rig equipment presentation

7/28/2019 Rig Equipment Presentation

http://slidepdf.com/reader/full/rig-equipment-presentation 1/72

Howard A. Garig

DRILLING TECHNICIAN SCHOOL ExxonMobil Development Company

Houston, Texas2004

Rig Equipment and InspectionPresentation 10

Learning Objectives

You should be able to:• Identify different types of drilling rigs

• Describe their operating environments

• Identify main rig systems and equipment• Describe the functions of the systems

• Understand the rig inspection process andyour role in it

Information Sources

• EMDC Drilling OIMS Manual

• API Recommended Practices

• Previous Rig Inspection Plans

• World Oil Composite Catalogs• OPL Marine Drilling Units of the World

• Dave Steubner- EMDC Global Rig Coordinator

• World Oil Magazine - Yearly Rig Editions• IADC Drilling Manual

• Vendor Material

Rigs Categorized by Operating Environment

• Drill ship

• Semi-submersible

• Jack-up

• Platform

• Barge

• Land

Land Rigs

• Solid foundation needed for land rigs• Carrier-mounted/trailerized mobile rigs for fast rig move

• Helicopter transportable rigs for locations without accessible road

Heli-rig on Papua New Guinea

Barge Rigs

• Mostly for inland water or offshore areas with calmweather

• Inland barge often towed to

location with draft < 6 feet• Submersible barge

ballasted until lower hullrests on soft bottom

• Mud barge also available

Platform Rigs

• Operated anywhere a platform canset – jacket, TLP, DDCV

• $20k - $40k daily rental• $20M - $100M to build

• Ability for supply boat off-loadingbeing the limiting factor for operations in severe weather

• Weight and space requirementsimpact platform design and cost

Jade - Equatorial Guinea

Platform Rigs

Malaysia: Tioman T-2 at Tapis E

Malaysia: Seahawk at Palas A • Compact/integrated designand tender-assisted drillingreducing weight and spacerequirements

Platform Rigs - Designed by EM

Jotun B-Norway

Hibernia - Newfoundland

Ringhorne - Norway

Jack-Up Rigs

• Operated up to 400’ water depth

• $20k - $120k daily rental• Relatively calm weather needed

for installation, for example:wave height < 5 feet and wind <15 knots

• Rig can move horizontally ontothe top of a platform for cantilever operations

Drill Ships

• Operated up to 10000’ water depth

• $100k – $200k daily rental• Moored or dynamically-

positioned in place• High Speed Mobilization• Storage Capacity

Jack Ryan

Semisubmersible

• Operated up to 10000’water depth

• $60k - $230k daily rental• Most have thrusters to

assist in towing andpositioning for mooring

• Moored or dynamicallypositioned in place

• The deck is usually higher

than drill ship

Leiv Eirikssen

• By height of mast – single, double, triple, fourble• By derrick hookload capacity – 0.5 M lbs, 1.0 M lbs, 1.3 M lbs• By rated well depth – 5000’, 10,000’, 20,000’, 35,000’ • By applications – drilling, workover, completions

• By design – 3rd, 4th, 5th generation MODU – API, light weight, integrated – SCR, mechanical

Rigs Categorized by Operational Capability

Moored vs Dynamically Positioned (DP)Ships and Semis

• No “drive off” risk for moored rigs

• More fuel consumption for DP rigs, high horsepower needed for thrusters (5000-25,000 HP)

• Shorter rig up/down time for DP rigs, allowing fastmoving to avoid hazards

• In general, lower water-depth limit for moored rigs

Cost Savings: DP

DP Cost Savings vs. Well Days

Operations ~ 5000' WD

Well Days-Exclude Anchor Work

i n g s

( K U S D )

DP Cost

Savings

25 50 75

t L o s s

Maximum Savings Realized by DP:

• Multiple wells or batch setting over an area larger than a rig’s mooring radius

• Shorter term exploration well programs

Maximum Savings Realized byMooring:

• Template or drill center operationsfitting within a rig’s mooring pattern

• Longer term operations where mooringis a small percentage of total program

Cost Savings: Moored

DP Cost Savings vs. Well Days

Operations ~ 5000' WD

Well Days-Exclude Anchor Work

i n g s

( K U S D )

DP Cost

Savings

25 50 75

t L o s s

Floating Rig Considerations

• Need for heave compensation• Previously done with bumper subs - now use

of passive and active heave compensators

Crown MountedCompensator

Block MountedCompensator

Rig Site Zoology

Mousehole

Doghouse

Rig Site Zoology

Catwalk

Possum Belly

Rig Systems and Components

• Power System

• Hoisting System

• Rotating System

• Circulation System

• Well Control System

Reprinted with permission from PetroleumExtension Service, UT Austin

5 primary systemsassociated with drilling rig

Power System

• Engines: internal combustion engines provide shaft power • Transmission:

– Mechanical - engine shaft power to compound for distribution

– Electrical - engine shaft power to electrical generators &then distributed through silicone controlled rectifier (SCR)that converts AC electrical power to DC for variable speedmotors

Hoisting System

• Drawworks, crown and traveling block -- Deliver hoisting power

to the hook

• Mast/derrick and substructure -- Provide a structural reaction tothe hoisting forces and setback. Setback is the amount of pipeweight that can be vertically racked while the maximum hookload is being carried.

Hoisting System-Hydraulic

• A new type of hoisting system has recently been employed ona few new semis and drill ships. The concept is known as aRam Rig or Hydra Lift Rig. Both concepts use hydrauliccylinders to move the load up and down.

Hoisting System

• Hook, links & elevators -- Provide a force path from the

drill stem to the rotary drill line• Rotary swivel -- Provide for the rotation of the drill stem

with respect to the hook, while providing a force path tothe hook and a fluid path to the drill stem

• Maximum hook load = heaviest string of casing (typically)

Rotating System

• Rotary table -- Deliver rotating power to the drill stem throughthe kelly & associated bushings, usually gear driven from a sideshaft.

• Kelly is typically a 40’ long, square or hexagonal shaped, thick

wall pipe, with a valve (kelly cock) that can be closed to preventbackflow.

Rotating System

• Top drive - Hangs from thehook. Motor providestorque to the drill stemthrough a drive shaft.

• Advantages:1) Rotate while tripping

out2) Can add 3 joints at a

time3) Making up or breaking

out pipe easier

Varco Maritime Hydraulics

Circulating System - Mud Pits

• Mud pits -- Hold drilling andcompletion fluids

• Various pit sizes – Slug Pits - 30-100 bbls to mix

small batches of fluid- usuallydirectly hooked to hoppers and

mixing lines – Active pits - 100-1000 bbls holdsfluid regularly circulated throughwell

– Reserve pits - 100-1000 bblsholds fluid for reserve use on

well. On land may be earth pit – Sand Trap/Treatment Pits -

usually series of 3 pits wheremud initially returns from solidscontrol equipment. Pump to andreturn from secondary solids

control such as desanders,desilters etc..

Circulating System - Mud Pumps

• Mud pumps – 2-3 pistonpumps (often with centrifugalbooster pumps) to circulatemud

• Larger pump cylinder liner for

higher flow rate and smaller liner for higher pressure

• Typically need high flowratefor surface hole and highpressure for production hole

Circulating System- Standpipe Manifold

Standpi pe # 2 tan dpipe # 1 Jet Li ne Bruner Booms

Te st Hose

11 Li ne

Riser Boo st

To Choke M anifol d

Standpipe Manifold -directs HP mud flowfrom mud pumps todrill string or other desired path

Circulating System - Solids Control

• Shale shaker, desander, desilter & centrifuge -- Provides for theremoval of drilled solids from the drilling fluid upon return fromthe well bore annulus

