Land rig handbook

The Wee Land Rig handbook
An introduction to safer land based drilling operations
Peter Aird..
December 2008 Rev 1.
.

The ‘Wee’ Land Rig Handbook.
The oil and gas industry employs hundreds of thousands of people and is a vital
component of the World economy. Drilling quality, safety, health and environmental
accidental loss control prevention is thus vital to the success of this industry.
This documents intent is to introduce drilling tasks and activities in order persons to be
enabled to identify the common work hazards and risk management controls needed to
reduce, mitigate and prevent accidental loss, unplanned events and personal injuries from
occurring on a day to day basis.
I hope it aids to do simply this.
Peter Aird.
December 2008 rev 1.
An introduction to drilling operations

Introduction
All companies in the oil and gas industry have individual operational
standards, instructions, health, safety and environmental programs.
This document does not replace these solely providing only an
ties
d
is
orker safety awareness is necessary to prevent all accidental loss
t the end of many sections, typical hazards and potential solutions
s.
overview to the typical operational tasks, key aspects and activi
needed to be safely managed and control the hazards and risks that
may exist at the worksite Ref. disclaimer on page 3
This document principle intent is for use in familiarization training,
educational and personal development to better understand,
comprehend and realize the workplace hazards that exist to enable
persons to apply corrective solutions to their daily operational
activities. This document cannot identify all the hazards, risk an
solutions that exist, serving only as a guide. Finally the focus of th
document is prevalent to land based operations only.
W
at the workplace including personal injury prevention during all
phases of drilling and servicing operations. Procedures and
processes will include safety meetings, Job Safety Analyses, risk
assessments and general and task-specific training.
A
are identified to provide more details needed to be considered to
assure safe work practices and procedures are followed at all time

Disclaimer
is not a standard, nor regulation, and creates no new or otherwise
ees
t
ealth Acts will exist in each specific operating region, location and/or
hazard-
yers
tion.
il and Gas Industry Disclaimer:
m recognized and credible sources, it
othing contained herein shall be construed to establish an industry-accepted standard
f
This document
legal obligations. The document service only as an advisory guide, where all
informational contained in content is intended to assist employers and employ
in providing a safe, healthful and environmentally complaint workplace through
effective prevention programs adapted to the needs of each place of employmen
tools, equipment, practices and procedures used. .
H
environment and will require employers and employees to comply with
specific safety and health standards. In addition, employers must provide their
employees with a workplace free from recognized hazards likely to cause
equipment failure malfunction, injury, serious loss or physical harm. Emplo
can also often be cited for violating statutory rules and regulations if there is a
recognized hazard that they then do not take steps to prevent or abate the
hazard. However, failure to implement such guidelines is not, in itself, a viola
O
Although the document was developed fro
is not to be construed as an industry consensus standard as indicated in the
following disclaimer.
"N
of drilling or energy servicing safe operating procedures. No suggested method, practice,
precaution or program set forth in this guide should be relied upon to establish a legal
standard of conduct or a legal duty, the violation of which would constitute culpability o
any degree in any legal proceeding. Information and/or data provided is for
informational assistance only and should not be utilized or considered as a
comprehensive safety and health program or accepted industry standard."

Table of contents
The Wee Land Rig handbook ............................................................................................. 1
Introduction......................................................................................................................... 3
Disclaimer....................................................................................................................... 4
Table of contents............................................................................................................. 5
Safety and health program .................................................................................. 9
Hot work/Welding................................................................................................... 12
H2S ............................................................................................................................... 19
Release of H2S.............................................................................................................. 20
Site preparation ................................................................................................................. 24
Leveling site.................................................................................................................. 24
Excavation and trenching.............................................................................................. 25
Conductor hole, rat-hole and mouse-hole.................................................... 26
Transporting equipment.................................................................................................... 28
Transporting equipment by truck.................................................................................. 28
Unload at drill site......................................................................................................... 29
Drilling.............................................................................................................................. 30
Rigging Up.................................................................................................................... 30
Drilling ahead................................................................................................................ 41
Rotating Systems .......................................................................................................... 48
Rotating Systems .......................................................................................................... 49
Making a connection..................................................................................................... 51
Mud circulating system................................................................................................. 57
Drilling Fluids............................................................................................................... 63
Drilling Fluids............................................................................................................... 64
Tripping in and out........................................................................................................ 66
Casing operations.............................................................................................................. 74
Casing operations.............................................................................................................. 75
Installing casing tools ................................................................................................... 76
Running casing into the hole......................................................................................... 77
Installing casing accessories ......................................................................................... 78
Circulating and cementing............................................................................................ 79
Introduction to well control .............................................................................................. 81
Blowout Prevention Program........................................................................................ 84
Monitoring and Maintaining Mud System.................................................................... 85
Installing BOPs, Accumulator, and Choke Manifold ................................................... 86
Testing BOPs Accumulators, and Choke Manifold...................................................... 88
Maintaining Surface Control System............................................................................ 88
Maintenance activities ...................................................................................................... 89
Rig floor........................................................................................................................ 89
Drilling line maintenance..................................................................................... 91
Wire rope maintenance........................................................................................ 92
Mud circulation system ........................................................................................ 93
Generators, electrical motors and electrical systems .................................................... 94
Engines.......................................................................................................................... 95

Derrick equipment maintenance ................................................................................... 96
Appendices........................................................................................................................ 97
Appendix 1: Physical properties of H2S....................................................................... 97

Abbreviations
ADP Aluminium drill pipe MST Magnetic steering toll
AFE Authority for expenditure MW Mud weight
API American Petroleum Institute MWD Measurement while drilling
B/U Bottoms up NDT Non destructive testing
BHA Bottom hole assembly NMDC Non-magnetic drill collar
BHO Sub Bottom hole orientation sub NPT Non productive time
BHP Bottom hole pressure OBM Oil based mud
BOD Basis of Design OD Outside diameter
BOP Blow out preventer OIM Operation's installation manager
CBL Cement bond log OWE Offshore well engineer
CHH Casing head housing P&IDS Piping and instrumentation diagram
CLP Choke line pressure PBR Polished ball receptacle
CMC Carboxymethylcelluose PCWD Pressure control while drilling - rotating diverter
/ head
DC Drill collar PDC Polycrystalline diamond compact
DDR Daily drilling report PDHG
DIMS Drilling information management system PDM Positive displacement mud motor
DMS Drilling management system PFD Process flow diagram
DP Drill pipe POB Personnel on board
DS Drill string standard POBM Pseudo oil based mud
DST Drill string test POOH Pull out of hole
DSV Down hole safety valve PPG Pounds per gallon
DSV Drilling supervisor PSI Pounds per square inch
ECD Equivalent circulating density PTW permit to work
ECP External casing packer PVT Pit volume totaliser
ECPICV External casing packer internal control
valve
RDM Regional drilling manager
EMW Equivalent mud weight RIH Run in hole
ESD Emergency shut down ROV Remotely operated vehicle - robotic submarine
FG Formation pressure equivalent density RPM Revolutions per minute
FIT Formation integrity test RTTS Retrievable packer
FMS Flush mounted slips SCR Slow circulation rate
FMS Formal method statement SCSSV Sub surface safety valve
FRAC Fracture SF Safety factor
GOR Gas oil ratio SICP Shut in casing pressure
HAZOP Hazard and operability analysis SIDPP Shut in drill pipe pressure
HCR High closing ratio SPM Strokes per minute
HP High pressure SSP Stand pipe pressure
HPE Hydrostatic pressure equivalent of 1bbl
mud in well
TCL Tubing conveyed logging
HPHT High pressure high temperature TFA Total force area
HWDP Heavy weight drill pipe TIW Texas iron works
IBOP Internal blow out preventer TOC Top of cement
ID Internal diameter TRSSSV Tubing retrievable sub surface safety valve.
IFG Influx density TVD Total vertical depth
ISP TVDRKB Total vertical depth rotary Kelly bushing
IWCF International well control forum UBD Under balanced drilling
JSA Job Safety Analysis UBHOsub Universal bottom hole orientation sub
KOP Kick off point ULSEL Ultra-long spaced electronic log
KPI Key performance indicator VBR Variable bore rams
KT Kick tolerance WOH Weight on hook
LCM Lost circulation material W&W Wait & weight well kill method
LMRP Lower marine riser package WBM Water based mud
LOT Leak off test WEG
LP Low pressure WOB Weight on bit
LTI Lost time incident WWD World wide drilling
LWD Logging while drilling
MAASP Maximum annular allowable surface
pressure
MD Measured depth
MMSCF/D Million standard cubic feet per day

MODU Mobile offshore drilling unit
MPI Magnetic particle inspection
MPLT
MR Migration rate
Note: The drilling industry is characterized by abbreviations and names
which can sound weird or mean multiple things. To avoid
misunderstandings please ask if in doubt

General health and safety
The following pages list general safety and health concerns. Each topic
is linked to a page with more information about the activity and
sources of information.
 One of the first objectives of any company is to Establish a
safety and health program.
 Employers should seek consultation to advise about potential
hazards at their worksites, improve their occupational safety and
health management systems, and particularly focus on
behavioral safety programs for their employees.
Specific general health and safety topics covered here-in are:
 General Safety and Health Resources
 Slips, Trips, and Falls
 Strains and Sprains
 Weather Conditions
Safety and health program
General safety and health resources
General safety and health resource subject matters to cover are:
 Crane, Derrick, and Hoist Safety.
 Electrical.
 Fire Safety. OSHA Safety and Health Topics Page.
 Hand and Power Tools.
H2S Controls
- Confined Spaces.
- Pressure Vessels.
o Compressed Gas and Equipment.
o Control of Hazardous Energy (Lockout/Tagout)
 Hydrogen Sulfide
 Ventilation.
 Respiratory protection as it relates to oil fields.
- Hot Work - Welding
- Control of Hazardous Energy (Lockout/Tagout)

- Motor Vehicles Safety.
- Powered Industrial Trucks.
Personal Protective Equipment (PPE)
 Personal Protective Equipment (PPE).
 Eye and Face Protection.
 Personal Protective Equipment for General Industry.
 Noise and Hearing Conservation.
 Working at heights
Slips trips and falls
There are many ways to protect from slips, trips, and falls. Even so,
they still happen and the following are means to either prevent slips,
trips, and falls or to minimize the consequences if they should happen.
 Wear personal protective equipment (such as hard hats, work
gloves, safety shoes, and eye protection).
 Be aware of the slipping and falling hazards when working on the
drilling floor, servicing rig floors or other platforms.
 Keep all work areas clean and clear of oil, tools, and debris.
 Use non-skid surfaces where appropriate.
 Provide guardrails and guards around work areas that are prone
to slips, trips, and falls.
 Install, inspect, and secure stairs and handrails.
 Instruct workers on proper procedures for using and installing
ladders.
 Use only ladders in good repair that do not have missing rungs.
 Do not install stairs with missing or damaged steps. Repair them
before installing them.
 Keep walkways clean and free of debris and tripping hazards.
 Keep all cords and hoses orderly and clear of walking spaces.
 Cover open cellars.
 Conduct a pre-job inspection to identify, then eliminate or
correct hazardous work surfaces.
 Walking/Working Surfaces Standard requires: Keep all places of
employment clean and in an orderly condition.
 Keep aisles and passageways clear and in good repair, with no
obstruction across or in aisles that could create a hazard. Provide
floor plugs for equipment so power cords need not run across
pathways.

