Major Work Activity E – Performs drilling operations

Task E-12 Prepares drill string

Task Descriptor

The drill string consists of the BHA which includes a bit, bit subs, collars, cross-overs, heavy-weight drill pipe and specialized drilling tools such as mud motors, power drive, jars, reamers and shock subs. The BHA is suspended from lengths of drill pipe. The assembly of drill pipe and BHA is called the drill string. The drill string is lengthened by adding sections of pipe. The drill string is used for drilling the surface hole or main hole.

E-12.01 Takes measurements of bottomhole assembly (BHA) and drill string

Essential Skills

Oral Communication, Numeracy, Document Use

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-12.01.01P	measure and record length of *BHA components*	length of *BHA components* is measured and recorded using derrick/strap tape measure according to IRP
E-12.01.02P	measure inside diameter ( ID)/outside diameter ( OD) of *BHA components*	ID/ OD of *BHA components* are measured using callipers and tape measures
E-12.01.03P	input measurement data into electronic drilling recorder	measurement data is entered into electronic drilling recorder
E-12.01.04P	size drill bit nozzles (jets)	drill bit nozzles (jets) are sized using nozzle gauge according to operator’s instructions

Range of Variables

BHA components include: drill collars, cross-overs, heavyweights, specialized tools

	Knowledge
	Learning Outcomes	Learning Objectives
E-12.01.01L	demonstrate knowledge of procedures used to take measurements of BHA and drill string	explain procedures used to measure and record length of *BHA components*
		explain procedures used to measure the diameter of *BHA components*
		identify types of equipment required to measure *BHA components*
		explain how to record into the electronic drilling recorder
		explain procedures used to size drill bit nozzles (jets) and to gauge bits

Range of Variables

BHA components include: drill collars, cross-overs, heavyweights, specialized tools

E-12.02 Picks up bottomhole assembly (BHA) and drill string

Essential Skills

Oral Communication, Working with Others, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-12.02.01P	tighten lifting nubbins, pickup subs and protectors	lifting nubbins, pickup subs and protectors are tightened prior to hoisting
E-12.02.02P	hoist BHA to floor	BHA is hoisted to floor using proper holdback procedures with *equipment*
E-12.02.03P	lower and secure BHA components into mousehole	BHA components are lowered and secured into mousehole according to rig specifications
E-12.02.04P	remove nubbins or pickup subs, if necessary	nubbins and pickup subs are removed, if necessary
E-12.02.05P	latch elevators onto collar pickup subs or zip grooves, or prepare tubular to be picked up with top drive	elevators are latched onto collar pickup subs or zip grooves, or tubular is prepared to be picked up with top drive according to specifications and compatibility

Range of Variables

equipment includes: winches, collar slings, rigging/hoisting equipment, snubbing rope, hydraulic catwalks, pickup nubbins and subs, pipe arm, elevators

	Knowledge
	Learning Outcomes	Learning Objectives
E-12.02.01L	demonstrate knowledge of procedures used to pick up BHA and drill string	explain procedures used to tighten lifting nubbins, pickup subs and protectors
		identify types of thread connections
		identify *equipment* used to hoist collars
		identify hazards and safe operating procedures for hoisting collars
		explain procedures used to size and latch elevators onto collar pickup subs or zip grooves
		explain procedures used to prepare tubulars to be picked up with top drive

Range of Variables

equipment includes: winches, collar slings, rigging/hoisting equipment, snubbing rope, hydraulic catwalks, pickup nubbins and subs, pipe arm, elevators

E-12.03 Makes up bottomhole assembly (BHA)

Essential Skills

Numeracy, Document Use, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-12.03.01P	install each BHA component	BHA components are installed according to IRP using *tools and equipment*
E-12.03.02P	torque each connection	connections are torqued according to specifications using compatible tongs or iron roughnecks
E-12.03.03P	install dog collars on required BHA components	dog collars are installed on required BHA components
E-12.03.04P	change bit nozzles	bit nozzles are changed according to operator’s requirements
E-12.03.05P	install bits	bits are installed according to manufacturers’ specifications

Range of Variables

tools and equipment include: pipe spinners, chain tongs, iron roughneck, top drive, rig tongs, dog collars, slips, elevators

	Knowledge
	Learning Outcomes	Learning Objectives
E-12.03.01L	demonstrate knowledge of procedures used to make up BHA	identify BHA components
		explain procedures used to torque BHA component connections
		explain procedures used to install dog collars on BHA components
		identify types of bit nozzles used on BHA
		explain procedures used to install bit nozzles
		identify types of bits and bit breakers
		identify threads and torque values

Task E-13 Operates blowout preventer (BOP) equipment and associated components

Task Descriptor

BOPs are used to control kicks and prevent blowouts. A thorough understanding of the function, operation, maintenance and testing of the BOP is an essential part of crew training and vital in the event of a kick situation. BOPs must be used in drilling operations and tested at specific intervals as per governing regulations.

E-13.01 Prepares for blowout preventer (BOP) installation

Essential Skills

Thinking, Working with Others, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-13.01.01P	organize *tools and equipment*	*tools and equipment* are organized
E-13.01.02P	clean BOP component flanges, gaskets, nuts and studs	BOP component flanges, gaskets, nuts and studs are cleaned
E-13.01.03P	inspect *tools and equipment* and *components*	*tools and equipment* and *components* are inspected
E-13.01.04P	remove fluid from casing	fluid from casing is removed by displacing, pumping or using air pressure according to company policies
E-13.01.05P	measure out casing bowl height	casing bowl height is measured out for positioning BOP
E-13.01.06P	measure and cut casing or back off landing joint	casing is measured and cut or landing joint is backed off according to required height and rig specifications
E-13.01.07P	remove flow line, lay down cut-off casing or landing joint and conductor, if necessary	flow line is removed, cut-off casing or landing joint and conductor are laid down, if necessary
E-13.01.08P	install casing bowl onto casing using *methods*	casing bowl is installed into casing using rigging/hoisting equipment and *methods*
E-13.01.09P	lay down mousehole, if necessary	mousehole is laid down using rigging/hoisting equipment, if necessary

Range of Variables

tools and equipment include: nuts, studs, ring gaskets, hydraulic fittings, flow-tees, hammer wrenches, hammers, pneumatic wrench, hydraulic wrench, BOP slings, fall arrest equipment

components include: annular preventer, blind rams, HCR valve, pipe rams, shear rams, drilling spool, casing bowl, kill lines, manually operated valves, flange lines, bleed-off lines

methods include: weld on, screw on, slip on

	Knowledge
	Learning Outcomes	Learning Objectives
E-13.01.01L	demonstrate knowledge of procedures used to prepare for BOP installation	identify types of *tools and equipment* required for the installation of BOP
		describe methods used to remove fluid from casing
		explain procedures used to calculate casing bowl space requirements
		explain procedures used to cut casing
		identify hazards and safe operating procedures when using *tools and equipment* and rigging/hoisting equipment

Range of Variables

tools and equipment include: nuts, studs, ring gaskets, hydraulic fittings, flow-tees, hammer wrenches, hammers, pneumatic wrench, hydraulic wrench, BOP slings, fall arrest equipment

E-13.02 Nipples up blowout preventer (BOP)

