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4/20/2012
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Primary funding is provided byy g p y
The SPE Foundation through member donations and a contribution from Offshore Europe
The Society is grateful to those companies that allow their professionals to serve as lecturers
Additional support provided by AIME
Society of Petroleum Engineers Distinguished Lecturer Programwww.spe.org/dl 1
Drilling Automation:New Prospects and Prospectors?New Prospects and Prospectors?
Fred FlorenceNational Oilwell Varco
Society of Petroleum Engineers Distinguished Lecturer Programwww.spe.org/dl
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4/20/2012
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Drilling Automation
Will automation eliminate the need for a driller
• Why automated drilling?
• Mechanization andneed for a driller on the rig?
• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
3
g
• What is the latest?
• What comes next?
• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
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• Drilling Safety and Performance
Why Automated Drilling?
• Completions Accuracy and time to deploy
• Production Well placement and better well quality
• Reservoir Getting logs reliablyReservoir Getting logs reliably
Maybe you can think of other reasons.
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• Today drilling is a
Why Automated Drilling?
• Today drilling is a manual process– Rheostats
– Levers
– Steel bar
– Gaugesg
6Source: Schlumberger – SPE Conference
4/20/2012
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• New control systems
Why Automated Drilling?
• New control systems can mechanize surface activities
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Why Automated Drilling?
• Improve Safety at well center and overall
• Reduce process variability of repetitive tasks
• Reduce wellbore risks
• High speed calculations and models can adapt to dynamic events
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• Simultaneous activities go beyond human capabilities
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• Need to tie
Drilling Automation?
Draw-works
Mud Pump
Top Drive
DrillerMPDMud
Proc SensorsOffsite
Monitoring & Support
Coil TubingCement???
Each machine has its own control
• Need to tie the surface machines to the downhole equipment and data
Geologist Drilling Eng
OFF SITE
Magic Box-Closed Loop Control-Envelope Protection-BHA Downlinking-What Else?
3rd Parties- Command/Limits
- No direct machine control
Steering Equip.
Survey Meas.
Formation Evaluation
Drilling Mechanics Measurements
At Bit Meas
.
Distributed Sensors
Comms Method
• Automate the downholeprocess 9
Source: Research Council of Norway –IRIS Conference 2008
Source: Schlumberger – IRIS Conference 2009
Draw-works
Mud Pump
Top Drive
DrillerMPDMud
Proc
Magic Box
SensorsOffsite
Monitoring & Support
Coil TubingCement???
Each machine has its own control
SurfaceSurfaceRemoteRemote
Geologist Drilling Eng
OFF SITE
Magic Box-Closed Loop Control-Envelope Protection-BHA Downlinking-What Else?
3rd Parties- Command/Limits
- No direct machine control
Steering Survey Formation Drilling Mechanics At Bit
Distributed Sensors
Comms Method
RemoteRemote
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Steering Equip.
Survey Meas.
Formation Evaluation
Drilling Mechanics Measurements
At Bit Meas
. DownholeDownhole
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Drawworks
MudPump
TopDrive
DrillerMPDMud
Proc SensorsCoilTubingCement???
Magic Box-Closed Loop Control-Envelope Protection-BHA Downlinking
Comms Method
Each machine has its own control
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o g-What Else?
SurfaceSurface
Steering
Equip.
Survey
Meas.
Formation
EvaluationDrilling Mechanics Measurements
At Bit
Meas
.
Distributed SensorsDownholeDownhole
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Offsite Monitoring &
Support
RemoteRemote
3rd Parties- Command/Limits
Support
ON SITE
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Geologist Drilling Eng
OFF SITE
- No direct machine control
Draw-works
Mud Pump
Top Drive
DrillerMPDMud
Proc
Magic Box
SensorsOffsite
Monitoring & Support
Coil TubingCement???
Each machine has its own control
Geologist Drilling Eng
OFF SITE
Magic Box-Closed Loop Control-Envelope Protection-BHA Downlinking-What Else?
3rd Parties- Command/Limits
- No direct machine control
Steering Survey Formation Drilling Mechanics At Bit
Distributed Sensors
Comms Method
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Steering Equip.
Survey Meas.
Formation Evaluation
Drilling Mechanics Measurements
At Bit Meas
.
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The “Magic Box”
• BHA Downlinkingg
• Envelope protection
• Closed loop control
• What else?
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The “Magic Box”
• BHA Downlinkingg
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The “Magic Box”
• Closed loop controlp
Parameter A
Autodriller controls payout based on boundary conditions
Parameter B
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The “Magic Box”
• What else?