 Use waterproof footgear to decrease slip/fall hazards.
Strains and sprains
General solutions for strains and sprains include:
 Use proper lifting technique.
 Hoist slowly to limit pipe momentum.
 Seek assistance when moving awkward and heavy guards and
covers.
 Use proper stance and slip-lifting techniques. Slips have three
handles and should be lifted jointly by more than one person.
 Use lifting equipment and limit manual positioning of elevators.
 Practice proper hand placement and use of pullback (tail) ropes.
 Use mechanical lifting aids, proper lifting techniques, and team
lifting where appropriate.
 Use proper hand and body positioning.
 Ergonomics.
 Hand Injury
 Lifting
 Repetitive motions
Weather conditions
Weather conditions can create hazardous working conditions: therefore
it is necessary to monitor weather conditions and forecasts to allow
time to prepare for such conditions as may occur. Lightning is
especially hazardous and unpredictable. When lightning is present,
crews must avoid situations where they could become part of potential
current paths.

Hot work/Welding
ot work is any work that
at
t
l
s, tank batteries, gas separators, oil
 Hot Work, Fire, and Explosive Hazards
gnition Sources
Hot work fire and explosive
erforming hot work such
posed
s
om
otential Hazard:
 Getting burned by fires or
.
H
involves burning, welding,
using fire- or spark-
producing tools, or th
produces a source of
ignition. Welding and
cutting operations are
common to drilling and
servicing operations. Tes
for flammable gases in the
work area before starting
any hot work. Potentially
hazardous areas include,
but are not limited to, wel
heads, fuel tanks, mud tank
treaters, or confined spaces where gases can accumulate.
 Welding, Cutting and Brazing
 Cylinder Storage
 Grinding
 Well Site I
hazards
Workers p
as welding, cutting, brazing,
soldering, and grinding are ex
to the risk of fires from ignition of
flammable or combustible material
in the space, and from leaks of
flammable gas into the space, fr
hot work equipment.
P
explosions during hot work
Figure 1: Hot work welding
Figure 2: Welding with fire control.

Possible Solutions:
The basic precautions for fire prevention are:
 Perform hot work in a safe location, or with fire hazards removed
or covered.
 Use guards to confine the heat, sparks, and slag, and to protect
the immovable fire hazards.
Special Precautions:
 Do not perform hot work where flammable vapors or
combustible materials exist. Work and equipment should be
relocated outside of the hazardous areas, when possible.
 Make suitable fire-extinguishing equipment immediately
available. Such equipment may consist of pails of water, buckets
of sand, hose, or portable extinguishers.
 Assign additional personnel (fire watch) to guard against fire
while hot work is being performed. Fire watchers are required
whenever welding or cutting is performed in locations where
anything greater than a minor fire might develop.
 Fire watchers shall:
 Have fire-extinguishing equipment readily available
and be trained in its use.
 Be familiar with facilities for sounding an alarm in the
event of a fire.
 Watch for fires in all exposed areas, try to extinguish
them only when obviously within the capacity of the
equipment available, or otherwise sound the alarm.
 Maintain the fire watch at least a half hour after
completion of welding or cutting operations to detect
and extinguish possible smoldering fires.
Potential Hazard:
 Getting burned by a flash fire or explosion that results from an
accumulation of flammable gases, such as Methane or Hydrogen
Sulfide, around the wellhead area.

Possible Solutions:
 Monitor the atmosphere with a gas detector. If a flammable or
combustible gas exceeds 10 percent of the lower explosive level
(LEL), the work must be stopped.
 Identify the source of the gas and repair the leakage.
Additional References:
 Applicable standards with reference to
 Flammable and combustible liquids
 Welding, cutting, and brazing - general requirements
 Oxygen-fuel gas welding and cutting
 Arc welding and cutting
 Resistance welding
 American Petroleum Institute (API)
 RP 54, Recommended Practice for Occupational Safety for
Oil and Gas Well Drilling and Servicing Operations, Wireline
Service.
 Publication 2201, Procedures for Welding Or Hot Tapping
On Equipment Containing Flammables, (1995).
Welding cutting and brazing
All hot work is potentially
hazardous and a hazard
assessment should be
performed to determine where
the hazards exist.
Potential Hazard:
Figure 3: Welding - Hot work.
 Injury and illness caused
by hot work (such as,
welding fumes, UV light,
sparks, noise, or skin
injury).

Possible Solutions:
 Inspect the work area to ensure that all fuel and ignition sources
are isolated by shielding, clearing the area, lockout/tagout,
soaking flammable material with water.
 Wear appropriate PPE, such as face shield, leather welder's vest,
and gauntlet gloves. Use cotton or denim clothing.
 Provide UV shielding for arc welding where practical.
 Inspect welding and cutting equipment before use (arc or gas
welding/burning).
 Leak test gas torches, gauges, and hoses.
 Review the hot work permit if available.
 Ensure the availability of adequate fire watch/fire protection
equipment.
 Ensure adequate ventilation from toxic welding and cutting
fumes.
Special Hazard:
 Accumulation of toxic gases within a confined space.
 A hazardous atmosphere exists in oxygen-deficient (atmospheric
concentration of less than 19.5 percent) or oxygen-enriched
(atmospheric concentration of more than 23.5 percent).
Possible Solutions:
 Ventilate toxic metal fumes mechanically, if entering a confined
space, such as inside of a mud tank, water tank, oil tanks,
hoppers, sump, pit or cellar.
 Use a written permit system to document authorization to enter,
the work to be performed, and the results of the gas monitoring
where there is a potential for toxic, flammable, or oxygen-
deficient atmosphere. Both a hot work and confined entry permit
may be required for welding, cutting or brazing within a confined
space.

Additional Information:
 Recommended Safe Procedures and Guidelines for Oil and Gas
Well Servicing. Association of Energy Services Companies
(AESC).
 OSHA Fact Sheet. 54 KB PDF, 2 pages.
 Use of Anchors and Guywires. 72 KB PDF, 12 pages.
 Use of Compressed Gas Cylinders. 12 KB PDF, 3 pages.
 Crane Operation. 15 KB PDF, 4 pages.
 Proper Electrical Safety (including hot sticks). 17 KB PDF, 4
pages.
 Hot Work. 9 KB PDF, 2 pages.
 Fall Protection Systems. 16 KB PDF, 4 pages.
 H2S - Hydrogen Sulfide. 14 KB PDF, 2 pages.
 Respirator Usage. 68 KB PDF, 18 pages.
 Use of wooden, metal and plastic (fiberglass) portable
ladders. 17 KB PDF, 4 pages.
 Scaffolding. 23 KB PDF, 7 pages.
 Vehicle Operation. 10 KB PDF, 2 pages.
 Safety in Welding and Cutting
Cylinder storage Figure 4: Properly stored cylinders
Potential Hazard:
 Falling or rolling injuries from improper gas
cylinder storage
Possible Solutions:
 Ensure cylinders are properly stored in an upright
position and chained in separate racks.
 Store full and empty cylinders separately.

Potential Hazard:
 Valve opening or break off, exposing workers to toxic fumes and
flammable gas, caused by improper gas cylinder storage
Possible Solutions:
 Store cylinder properly.
 Always remove gauges and regulators, and install protective
valve caps before transporting.
Potential Hazard:
 Gas cylinders causing fires or explosions
Possible Solutions:
 Store cylinders in a dry, well-ventilated location.
 Avoid storing flammable substances in the same area as gas
cylinders.
 Avoid storing cylinders of oxygen within 20 feet of cylinders
containing flammable gases.
 Store all cylinders upright and chained in separate racks.
 Store full and empty cylinders separately.
Grinding
Figure 5: Hand Grinding
Potential Hazard:
 Grinding (that results in
sparks, noise, eye and skin
injury from flying metal
filings, grinding wheel pieces,
etc.).
 Having fingers or hands
caught in the grinding wheel,
resulting in amputation.
 Being struck by portable
grinder.

Possible Solutions:
 Wear appropriate PPE, such as face shield. Use cotton or denim
clothing.
 Inspect grinding equipment before use.
 Review the hot work permit if available.
 Ensure the availability of adequate fire watch/fire protection
equipment.
Ignition sources
There are a number of potential sources of ignition for flammable
gases and liquids on the drill site. It is necessary to provide for a
general ignition safety program which could pre-empt potential
hazards of fire and explosion.
Potential Hazard:
 Ignition and explosions of flammable gases or vapors from:
 Internal-combustion engine sparks
 Open flames from any source
 Smoking
 Welding operations
 Electric power tools
 Two-way radios
 Vehicles with catalytic converters
 Portable generators
Possible Solutions:
 Provide spark arrestors for internal-combustion engines.
 Post "NO SMOKING" signs wherever a flammable gas or vapor
hazard exists.
 Locate "spark producing" equipment or facilities well away from
potential hazard areas.
 Prohibit vehicles with catalytic converters from the immediate
vicinity of the rig.
 Prohibit open flames from the vicinity of the rig.