Essential Skills

Oral Communication, Working with Others, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-13.02.01P	position BOP with rig-specific *handling equipment* onto casing bowl	BOP is positioned onto casing bowl with rig-specific *handling equipment*
E-13.02.02P	fasten BOP to casing bowl	BOP is fastened to casing bowl using *tools and equipment*
E-13.02.03P	fasten HCR and kill line valves to the BOP stack	HCR and kill line valves are fastened to the BOP stack using rigging/hoisting equipment
E-13.02.04P	assemble choke line(s) from HCR valve to choke manifold	choke line(s) is assembled from HCR valve to choke manifold
E-13.02.05P	rig in flow-tee, flow line, catch tray and hole fill hose	flow-tee, flow line, catch tray and hole fill hose are rigged in
E-13.02.06P	align BOP to rotary table centre using *aligning tools*	BOP is aligned to rotary table using *aligning tools*
E-13.02.07P	route and attach hydraulic lines to BOP components	hydraulic lines are routed and attached to BOP components
E-13.02.08P	assemble flare and degasser lines	flare and degasser lines are assembled according to regulations
E-13.02.09P	prepare for winter operations, if required	BOP system is prepared for winter operations, if required and according to regulations

Range of Variables

handling equipment includes: BOP slings, BOP handler

tools and equipment include: nuts, studs, ring gaskets, hydraulic fittings, flow-tees, hammer wrenches, hammers, pneumatic wrench, hydraulic wrench, BOP slings, fall arrest equipment

aligning tools include: turnbuckle straps, chains, boomers, chain hoists

	Knowledge
	Learning Outcomes	Learning Objectives
E-13.02.01L	demonstrate knowledge of procedures used to nipple up BOP	identify hazards and safe operating procedures when using rigging/hoisting equipment
		identify the tools required to fasten BOP to casing bowl
		describe the function of the HCR and kill line valves
		identify the tools required to align BOP to the rotary table centre
		identify the requirements for cold weather operation
		describe hazards and risks associated with nipple up procedures
		describe BOP stack classification
		explain how to calculate casing bowl space requirements
		identify BOP *handling equipment*
		describe the inspection criteria for a BOP
		identify flange types, gaskets, sealants and fasteners to make connections
		identify the hose bend radius and fluid turn requirements
		identify regulatory requirements of fire rated hoses and fittings and their application

Range of Variables

handling equipment includes: BOP slings, BOP handler

E-13.03 Performs blowout preventer (BOP) accumulator functions

Essential Skills

Thinking, Document Use, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-13.03.01P	visually check accumulator fluid levels in the reservoir and accumulator pre-charge bottle pressures	accumulator fluid levels in the reservoir and accumulator pre-charge bottle pressures are checked
E-13.03.02P	visually check nitrogen back-up bottle pressures	nitrogen back-up bottle pressures are checked according to regulations
E-13.03.03P	close bleed off valve on accumulator manifold	bleed off valve on accumulator manifold is closed
E-13.03.04P	start accumulator pump and record pre-charge pressure	accumulator pump is started and pre-charge pressure is recorded according to regulations
E-13.03.05P	record accumulator operating pressure	accumulator operating pressure is recorded according to regulations
E-13.03.06P	function test *BOP components* and record close/open times, remaining pressure and recharge time	*BOP components* are function tested and close/open times, remaining pressure and recharge time are recorded according to regulations
E-13.03.07P	visually check hoses and fittings	hoses and fittings are checked for *problems*
E-13.03.08P	troubleshoot *accumulator malfunctions*	*accumulator malfunctions* are resolved
E-13.03.09P	bleed off accumulator pressure using *method* prior to correcting any identified malfunctions	accumulator pressure is bled off using *method* prior to correcting any identified malfunctions

Range of Variables

BOP components include: annular preventer, blind rams, HCR valve, pipe rams, shear rams

problems include: leaks, air-lock, hose disconnect, coupler failure, hose collapse, frozen hose

accumulator malfunctions include: incorrect hose hook-up, faulty PLC, air remotes, loss of pressure, blockage, frozen air line, faulty accumulator manifold valve, plug screen, manifold valve actuator

method includes: accumulator manifold valves to be set in neutral position when opening accumulator manifold bleeder valve to zero system pressure

	Knowledge
	Learning Outcomes	Learning Objectives
E-13.03.01L	demonstrate knowledge of procedures used to charge and function test BOP accumulator	explain the purpose and procedures for charging and function testing the BOP accumulator
		describe methods used for troubleshooting *accumulator malfunctions*
		identify the pressures required for the function test to meet regulations
		identify close/open and recharge times and relative pressures required to meet regulations
		describe the BOP and accumulator function test

Range of Variables

E-13.04 Pressure tests blowout preventer (BOP) and components

Essential Skills

Document Use, Thinking, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-13.04.01P	make up test plug/cup on bottom of drill pipe to required torque	test plug/cup is made on bottom of drill pipe to required torque
E-13.04.02P	run test plug/cup and drill pipe through BOP stack and land in casing bowl	test plug/cup and drill pipe are run through the BOP stack and landed in casing bowl according to operator’s instructions
E-13.04.03P	secure drill pipe to offset hydraulicing, if required	drill pipe is secured to offset hydraulicing, if required
E-13.04.04P	close each *BOP component* and manifold valve separately and apply required pressures (low and high)	each *BOP component* and manifold valve is closed separately, and required pressures (low and high) are applied using mud pumps or third-party pressure testers to ensure each component holds the pressure
E-13.04.05P	troubleshoot *pressure testing problems*	*pressure testing problems* are resolved using *methods*
E-13.04.06P	visually inspect and monitor *BOP components*	*BOP components* are visually inspected and monitored for pressure loss
E-13.04.07P	record *pressure test data*	*pressure test data* is recorded according to regulations
E-13.04.08P	bleed off pressure at casing bowl	pressure is bled off at casing bowl to correct any identified leaks or pressure losses
E-13.04.09P	set up or align manifold valves	manifold valves are set up or aligned according to operator’s instructions
E-13.04.10P	prepare manifold and kill and bleed-off lines for winter operations, if required	manifold and kill and bleed-off lines are prepared for winter operations according to regulations, if required
E-13.04.11P	install kill line hose(s)	kill line hose(s) is installed according to regulations

Range of Variables

BOP components include: annular preventer, blind rams, HCR valve, pipe rams, shear rams, drilling spool, casing bowl, kill lines, manually operated valves, flange lines, bleed-off lines, stabbing valve, inside BOP, Kelly cocks, manifold gauges

pressure testing problems include: pressure drop, leaks, failed BOP component, by-pass, gauge malfunction

methods include: re-functioning component, flushing component, repositioning pipe, changing component, tightening flange connection

pressure test data includes: high/low test pressures, duration of pressure test, components tested, motor kills, function test, visual inspection of vent and degasser lines

	Knowledge
	Learning Outcomes	Learning Objectives
E-13.04.01L	demonstrate knowledge of procedures used to pressure test BOP and components	describe pressure test procedures
		explain the importance of conducting a pressure test
		explain the procedures used to bleed off pressure
		calculate MACP
		identify hazards and safe operating procedures associated with pressure testing BOP and components