• Component selection depends on mud weight, mud cost,equipment cost, and disposal cost

Deciliter

Centrifuge

Desander

Shaker

Circulating System - Other Mud Treatment

• Gumbo Chain - for handling high volumes of soft-gumboshales- mostly used in GOM top hole sections

• Degassers - for removal of gas from mud stream post solids

control

Gumbo Chains Degassers

Circulating System - Drilling Riser

• As a return mud flow path fromwell at sea floor

• Typically consisting of slip joint,riser joints and LMRP (lower marine riser package) for floaters

• Casing often used as riser for platform drilling

• Riser weight supported bybuoyancy can and tensioner

• Low pressure riser for floatingdrilling and high pressure riser for platform drilling, dual risersfor extreme conditions

• Kill/choke lines attached to riser and booster line used to assistcuttings transport

Well Control System

PUMP-TYPE TRIP TANK LAYOUT

F I LL LI N E

F LO W LI N E

CENTRIFUGALPUMPS

BELLNIPPLE

ANNULARBOP

BOPSTACK

MUDSTANDPIPE

FLOW RATERECORDER

PVTRECORDERBOP REMOTE

CLOSING UNITHYDRAULIC

CHOKE CONSOLE

F I LL LI N E

T O M U D T A N K

RELIEFVALVE

PUMPISOLATION

T O M U D

S T A N D P I P

ET O K I L L L I N E

BOP ACCULULATOR UNIT

MAIN CLOSING UNITT O R E M O T E

C L O S IN G U N IT

O N R IG F L O O R

GRAVITYTRIP TANK

KILL LINEFROM MUD PUMP

ORHIGH PRESSURE

CHECKVALVE

BOPSTACK

WELLHEAD

DRILL STRINGFLOAT VALVE

HYDRAULICCONTROLED

FLOW RATEDETECTOR F L O W L I N E

HYDRAULICCHOKE

CHOKEMANIFOLD

B Y P AS S

MUD GASSEPERATOR

FLARE STACK

RESERVE PIT

SHALE SHAKERDEGASSER

PIT VOLUME TOTALIZER(PVT)UPPER KELLY

SAFETY VALVE

LOWER KELLYSAFETY VALVE

DRILL PIPESAFETY VALVE

INSIDEBOP

Example Schematic Layout of Well Control Equipment

Kick Detection Equip.Kick Containment Equip.Kick Circulating Equip.

Choke Manifold

BOP Control System

Poor Boy Degasser Trip Tank

Well Control System

• Blowout preventer (BOP) stack -- Providespressure isolation andcontrol during kicks

• Pressure rating is basedon maximum anticipatedsurface pressure duringa well control event

• BOP stack arrangementimportant. Annular,Ram, pipe shear ramsBOP

Well Control System

Annular

Rotating Head

WH Connectors

Well Control System

Land BOP Stack

SubseaBOPStack

Well Control System

• Accumulators store fluidunder high pressure for control devices

Well Control System

• Activated by remote controlunit on rig floor. Can openor close BOP quickly.

• Choke also remotelycontrolled

Well Control System

• Choke Manifold providespositive pressure and flowrate control of the wellduring a kick or live drillingoperation

• Equipped with both manualand remote chokes

• Allows flow to be directed topoor boy de-gasser, flareline, other routes

G as Li ne

T es t P ort

KI LL LI N E 10

T es t P ort

13 F ro nt Vi ew

To Mu d Ga s Se pa ra to r

T es t P ort

C H O KE LI N E

To St an d Pi pe Ma ni f old

Back Side H

Well Control System

Manual Choke

Remote Choke

Well Control System

• Poor Boy Degasser • Vessel Size• Internal Baffles• Gas Outlet• Target Plate• U- tube liquid seal