 American Petroleum Institute (API).
 RP 54, Recommended Practice for Occupational Safety for
Oil and Gas Well Drilling and Servicing Operations, Wireline
Service.
 RP 500, 3rd Edition, Classification of Locations for Electrical
Installations at Petroleum
Facilities Classified as Class 1, Division 1 and Division 2.
 RP 505, 2nd Edition, Classification of Locations for
Electrical Installations at Petroleum
Facilities Classified as Class 1, Zone 0, Zone 1 and Zone 2.
 Accident Prevention Reference Guide. International Association
of Drilling Contractors (IADC).
H2S
Note: It is not the intent of this section
to create an H S contingency plan.2
Hydrogen Sulfide or sour gas (H S) is a
flammable, colorless gas that is toxic at
extremely low concentrations. It is
heavier than air, and may accumulate
in low-lying areas. It smells like "rotten
eggs" at low concentrations and causes
you to quickly lose your sense of smell.
Many areas where the gas is found
have been identified, but pockets of the
gas can occur anywhere.
2
Iron sulfide is a byproduct of many
production operations and may
spontaneously combust with air.
Flaring operations associated with H S production will generate Sulfur
Dioxide (S0 ), another toxic gas.
2
2
Active monitoring for hydrogen sulfide gas and good planning and
training programs for workers are the best ways to prevent injury and
death.
Also see: NIOSH Classification of H S Hazard Areas.2
Figure 6: Hydrogen sulfide warning sign:
Warning Hazardous Area is in yellow
letters on a black background. In black
letters on a yellow background, the sign
says Hydrogen Sulfide, Extreme Health
Hazard, Fatal or Harmful if Inhaled

Release of H2S
All personnel working in an area where concentrations of Hydrogen
Sulfide may exceed the 10 Parts Per Million (PPM) should be provided
with training before beginning work assignments.
Potential Hazard:
 H2S exposure greater than the Permissible Exposure Limit (PEL)
Possible Solutions:
Implement an H S contingency plan (see API) including, but not
limited to:
2
 Appropriate instruction in
the use of hydrogen sulfide
safety equipment to all
personnel present at all
hydrogen sulfide hazard
areas.
 Gas detection where
hydrogen sulfide may exist.
 Appropriate respiratory
protection for normal and
emergency use. Respiratory
Protection Standard for
(H2S).
For emergency response
information, refer to Hazardous Waste and Emergency Response
standards.
Figure 7: SCBA

Comprehensive training should be provided for workers in H2S
operations. Example topics include:
 Identification of the characteristics,
sources, and hazards of Hydrogen
Sulfide.
 Proper use of the Hydrogen Sulfide
detection methods used on the site.
 Recognition of, and proper response
to, Hydrogen Sulfide warnings at the
workplace.
 Symptoms of Hydrogen Sulfide
exposure.
 Proper rescue techniques and first-
aid procedures to be used in a
Hydrogen Sulfide exposure.
 Proper use and maintenance of
personal protective equipment. Demonstrated proficiency in
using PPE should be required.
 Worker awareness and understanding of workplace practices and
maintenance procedures to protect personnel from exposure to
hydrogen sulfide.
 Wind direction awareness and routes of egress.
 Confined space and enclosed facility entry procedures.
 Locations and use of safety equipment.
 Locations of safe briefing areas.
 Use and operation of all Hydrogen Sulfide monitoring systems.
 Emergency response procedures, corrective action, and
shutdown procedures.
 Effects of Hydrogen Sulfide on the components of the Hydrogen
Sulfide handling system.
 The importance of drilling fluid treating plans prior to
encountering Hydrogen Sulfide.
 RP 49, Recommended Practice for Drilling and Well Servicing
Operations Involving Hydrogen Sulfide. American Petroleum
Institute (API), (2001, May/Reaffirmed 2007, March). Includes
well drilling, completion, servicing, workover, downhole
maintenance, and plug and abandonment procedures conducted
with hydrogen sulfide present in the fluids being handled.
Figure 8: Gas detector

Metal Fatigue
Metal fatigue, including hydrogen
embrittlement or sulfide stress
cracking, can result in a release of
hydrogen sulfide gas.
Potential Hazard:
 Being exposed to Hydrogen
Sulfide.
 Getting Injured due to
equipment failure.
Possible Solutions:
 Select materials in accordance with the MR0175/ISO15156
criteria for H2S service.
 MR 0175, Metals for Sulfide Stress Cracking and Stress
Corrosion Cracking Resistance in Sour Oilfield
Environments. National Association of Corrosion Engineers
(NACE), (2003, December) [Also ISO 15156, Petroleum
and natural gas industries—Materials for use in H2S
containing environments in oil and gas production,
International Standards Organization (ISO)].
 About MR 0175. Reviewed and approved 15
proposals for change to the standard.
 Treat drilling fluids to chemically reduce corrosion failures.
Figure 9: H2S metal failure

Accumulation of H2S
It is possible for hydrogen sulfide gas to accumulate in any low or
enclosed area, such as a gas venting system, mud system, cellars,
pits, and tanks.
Potential Hazard:
 Being exposed to Hydrogen Sulfide.
Possible Solutions:
 Provide adequate ventilation for the removal of any accumulation
of H2S.
 Implement effective confined space entry program.

Site preparation Figure 10: Clearing the site
Site preparation for an oil
and gas well, in most
instances, looks like any
other construction site.
Safety and Health
Regulations for Construction
are used to assess safety
compliance during this phase
of the development of a
drilling site.
Once the location for the
site has been established,
the area is prepared for drilling, with the following steps
Leveling site
The site is leveled (if necessary) with a bulldozer and/or a grader.
Potential Hazards: Figure 11 : Levelling uneven ground
 Damaging buried
pipelines and cables.
 Unpredictable weather
changes can create
unexpected hazards.
 Irritant and toxic
plants, pollens, and
other entrained
materials.
 Uneven ground may
cause bulldozers to roll
over.
Possible Solutions:
 Perform a site line location survey.
 Plan for hazards due to unpredictable changing weather.
 After weather changes, conduct inspections for new hazards.

 Protect employees engaged in site clearing from hazards of
irritant and toxic plants. Teach the employees about available
first aid treatments.
 Provide rollover guards on all equipment used in site clearing
operations.
 Provide overhead and rear canopy guards on rider-operated
equipment.
Excavation and trenching Figure 12: Mud pit
The scale and duration of
excavating and trenching are
very minor and site-specific. On
some drilling sites, a below-
ground-level cellar may be
excavated. This is where the
main borehole is to be drilled.
A reserve and settling pits may
also be excavated and are used
for water or drilling fluid (mud)
discharges.
Potential Hazards:
 Dust and other airborne contaminants can cause respiratory
problems or allergic reactions. Figure 13: Excavation on a land rig site
 Damaging buried pipelines
and cables.
Possible Solutions:
 Wear appropriate
respiratory protection.
 Perform a site line location
survey.

Conductor hole, rat-hole and mouse-hole
Figure 14: Conductor holePrior to commencing the rig-up
process, the conductor, rat-
hole and mouse-hole are
completed.
Special companies may be
hired to begin drilling these
three holes:
 Conductor hole and
conductor pipe
 Rathole
 Mouse hole
Conductor hole and conductor pipe
This is a largest diameter hole, lined with pipe, also called a starter
hole, variant in depth e.g. down of tens of feet to a few hundred feet depending
on the local geology.
Figure 15; installing conductor hole
Some sites e.g. where geology
permits, do not require a
conductor hole.
Potential Hazard:
 Being struck by hoisting
line or suspended drill or
casing.
Possible Solutions:
 Wear Personal Protective
Equipment: hard hats,
safety glasses, safety toe boots, and work gloves.
 Keep employees away if they are not working at this job.

Rat-hole
A rat-hole is a hole emanating from the rig floor, then 30 to 35 feet
deep below the drill floor, lined with casing that projects above the
floor, into which the kelly and/or tubulars are placed when tubular
hoisting or lowering operations are in progress.
This is either done by the portable rig that drills the conductor hole or
can be done by the primary rig after rigging-up.
Potential Hazard:
 Falling or stepping into an uncovered rathole.
Possible Solution:
 Cover the hole until it is lined with casing or other material
during rigging-up.
Mouse-hole Figure 16: General conductor mouse and rat-hole
arrangement.
A mouse-hole is a shallow bore
hole under the rig floor, usually
lined with pipe, in which joints
of drill pipe are temporarily
placed.
This is either done by the
portable rig that drills the
conductor hole or can be done
by the drilling rig after rigging-
up.
Potential Hazard:
 Falling or stepping into an uncovered mousehole.
Possible Solution:
 Cover the hole until it is lined with casing or other material
during rigging-up

Transporting equipment
Depending on the location of the
well, access to the site may
require preparation of a road bed.
A site, and its access road, must
accommodate a large number of
temporary and semi-permanent
structures and tanks, all brought
in by truck. The tasks are:
Figure 17: Transporting equipment
 Transporting equipment by
truck
 Unload at drill site
Transporting equipment by truck
Equipment is loaded on trucks at the previous drill site or storage yard,
secured and transported to
the new drill location.
Potential Hazards:
Figure 18: Transporting the derrick
- At a newly prepared
drill site, the soils may
not be compacted
sufficiently to support
the incoming load. This
could cause the load to
become unstable
- The load may not be secured properly, causing it to shift or the
tie-downs to fail.
- In slick conditions, the truck may slide off the road
Possible Solutions:
 Make sure that the access road and drill pad at the drill site has
been properly prepared before attempting to drive on it.
 Drive slowly; always being cautious of shifting weight.
 Loads should be tied down with proper devices and inspected
before and during transport. General rules for protection against
shifting or falling cargo generally exist and should be consulted.
 Always drive with caution, whatever the conditions.