E-13.05 Nipples down blowout preventer (BOP) and related equipment

Essential Skills

Working with Others, Oral Communication, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-13.05.01P	select and use *tools and equipment*	*tools and equipment* are selected and used
E-13.05.02P	disconnect flow line and remove flow-tee	flow line is disconnected and flow-tee is removed
E-13.05.03P	bleed off accumulator and disconnect hydraulic lines	accumulator is bled off and hydraulic lines are disconnected
E-13.05.04P	position BOP *handling equipment*	BOP *handling equipment* is positioned according to rig specifications
E-13.05.05P	bleed off HCR and choke system(s)	HCR and choke system(s) are bled off
E-13.05.06P	disconnect *lines, valves* and bottom drilling spool	*lines, valves* and bottom drilling spool are disconnected according to operator’s instructions
E-13.05.07P	remove casing, if required and as required	casing is removed, if required and as required
E-13.05.08P	perform visual inspection of BOP	BOP is visually inspected for signs of wear and tear
E-13.05.09P	store and secure *BOP components*	*BOP components* are stored and secured in designated area according to rig specifications

Range of Variables

tools and equipment include: hammer wrenches, hammers, pneumatic wrenches, hydraulic wrenches, BOP slings, fall arrest equipment

handling equipment includes: BOP slings, BOP handler

lines include: kill, bleed-off (sweep, choke, HCR), flare, degasser

valves include: kill, HCR, check, manual, manifold

BOP components include: annular preventer, blind rams, HCR valve, pipe rams, shear rams, drilling spool, kill lines, manually operated valves, flange lines, bleed-off lines, stabbing valve, inside BOP

	Knowledge
	Learning Outcomes	Learning Objectives
E-13.05.01L	demonstrate knowledge of procedures used to nipple down BOP and related equipment	identify BOP and related equipment and their functions
		identify hazards and safe operating practices for nippling down BOP and related equipment
		identify BOP *handling equipment*

Range of Variables

handling equipment includes: BOP slings, BOP handler

Task E-14 Performs drilling activities

Task Descriptor

Drilling activities are done in the search for natural resources. This task covers those drilling activities performed after a surface hole has been drilled. Drilling fluids are constantly pumped through the drill string in order to cool the drill bit, clean the annulus and maintain the condition of the hole. Rig technicians must closely monitor all aspects of drilling. Appropriate well control operations that can prevent release of unrefined product to the atmosphere are critical to ensure safety and environmental protection.

E-14.01 Maintains drilling fluids

Essential Skills

Numeracy, Document Use, Working with Others

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.01.01P	transfer fluids from *reserve tanks* to mud system	fluids are transferred from *reserve tanks* to mud system in order to maintain mud properties and volumes using *equipment*
E-14.01.02P	test drilling fluid for *properties*	drilling fluid is tested for *properties* and results are documented
E-14.01.03P	follow mud program or directions	mud program or directions provided by the operator’s representative are followed
E-14.01.04P	adjust mix	mix is adjusted to counter *problems with drilling fluids* by adding additives
E-14.01.05P	alter density	density is altered by changing shaker screens, running centrifuges and adjusting water rate, dumping and diluting, and adding weight materials
E-14.01.06P	maintain system volumes	system volumes are maintained at a consistent rate by monitoring pit volume totalizer ( PVT) and adjusting with makeup volume
E-14.01.07P	manage wellbore cuttings	wellbore cuttings are managed by *mechanical means*
E-14.01.08P	calculate circulation times and *volumes*	circulation times and *volumes* are calculated using standard formulas, charts and specifications

Range of Variables

reserve tanks include: tank farms, pre-mix tanks, water tanks

equipment includes: transfer pumps, vacuum unit

properties include: pH, weight, viscosity, fluid loss, chloride content, sand content, rheology

problems with drilling fluids include: low or high viscosity, mud rings, dehydration, clobbering (thickening of mud), aerated mud, excessive density, solids content, pH levels

mechanical means include: shakers, centrifuges, dryers, excavators, loaders, trucks

volumes include: surface capacity, annular and pipe capacity, pipe displacement, pump capacity and output

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.01.01L	demonstrate knowledge of procedures used to maintain drilling fluids	describe *types of drilling fluids* and their uses
		describe procedure used to perform calculations and measurement for drilling fluids
		identify hazards and *safe operating procedures* for maintaining drilling fluids
		describe procedure used to test drilling fluids
		describe procedure used to alter mud density
		interpret mud program/stick diagram
		interpret mud report data

Range of Variables

types of drilling fluids include: gel-chem, invert, potassium, silicates, polymers, water, brine, flocculent water, foam

safe operating procedures include: use of SDS, mixing procedures for specific materials

E-14.02 Operates electrical drive systems

Essential Skills

Thinking, Working with Others, Continuous Learning

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.02.01P	synchronize generators	generators are synchronized according to manufacturers’ specifications
E-14.02.02P	power up and power down the *auxiliary power*	*auxiliary power* is powered up and down according to manufacturers’ and rig specifications
E-14.02.03P	operate breakers	breakers are operated according to manufacturers’ specifications, codes and regulations
E-14.02.04P	check operation of heating, ventilation and air conditioning (HVAC) system	operation of HVAC system is checked on an ongoing basis according to rig specifications
E-14.02.05P	operate *control panel*	*control panel* is operated according to rig specifications and operator’s parameters
E-14.02.06P	troubleshoot electrical and communication problems	electrical and communication problems are resolved

Range of Variables

auxiliary power includes: 110, 220, 480 and/or 600 volt power, supply lighting, heaters, electric motors, cooling systems, hydraulic systems, PLC systems, batteries

control panel includes: VFDs, single board computers (SBC), human machine interface (HMI), driller’s console, EDR, computer system, PLC

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.02.01L	demonstrate knowledge of electrical drive systems, their applications and procedures for use	describe the differences between AC and DC drive systems
		identify the types of components of a DC drive system and their use
		identify the types of components of an AC drive system and their use
		explain how generators load share and synchronize
		explain how breakers are energized
		identify types of *control panels* and their use
		describe importance and function of HVAC systems
		describe power up and power down procedures

Range of Variables

control panel includes: VFDs, single board computers (SBC), human machine interface (HMI), driller’s console, EDR, computer system, PLC

E-14.03 Operates drilling equipment

Essential Skills

Digital Technology, Working with Others, Continuous Learning

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.03.01P	operate *driller controls*	*driller controls* are operated to control drilling equipment
E-14.03.02P	operate *drawworks controls*	*drawworks controls* are operated to raise and lower drill string
E-14.03.03P	operate top drive	top drive is operated to handle and rotate tubulars
E-14.03.04P	engage and adjust pump, rotary and auto-driller	pump, rotary and auto-driller are engaged and adjusted to desired *drilling parameters*
E-14.03.05P	identify *problems* if and when they occur	*problems* are identified
E-14.03.06P	modify *drilling parameters*	*drilling parameters* are modified to adapt to changing conditions and resolve *problems*
E-14.03.07P	calibrate *drilling instrumentation*	*drilling instrumentation* is calibrated to adjust for hook load, threshold, hole depth tracking, and changes in string
E-14.03.08P	connect drill string tubulars	drill string tubulars are connected according to rig specifications

Range of Variables

driller controls include: hydraulic controls, pneumatic controls, electric controls

drawworks controls include: brake handle, joystick, clutch, rheostat, throttle

drilling parameters include: pump rate, weight on bit (WOB), rotary speed, torque limits, differential pressure, rate of penetration (ROP) limits

problems include: torque spikes, sloughing, differential pressure changes, deviation, loss of circulation, kick warning signs

drilling instrumentation includes: pressure gauges, torque sensors, weight indicators, transducers, EDR, auto-driller

