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SchlumbergerP
ublic
Equipment, Systems and Processes
Mark E. Teel
Client-Relations Manager
SRC Schlumberger Rosharon Center
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2 Initials
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3 Initials
5/15/2012
The Life of Oil and Gas Wells and ReservoirsSeismic
ExplorationExploration
DrillingDevelopment
DrillingFormationEvaluation
WellTesting
Casing andCementing
Complete StimulateWorkoverInterventions
Monitor andManage
Plug andAbandon
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4 Initials
5/15/2012
Oil and Gas Drilling Rigs
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5 CAP
How deep is deep?
500 m
(1640 ft)301 m
(988 ft)
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6 Initials
5/15/2012
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7 Initials
5/15/2012
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8 Initials
5/15/2012
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9 Initials
5/15/2012
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10 CAP
Identifying Needs and Challenges
So, How deep
are we going?
Deeper than
ever!
Empire
State
Building
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11 Initials
5/15/2012
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12 CAP
How deep are we going below the seafloor?
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13 Initials5/15/2012
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14 CAP
How deep are we going below the seafloor?
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15 Initials5/15/2012
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17 Initials5/15/2012
Wellbore Architecture
WellCompletions
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Multilateral Wells and Wellbore Junctions
StrengthSolids Exclusion
Hydraulic Pressure Isolation
Lateral accessDefine technique, coiled tubing, wireline, rig
Size and type of tools for intervention
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20, Completion Basics15-May-12
What is a well completion?
Equipment installed and procedures performed in oil or gas
wellbores to facilitate flowing fromproductionor pumping
intoinjectionsubsurface formations after drilling, running
steel casing and cementing the primary casing or liner in place.
Production tubing and other equipment components of a well
completion helptransport hydrocarbonsto surface in an
efficient cost-effective, controlled, measured, and safe manner.
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Well Completions Conveyance, or transport, into and out of
Data acquisition Flow control and flow management
Communication and data transmission
SAFETY !
Completion installations can be:
temporary for well testing or
permanent for long-term production
life of a well, field, or reservoir
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22 Initials5/15/2012
Oilwell PerforatingPerforate
Wireline conveyed
TCPTubing Conveyedperforating
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Explosive Shaped-Charges
TCP Tubing-Conveyed Perforating
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Shaped Charge Animation (to 30 microseconds)
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Shaped Charge Animation (to 140 microseconds)
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28 Initials5/15/2012
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29, Completion Basics15-May-12
Cased, Cemented and Perforated
The most common type of well completion
Selective production, stimulation and zonal isolation
Pressure control and safety
Multiple individual zones completed in a single wellbore
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PERF Lab Testing CapabilitiesPV-93 Test (2008) PV-94 Test#001 (2009)
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32, Completion Basics15-May-12
Well Classifications Wellbore and reservoir interaction
Steel cased, cemented and perforated
Openhole, or barefoot
Standalone screens, gravel and frac packs
Vertical, high-angle, and horizontal
Flowing method Natural flow
Artificial lift
Number of completed zones Single
Multiple
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Completions tubulars and equipment-plumbing
33, Completion Basics15-May-12
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34 Initials5/15/2012
Well
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35 Initials5/15/2012
Wellbore Architecture
WellCompletions
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36, Completion Basics15-May-12
Packers ANCHOR production tubing inside cemented casing SEAL to isolate the tubing-casing annulus and act as a
pressure barrier between formation, or reservoir pressure,
and the upper wellbore annulus or between multiple zones
PROTECT upper steel casing from erosion, corrosion:
H2O, H
2S, CO
2
Available in different types:
Permanent
Retrievable
Single, dual or triple string, multi-ported, sealbore
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X-Series Retrievable Production Packers
XHP
XMP
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38, Completion Basics15-May-12
Openhole Sandface Completions
Advantages
Maximizes area open to flow
Decreases pressure drop, or pressure drawdown
Minimizes formation damage from cementing,
perforating and completion fluids and operations
Disadvantages
Lack of pressure containment and selective control
Possible borehole instability and risk of hole collapse
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Mechanical Screens and ICD Inflow Control Devices
39, Completion Basics15-May-12
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Swellable Openhole Packers
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WellC l
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42 Initials5/15/2012
Sand-Control Completions and Pumping
Completions
Z l
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43, Completion Basics15-May-12
Zones to be completed
When more than one zone will be
producing at the same time
When zones are prepared to produce
at different periods of time without
need of major intervention (workover)
May need: dual, triple strings, sliding