Unload at drill site
Equipment is unloaded and placed approximately where it will be
rigged up.
Figure 19: Unload doghouse at drill site location
Potential Hazard:
 Improperly secured
loads could cause
equipment to slide or
collapse during
unloading.
Possible Solution:
 Inspect loads before
loading or unloading.

Drilling Figure 20; Typical land drilling rig
Worker safety awareness is
necessary for injury prevention
during all phases of drilling
operations. Procedures and
processes will include safety
meetings and general and task-
specific training. At the end of each
card, resources are identified which
provide more details for establishing
safe work practices and procedures.
Rigging Up
Rigging up is placing and assembling
the various parts of equipment that
make up the rig, and preparing the
rig for drilling.
There are many rig designs,
and this document does not
cover each type individually.
This document therefore
focuses on the common
hazards and solutions that
many rig designs share.
During assembly of the rig,
some equipment may be
handled and set with crane,
rig up trucks, or forklift,
depending on the size of the rig.
It should be noted that overhead
hazards such as high voltage
power lines may be present.
There may be two or more crews
(teams) working together in the
rigging up process. The rigging
up process includes the following
steps, some of which are done
simultaneously: (See servicing –
rigging up.)
Figure 21: Hoisting the drilling mast
Figure 22: Setting up the substructure.

Setting up the substructure
ositioned at or near the exact location
he substructure is assembled, pinned together, leveled, and made
quipping the cellar begins but can be done throughout the rigging up
otential Hazards:
 Being struck by the crane, load, truck, or forklift tipping.
Possible Solutions:
 Instruct all workers in safety procedures and ensure that they
nd other body
otect from burns.
Equipment is unloaded and p
that it will occupy during operations.
T
ready for other rig components on the floor.
E
process. This includes welding on a drilling nipple to the conductor pipe
and attaching a flow line.
P
 Pinched fingers when assembling equipment.
 Burns from cutting and welding on the drilling nipple.
 Temporary eye irritation from welding light flash.
 Falling from heights.
are knowledgeable about job hazards. This can be done during
pre-job safety meetings or JSA briefings.
 Instruct workers to stand clear and keep hands a
parts away from pinch points.
 Wear proper long sleeve clothing to pr
 Wear proper welding eye/face protection.
 Avoid looking directly at the flame or arc when welding.
 Wear fall protection when working from heights.

Setting up the rig floor and mast or derrick
place, the process of setting up
ails
e
d
e
e
to the draworks.
he bottom of the mast is raised to
e
thorough inspection of the mast sho
spooled onto the draworks
en
nt can
ncy
e
Once the substructure is set in
the rig floor begins. Begin by
installing stairways and guardr
to allow access to the rig floor.
Then, the draworks is set in plac
and secured to the substructure.
On mechanical rigs, the engines
are set in place and the
compound and associate
equipment connected to th
draworks. On electric rigs, th
electric cables (lines) are strung
T
the rig floor and pinned in place.
The crown section is then raised
into place on the derrick stand. Th
"A-legs" are raised and pinned into
place. The monkey board is pinned
in place on the mast and all lines
and cables are laid out to prevent
tangling when the mast is raised. A
uld be made before raising the
mast/derrick. The mast is now ready to be raised. The engines are
started, and the drilling line is
drum. Once the mast has be
raised and pinned, the
remaining floor equipme
be set into place. If the rig has
safety guy-lines, they must be
attached to the anchors and
properly tensioned prior to
continuing the rigging up
process. A derrick emerge
escape device is installed on th
mast.
Figure 23: Raising the doghouse and drill floor
Figure 25: Setting the mast on the rig floor
Figure 24: Setting the crown on the derrick stand

Figure 26: Rigging up the mastPotential Hazards:
 Falling or tripping during
rigging up.
 Falling from rig floor.
 Being struck by swinging
equipment.
 Being struck by falling
tools.
 Being crushed or struck
by equipment due to
failure or overloading of
hoisting equipment.
 Getting entangled in lines during raising of the derrick or mast.
 Failure to properly install derrick emergency escape device.
Possible Solutions:
Figure 27: Raising the mast Install, inspect, and secure
stairs and handrails.]
 Do not use guardrails for
anchor points or for lifting
or supporting loads.
 Use fall protection when
installing or removing
guardrails.
 Use a tag line to guide
equipment, rather than
positioning yourself under
suspended loads.
 Check the derrick for unsecured tools before raising it.
 Allow only the operator raising the mast to be on the rig floor.
 Uncoil all lines so that they are clear of all workers when the
mast or derrick is raised.
 Attach safety lines to all tools hanging from the rig.
 Keep a safe distance from moving equipment.
 Install derrick emergency escape device properly in accordance
with manufacturers recommendations.

Installing handrails, guardrails, stairs, walkways, ladders
Handrails, guardrails, stairways, Figure 28: Stairways, guardrails and ladders
walkways, and ladders are installed
where they are needed for safety
and access.
Potential Hazards:
 Falls from ladders.
 Falls or slips from ladders
and stairs due to damaged or
missing rungs or steps.
 Slips or falls on walkways
due to debris or uneven
surfaces.
Falls from heights.
 Falling into the mud pit or mixing tank.
Figure 29: StairwaysPossible Solutions:
 Follow established
procedures and best
work practices.
 Instruct workers on
proper procedures for
using and installing
ladders.
 Use only ladders in
good repair that do not
have missing rungs.
 Do not install stairs
with missing or damaged steps. Repair them before installing
them.
Keep w alkways clean and free of debris and tripping hazards.
 Use proper fall protection.
 Place guardrails in place prior to working in elevated areas.

Installing the power system
Installing the power system is
usually done simultaneously
with setting up the rig floor,
because power is needed to
operate the equipment. Today
there are generally two types
of rigs being used on land. A
mechanical rig is powered by
engines and compound. An
electric rig is powered by
engines and generators. This t
which drive the machinery. All power cords, belts, and chains need to
be connected to the machinery from their associated power source.
Simultaneously, the fuel lines and tanks need to be hooked up. Then,
start the engines.
ype supplies power to electric motors,
Potential Hazards:
 Tripping on power cords and hoses.
 Slips and falls on slick walking services.
 Getting caught in pinch points.
 Exposure to chemical hazards.
 Being shocked or electrocuted.
Possible Solutions:
 Keep all cords and hoses
orderly and clear of
walking spaces.
 Clear and clean all
walkways and walking
surfaces of slipping
hazards.
 Use caution around all
chain and belt pinch point
areas. Install all guards.
 Use proper PPE when working with chemicals.
 Use proper lockout/tagout/ procedures
Figure 30: Engines and generators
Figure 31: Power house

Rigging up the circulating system
While one crew finishes preparing
the rig floor, another crew
might be rigging up the mud
circulating system. This is
further explained in a separate
section.
The mud tanks and mud pumps
are set into the predetermined
location.
The mud lines are then
connected and electric cords are
strung.
Potential Hazards:
Figure 32: Mud pumps
 Being struck by or crushed by equipment being set into place.
 Getting caught in pinch
points.
Figure 33: Mud system
 Being struck by crane,
load, truck or forklift
tipping.
 Being struck by hammer
when connecting mud line
unions.
Possible Solutions:
 Keep a safe distance from
equipment that is coming together or moving.
 Maintain a safe distance from all pinch points.
 Stand clear of workers that may be swinging hammers.

Installing the Auxiliary Equipment
uipment must be set into place
he catwalk and pipe racks
otential Hazards:
 Getting struck or
ght
ing loaded onto racks.
the pipe racks
Possible Solutions:
 Keep a safe distance
ks
All remaining drilling and auxiliary eq
and installed where needed.
T
are positioned and the pipe
and drill collars are set on
the racks.
P
pinched by, or cau
in between, tubulars be
 Having feet pinched or crushed when setting up
and catwalk.
from equipment that
is coming together.
 Use a tag line to
guide the pipe rac
and catwalks into
position.
Figure 34: Tubulars on pipe racks
Figure 35: V-door, pipe ramp, pipe-rack & catwalk

Inspecting the rig
inspection
ger
r
otential Hazards:
 Falling from the rig.
:
 Use proper fall
lking spaces.
Perform a complete
of the rig before operating. The
driller and/or rig
Superintendent /
toolpusher / mana
should walk around the
entire rig and inspect for
missing or loose pins and
bolts, equipment guards,
adequate guard railings,
proper line and cable
placement, and unclea
walkways.
P
 Tripping on power
cords and hoses.
 Slipping and falling
on slick walking
services.
Possible Solutions
protection.
 Keep all cords and hoses orderly and clear of wa
 Clear and clean all walkways and walking surfaces of slipping
hazards.
Figure 36: Inspecting the rig
Figure 37: Inspecting rig equipment

Rigging down
After production casing is run and cemented, the rig is taken down and
moved to another site. The rigging down process is basically the
reverse of rigging up.
The hazards and solutions are similar to those for rigging up.
Figure 29 presents a land rig rigged up and ready to commence
operational activities.
In addition figure 30 further presents a more modern modular land rig
and all its components.
Figure 38: Typical light land rig.

Figure 39: A modular land rig schematic with all modules as numbered.

