program; and

(c)  the analyses to be carried out concerning the flows of the surface casing vent and the migration of the gas;

(21)  the following information concerning the fracturing fluids used:

(a)  the commercial name of all the additives and their function;

(b)  the maximum concentration of each additive and of each additive in the fracturing fluid;

(22)  an evaluation of the risks related to the presence of additives in the fracturing fluids and the practices and operational audits provided for the management of the risks and including, in particular,

(a)  the physical, chemical and toxicological properties of the additives in the fracturing fluid;

(b)  the classification of the additives based on their chemical ingredients and their potential impact on the safety and health of persons;

(c)  the identification of the additives for which specific verifications or practices are required to reduce the risks on the safety and health of persons and on the environment; and

(d)  the nature of the specific verifications and practices planned;

(23)  an evaluation of the propagation of the fractures including, in particular, an analysis of the communication potential between the stimulated well and the adjacent drilling holes carried out in compliance with the Industry Recommended Practice, IRP: #24, Fracture Stimulation, published by the Drilling and Completions Committee, by using the relevant data to which the holder has access;

(24)  an evaluation of the capacity of the geological formations located between the petroleum zone and the base of the usable groundwater aquifer to act as a confining layer and contain the effects of the fracturing, or the reasons why it is not required; if applicable, the evaluation must contain, in particular,

(a)  an analysis of the mobility of the fracturing fluid in the zone located between the fracturing intervals planned and the base of the usable groundwater aquifer;

(b)  a simulation of the fracture pattern and the location of the faults; and

(c)  an analysis distance covering double the half length of the fracture planned on the entire depth of the wellbore;

(25)  a seismicity analysis based, in particular, on

(a)  the normal local and regional seismic activity determined from the historical data available;

(b)  the pre-existing geological constraints near the fracturing work contemplated;

(c)  the evaluation of the risk of seismicity induced by the fracturing work; and

(d)  the evaluation of the probability that an earthquake of a 2.0 magnitude or more occurs;

(26)  the measures planned for the management of petroleum, formation fluids, drilling fluids, chemical substances and other discharges;

(27)  a summary of the results of any fracturing simulation or modelling carried out;

(28)  if applicable, the list of licences, certificates and other authorizations to be obtained;

(29)  the list of references used during the preparation of the technical program, in particular, the standards from recognized organizations and guidelines from other Canadian jurisdictions; and

(30)  any other information or document deemed necessary by the Minister.

Where the holder observes a probability of an induced seismicity of a 2.0 magnitude or more, the technical program must also contain a plan for the monitoring, mitigation and response to the induced seismicity including, in particular,

(1)  a quality and quantity monitoring plan that covers a radius of 10 km from the fracturing zone allowing the detection of an earthquake of a 2.0 magnitude or more including, in particular,

(a)  a map of the temporary or permanent seismic monitoring equipment stations;

(b)  the specifications of the seismic monitoring equipment, the data transmission method and their accuracy in measuring the location, depth and magnitude of a seismic activity;

(c)  the monitoring procedure, identification of the persons responsible and the speed of the detection and location of an earthquake and the communication of the information; and

(d)  a monitoring period comprised between the start of the work and the shortest of the following periods:

i.  60 days after the end of the fracturing work;

ii.  the end of the return of the flow-back water to the surface; and

(2)  the measures applicable if the recorded magnitude of the induced seismic activity exceeds those provided for in section 207.

Where work is planned in a temporarily closed well, the technical program must also contain the annual inspection worksheet provided for in Schedule 2.

The term “fracturing half-length” means the radial distance separating the well and the outer tip of a fracture propagated by fracturing.

O.C. 1252-2018, s. 192.