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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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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?

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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

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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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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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