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.03.01L	demonstrate knowledge of drilling equipment, their applications and procedures for use	identify *driller controls* and their procedures for use
		identify drawworks and their procedures for use
		identify top drives and their procedures for use
		identify pumps, rotaries and auto-drillers and their procedures for use
		describe how to calibrate and function test *drilling instrumentation*
		describe the functions and limitations of drilling equipment
		identify and describe types of *braking mechanisms*
		identify *components of brakes*
E-14.03.02L	demonstrate knowledge of procedures used to operate drilling equipment	describe *drilling parameters* and their effect on drilling performance
		identify hazards and danger zones while drilling

Range of Variables

driller controls include: hydraulic controls, pneumatic controls, electric controls

drilling instrumentation includes: pressure gauges, torque sensors, weight indicators, transducers, EDR, auto-driller

braking mechanisms include: band brake, eaton brake, hydrodynamic brake, magnetic brake, AC braking system, emergency brake

components of brakes include: linkages, pads, bands, bearings, cooling systems, equalizer bars, discs, cotter pins, drums, grease nipples (zerks), AC brake components (choppers, resistors)

drilling parameters include: pump rate, weight on bit (WOB), rotary speed, torque limits, differential pressure, rate of penetration (ROP) limits

E-14.04 Monitors drilling operations

Essential Skills

Thinking, Digital Technology, Continuous Learning

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.04.01P	interpret *hole condition indicators*	*hole condition indicators* are interpreted
E-14.04.02P	monitor integrity of *bottomhole assembly*	*bottomhole assembly*’s integrity is monitored so that drilling parameters are adjusted as necessary
E-14.04.03P	monitor hole deviation	hole deviation is monitored using *surveying equipment*
E-14.04.04P	monitor tank volume alarms	tank volume alarms are monitored for gain or loss of flow and volume
E-14.04.05P	visually monitor cuttings and fluids	cuttings and fluids are visually monitored for changes in returns
E-14.04.06P	monitor gauges and outputs	gauges and outputs are monitored to evaluate drilling performance
E-14.04.07P	monitor gas detector	gas detector is monitored for abnormal increases in readings
E-14.04.08P	monitor pump gauges for abnormal pressures	pump gauges are monitored for abnormal pressures to identify *problems*

Range of Variables

hole condition indicators include: penetration rate, cuttings, fluid returns, torque, drag, doglegs, pump pressure, geological formations

bottomhole assembly includes: bit, mud motor, stabilizers, jars, agitators, reamers, survey tools

surveying equipment includes: wire line, single shot, measurement while drilling (MWD) tool, MWD screen

problems include: washes in drill string, plugged jets, failures in mud motor, contamination, failures in pump valves, seats, liners and heads, lost circulation

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.04.01L	demonstrate knowledge of procedures used to monitor down-hole drilling equipment	explain procedures used to monitor gauges and outputs on equipment
		describe *hole condition indicators* and their causes
		explain procedures used to conduct a deviation survey
		identify types of *surveying equipment*
		identify *characteristics* that would signify down-hole drilling equipment issues
		explain procedures used to monitor cuttings and fluids
E-14.04.02L	demonstrate knowledge of procedures used to monitor *surface drilling equipment*	describe the function of mud tanks
		explain procedures used to monitor mud tanks and pit volume totalizer ( PVT)
		describe gas detection systems
		describe significance of gain or loss in pump pressure

Range of Variables

hole condition indicators include: penetration rate, cuttings, fluid returns, torque, drag, doglegs, pump pressure, geological formations

surveying equipment includes: wire line, single shot, measurement while drilling (MWD) tool, MWD screen

characteristics include: loss or gain of differential pressure, loss of rate of penetration (ROP), loss or gain of torque, tight connections, no pulses on MWD screen, loss of ROP while sliding, and the combinations of any or all of these

surface drilling equipment includes: mud pumps, drawworks, top drives, swivels, shakers

E-14.05 Responds to changing well conditions

Essential Skills

Thinking, Working with Others, Digital Technology

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.05.01P	correct lack of ROP	lack of ROP is corrected with *potential resolutions*
E-14.05.02P	correct tight hole conditions	tight hole conditions are corrected with *potential resolutions*
E-14.05.03P	correct loss of circulation	loss of circulation is corrected with *potential resolutions*
E-14.05.04P	correct mechanical pipe sticking issues	mechanical pipe sticking issues are corrected with *potential resolutions*
E-14.05.05P	correct differential pipe sticking issues	differential pipe sticking issues are corrected with *potential resolutions*

Range of Variables

potential resolutions include:

for lack of ROP: increasing or decreasing of WOB, increasing or decreasing rotary, increasing or decreasing pump rate, adding mud additives (e.g. nutshells, detergents, sawdust, lubricants), changing BHA, adjusting mud properties;

for tight hole conditions: changing drilling parameters and fluid properties, performing wiper trip, working the pipe prior to connections, and pumping sweeps;

for loss of circulation: mixing and spotting loss-of-circulation-material (LCM) pill, decreasing pump rate, decreasing density, lowering water loss, pumping plugs (cement, barite, gunk) and running casing;

for mechanical pipe sticking issues: establishing free point, rotating drill string, pulling tension, back reaming, spotting lubricant, spotting acid, washing over, changing mud properties and jarring;

for differential pipe sticking issues: spotting oil-based pills, applying weight and torque, displacing wellbore with nitrogen;

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.05.01L	demonstrate knowledge of *problematic well conditions* and *potential resolutions*	identify *problematic well conditions* and their causes
		describe *potential resolutions*

Range of Variables

problematic well conditions include: loss or gain of differential pressure, lost circulation, loss of ROP, loss or gain of torque, tight connections, loss of ROP while sliding, and the combinations of any or all of these

potential resolutions include:

for tight hole conditions: changing drilling parameters and fluid properties, performing wiper trip, working the pipe prior to connections, and pumping sweeps;

for differential pipe sticking issues: spotting oil-based pills, applying weight and torque, displacing wellbore with nitrogen;

E-14.06 Performs well control operations

Essential Skills

Document Use, Numeracy, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-14.06.01P	perform *inspections for well control*	*inspections for well control* are performed according to Canadian Association of Oilwell Drilling Contractors ( CAODC) blowout prevention and well control procedure chart
E-14.06.02P	function test well control equipment	well control equipment is function tested according to regulations
E-14.06.03P	identify primary and secondary *kick warning signs*	primary and secondary *kick warning signs* are identified
E-14.06.04P	determine validity of signs and responses	appropriate responses to the warning signs are determined according to CAODC protocol and jurisdictional regulations
E-14.06.05P	select valve alignment	valve alignment is selected according to well control method
E-14.06.06P	operate *BOP controls* to shut in the well	*BOP controls* are operated according to company policies and OEM recommendations
E-14.06.07P	light flare stack	flare stack is lit to burn off gas at surface
E-14.06.08P	read and record *well control data*	*well control data* is read and recorded
E-14.06.09P	determine *type of well control method* to apply	*type of well control method* is determined according to well characteristics and regulations
E-14.06.10P	increase mud density, if required	mud density is increased as required to achieve required weight to kill well by adding *additives* according to operator instructions
E-14.06.11P	circulate out contaminated mud while monitoring tank volumes and maintaining drill pipe pressure	contaminated mud is circulated out to reduce the risk of a second influx (kick)
E-14.06.12P	troubleshoot *changing conditions*	*changing conditions* are resolved
E-14.06.13P	evaluate conditions to determine next steps	next steps are determined according to evaluation and regulations