Rig Floor Layout

Typical STX Land Rig

New Offshore Platform

Drilling Equipment Controls

Rig Floor Equipment

Iron Roughneck• Make-up and Breakout of

tubulars

• Replaced Manual Tongs

• Increased Safety

• Integral Spinner

• Still use manual tongs for large DCs or BHA components

Rig Floor Equipment

Manual Tongs• Make-up and Breakout of

tubulars

• Safety focus on proper use

and tong BU lines• Pipe spinner in place of chain

for safety

• Still use manual tongs for

large DCs or BHA components

Pipe Spinner

Rig Floor Equipment

Torque-up Devices• Draw works - MU/BO line

– Traditional method stillwidely in use

• Hydraulic Cathead

– Found on newer rigs or installed on older ones

– Safer, dedicated unit

Rig Floor Equipment

Flush Mounted Slips

DP Elevators

AdjustableElevators

Pipe Handling Equipment

Large OD Handling Equipment

• Casing• Riser

Rig Inspections

• Purpose of Rig Inspections• Inspection Requirements

• 3rd Party Inspections

• QA/QC of Inspections• Inspection Planning and Follow-up

Purpose of Rig Inspections

• Safety

• Regulatory Requirements

• OIMS Requirements

• Assure rig meets contract requirements• Equipment verification

• Familiarity with rig capabilities

OIMS Requirements

• Sections 3,6 and 8 of the OIMS Manual“Procedures shall be in place for initial inspectionand acceptance of critical drilling equipment”

• In Reference to: – Safety – Regulatory Requirements

– Drilling Design Standards

– Drill Team Specific Acceptance Criteria

Inspection Requirements

“A checklist shall be developed, customized for thespecific rig, area and/or operation. Equipmentacceptance criteria shall be incorporated into thechecklist, where practical”

• Guidelines: – Safety

– Regulatory Requirements

– Well Type, Duration of Program, Drilling DesignStandards

– Inspection Team Make-up: EM personnelspecialists, 3rd party Inspectors etc..

Inspection Team

• BOP and Well Control Equipment - West Inc, someModuSpec

• Marine Safety - URC aid on critical subjects, ModuSpec

• Rig Equipment Acceptance - ModuSpec

• NDT testing personnel - T.H. Hill or other

• Tubulars, handling Equipment - T.H. Hill

• Hygiene - EM Health Inspection Team

• Solids Control - Mud Company selected as contractor

QA/QC of Inspections

• Document Verification• Daily Interaction-discussion of inspection progress

• Witnessing of tests

• Critical equipment - testing verification

Inspection Planning and Follow-Up

• Coordinate with Superintendent on inspectionschedules

• Develop Checklist to track progress

• Develop Follow Up list to track outstanding items• Track Progress on Follow-up items until

completed

MODU Ri I i

Marine Safety Audit and Stability Review and EER Analysis

Helicopter Facilities

Supply Vessels

Solids Control Equipment

Environmental Aspects: Closed drain systemetc...