sleeves, permanent control valves
Remedial workovers difficult whenmore than one tubing is used
Sequential Production with a
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44, Completion Basics15-May-12
Sequential Production with a
Packer and Single Tubing String
Zone 2: 1000 psi
Zone 1: 1500 psi
Sequential Production with a
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45, Completion Basics15-May-12
Sequential Production with a
Packer and Single Tubing String
Zone 2: 1000 psi
Zone 1: 1500 psi
Commingled Production with a
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46, Completion Basics15-May-12
Commingled Production with a
Packer and Single Tubing String
Zone 2: 1000 psi
Zone 1: 1500 psi
Packers and Sliding Sleeves or Valves
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47, Completion Basics15-May-12
Packers and Sliding Sleeves or Valves
and Single Tubing String
Zone 2: 1000 psi
Zone 1: 1500 psi
Sliding Slee es
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48, Completion Basics15-May-12
Sliding Sleeves
Provide communication tubing-annulus
Used to circulate wells
To produce selectively different zones
Reduced internal diameters
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49, Completion Basics15-May-12
Flow Management: Two Production Zones
Dual producing zones, formations or reservoirs
Drilling, well-construction and well-completions savings
l A l
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Flow Management: Accelerated Production
and Optimal Reserve Recovery
Intelligent Completions benefits and history
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0.7
0.6
0.5
0.4
0.3
0.2
0.1
100 200 300 400 500 600 700
Days
Intelligent Completions benefits and history
Cumulative Oil Production and Flow Strategy Comparison
Sequentia
l
Uncontrolled
Commingled
Controlled
Commingled
Flow Management
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Oseberg
B-38 is the 2nd well
drilled exclusively in
the Ness formation
Ness target contribution
70,000 B/D350,000 B/D
(field)
7 in. QUANTUM
isolation
packers
Completion string
Subsurface Safety
Valve
Flow control valve
1 per zone
9-5/8 in. QUANTUM
production packer
Flow Management
Permanent Downhole Flow-Control Valves
Phase 1 Prove the ValueSPE 71677 & 107117
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SchlumbergerConfidential
-2700
-2600
-2500
Depth
m TVD MSL
Middle Tarbert coal
UN 1
30/9-B-39 T3*
T3T4
-2700
-2600
4000 5000 6000
4000 5000 6000
@ 2701.5m TVD MSL
OWC UN1/LN35 GS
0 0 .2 0 .4 0 .6 0 .8 1 .0
Ki lometer
LN35
T1
T2UN2 coa l
Top LN35 coal
LN1 coal
DUNLIN GP.
LN 2
LN35
GAMMA MAIN
GAMMA SOUTH
Intra Heather sand,part ly cemented
T5
?
B -38 B , p lan
B38AT2, plan*
B -38 AT2, bore t*
Ran./Et ive Fm
B-38 A , bore t *
Oseberg Fm
OWC GM UN1
OWC GMLN35
Ness Fm.
SHETLAND GP.
Draupne Fm.
Heather Fm.
Tarbert Fm .
-2500
TD
B38AT2
TD
B38A
??
L e g e n d :
*the wells are projected onto the cross-section
TARGETS: mT V D MS L mT V D R K B mMD
T1 2610.0 2668.0 5616,5
T 2 2617.5 2675.5 5836,8
T 3 2663.8 2721.8 6180,0T 4 2670.4 2728.4 6559,7
T 5 2655.9 2713.9 6781,8
Vertical displacement from O FC
Zone 1Zone 1
Zone 3Zone 3
Zone 2Zone 2
Production was declining
Require to produce
untapped reserves
Not continuous
reservoirs
Required long reach and
highly deviated Required to control gas
coning and water
breakthrough.
Case study : Multiple zones selective wells - Norway (2000 2001)SPE 71677 & 107117
Phase 1 Prove the ValueSPE 71677 & 107117
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SchlumbergerConfidential
Long reach & highly deviated Monobore wells
9-5/8 Casing with 7 liner though reservoir
9-5/8 Production and 7 Isolation packers
TRFC-HN remotely operated flow control valves
Hydraulic control lines to surface
Intervention capability
Pressure & temperature monitoring
9 5/8 Casing
3 Flow Control
Valve3 Flow Control
Valves7 Liner
Production
packer
Case study : Multiple zones selective wells - Norway (2000 2001)SPE 71677 & 107117
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55 Initials5/15/2012
Expansion joints
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56, Completion Basics15-May-12
Expansion joints
Allow thermal expansion and
contraction of tubing string
between fixed points
Allows tubing disconnection and
reconnection of upper completion
with sealing
Composed of a assembly with
elastomer seal and wiper rings,
depending on downhole conditions
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58, Completion Basics15-May-12
Pump-Out Plugs Base component of production tubingstring, many times for hydraulically
set packers
Guide re-entry of intervention tools
into tubing once seat and ball are
expended
Allow for easy liner top entry in high-
angle wells
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Reentry Guide
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60, Completion Basics15-May-12
Reentry Guide
Component in the production tubing
Guide reentry of intervention tools
back into tubing
Allow for easy liner top entry in
high-angle wells
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Landing Profile Nipples and Locks
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62, Completion Basics15-May-12
Landing Profile Nipples and Locks
Allow landing and locking of multiple
accessories in the tubing string for:
Flow control
Plugging devices
Many different profiles
Basic types: No-go and selective
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Completion Accessories-Chemical Injection
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Completion Accessories Chemical Injection
64 CAP
SchlumbergerPrivate
DCIN - Features
New generation of chemical injection mandrels
One piece body (no welds)
Limited leak paths Internal check system
Proven supplier of check valves
Checks can be tested to full working pressure installed in to themandrel
Optional profile
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Control-Line Clamps and Protectors
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66, Completion Basics15-May-12
Purpose
Protect control line
Support control line
Features
Location on tubing couplings
Lightly grip control line
Multiple line capability
Upset for Large O.D. assemblies.