Range of Variables

inspections for well control include: stabbing valve and inside BOP, BOP and related valve handles, flare and degasser lines, flare igniter checks, accumulator (gauges, fluid levels, leaks) and BOP equipment, valve alignment and gauges in choke manifold

kick warning signs include: primary: increase in flow from well, increase in mud tank volume, well flows on its own, hydraulicing pipe; secondary: erratic torque, fluctuations in weight indicator, rapid change in mud properties, change in pump pressure, loss of volume, fluid dropping in the well, drilling break, pulling wet after pulling dry while tripping, improper hole fill volume

BOP controls include: annular preventers, pipe rams, blind rams, hydraulically controlled remote (HCR) valve, remote choke

well control data includes: shut-in drill pipe pressure, shut-in casing pressure, MACP, pit gain, initial circulating pressure (ICP), reduced speed pump pressure (RSPP), final circulating pressure (FCP)

type of well control methods include: driller’s method, concurrent method, circulate-and-weight method, wait-and-weight method, volumetric method, low choke, modified low choke

additives include: barite, bentonite, calcium carbonate

changing conditions include: plugged jets, sloughing hole, loss of circulation, plugged choke, washed choke, wash in drill string

	Knowledge
	Learning Outcomes	Learning Objectives
E-14.06.01L	demonstrate knowledge of crew members’ roles in well control procedures	describe the crew members’ roles in well control procedures
		identify the warning signs and causes of a kick
		describe the function of the stabbing valve and inside blowout preventer
		explain MACP
		identify correlations between gauge readings
		describe the functions of kick detection equipment
		describe BOP drill requirements
		explain the purpose of kill mud
		identify crucial pressures
		describe well control methods
		identify abbreviations and formulas for well control
		explain well control calculations
		identify the difference between primary and secondary *kick warning signs*
		identify the difference between a soft shut-in and a hard shut-in
		explain the primary, secondary, and tertiary levels of well control
		interpret and use the well control formulas and tables
		describe a leak-off test
		describe a formation integrity test
		calculate accumulator requirements
		complete well control kill sheets
		identify the advantages and disadvantages associated with each of the secondary methods of well control
		explain troubleshooting methods during well control to address *changing conditions*

Range of Variables

changing conditions include: plugged jets, sloughing hole, loss of circulation, plugged choke, washed choke, wash in drill string

Task E-15 Performs tripping activities

Task Descriptor

Tripping (pulling or running tubulars out of, or into, the wellbore) is necessary for multiple reasons. These reasons may include the change of the drill bit or BHA, doing wiper trips, and after achieving total depth (TD).

E-15.01 Prepares for trip

Essential Skills

Oral Communication, Thinking, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-15.01.01P	organize tools and equipment for tripping activities	tools and equipment for tripping activities are organized according to rig specifications
E-15.01.02P	inspect and prepare *tripping equipment*	*tripping equipment* is prepared and inspected for missing, damaged or worn components
E-15.01.03P	set up catwalks, bird baths, monkeyboard and pipe racks	catwalks, bird baths, monkeyboard and pipe racks are set up according to rig specifications
E-15.01.04P	set up trip tank	trip tank is set up to monitor and fill hole with drilling fluid
E-15.01.05P	prepare circulating system for winter operations	circulating system is prepared for winter operations according to rig procedures
E-15.01.06P	calculate hole fill volumes and record on trip sheet	hole fill volumes are calculated according to trip conditions and recorded on trip sheet
E-15.01.07P	prepare and pump high density pill	high density pill is prepared and pumped

Range of Variables

tripping equipment includes: pipe spinners, iron roughneck, rig tongs, pipe arm, dog collars, catwalk, slips, elevators, pipe wipers (strippers), iron derrickhand, crown saver, safety stops, bails

	Knowledge
	Learning Outcomes	Learning Objectives
E-15.01.01L	demonstrate knowledge of motorhand’s role in preparing for trip	identify equipment used for tripping operations
		describe the procedures used to inspect tripping equipment
		describe preparations on the drill floor for tripping
		explain procedures used to set up catwalks, bird baths, pipe racks and trip tank
E-15.01.02L	demonstrate knowledge of derrickhand’s role in preparing for trip	describe monkeyboard preparation for tripping
		identify hazards and safe operating procedures when tripping
		explain procedures used to set up mud tank for tripping
E-15.01.03L	demonstrate knowledge of driller’s role in preparing for trip	calculate hole fill volumes/trip data
		document trip record
		explain flow check requirements during tripping
		describe cold weather preparation for tripping
		identify hazards and safe operating procedures when tripping
		describe procedures to organize pipe placement before tripping

E-15.02 Trips drill string and bottomhole assembly (BHA)

Essential Skills

Oral Communication, Working with Others, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-15.02.01P	monitor fluid volumes for accuracy and record on trip sheet	fluid volumes are monitored while tripping and at flow check intervals and recorded on trip sheet and volume discrepancies are interpreted
E-15.02.02P	hoist or lower drill string	drill string is hoisted and lowered while monitoring weight indicator
E-15.02.03P	make up and break tubulars	tubulars are made up and broken using *tools*
E-15.02.04P	handle tubulars with *equipment*, as required	tubulars are handled with *equipment* as required
E-15.02.05P	use winches on the rig floor	winches on the rig floor are used to manipulate *drilling tools*
E-15.02.06P	contain mud to floor area	mud is contained to floor area using mud containment systems
E-15.02.07P	perform flow checks	flow checks are performed according to regulations and IRP
E-15.02.08P	perform pipe count	pipe count is performed and verified to match the tally
E-15.02.09P	change BHA and relative tally, if required	BHA and relative tally are changed, if required, according to operator’s instructions

Range of Variables

tools include: tongs, iron roughnecks, pipe spinners, slips, pipe arm, top drive

equipment includes: iron derrickhand, launchers, skate, wranglers, pipe arm, top drive

drilling tools include: pickup subs, jars, bits, bit subs, specialized drilling tools

	Knowledge
	Learning Outcomes	Learning Objectives
E-15.02.01L	demonstrate knowledge of motorhand’s role in tripping drill string and BHA	explain floor preparation
		describe the procedures used to transfer fluid into or out of the trip tank
		describe the procedures for use of tools used to trip drill string and BHA
E-15.02.02L	demonstrate knowledge of derrickhand’s role in tripping drill string and BHA	describe hand signals and other communication methods used between a derrickhand and a driller
		identify hazards and safe operating procedures associated with tripping
		describe activities performed at the monkeyboard
E-15.02.03L	demonstrate knowledge of driller’s role in tripping drill string and BHA	describe procedures used to monitor fluid levels
		identify *tools* required to make up and break pipe and collars
		perform pipe count/tallies
		identify hole conditions for trip speeds
		identify hazards and safe operating procedures when using winches
		identify hazards and safe operating procedures when tripping