Drilling ahead
Handling Tubulars
rom trucks onto the pipe-rack. The floor crew
ist
ote: The rig supervisor should hold a pre-job meeting with the crew
otential Hazards:
 Being struck by rolling or
r caught
ple,
ips, and falls.
Possible Solutions:
 Use powered industrial
he
s
r of suspended,
rough the V-door.
The pipe is unloaded f
brings pipe from the pipe rack and catwalk, using the cat-line, air ho
or hydraulic winch, up to the drilling floor and places it in the mouse-
hole. This is done for every connection.
N
to review responsibilities and to coordinate the operations to be
performed.
P
falling tubulars.
 Being struck by o
between tubulars and
other objects during
movement (for exam
being struck by tubulars
being tailed into the rig
floor).
 Slips, tr

truck (forklift) properly.
 Work the tubulars from t
ends from ground level.
 Chock or pin tubulars on
the racks properly.
 Level your pipe rack
properly.
 Stand clea
hoisted, or moving loads.
Be aware of tubulars or
equipment being lifted th
Figure 40: Loading Tubulars
Figure 41: Cat-walk, pipe-rack and V-door

Potential Hazards:
 Getting struck by falling tubulars due to lifting equipment failure.
Possible Solutions:
- Instruct workers in the need for proper use, inspection, and
maintenance practices. Before each tour inspect the:
- Wire rope and slings,
- Cat-line ropes and knots (do not allow a rope to lie in standing
water), and
- Chains and hooks.
- Stand clear of suspended, hoisted or moving loads and be aware
of your surroundings.
Figure 42: Typical drilling 'Mud' fluidPreparing the drilling fluid
Drilling fluid is an important
component in the drilling process.
A fluid is required in the wellbore
to:
 Cool and lubricate the
drilling bit,
 Remove the rock
fragments, or drill cuttings,
from the drilling area and
transport them to the
surface,
 Counterbalance formation pressure to prevent formation fluids
(i.e. oil, gas, and water) from entering the well prematurely
(which can lead to a blowout), and
 Prevent the open
(uncased) wellbore from
caving in.
Figure 43: Mixing pump and hopper
The mud is monitored
throughout the drilling process.
A mud engineer and/or the
Derrickman may periodically
check the mud by measuring its
viscosity, density, and other
properties.

Potential Hazards:
Figure 44: Typical chemical mixing
container
 Burns, or physical injury caused by
contact with skin or eyes.
 Being exposed to explosions or violent
reactions from chemicals mixed
improperly.
 Being exposed to inhalation hazards.
 Receiving strains and sprains.
 Slips, trips and falls.
Possible Solutions:
 Ensure workers follow the safe
handling procedures found in Material
or appropriate Chemical Handling
Safety Data Sheets
 Wear appropriate personal protective
equipment, including, eye and face protection.
 Wear appropriate respiratory protection when handling chemicals
and/or mud additives.
 Provide an eyewash station and other appropriate flushing
apparatus as recommended by the MSDS.
 Provide adequate ventilation.
 Use proper mixing procedures.
 Use designated containers for mixing certain chemicals (for
example, baffled container with lid).
 Substitute less hazardous materials or use pre-mixed mud.
Note: Tank cleaning is a high-hazard operation requiring confined
space entry procedures, training for personnel, PPE, and specialized
equipment.

 RP54, Occupational Safety for Oil and Gas Well Drilling and
Servicing Operations. American Petroleum Institute (API), (1999,
August 1). Includes procedures for promotion and maintenance
of safe working conditions for employees engaged in rotary
drilling operations and well servicing operations, including special
services. Applies to rotary drilling rigs, well servicing rigs, and
special services as they relate to operations on locations.
 Accident Prevention Guide. International Association of Drilling
Contractors (IADC).
 Drilling Technology Series, Petroleum Extension Service (PETEX),
University of Texas at Austin.
 Unit I: The Rig and Its Maintenance
 Unit II: Normal Drilling Operations
 Unit III: Non-routine Operations
 Unit IV: Man Management and Rig Management
Starting Drilling
Figure 45: Lowering the drill
bit on a drill collar
To start drilling, a surface drill bit is attached to
a bottom-hole drill collar, which is in turn
attached to heavy weight drillpipe and then
drillpipe until the required length of drillstring**
is run to the bottom of the wellbore where the
kelly is then finally made up and attached.
Once the complete drillstring and all the
required components are made up made up, the
driller attached the kelly and lowers the
drillstring and kelly through the rotary table and
engages the mud pump(s) to check for leaks
and other abnormalities.
The driller lowers the drill string and the kelly
busing is set in the rotary drive bushing and the
rotary table or top drive is then engaged. The
driller then slowly lowers the rotating drillstring
and bit to bottom and begins the drilling
operation. #
]
** A drillstring can be made up to typically consist of of: Bit, Drill collars, MWD
tools, LWD tools, Stabilizers, Floats, Heavy Weight Drill Pipe, and Drill pipe.
MWD = Measurement while drilling tools LWD = Logging while drilling tools.

Drill Collars
Drill-collars ‘DC’ as illustrated in figure 36 are heavy,
large diameter pipe.
Their primary purpose is to provide both stiffness and
rigidity to dampen dynamic drillstring effects as weight
is applied to the bit. e.g. vibration, side loadings etc.
Drill-pipe itself is not able to withstand any
compression, as the pipe would buckle. Therefore it is
important to keep the drill pipe in tension at all times
particularly in vertical wells.
This is achieved by use of the stiffer more rigid Drill
Collars that can be placed in compression with
minimal detrimental effects.
Also by keeping the neutral point of the drill string
within the drill collars the drill pipe will always be in
tension and thus not prone to unwarranted cyclic
stress or fatigue loadings.
Figure 46: Typical dril collar
Stabilizers
Stabilizers as presented in figure 37 are used to keep
the drill string in the centre of the hole. A bit will
always be of a larger diameter compared to the drill
collars. Stabilizers can also be sized and shaped for
directional drilling needs to allow the drill string the
ability to follow a certain build or drop in angle bend
as a result in change of RPM and weight on Bit.
Figure 47: Drillstring stabilizer

Heavy Weight Drill Pipe Figure 48: Heavy weight drillpipe (HWDP)
Heavy weight drill pipe ‘HWDP’ are used as
the transition pipe between the Drill
Collars and the Drill pipe.
This is due to the stiffness of the drill
collars and the flexibility of the drill pipe.
In higher angle and horizontal wellbore
more HWDP will be run and less drill
collars in the bottom hole assembly.
Drill Pipe
Drillpipe constitutes the longest section
of the drill string and serves two primary
functions i.e.
1. Provides a conduit for the drilling
fluid (mud), to be able to
transport the mud from surface
down to the bit.
2. Allows transmission of rotation
power via a rotary table or top
drive to drillstring, ultimately
allowing the bit to be rotated so
drilling can ensure.
Average drill pipe sizes are: 3-½”, 4-
1/2”, 5”, 5-½”, 5-7/8” and 6-5/8”.
Drill pipes are also available in different
steel grades and weights. E.g. E-95, S-
135. Weight is expressed in pounds per
foot e.g. 5”DP @ 19.5lbs/ft.
The drill pipe used is also dependent on the diameter of the hole and the tensile
strength required. The wall thickness of drill pipe is quite small, 1/2”. This does
leave much material to cut thread in, so therefore both end of the pipe are fitted
with special threaded end. These ends are called a tool joint.
Potential Hazards:
- Being struck by the tongs, the make-up chain, or pipe.
- Being caught between collars and tongs, spinning chain, and
pipe.

Possible Solutions:
 Implement an effective pipe handling, make-up, break-out
procedure:
 Stand outside the tong swing radius when breaking pipe.
 Use proper tong latching techniques and use proper hand
and finger placement on tong handles
 Stand clear of the rotary table when it is rotating.
 Use a tail rope on the spinning chain to keep hands away.
Potential Hazards:
 Receiving strains and sprains during lifting or controlling
movement of drill collars, bit breaker, pipe, and tongs.
Possible Solutions:
 Use proper lifting technique.
 Hoist slowly to limit pipe momentum.
 Use mechanical lifting aids such as a rig floor winch.
 Use tail rope to guide as necessary.
Potential Hazards:
 Slips, trips, and falls.
Possible Solutions:
 See slips, trip and falls in general health and safety section.
Potential Hazards:
 Encountering shallow gas
Possible Solutions:
 See well control Ref. Blowout prevention program.

International Association of Drilling Contractors (IADC), (2006) and
other bodies e.g. IWDF. ensure that well control training schools
adhere to a core curriculum developed by industry.
Bits
Bits can be of different designs, depending on their purpose. The roller cone bit
illustrated in figure 40 is a milled tooth type with tungsten carbide insert cutters.
PDC bits as illustrated in figure 42 i.e. Poly-crystalline diamond compact bit are
also used to provide more durability as illustrated above.
Figure 49: Roller Tri-cone bit
Figure 50: Pumping through bit at surface
Figure 51: PDC bit

Rotating Systems
A conventional rotating system consists of:
1. Rotary table
2. Master bushing with insert bushings
3. Swivel Kelly and Kelly drive bushing.
Figure 52: Top drive system 'TDS'All these components are now on
modern rigs and new builds been
mainly replaced with one piece of
equipment called the TOPDRIVE
(NOV) or as Maritime Hydraulics
calls it: The Derrick Drilling
Machine.
A top-drive consists of an electric
or hydraulic motor, sometimes
two, which, via a gearbox, drive
a small piece of pipe called a
Quill. Underneath the Quill the
IBOP and the Lower Safety Valve
(Kelly valve) are connected.
Lower Safety valve is like the
IBOP a
ball valve;
however this one is operated
manually.
Figure 53: Master bushings
Nowadays rigs are still fitted with a
rotary table but it is not used for
driving purposes anymore. It is only
used in rare occasions, for example
during BHA handling.
Inside the rotary table a set of
master bushings is placed and
within the master bushings a set of
inserts bushings is placed.

Between the lower Kelly Valve and the drill
pipe a saver sub is placed. The saver sub is
intended as a sacrificial thread to protect the
thread of the Kelly valve connection and to
act as a crossover between the Kelly valve
and the drill pipe.
Figure 54: Full operating safety
valve
To shut of the drill string we either float
valves installed deep in the string, near the
bit. Or at surface an “IBOP”, “Kelly Valve” or
full operated safety valve on the Top-drive or
just below the swivel.
There are also tools
available for closing
the drill string when
the top-drive is
unable to screw into
the drill-pipe.
Figure 55: IBOP stab in valve.
For example during
tripping operations
(this is when the
string is pulled out
of the hole) and the
Top-drive is in the
top of the derrick. In such a case a safety
valve is manually stabbed on top of the string
and on top of that a one-way valve is fitted.
(IBOP).