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• IRIS with models-to-controls in Norway via “Drilltronics”
• SPE/IADC Amsterdam 2011
Two SPE papers showing ROP enhancement of about 30%
• Also JPT series of articles of Sept 2011
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The “Magic Box”
• BHA Downlinking • Commercial todayg
• Envelope protection
• Closed loop control
• What else?
y
• “Limits Management”
• For limited tasks
• A few already in field-testing
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• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
• First designs allowed for
Mechanization & Automation
allowed for manual back up.
• Newer designs allow more options for
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options for faster performance.
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• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
• Drill crew
O / ff it h b t d t
New Roles and Responsibilities
• On / off switch, but needs to understand impact of others
• Still in charge of the process
• Company representative
• Use as a tool, but need ability
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to make changes to suit new conditions
• Use case/safety case
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• For service company personnel
N t i hi
New Roles and Responsibilities
• New access to rig machinery
• What will they do with it
• Fewer personnel at rigsite
• More value downhole? offsite?
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• Off-site
W ll l i h
New Roles and Responsibilities
• Well planning changes
• Advisory versus more rapid
local control
• More multi-functional, but how to manage it?
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• What happens when communications go down?
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• May need an extra technician,
b t i il t ddi
New Roles and Responsibilities
but similar to adding a
subsea engineer offshore
• Depends on value
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• Its is different
All d t k h th
New Roles and Responsibilities
• All need to know how the difference affects the program
• Human factors as much or more than technology
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• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
Land Rigs, Too?
• High value for deepwater rigs
• Also for conventional and non-conventional land– Well placement
– ROP enhancement
– Reduction in NPT
– Fewer service personnel
and associated travel costs
C t l l d
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– Capture lessons learned
– Some say “well manufacturing”
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• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
• SPE Drilling Systems Automation
What Is The Latest?
• SPE Drilling Systems Automation Technical Section (DSATS)
• IADC Advanced Rig Technology Committee (IADC ART)
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( )
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• SPE Conferences and Forums
What Is The Latest?Drilling Systems Automation Technical Section (DSATS)
• SPE Conferences and Forums
• Sub-committees
• Standard Protocol and Language
• Reliability
• Road Map
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• Road Map
• New Issues and Developments
http://connect.spe.org/dsatshttp://connect.spe.org/dsats
• San Diego, CA, USASPE/IADC Drilling Conference - DSATS Panel Session
5 Mar 2012
What Is The Latest - DSATS?
• Graz, AustriaIEEE International Instrumentation and Measurement Technology Conference13-16 May 2012
• Vail, CO, USASPE Workshop “Drilling System Automation - The Next Big Jump”16-18 July 2012
• International Drilling Competition 2012/2013
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• International Drilling Competition 2012/2013
• Field data for Universities?
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• Advanced Rig Technology (ART) D illi C t l S b itt
What Is The Latest? International Association of Drilling Contractors (IADC)
Drilling Controls Subcommittee
• Control philosophy of contractors
• Business case
• Rig interface
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ART Drilling Controls Subcommittee
What Is The Latest - IADC?
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• Security
What Is The Latest – Concerns?
• Reliability
• Performance
• IP protection
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• Why automated drilling?
• Mechanization and• Mechanization and automation
• New roles and responsibilities
• Land rigs too?
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g
• What is the latest?
• What comes next?
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What comes next?
• New technologies allow i t ti f f dintegration of surface and downhole on advanced rigs
• Migration to conventional rigs to improve performance
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rigs to improve performance depends on local issues
What comes next?
• What change t l t ?can we tolerate?
• What value does it bring?
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4/20/2012
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Conclusions
• Operators and contractors see the value of providing automated systems applied to theproviding automated systems applied to the drilling process, not just pipe handling
• Guidelines are being developed that may be adopted as industry standards
• Implementation issues are being resolved
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Conclusions
• New models are emerging and they now have a means to connect to the rig equipmentmeans to connect to the rig equipment
• The connection of models and/or remote controls to the drilling machines is proven and beneficial
• Drilling automation continues to evolve and will require new organizations and business models
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require new organizations and business models
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Thank you for your time and attention.
I also wish to thank my employer, National Oilwell Varco, for allowing me to participate in this program, and many thanks to the SPE for the invitation to visit its sections and meet so many interesting people.
The future of drilling automation will likely affect most of us.
Your participation is encouraged. Join us.
http://connect.spe.org/dsats/http://connect.spe.org/dsats/
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