Various types and sizes of lines.
Flow Control: FIV Formation Isolation Valve
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Bi-directional ball valve to provide a
Safety Barrier during the well completion
program
Rig time savings via remote actuation
Improve and enhance reliability and
operability
Next Generation FIV
n-Trigger
New MechanicalSection
New Ball Section
Contingency Opening
Tool
API Debris Testing
Actuation Module
Mechanical / Ball Module
n-Trigger
S-Trigger
MFIV-II
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Mechanical Ball
Shifting tool interface
Holds valve open/close
Barrier
- Rotates
open/close
Same mechanical and ball sections as FIVSame mechanical and ball sections as FIV--IIII
Same shifting tools as FIVSame shifting tools as FIV--IIII Extensions 3ft, 6ft or 9ft, same as for FIVExtensions 3ft, 6ft or 9ft, same as for FIV--IIII
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Flow Control
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Surface-Controlled Subsurface Safety ValvesPrimary purpose
Emergency well-control device
Prevent: (Piper Alpha)personnel, environmental,
equipment, and reserve losses
Secondary purpose Downhole flow control
allow for wellhead maintenance
serve as a secondary barrier
SafetyValveConstructionSafetyValveConstruction
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Hydraulic PistonHydraulic Piston Power SpringPower Spring FlapperFlapper
Power SourcePower Source[Opening Force][Opening Force]
Closure MechanismClosure MechanismPower SourcePower Source[Closing Force][Closing Force]
Surface Controlled Subsurface Safety Valve (SCSSV)Surface Controlled Subsurface Safety Valve (SCSSV)
StandardSpringStandardSpringTypeDesignTypeDesign
FlapperClosureFlapperClosure
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FlowtubeFlowtube
pp
PowerSpringPowerSpring
Hydraulic
PistonHydraulic
PistonPiston
BorePiston
Bore
Production
Production
TubingPressureTubingPressure
FlowTubeandFlapperClosureMechanismsFlowTubeandFlapperClosureMechanisms
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Intelligent CompletionsMonitor and
Manage
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75 Initials5/15/2012
Reservoir Monitoring Control.Real time production optimization
Reservoir EnergyPressure
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76 Initials5/15/2012
Water drive Gas drive Solution-gas drive
Artificial Lift Technologies
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77 Initials5/15/2012 Electrical submersible pumps
Gas lift valves
Natural Flow or Artificial Lift
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78, Completion Basics15-May-12
Natural flow: Enough reservoir
pressure to bring fluids to surface
Artificial lift: Add energy to the fluid
Electrically driven, mechanical
positive-displacement beam pumps
ESP electric submersible pumps
Gas lift (re-injecting produced gas)
Side-Pocket Mandrels
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SchlumbergerPublic
79, Completion Basics15-May-12
Annulus-tubing communication
device in an artificial-lift completion
A valve is located to allow gas toenter the tubing to lift the oil
More than one are installed in a well
INJECTION GAS
PRODUCED FLUID
PRESSURE (PSI)1000 20000
CONSTANT FLOW GAS LIFT WELL
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INJECTION GAS
DEPT
H(
FT
TVD)
1000
2000
3000
4000
5000
6000
7000
0
OPERATING GAS LIFT
VALVE
CASING PRESSURE WHEN
WELL IS BEING GAS LIFTED
FBHP
SIBHP
FLOWINGTUBINGPRES
SUREGRADIENT
Gas lift
valves
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Stimulate
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Stimulation, Pumping Services
Acidizing
Fracturing
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P&A Plug and AbandonAbandonment
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Four Life Stages of Reservoir Development
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87 Initials5/15/2012
Stage 2
Delineation
Determinethereservoirextent
Determinereservoirproperties
Determine
reservoirmodel
Furtherreduce risk
Stage 1
Exploration
Starting to reducethe risk
Choose the rightpoint
Locate potentialreservoir
Stage 3
Development
Achieving fullproduction
Refine reservoir model
Reservoir monitoring
Continue reducing therisk
Stage 4
Late Life
Water production
Depleted pressure
Intervention
Stimulation
Flow assistance
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Focus on Technology and the Reservoir Life Cycle
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Exploration Appraisal Development Production
Reservoir Optimization
Traditional Development
CashFlow
+
0_ Time