Making a connection
Figure 56: Setting the drillstring slips into the
rotary table bushings
Preparing to break out the pipe
The driller stops the drill string from
rotating, and hoists the drill string
with the draworks until the kelly is
out of the rotary table. The driller
then shuts down the mud pump(s).
The floor hands set the slips around
the joint of pipe. The tongs are then
latched onto the tool joints above
and below the connection.
Potential Hazards:
 Pinching fingers or other body
parts between slips or slip
handles and rotary table.
 Experiencing muscle strain
from improper lifting
technique.
 Pinching fingers when latching
the tongs onto the pipe.
Possible Solutions:
 Implement effective, safe work
procedures for using slips and
tongs, which include:
 Proper finger and hand placement on slip handles and tong
handles
 Proper stance and slip lifting techniques.
 Proper tong latching techniques

Breaking out the pipe
The tongs and cathead are used to break out the pipe. Either the
rotary table top drive or kelly spinner is used to spin the drill string or
kelly to unscrew it from the drill pipe joint.
Figure 57L Breaking out drillpipe using the rig tongsPotential Hazards:
 Being struck by:
- Swinging tongs if the
tong dies fail, or the
tong counterweight lines
were to break
- The slip handles if the
rotary table is used to
spin the drill string
- Reverse backlash of
tongs (backbiting)
during spinning out
operations
- The tongs if a snub line
breaks or the tongs come unlatched
- Pipe Figure 58: Drill floor hazardous layout area diagram
when using rig tongs
Possible Solutions:
 Inspect tong dies,
counterweight cables, and
snub lines prior to each
usage.
 Implement an effective
spinning out pipe
procedure:
 Personnel other than tong
operators stand outside
the tong swing radius
when breaking pipe.
 No one should stand in
the red zone Ref. fig 37
 Use proper tong latching

techniques and use proper hand and finger placement on tong
handles.
 Stand clear of the rotary table when it is rotating.
 Use special operational procedures when using a high torque
connection.
 Maintain good communication between floor crew and driller.
Potential Hazards:
 Release of excess drilling mud resulting in skin contact, loss of
footing, etc.
Possible Solutions:
 Use a mud bucket to direct mud down into the rotary table.
 Close the mud saver valve on the kelly (if present).
Figure 59: Making connection in mouse hole
Making up pipe in mouse-hole
The crew swings the kelly out over
the mouse-hole and stabs it into a
new joint of pipe. The driller then
spins up the kelly using the kelly
spinner or spinning chain and the
crew uses tongs to torque the
joint.
Potential Hazards:
 Being struck or pinched by
the kelly.
 Losing footing while swinging the kelly out over the mouse hole
and stabbing it into a new joint of pipe.
 Being struck by or caught in the spinning chain.

Possible Solutions:
Figure 60L Pipe in mouse hole ready for
next connection Use proper hand placement
 Keep the work area around the
rotating table clean and clear of
mud, ice, snow, debris and other
materials that may cause slipping
or tripping.
 Inspect chain for broken or
distorted links. Chains with the
metal reduced by wear at any
point less than 90 percent of its
original cross section area should
be discarded.
 Lubricate and maintain guide
rollers to prevent undue wear on
the chain or cable.
Raising the kelly and making a new connection
The driller uses the draworks to raise the kelly and attached joint out
of the mouse hole.
Potential Hazards:
Figure 61: Raising the travelling
equipment and kelly to make a
connection
 Being struck by debris or overhead
objects if the traveling block runs
into the crown block or if the
traveling block or swivel hits the
derrick.
 Being struck by kelly or pipe.
Possible Solutions:
 Install a crown safety device on
the draworks and ensure proper
functioning.
 Keep personnel clear of the
potential swing path of the kelly
and pipe.

Adding pipe to the string
The new joint is guided over to the drill
hole, the tool joint is doped, and
stabbed into the end of the pipe
suspended in the rotary table with the
slips.
The joints are threaded together using
the pipe spinner, kelly spinner, or
spinning chain. Final torque is provided
by the tongs.
The draworks lifts the kelly and
attached string to facilitate removal of
the slips.
Potential Hazards:
 Being struck by:
 Swinging kelly and pipe
 Tongs if the stabber
misses the stump
 The jerk or spinning chain
 Being caught between the
swinging pipe and the tongs.
 Being caught between the joint
of pipe being stabbed and the
stump.
 Getting pinched between tongs or pipe spinner and pipe.
Possible Solutions:
 Never step over a jerk chain and stay clear of spinning chain
when a connection is being made.
 Keep hands away from end of stump or inside of pipe.
 Keep feet and legs away from underneath tongs when the pipe is
being stabbed.
 Use proper tong latching techniques and hand and finger
placement on tong handles.
 Never stand or walk under suspended loads.
Figure 62: Applying dope to a tubular
connection
Figure 63: Pulling slips

 Keep the work area around the rotary table clean and clear of
drilling fluids, mud, ice, snow, debris, and other materials that
may cause slipping or tripping.
 Inspect chains for worn or damaged links, and replace a chain
having a broken or distorted link with the metal reduced by wear
at any point less than 90 percent of its original cross section
area.
Resuming drilling
Figure 64: Lowering the kelly bushing into the
rotary table to resume Rotary Drilling Operations
The driller starts the pump and
picks up off the slips. The drill
crew then removes the slips. The
driller lowers the string until the
kelly drive bushing engages the
master bushing. Once the
bushings are in place, the driller
begins rotating the drill string,
lowers the bit back to bottom,
and continues making hole.
Potential Hazards:
 Being thrown off the rotary
table when engaged.
 Getting caught by loose clothing.
Possible Solutions:
 Stand clear of the rotary table.

Mud circulating system
Mud serves a couple of important functions within the drilling process:
- Well control, a column of mud of the correct mud weight keeps the well
stable. The mud weight is always chosen to provide sufficient overbalance
in relation to the formation pressure.
- Cooling the Bit
- Transport Cuttings to surface
A mud circulation system as
illustrated in figure 24 would
typically consist of the
following components:
Figure 65: Mud circulation system
1. Mud pits
2. Charge pumps
3. Mud pumps
4. Standpipe manifold
5. Standpipe hose
6. Swivel , wash pipe
7. IBOP (Mud Saver
Valve) in Top drive
8. Drill string
9. Annulus
10.B.O.P.
11.Flow line,
12.Flow divider
13.Shakers
14.Treatment tanks
Mud pits
Mud Pits can be seen as plain storage tanks. They have a couple of
connections to various suction lines (described later on) and a couple of
return lines. They are also fitted with big mixers which will prevent the barite
from falling out.
Barite is the weighting material used for increasing the mud weight.
Charge pumps
Charge pumps are connected to the mud pits and provide mud to the mud
pumps. Charge pumps are needed since a gravitational feed directly from the
pit will not provide the mud pumps with sufficient flow.

Figure 66; Example of a triplex mud pump
Mud pumps
Mud pumps can be
described as big triplex
plunger pumps. They can
operate up to 7500 psi;
can be AC or DC driven
with a power range up to
2200hp. The loc400 is
fitted with 800hp pumps
with a Pmax of 5000psi
with 4”liners.
Figure 67: Cross section of a triplex
mud pump

Standpipe manifold / Standpipe
The Standpipe manifold is located on the drill-floor; from here the driller can line-up
the mud pumps to the Top-drive or kelly. This is also the place where the gauges are
fitted which shows the driller the mud pressure, also referred to as the Standpipe
Pressure.
Standpipe hose
The standpipe hose connects the standpipe to the top-drive or kelly.
Swivel, wash pipe
The top drive or rotary table and kelly
via a kelly master bushing is rotating the
drill string.
Figure 68: Wash-pipe
The wash pipe provided a circulating
conduit link needed between the high
pressure circulating system ‘mud
pumps’ the rotating system and the
drillstring. It does this by providing a
high pressure swivel and sealing
capability between the stationary part
(where the standpipe hose is connected)
and the rotating part to which the drill
string is connected.

Drilling fluid flow path Figure 69: Fluid flow through bit
and wellbore annulusAs illustrated in the circulating system the
drilling fluid is pump via the mud pits,
circulating lines down the drillstring through
the drilling assembly and eventually exiting out
of the bit. Here, the bit is fitted with nozzles of
a specific size. Nozzles clean the bit and the
bottom of the wellbore thereby increasing the
efficiency and effectiveness of the cutting
removal process by jetting the cuttings from
the bit and bottom of the well.
Once fluid flow exits the bit is then enter what
is termed the wellbore annulus.
The annulus is geometrical section
clearances that exist between the
bottom-hole assembly, drillstring, drill
pipe etc and the wellbore formation or
casing, riser, diameters.
Separating mud from cuttings
To re-clarify Drilling mud is therefore
used to control the subsurface
pressures, lubricate the drill bit,
stabilize the well bore, and carry the
cuttings to the surface, among other
functions.
The mud flow path is for Mud to be
pumped from the surface through the
hollow drill string, exits through
nozzles in the drill bit, and returns to
the surface through the annular space
between the drill string and the walls
of the hole.
As the drill bit grinds rocks into drill
cuttings, these cuttings then become
entrained in the mud flow and are
carried to the surface. In order to
return the mud to the re-circulating
Figure 70: Recirculation system.

mud system as illustrated in figure 61 and to make the solids easier to
handle, the solids must be separated from the mud.
On top of the BOP low pressure piping is fitted. A funnel shaped piece
is fitted at the top and serves as a guide for the tools which are
lowered into the well. This is also
called the Bell Nipple.
Figure 71: Drilling mud exiting the surface flowline
On the Bell nipple side outlets
are fitted which permit the
drilling fluids to flow though the
flow-line to the flow divider.
The flow line is just a large
diameter pipe which connects
the bell-nipple to the flow
divider. Figure 72: Flow divider prior to shale shakers
The Flow divider is meant to
provide each shaker with an equal
amount of mud, this to prevent one
shaker to overflow whilst the others
are not getting any mud at all.
The first step in separating the
cuttings from the mud involves
circulating the mixture of mud and
cuttings over vibrating screens
called shale shakers.
The liquid mud passes through the screens and is recirculated back to
the mud tanks from which mud is withdrawn for pumping down-hole.
The drill cuttings remain on top of the shale shaker screens; the
vibratory action of the shakers moves the cuttings down the screen
and off the end of the shakers to a point where they can be collected
and stored in a tank or pit for further treatment or management.