Range of Variables

tools include: tongs, iron roughnecks, pipe spinners, slips, pipe arm, top drive

E-15.03 Lays down tubulars

Essential Skills

Working with Others, Thinking, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-15.03.01P	flush tubular, as required	tubular is flushed to prevent corrosion of tubular and for environmental reasons
E-15.03.02P	install lifting nubbins, pickup subs and protectors prior to laying down	lifting nubbins, pickup subs and protectors are installed prior to laying down according to rig specifications
E-15.03.03P	lower tubulars	tubulars are lowered using *equipment*
E-15.03.04P	tier pipe on pipe racks or tubs	pipe is tiered on pipe racks using stripping, chocks and loader

Range of Variables

equipment includes: hydraulic catwalks, winches, loaders, laydown lines, pipe arm, laydown truck, bumper block

	Knowledge
	Learning Outcomes	Learning Objectives
E-15.03.01L	demonstrate knowledge of laying down tubulars	describe types and grades of tubulars
		identify types of *equipment* used to lower tubulars
		describe the procedures used to handle tubulars
		identify types of storage used for tubulars

Range of Variables

equipment includes: hydraulic catwalks, winches, loaders, laydown lines, pipe arm, laydown truck, bumper block

Task E-16 Performs casing activities

Task Descriptor

Rig technicians are responsible for ensuring that casing strings are prepared for running.

Surface casing provides a suitable anchor for the BOP stack and well control, and isolates surface groundwater from the wellbore.

Intermediate casing provides a means of well control and protects against unstable formations such as loss circulation zones and high pressure zones.

Production casing provides the means to transport the hydrocarbons to the surface.

When running casing, rig technicians must work with third-party equipment and contractors.

E-16.01 Prepares casing

Essential Skills

Numeracy, Working with Others, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-16.01.01P	unload and tier casing	casing is unloaded and tiered using loader, boom truck (picker) or excavator
E-16.01.02P	remove casing protectors to drift and visually inspect threads	casing protectors are removed and threads are visually inspected to identify casing defects and drifted to identify uniform ID
E-16.01.03P	number and measure casing, float collars, shoe joints and marker joints	casing, float collars, shoe joints, marker joints and other casing-related tools are numbered and measured

	Knowledge
	Learning Outcomes	Learning Objectives
E-16.01.01L	demonstrate knowledge of procedures used to prepare casing	identify types of equipment used to unload casing
		explain the crew members’ roles in preparing casing
		describe the setup and preparation of casing
		identify hazards and safe operating procedures for preparing casing
		describe procedures used to identify casing defects
		describe the purpose of running casing
		describe casing string design
		describe how casing is matched with well control equipment

E-16.02 Installs casing equipment

Essential Skills

Oral Communication, Working with Others, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-16.02.01P	inspect *third-party service provider equipment*	*third-party service provider equipment* is inspected to ensure that it is certified according to IRP
E-16.02.02P	hoist *third-party service provider equipment* to rig floor	*third-party service provider equipment* is hoisted to rig floor using rigging/hoisting equipment
E-16.02.03P	hang up power tongs or rig-in top drive casing running tool	power tongs or rig-in top drive casing running tool are hung up according to rig specifications
E-16.02.04P	attach elevators to bails	elevators are attached to bails according to rig specifications
E-16.02.05P	hook up casing fill equipment	casing fill equipment is hooked up according to rig specifications
E-16.02.06P	hook up pipe alignment tool and stabbing board	pipe alignment tool and stabbing board are hooked up according to rig specifications
E-16.02.07P	rig in third-party thread monitoring system, if required	third-party thread monitoring system is rigged in, if required according to operator’s instructions

Range of Variables

third-party service provider equipment includes: power tongs, elevators, spider, slips, bail extensions, top drive casing running tool, fill hose

	Knowledge
	Learning Outcomes	Learning Objectives
E-16.02.01L	demonstrate knowledge of procedures used to install casing equipment	identify types of *third-party service provider equipment* required to install casing, their applications and procedures for use
		identify the types of certifications that are required on site
		identify hazards and safe operating procedures when installing casing equipment

Range of Variables

third-party service provider equipment includes: power tongs, elevators, spider, slips, bail extensions, top drive casing running tool, fill hose

E-16.03 Runs casing

Essential Skills

Working with Others, Oral Communication, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-16.03.01P	raise casing to the rig floor	casing is raised to the rig floor using *retrieval equipment*
E-16.03.02P	pick up casing with elevators or top drive casing running tool	casing is picked up with elevators or top drive casing running tool and set in previous joint (stump)
E-16.03.03P	centre and stabilize casing, if necessary	casing is centred and stabilized, if necessary
E-16.03.04P	make up casing joints together	casing joints are screwed together using *tools and equipment* according to manufacturers’ specifications or operator’s instructions
E-16.03.05P	install *casing accessories*	*casing accessories* are installed according to operator’s instructions
E-16.03.06P	lower casing into wellbore	casing is lowered into wellbore according to operator’s instructions
E-16.03.07P	fill casing	casing is filled according to operator’s instructions and rig procedures

Range of Variables

retrieval equipment includes: winch lines, hydraulic catwalk, pipe arm

tools and equipment include: chain tongs, third-party power tongs, top drive casing running tool, slips, bails, elevators

casing accessories include: centralizers, scratchers, turbolizers, cement basket, spiralizers, stand-off bands, packers, frac ports

	Knowledge
	Learning Outcomes	Learning Objectives
E-16.03.01L	demonstrate knowledge of procedures used to run casing	explain the crew members’ roles in running casing
		identify types of *tools and equipment* required to run casing, their applications and procedures for use
		identify hazards and safe operating procedures for running casing

Range of Variables

tools and equipment include: chain tongs, third-party power tongs, top drive casing running tool, slips, bails, elevators

E-16.04 Circulates casing

Essential Skills

Thinking, Numeracy, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-16.04.01P	install *circulating equipment*	*circulating equipment* is installed according to operator’s instructions
E-16.04.02P	initiate circulation	circulation is initiated with high precautions to maintain wellbore integrity
E-16.04.03P	circulate casing	casing is circulated using *circulating equipment* according to rig specifications
E-16.04.04P	reciprocate casing	casing is reciprocated
E-16.04.05P	monitor circulating parameters	circulating parameters are monitored for *unexpected changes* and react according to operator’s instructions
E-16.04.06P	condition drilling fluid	drilling fluid is conditioned according to operator’s instructions

Range of Variables

circulating equipment includes: circulating head, chiksan, top drive casing running tool, circulating hoses

unexpected changes include: change in pressure, volumes, string weight, drilling fluid properties, torque

	Knowledge
	Learning Outcomes	Learning Objectives
E-16.04.01L	demonstrate knowledge of procedures used to circulate casing	explain the crew members’ roles in circulating casing
		identify types of equipment required to circulate casing, their applications and procedures for use
		describe potential *hole conditions* and how to adjust parameters to correct
		describe procedures used to condition drilling fluid
		identify formulas related to volumes and circulating times

Range of Variables

hole conditions include: wellbore packing off (hydraulicing), loss of circulation, sloughing wellbore