Medical & Hygiene Facilities and Personnel

3rd Party Drill Tools

Fluid systems operability

Derrick Inspection/Risk Assessment

Mooring Equipment

Handling Tools

C&K Manifold and Lines

Lifting Equipment

Structural Inspection

Classification survey of hull, structure and well controll equipment

Production Test Lines

BOP and Diverter Equipment

Personnel Qualifications

High pressure piping survey and repairs

Burner booms

Water tight doors

Riser/Slip Joint/Flex joint Inspection

All tubulars DS-1 cat.4

BOP Control System

Rig Acceptance Checklists- Witness of operation

Poor Boy Degasser

Up to date Manufacturer- equipment Recalls

MODU Rig Inspections

Risk Assessment Issues Identified

9-Jun-03 FOLLOW UP SHEET FOR HAKURYU V INSPECTION PLAN

PRIORITY DATE

DESCRIPTION % FINISH complete COMMENTSStructural Inspection 0

Stability Review-ModuSpec 0

Marine Safety Audit-ModuSpec 0

Derrick Inspection-Dreco 0

Derrick Risk Assessment-JDC and EMDC OS 0

EER Analysis-ModuSpec 0

Mooring Equipment-EMDC Eng & ModuSpec 0

Mooring Analysis-URC 0

Riser Analysis-URC 0

Riser Inspection-West & 3rd party NDE 0

Riser Slip Joints-West & 3rd party NDE 0

Riser Flex Joint and Riser A daptor-West 0

Riser Tensioners-West 0

Riser Handling Tools-West & 3rd party NDE 0

Diverter & Ball Joint-West 0

BOP Preventers-West & 3rd party NDE 0

BOP Annulars-West 0

BOP Connectors-West 0

BOP Control System-West 0

BOP Flexible Hoses-West & 3rd party NDE 0

Choke Manifold & Lines-West & 3rd party ND 0

Poor Boy Degasser-West 0

Production Test Line-West & 3rd party NDE 0Drill String-EMDC OS and 3rd party NDE 0

Lifting Equipment-Drilling- West & 3 rd party 0

Lifting Equipment-Cargo- EMDC OS 0

Lifting Equipment S hore-Logistics Supervisor 0

Rig Acceptance Checklist- EMDC OS& West 0

Medical Hygeine- IMOHD & AEA SMI Doctor 0

Personnel Qualifications- Opts. Supt. 0

Third Party Drill Tools- 3rd party inspections 0

Helicopter Operations Audit-MPN Aviation 0

Helicopter Facilities Rigsite-MPN Aviation 0

Total finish (average on all items above) 0.00 %

0 20 40 60 80 100

Rig Inspections- Inspection Plans

Rig Inspections - Non Destructive Testing

• Magnetic ParticleInspection

• Ultraviolet• Eddy Current

• Ultrasonic

Riser Spider

Handling Equipment Lifting Equipment

• Ideal for identification of fatigue related failures• Highly dependant on experience level of inspector • Also applied to other areas - such as crane pedestals,

structural areas

Rig I ti N D t ti T ti g

HP Piping

• UT of HP piping is ahigh priority

• Focus on high flowareas(tees, elbows)

• Well control andstandpipe

• Lines in closeproximity to cementand mud pumps

• Freshly painted lines -may have been painted to

cover extensive corrosion

Rig Inspections Visual

Rig Inspections - Visual

Wire Rope

Rig Inspections Being Thorough

Rig Inspections - Being Thorough

BOP C&K Line Hose

Shows normalwear and tear.Passed both lowand Highpressure

tests to companyguidelines.

Rig Inspections Being Thorough

Rig Inspections - Being Thorough

Upon visual inspection of theinside of the hose with aboroscope the inner liningwas found to be damaged andthe hose rejected.

Rig Inspections - Tubulars

Tubular inspection based on DS-

1 Criteria.Varies on well requirements

• Dependent on Inspector Quality

• Perform as early as possible -in case of high rejection rate

• Mark and separate failedtubulars - get off rig!!

Ri I i Vi l H F

Rig Inspections - Visual: Human Factors

• Does driller have aclear view ?

• What type of work arewe going to be doingwith the rig ?

• Weight Indicator working properly ?

• Pressure monitoringsufficient ?

• Do we have amudloggers screenon the rig floor - dowe need it ?

Rig I ti Vi l H F t

Ri I ti Ri O bilit E i t

Rig Inspections - Rig Operability: Equipment

• Does the rig have sufficient pump capacity for our planned

operations ?• Is the solids control equipment up to our program

requirements ?• How will this rig’s equipment capability limit us?

Rig I ti Rig O bilit S d L t

Rig Inspections - Rig Operability: Space and Layout

• Does the rig have enough roomfor our planned operations ?

• Is pit capacity sufficient ?

Summary

• Learned about different types of rigs and their operating environment

• Learned about 5 main rig systems, their

functions and some broad selection criteria• Learned about tubular and other rig type

handling equipment

• Learned about rig acceptance inspection work

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