Figure 73 : Shale shakers removing
cuttings from drilling mud
Often two series of shale
shakers are used. The first
series (primary shakers)
use coarse screens to
remove only the larger
cuttings. The second series
(secondary shakers) use
fine mesh screens to
remove much smaller
particles.
In general, the separated
drill cuttings are coated with
a large quantity of drilling
mud roughly equal in
volume to the cuttings.
Figure 74: Mud tank storage
Additional mechanical
processing is often used in
the mud pit system to further remove as many fine solids as possible
because these particles tend to interfere with drilling performance.
This mechanical equipment usually belongs to one of three types:
1) Hydro-cyclone-type de-silters and de-sanders,
2) mud cleaners (hyd-rocyclone discharging on a fine screened
shaker), and
3) rotary bowl decanting centrifuges. The separated fine solids are
combined with the larger drill cuttings removed by the shale shakers.

Figure 76: Vertical cuttings dryer Figure 75: Example of Dried cuttings
If the solids collected by the shale
shakers are still coated with so much
mud that they are unsuitable for the
next reuse or disposal step or if the
used mud is valuable enough to
collect as much of it as possible, the
solids can be further treated with
drying shakers utilizing high
gravitational separation, vertical or horizontal rotary cuttings dryers,
screw-type squeeze presses, or centrifuges. The cuttings dryers
recover additional mud and produce dry, powdery cuttings.
Figure 77: Centrifuge

Drilling Fluids
Drilling fluid functions
Drilling fluid is an important component in the drilling process. A fluid
is required in the wellbore to: Figure 78: Drilling Fluid (mud) in a mud pit
- Cool and lubricate the drill
bit
- Remove the rock
fragments, or drill
cuttings, from the drilling
area and transport them
to the surface,
- Counterbalance formation
pressure to prevent
formation fluids (such as oil, gas, and water) from entering the
well prematurely (which can lead to a blowout), and
- Prevent the open (uncased) wellbore from caving in.
Drilling fluids types
There are several types of drilling fluids used depending on the drilling
conditions encountered:
- Water-based muds are used most frequently. The base may be
either:
o fresh water, or salt water.
- Oil-based muds.
- Synthetic materials. The oil and gas extraction industry has
developed many new oleaginous (oil-like) base materials from
which to formulate high-performance drilling fluids.
- A general class of these fluids is called synthetic materials, such
as
o The vegetable esters,
o Poly alpha olefins,
o Internal olefins,
o Linear alpha olefins,
o Synthetic paraffins,
o Ethers, and others.
- Air and foam fluids may be used in drilling wells.
o These fluids are less dense than drilling muds.

Drilling Fluid additives
Drilling muds typically have several additives. (Air and foam fluids
typically do not contain many additives because the additives are
either liquid or solid, and will not mix with air and foam drilling fluids.)
The following is a list of the more significant additives:
- Weighting materials, primarily barite (barium sulfate), may be
used to increase the density of the mud in order to equilibrate
the pressure between the wellbore and formation when drilling
through particularly pressurized zones. Hematite (Fe2O3 )
sometimes is used as a weighting agent in oil-based muds
(Souders, 1998).
- Corrosion inhibitors such as iron oxide, aluminum bisulfate, zinc
carbonate, and zinc chromate protect pipes and other metallic
components from acidic compounds encountered in the
formation.
- Dispersants, including iron lingosulfonates, break up solid
clusters into small particles so they can be carried by the fluid.
- Flocculants, primarily acrylic polymers, cause suspended
particles to group together so they can be removed from the
fluid at the surface.
- Surfactants, like fatty acids and soaps, de-foam and emulsify the
mud.
- Biocides, typically organic amines, chlorophenols, or
formaldehydes, kill bacteria and help reduce the souring of
drilling mud.
- Fluid loss reducers include starch and organic polymers and limit
the loss of drilling mud to under-pressurized or high-permeability
formations.

Tripping in and out
Tripping refers to the process of removing and/or replacing tubulars to
or from the well when it is necessary to change the bit, Downhole tools
or equipment or when preparing to run
certain tests in the well bore.
The activities that comprise tripping are outline in
this section
Figure 79: Setting back a stand of
tubulars in the drilling derrick
Every time a connection has to be made, the top
drive or kelly has to be disconnected from the drill
string.
To make this possible, the drill string is hung
of in the rotary table. This is done by means
of the slips. Slips are wedge shaped devices
which are fitted with dies. The insert
bushings of the rotary table have the same
wedge shape and provide support to the
slips. Once the slips bite the driller can
unscrew the top drive or kelly and hoist it all
the way up into the derrick.
The Drill pipe is brought to the drill floor by use of a winch or pipe
handler. This is an automated piece of equipment. On manual rigs pipe
was pulled up the floor by use a tugger and placed onto the drill-string
by hand.
The new joint is placed on top of the drill-string and will be made up
with the manual rig tongs or with an automated roughneck

Tripping out
ips
slips around the drill stem.
otential Hazards:
 Getting fingers or
s
er
Use proper hand
etting
 Use proper stance and slip lifting techniques. Slips have three
Setting the sl
The floor crew sets
P
other body parts
pinched between
slips or slip handle
and rotary table.
 Receiving muscle
strain from improp
lifting technique.
Possible Solutions:
placement when s
slips.
handles and should be lifted jointly by more than one person.
Figure 80: Setting the slips

Breakout the kelly and set it into the rat-hole.
Potential Hazards:
Figure 81: Kelly set in its rat-hole in
readiness to trip pipe- Release of excess drilling mud
resulting in skin contact, loss of
footing, etc.
Possible Solutions:
- Shut down the mud pumps
before breaking out the kelly.
- Close the mud saver valve on
the kelly (if present).
- Use a mud bucket to divert flow
of excess mud.
Potential Hazards:
 Being struck by the slip handles
if the rotary table is used to
spin the drill string.
Possible Solutions:
 Stand clear of the rotary table
when it is rotating.
 Consider other technologies (such as a pipe spinner, kelly, top
drive unit ) to eliminate this hazard.
Potential Hazards:
 Being struck by the kelly if the pullback line unhooks when kelly
is being pulled toward the rat-hole.
Possible Solutions:
 Implement an effective pullback line attachment procedure.
 Ensure workers stand in a safe location away from the pullback
line and rat-hole during this pullback operation.

The crew attaches elevators to the drillstring.
Potential Hazards:
 Being pinched by the elevator links while attaching elevators (or
attaching elevator links to the hook).
 Being struck by the elevators.
Possible Solutions:
 Use proper hand placement when attaching elevator links.
 Ensure workers stand away from swing-path of the elevators and
elevator links.
 Use lifting equipment and limit manual positioning of elevators.
 Use proper mounting procedures.
Figure 82: Example of elevators and elevator links

The floor crew latches the elevators onto the pipe.
Potential Hazards:
 Getting hands or fingers pinched in elevators.
 Being struck by elevators not securely latched.
 Getting hands or fingers caught between elevators and stump.
Possible Solutions:
 Ensure workers are instructed in proper latching procedure,
including the use of handles on elevators as they are descending
into place over the stump or tool joint.
 Inspect and maintain elevators.
Figure 83: Climbing derrick ladder to monkey-boardWorking in the monkey board
The derrick-man climbs up the
derrick to the monkey board.
From here he unlatches the
elevators and guides the stands
of pipe into the fingerboard. The
elevators are then lowered and
attached to the next stand of
pipe.
Potential Hazards:
 Falling while climbing up or
down the ladder.
 Falling from monkey board or fingerboard.
 Falling during an emergency descent.
Possible Solutions:
 Use climb assist device.
 Wear appropriate fall protection including a full body harness.
For Fall Protection guidance, consult, Fall Protection when
working from platforms documents.
 Reference appropriate Fall Protection guidelines.
 Wear the proper Personal Protective Equipment (PPE) such as:
 Hard hat
 Work gloves
 Safety-toed footwear

 Practice 100% tie-off while
working in the derrick.
Figure 84: Monkey board layout ‘birds nest view’
 Use slip-resistant coatings
or materials on working
surfaces.
 Train personnel in use of
emergency escape device.
Potential Hazards:
 Being caught between pipe
and other objects
Figure 85: Handling pipe on the monkey-
board
Possible Solutions:
 Practice proper hand
placement and use of pullback
(tail) ropes.
Potential Hazards:
 Being struck by dropped
objects.
Possible Solutions:
 Implement a dropped objects program, such as tie-off for all
tools.
 Use extra caution while personnel are working overhead.
 Do not carry tools while climbing the derrick ladder. Raise tools with a line to
any worker above the derrick floor.

Breaking out pipe, Reference page 27
Moving pipe to racking area Figure 86: Moving pipe to set back area
The stand is raised and
maneuvered to the pipe racking
area.
Potential Hazards:
 Getting hands and fingers
pinched between stands of
pipe.
 Getting feet or toes crushed
or amputated under a stand
of pipe.
 Receiving strains and
sprains.
Possible Solutions:
 Keep hands and fingers from
between pipe stands.
 Position feet away from the
bottom of the pipe stands
Tripping in
The sequence for tripping in to a well is as follows
 Elevators raised
 Tripping In -- Latching Elevators to Top of Stand
 Moving pipe to rotary
 Pipe is made up
 Slips are pulled
 Slips are set
 Elevators are unlatched
 Process repeated for all stands
 Pickup kelly and attach to drill string
 Break circulation, and
 Resume drilling

In regards to latching elevators at the top of a stand, the derrick-man
latches the elevators onto the pipe from the monkey-board as
illustrated in figure presented below.
Potential Hazards:
 Getting hands or fingers pinched in elevators.
 Being struck by elevators not securely latched.
 Getting hands or fingers caught between elevators and stump.
Possible Solutions:
 Ensure workers are instructed in proper latching procedure.
 Inspect and maintain elevators.
Figure 87: Looking up to latch elevators to stand from the monkey board

Pipe handling equipment
On many of today’s modern rigs pipe
handling equipment picks up drill-pipe
automatically transporting the tubulars’ to
the drill floor so they can then in turn be
picked up by the elevators and hoisting
equipment into the derrick, rack back in
the derrick and/or run into the wellbore.
Examples of this are illustrated in the
figures that follow.