E-16.05 Performs cementing operations

Essential Skills

Thinking, Working with Others, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-16.05.01P	hoist required *third-party service provider cementing equipment* to rig floor	*third-party service provider cementing equipment* is hoisted to the rig floor using rigging/hoisting equipment
E-16.05.02P	bleed off rig circulation equipment and disconnect	rig circulation equipment is bled off and disconnected according to rig procedures
E-16.05.03P	install required *third-party service provider cementing equipment*	*third-party service provider cementing equipment* is installed according to third-party service provider instructions
E-16.05.04P	reciprocate casing	casing string is reciprocated to prevent channelling of cement and to ensure bond
E-16.05.05P	monitor casing movement and fluid returns to identify *cementing problems*	*cementing problems* are identified by monitoring casing movement and fluid returns
E-16.05.06P	chain down casing when plug is dropped to counter hydraulicing, if required	casing is chained down when plug is dropped to counter hydraulicing on shallow casing applications, if required
E-16.05.07P	transfer drilling fluids to cementers’ equipment, if required	drilling fluids are transferred to cementers’ equipment according to operator’s instructions, if required
E-16.05.08P	flush conductor barrel or BOP with water	conductor barrel or BOP is flushed with water to clean cement out of components
E-16.05.09P	install and set *hang-off equipment*	*hang-off equipment* is installed and set with casing string in tension according to operator’s instructions
E-16.05.10P	rig out *third-party service provider cementing equipment*	*third-party service provider cementing equipment* is rigged out

Range of Variables

third-party service provider cementing equipment includes: cementing head, manifold, hard lines, hoses, wiper plugs, bump plugs, cement pumper

cementing problems include: hydraulicing of casing, loss of returns, over-pull

hang-off equipment include: casing slips, mandrel hangers, hangers

	Knowledge
	Learning Outcomes	Learning Objectives
E-16.05.01L	demonstrate knowledge of procedures used to perform cementing operations	explain the crew members’ roles in performing cementing operations
		identify types of *third-party service provider cementing equipment* used to cement casing
		describe procedures used to prevent channelling of cement
		describe how to prepare tanks for displacement and cementing casing
		describe casing hydraulics and prevention
		identify hazards and safe operating procedures for performing cementing operations
		identify the types of cement programs

Range of Variables

third-party service provider cementing equipment includes: cementing head, manifold, hard lines, hoses, wiper plugs, bump plugs, cement pumper

Task E-17 Performs specialized drilling operations

Task Descriptor

These operations require specialized skills. They all may involve third-party contractors.

Coring is done primarily to obtain samples for geological analysis and testing.

Directional drilling curves the well during the drilling process using specialized equipment. It is done to increase production and locate deposits that are not directly beneath the surface location.

Underbalanced drilling is done to prevent damage to formations that may occur using conventional drilling fluid.

Managed pressure drilling (MPD) is done to drill at a higher ROP without increasing the mud weight and maintaining bottomhole pressure for the purpose of well control.

E-17.01 Performs coring activities

Essential Skills

Working with Others, Oral Communication, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-17.01.01P	assemble and disassemble *coring tools*	*coring tools* are assembled and disassembled according to coring hand’s instructions
E-17.01.02P	verify condition of wellbore prior to tripping operations	condition of wellbore is verified to ensure proper coring
E-17.01.03P	drill core sample	core sample is drilled with *coring tools* according to coring hand’s instructions
E-17.01.04P	retrieve, handle and package core	core is retrieved, handled and packaged using methods and procedures according to drilling plan and geologist’s instructions
E-17.01.05P	follow third-party service provider parameters and instructions	third-party service provider parameters and instructions are followed

Range of Variables

coring tools include: coring bits, barrels, catchers, clamps, pickup subs, sleeves, pup joints, wireline unit, core pipe

	Knowledge
	Learning Outcomes	Learning Objectives
E-17.01.01L	demonstrate knowledge of *coring tools* and coring procedures	identify *coring tools* their operation and procedures for use
		describe *coring tool* assembly
		describe *coring operations*
		explain purpose for coring

Range of Variables

coring tools include: coring bits, barrels, catchers, clamps, pickup subs, sleeves, pup joints, wireline unit, core pipe

coring operations are wireline retrievable and conventional

E-17.02 Performs directional drilling

Essential Skills

Working with Others, Digital Technology, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-17.02.01P	assemble and disassemble directional tools	directional tools are assembled and disassembled
E-17.02.02P	follow third-party service provider parameters and instructions while drilling	third-party service provider parameters and instructions are followed while drilling
E-17.02.03P	perform surveys with *directional tools and equipment*	surveys are performed according to manufacturers' specifications
E-17.02.04P	steer mud motor	mud motor is steered using *equipment*
E-17.02.05P	troubleshoot *communication issues* with survey tools	*communication issues* are resolved

Range of Variables

directional tools and equipment include: rotary steering, push-the-bit systems, steer-the-bit systems, MWD equipment, pipe screens

equipment includes: table brake, top drive, automated steering and oscillating systems

communication issues include: magnetism, aerated mud, pulsation problems

	Knowledge
	Learning Outcomes	Learning Objectives
E-17.02.01L	demonstrate knowledge of procedures used to perform directional drilling	identify *directional tools and equipment*, and their procedures for use
		describe procedures used to assemble and disassemble directional tools
		describe procedures used in directional drilling
		describe methods for troubleshooting *communication issues* while directional drilling
		describe *profile of deviated wells*
		explain differential pressures related to directional drilling

Range of Variables

directional tools and equipment include: rotary steering, push-the-bit systems, steer-the-bit systems, MWD equipment, pipe screens

communication issues include: magnetism, aerated mud, pulsation problems

profiles of deviated wells include: S-curves, extended reach, horizontal, long, short and medium radius build sections, multilateral, tangent, build-and-turn

E-17.03 Performs underbalanced drilling (UBD) and managed pressure drilling (MPD)

Essential Skills

Working with Others, Thinking, Numeracy

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-17.03.01P	assemble and disassemble underbalanced and managed pressure tools and equipment	underbalanced and managed pressure tools and equipment are assembled and disassembled according to third-party procedures
E-17.03.02P	follow third-party service provider parameters and instructions while drilling	third-party service provider parameters and instructions are followed while drilling
E-17.03.03P	use *communication methods*	*communication methods* are used to ensure timing and procedures are effectively followed according to IRP
E-17.03.04P	monitor gas and pressure while performing drilling and tripping operations	gas and pressure are monitored for levels according to the drilling plan and formation pressures
E-17.03.05P	shut in and equalize pressure during connections	pressure is shut in and equalized during connections according to formation pressures
E-17.03.06P	perform underbalanced tripping operations	underbalanced tripping operations are performed according to operator’s instructions
E-17.03.07P	perform snubbing and stripping procedures while underbalanced drilling ( UBD)	snubbing and stripping procedures are performed according to jurisdictional regulations

Range of Variables

communication methods includes: two-way radios, hand signals, written instructions

	Knowledge
	Learning Outcomes	Learning Objectives
E-17.03.01L	demonstrate knowledge of procedures used to perform UBD	identify tools and equipment used in UBD operations and describe the procedures for use
		describe UBD operations
		describe snubbing and stripping procedures
		identify *communication methods* and their procedures for use during UBD
E-17.03.02L	demonstrate knowledge of managed pressure drilling ( MPD)	identify tools and equipment used in MPD operations and describe the procedures for use
		describe MPD operations
		explain the effects of gas and pressure while performing drilling and tripping operations
		describe MPD tripping operations and considerations for mud displacement

Range of Variables

communication methods includes: two-way radios, hand signals, written instructions

Task E-18 Performs specialized well operations

Task Descriptor

Fishing and stuck pipe operations are important to deal with unexpected complications during drilling operations.