Casing operations
Casing is pipe usually larger in diameter and longer than drill pipe and
is used to line the hole. Casing operations occur periodically
throughout the drilling process starting with the surface casing,
intermediate casing, and ending with production string which takes
place during well completion.
The activities involved in casing operations can vary according to the
type of casing being installed, but generally fall into these steps:
- Installing casing tools
- Running casing into the wellbore
- Installing casing accessories
- Circulating and cementing.
Figure 88: Installing casing

Installing casing tools
Figure 89: Casing slips and elevators
Specialized casing
handling tools are
necessary to run casing.
Note: The special
service supervisor
should hold a pre-job
meeting with the special
service crew and other
involved personnel to
review responsibilities
and to coordinate the
operations to be
performed.
Potential Hazards:
 Being struck by or
caught between
tubulars and other
objects during movement (such as being struck by tubulars
being tailed into the rig floor).
 Experiencing strains and sprains from maneuvering tools.
 Falling from work platform and/or stabbing board.
Possible Solutions:
 Stand clear of suspended, hoisted or moving loads. Be aware of
tubulars or equipment being lifted through the V-door.
 Use proper hand and foot placement to avoid pinch points,
including use of tag lines.
 Use rig floor winch or other powered equipment to handle heavy
casing tools.
 Use fall protection while installing equipment in the derrick.

Running casing into the hole
Casing is run into the hole to a pre-determined depth.
Note: The special service supervisor should hold a pre-job meeting
with the special service crew and other involved personnel to review
responsibilities and to coordinate the operations to be performed.
Potential Hazards:
Figure 90: Lifting casing to the drill floor
 Hazards are similar to those for drilling ahead or tripping.
 Getting caught between, struck by, or pinched by the power
tongs, casing or other equipment.
 Being struck by or caught between tubulars and other objects
during movement (for example, struck by tubulars being tailed
into the rig floor).
 Falling from the stabbing board or work platform.
 Getting struck by dropped objects.

Figure 91: Casing stabber
Possible Solutions:
 Include the casing crew and
the drilling crew when
conducting a JSA and pre-job
safety meeting to coordinate
the activities of casing
operations.
 Stand clear of suspended,
hoisted, or moving loads. Be
aware of tubulars or
equipment being lifted through
the V-door.
 Emphasize all normal worker
safety procedures, such as fall
protection, PPE, placement of
hands and feet, and teamwork
and communication between
workers.
 Implement full fall protection
program for the casing stabber.
 Identify clearance between the stabbing board and casing
elevators.
 Secure all items used by the casing stabber overhead with a
safety line.
Figure 92: Casing float shoe
Installing casing accessories
As casing is being run, accessories
such as centralizers, scratchers,
guide shoe, and a float collar are
installed and used as needed.
Note: The special service supervisor
should hold a pre-job meeting with
the special service crew and other
involved personnel to review
responsibilities and to coordinate the
operations to be performed.

Potential Hazards:
Figure 93: Casing centralizer
 Dropping guide shoe or
float collar onto legs or
foot.
 Getting fingers pinched
between tools and
casing tongs when
manually moving guide
shoe or float collar.
 Back strain
 Exposure to hazardous
materials, especially
thread lock
compounds.
Possible Solutions:
 Use winch, air hoist, or other powered equipment to handle
guide shoe, float collar, or other heavy casing equipment.
Circulating and cementing
After the casing is landed, drilling fluid is circulated through the casing
and annulus to remove any residual gases and to condition the mud.
After circulating and conditioning the mud, the casing is cemented.
During this process the casing is reciprocated or rotated to allow the
scratchers to work to remove excess wall cake to give the cement a
better bond.
Usually another special servicing company is hired to conduct
cementing operations.

Potential Hazards:
 Being struck by high-pressure lines failing if not secured
properly.
 Having a high pressure connection failure caused by mismatched
or excessively worn hammer unions.
Possible Solutions:
 High-pressure lines properly secured.
 Use proper equipment inspection techniques to include hammer
particular problem with 602 and 1502, as they will
eyond the lower pressure rating number).
unions (Note: This is a
couple but will not hold b
Figure 94: Example high pressure cementing lines

Introduction to well control
Properly trained personnel are essential for well control activities. Well control consists of
two basic components: an active component consisting of drilling fluid pressure
monitoring activities, and a passive component consisting of the Blowout Preventers
(BOPs).
The first line of defense in well control is to have sufficient drilling fluid pressure in the
well hole. i.e. keep the wellbore full of the correct drilling fluids at all times.
During drilling, underground fluids such as gas, water, or oil under pressure (the
formation pressure) opposes the drilling fluid pressure (mud pressure).
If the formation pressure is greater than the mud pressure, there is the possibility of a
blowout. What could then result is presented I the figure below.
The activities involved in well control are:
 Blowout Prevention Program
 Monitoring and Maintaining Mud System
 Installing BOPs, Accumulator, and Choke Manifold
 Testing BOPs Accumulators, and Choke Manifold
 Maintaining Surface Control System
Figure 95: An example where well control has been lost on an oil & gas well.

Well-control can be divided into two barriers.
1. The primary barrier, this is the drilling mud.
2. The secondary barrier which are Blowout Preventers, FOSV’s,
Floats etc.
During normal drilling operations the hydrostatic pressure created by
the drilling fluid creates the primary barrier and prevents formation
fluids from entering the well.
When, for any reason, the well starts to flow the second barrier will
help us to control the well en to re-establish the primary barrier.
The well-control equipment must enable the driller to shut in the well
and to change out the drilling fluid with drilling fluid of a higher mud
weight all to be done in a controlled manner.
Incase the well start to flow the mud will flow to surface in two ways.
1. Through the drill string.
2. Through the annulus.
To shut of the drill string we
have a float down in the
string, the “IBOP” and the
“Kelly Valve” on the Top-
drive.
Figure 97: IBOP
Figure 96: Kelly valve
There are also tools available
for closing the drill string
when the top-drive is unable
to screw into the drill-pipe.
For example during tripping
operations (this is when the
string is pulled out of the
hole) and the Top-drive is in
the top of the derrick. In such
a case a safety valve is
manually stabbed on top of
the string and on top of that a
one-way valve is fitted.
(IBOP)

To shut of the annulus we have the BOP. The BOP is equipped with a
couple of different ways to secure the annulus.
1. Annular Preventer
2. Fixed Bore Pipe Ram
3. Variable Bore Pipe Ram
4. Blind Ram
5. Shear Ram
Figure 98: Annular preventer
The annular Preventer is a big rubber
element which rests on a piston. To close
the annular, hydraulic pressure is applied
to the bottom of the piston which in turn
pushes the rubber element against the
pipe and creates a seal. Annular
Preventers come in all kinds of different
designs. Some models are able to shut of
with nothing in the hole (CSO- complete
shut off).

Blowout Prevention Program
Potential Hazard: Figure 99: Land rig Blow out preventers
'BOP'
- Receiving injuries caused by loss of
well control.
Possible Solutions:
- Appropriate training for tasks
performed. Example topics
include the following:
o Causes of kicks, including
detection
o Pressure concepts and
calculations
o Well control procedures
o Gas characteristics and
behavior
o Fluids
o Constant bottom hole
pressure well control methods
o Well control equipment
o Regulatory information
- Use of appropriate well control equipment including:
o Specification
o Installation
o Maintenance
 Well CAP. International Association of Drilling Contractors
(IADC), (2006). Ensures that well control training schools adhere
to a core curriculum developed by industry.
 Standards. American Petroleum Institute (API).
 RP 53, Blowout Prevention Equipment Systems for Drilling
Operations. Second Edition, (2006, May).

Monitoring and Maintaining Mud System
The mud circulatory system consists of the elements shown in Fig.90.
Each part of this system must function and be in good repair to
maintain well control.
[For more information, see ]
If the mud level increases, it may be a sign that a kick is in progress.
On some rigs there is a mud float level gage which sounds an
automatic alarm if the mud exceeds a pre-specified level.
Maintenance Activities
Figure 100: Schematic of the circulating system: The drill bit, drill collar, annulus, drill pipe, kelly and
swivel are depicted in the upper right. Drilling mud flows through the mud return line (center) upon its
return to the surface from the hole to the shale shaker (upper left), then to the adjacent de-sander, de-
silter and degasser back to the mud tank (upper left). Mud passes through the suction line, and the mud
pump (center) circulates the mud through the discharge line (above), the stand pipe (upper right)
through the rotary hose (right) and the swivel (lower right), back to the kelly and into the drill pipe.

Potential Hazard:
- Loss of well control
(blowout)
Figure 101: Kick illustration: Schematic of mud
circulating system, with a close up view of the drill bit
hitting the lower vein at unexpected higher pressure.
KICK occurring. Mud pit fills. Shut-in well. Above the
animation is the illustration of the mud return from the
surface to the mud pit through the circulating system
Possible Solutions:
- Keep the mud circulating
system in good working
order
- Check and maintain the
properties of the drilling
fluid, including proper pit
level periodically
- Properly train crew in
monitoring and well control
procedures.
- Maintain a properly
functioning surface control
system
Installing BOPs, Accumulator, and Choke Manifold
Figure 102: BOP preventers
The blowout preventer (BOP),
accumulator and choke manifold
are installed by the rig crew after
the surface casing is set and
cemented. The accumulator and
choke manifold have been set
into place during rigging up and
now need to be hooked up and
tested. The choke line valve is
used to redirect the mud from the
well bore to the choke manifold
during a kick. The kill line valve is
used to direct drilling fluid to the
BOP during a kick.

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