Wireline logging is done to profile down-hole conditions. Wireline loggers’ readings are used by geologists, and the surface equipment itself is rigged in and out by rig technicians.

Drill stem testing is done to test production in a specific zone. It is performed by rig technicians under the direction of a third-party.

Sour wells, which contain H₂S, must be detected because of the extreme danger associated with this noxious gas.

Well completions are important because they set the stage for well production or abandonment.

E-18.01 Performs fishing and stuck pipe operations

Essential Skills

Working with Others, Oral Communication, Thinking

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-18.01.01P	operate controls to free drill string	controls are operated to free drill string using *procedures* according to operator’s instructions, company policies and IRP
E-18.01.02P	use *fishing tools and equipment* to retrieve stuck, twisted off or dropped pipe and junk	*fishing tools and equipment* are used to retrieve stuck, twisted off or dropped pipe and junk according to third-party instructions

Range of Variables

procedures include: jarring, spotting oil, spotting acid, manoeuvering drill string (working stuck/tight pipe), wireline operations (free pointing, perforating, chemical cutting, tool joint locating, mechanical backoff)

fishing tools and equipment include: washover pipe, magnets, spears, grapples, overshots, surface jars, bumper subs, baskets, junk subs, perforating guns

	Knowledge
	Learning Outcomes	Learning Objectives
E-18.01.01L	demonstrate knowledge of procedures used to perform stuck pipe operations	describe stuck pipe operations
		describe the instruments and controls of the drilling console
		describe the *procedures* used to free drill string
E-18.01.02L	demonstrate knowledge of procedures used to perform fishing operations	describe fishing operations
		identify types of *fishing tools and equipment* used to retrieve pipe

Range of Variables

fishing tools and equipment include: washover pipe, magnets, spears, grapples, overshots, surface jars, bumper subs, baskets, junk subs, perforating guns

E-18.02 Rigs wireline loggers in and out

Essential Skills

Working with Others, Oral Communication, Document Use

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-18.02.01P	operate controls to pick up wireline equipment with winches and blocks	wireline equipment is picked up with winches and blocks by operating controls
E-18.02.02P	assist third-party service providers by hanging and anchoring sheaves	sheaves are hung and anchored at height specified by third-party and rig specifications
E-18.02.03P	visually monitor well while logging	well is visually monitored while logging for flow or loss

	Knowledge
	Learning Outcomes	Learning Objectives
E-18.02.01L	demonstrate knowledge of procedures used to rig wireline loggers in and out	describe the procedures used to rig wireline loggers
		describe the procedures used to pick up wireline equipment
		identify the type of equipment used to pick up wireline equipment
		identify *safety hazards* specific to wireline loggers
		identify certification requirements for wireline equipment

Range of Variables

safety hazards include: radioactive materials, overhead hazards, wireline truck, catwalk/floor areas

E-18.03 Performs drill stem testing (DST)

Essential Skills

Working with Others, Oral Communication, Continuous Learning

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-18.03.01P	rig up *surface test equipment*	*surface test equipment* is rigged up
E-18.03.02P	operate controls to bring downhole test tools to rig floor	downhole test tools are brought to rig floor by operating controls
E-18.03.03P	assemble downhole test tools onto bottom of drill pipe	downhole test tools are assembled onto bottom of drill pipe according to third-party service provider instructions
E-18.03.04P	trip in and position drill string and downhole test tools	drill string and downhole test tools are tripped in and positioned according to company and third-party directions
E-18.03.05P	ignite flare stack to burn gas at surface	flare stack is ignited to burn gas at surface
E-18.03.06P	open and close tool	tool is opened or closed in order to conduct drill stem test according to operator’s requirements
E-18.03.07P	collect test samples	test samples are collected during tests according to operator’s requirements
E-18.03.08P	displace formation fluids and/or gases	formation fluids and/or gases are displaced using reverse circulation procedures

Range of Variables

surface test equipment includes: manifold, tanks, risers, test lines

	Knowledge
	Learning Outcomes	Learning Objectives
E-18.03.01L	demonstrate knowledge of procedures used to perform drill stem testing	describe types of drill stem testing
		explain procedures used to rig up *surface test equipment*
		explain procedures used to assemble downhole test tool onto bottom of drill pipe
		explain the importance and purpose of burning gas at surface
		explain reverse circulation procedures used to displace formation fluids and/or gases

Range of Variables

surface test equipment includes: manifold, tanks, risers, test lines

E-18.04 Performs sour well operations

Essential Skills

Thinking, Document Use, Working with Others

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-18.04.01P	monitor for sour gas	presence of sour gas is monitored using *equipment*
E-18.04.02P	operate controls while wearing *breathing apparatus*	controls are operated while wearing *breathing apparatus*
E-18.04.03P	perform *safety drills*	*safety drills* are performed periodically according to regulations and company policies
E-18.04.04P	respond to sour gas release at surface	response to sour gas release is completed according to sour well control procedures

Range of Variables

equipment includes: hand held units, mounted monitoring equipment

breathing apparatus includes: SCBA, third-party service provider supplied air breathing apparatus (SABA)

safety drills include: man-down, BOP, high angle rescue, evacuation

	Knowledge
	Learning Outcomes	Learning Objectives
E-18.04.01L	demonstrate knowledge of procedures used to perform sour well operations	define sour gas
		describe procedures used to monitor for sour gas
		describe procedures used in the event of a sour gas release
		identify types of *equipment* used to monitor for sour gas and their placement
		identify types of *PPE and safety* *equipment* used around sour gas
		explain H ₂S regulatory requirements

Range of Variables

equipment includes: hand held units, mounted monitoring equipment

PPE and safety equipment includes: SCBA, SABA, windsocks, light bars, sirens, air trailers, hoses, egress packs, H₂S sensors, flare guns, blowout ignition system, BOP stack

E-18.05 Completes the well

Essential Skills

Working with Others, Numeracy, Oral Communication

NL	NS	PE	NB	QC	ON	MB	SK	AB	BC	NT	YT	NU
NV	NV	NV	ND	ND	ND	NV	yes	yes	yes	NV	ND	ND

	Skills
	Performance Criteria	Evidence of Attainment
E-18.05.01P	set packers and bridge plugs	packers and bridge plugs are set to required depth according to regulations and operator’s instructions
E-18.05.02P	run *production casing*	*production casing* is run according to IRP and well plan
E-18.05.03P	position drill string for required cement plug intervals	drill string is positioned for required cement plug intervals according to regulatory requirements
E-18.05.04P	install wellhead or bonnet after nippling down BOPs	wellhead or bonnet is installed after nippling down BOPs according to IRP and third-party instructions

Range of Variables

production casing includes: tubing, slotted liners, blank liners, fracture (frac) assemblies

	Knowledge
	Learning Outcomes	Learning Objectives
E-18.05.01L	demonstrate knowledge of procedures used to complete the well	describe the purpose of running *production casing*
		describe cement plug operations
		describe bridge plug operations
		describe pressure testing of bridge plug
		describe the purpose of installing a well head or bonnet

Range of Variables

production casing includes: tubing, slotted liners, blank liners, fracture (frac) assemblies

Date modified:: 2018-01-31