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MPD Fundamentals
Rio de Janeiro, BrazilFeb 2011
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Agenda
About MPD
MPD Classification & Techniques
The MPD Engineering Process
How does MPD solve pressure related problems during drillingoperations?
Equipment used in MPD Operations
Operational considerations when doing MPD
Automated MPD Operations
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What is NOT MPD?
Independent of the fluid system,MPD ISNOT A TECHNIQUE TO DRILLUNDERBALANCED. By definition, MPDoperations are planned to keep thebottomhole pressure above the porepressure at all times.
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an adaptive drilling process used to precisely control the
annular pressure profile throughout the wellbore. The objectives
are to ascertain the downhole pressure environment limits and
to manage the annular hydraulic pressure profile accordingly.MPD is intended to avoid continuous influx of formation fluids to
the surface. Any influx incidental to the operation will be safely
contained using an appropriate process.
What is MPD?
IADC defines MPD as:
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Extends casing setting depth
Use of a lighter mud weight in cases where high mud weights is a
concern
Dynamic management of small influxes
Immediate Pressure Profile change by modifying WHP
Increases ROP
Reduces Formation Damage
Limits or avoids Lost CirculationAvoids Differential Sticking
Avoids cavings associated with geomechanical instability
Why MPD?
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MPD/UBO IADC Classification
The International Association of Drilling Contractors (IADC) has established anMPD/UBO Classification System based on three digits, each digit indicating:
0 Performance Enhancement only. Nohydrocarbons1 Well incapable of natural flow tosurface2 Well capable of flowing to surface butcontrol can be done conventionally3 Geothermal and non-hydrocarbonbearing formations4 Hydrocarbon bearing formations.MASP < MPD Equipment Rating5 Hydrocarbon bearing formations.MASP > MPD Equipment Rating
Risk Level Classification
A MPDB UBOC Mud Cap Drilling
Application Category
1 Gas2 Mist3 Foam4 Gasified Liquid5 Liquid
Fluid System Classification
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MPD Variations
Constant Bottom Hole PressurePressurized Mud Cap Drilling
Dual Gradient Drilling
HSE & Performance Drilling
Low Head Drilling
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DataGathering
FlowModeling
TechnicalPeer Review
FeasibilityStudy
EquipmentPre-Selection
P&ID EquipmentList
PersonnelList
Engineering
Operations
CandidateScreening
Client OpsData Collection
The MPD Engineering Process
FeasibilityStudy Approval
Fine TuneOperating Window
Develop Basisof Design
TechnicalPeer Review
UBD/MPDProgram
ExecutionPhase
1. Well Supervision2. Management of
Change3. Reporting
Evaluation Phase
Planning Phase I
Planning Phase II
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Case 1. Narrow Mud Weight WindowsHow is it done conventionally in Normal Mud Weight Window?
PorePressure
FractureGradient
Pressure
D e p
t h
2. Dynamic condition (pumps on)
1. Static condition (pumps off)
Dynamic PressureGradient (ECD)
Static PressureGradient (ESD)
SurfacePressure =
AtmosphericPressure
FrictionLosses
Pressure
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How is ittriedto be done conventionally inNarrowMud Weight Window?
PorePressure
FractureGradient
Pressure
D e p
t h
Dynamic PressureGradient (ECD)
Static PressureGradient (ESD)
2. Dynamic condition (pumps on)
1. Static condition (pumps off)
Loss of circulation!!!!!!
Case 1. Narrow Mud Weight Windows
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Solution: Constant BHP MPD NarrowMud Weight Window
Pressure
D e p
t h
PorePressure
FractureGradient
Static PressureGradient (ESD)Dynamic PressureGradient (ECD)
2. Dynamic condition (pumps on)
1. Static condition (pumps off)
BHP is constantat all times
Case 1. Narrow Mud Weight Windows
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Conventional vs. MPD Approach
Pressure
D e p
t h
PorePressure
FractureGradient
Gradient werelosses areobserved
2. Diesel Gradient
1. Water Gradient
Loss of circulation!!!!!!
Loss of circulation!!!!!!
Tried curing the losses No success
Tried curing the losses No success
3. Water + Nitrogen Success
Case 2. Formations that lose circulation at low pressure gradients
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Other techniques that can be appliedNon-existing Mud Weight Window
900 1000 1100 1200 1300800EMW (kg/m3)
I n f l u x
Underbalanced DrillingUsed when a Mud Weight Window does not exist (BHP isalways lower than the pore pressure at some point in the
well)Influx flow rate can be controlled dynamically using theWHPRequiressurfacefluid handlingfacilitiesIn the case of corrosive fluids from the reservoir, proper measurementsmust be taken to avoid corrosion
Losses
Losses
Mud Cap DrillingUsed when a Mud Weight Window does not exist (BHP isalways higher than the losses pressure at some point in
the well) A variation called Pressurized Mud Cap Drilling (PMCD) isusedfor safety reasonsRequireshigh volumes of sacrificial fluidFractureswide enough to inject cuttingsmust exist
900 1000 1100 1200 1300800EMW (kg/m3)
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Conventional Approach vs. MPD
In the previous slides, one of the most applied MPD techniquesknown as Constant Bottom Hole Pressure has been shown.One of the limitations of this technique (among other MPDtechniques) does not come from any technical, operational or logistic issue but from an old paradigm:
The presence of pressure on surface duringdrilling operations is undesirable
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Losing the control of the operation (and eventually, of the well)is what is undesirable, independently of the used drillingtechnique.
Independently of the well condition, you will detect any
pressure-related anomaly quicker using MPD than duringconventional operations.
Conventional Approach vs. MPD
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MPD: Technology for extreme environments
Deep Water ERDHorizontalMature DepletedOn & Off Shore HPHT
FracturedReservoirs
Kick detection Narrow margin ECD reduction Loss avoidance Wellbore stability
ECD reduction Loss avoidance Stuck pipe avoidance Hole cleaning Drilling optimization
Narrow margin ECD reduction Loss avoidance Wellbore stability Kick detection Drilling optimization Reservoir damage
Wellbore breathingavoidance
Kick detection Narrow margin Wellbore stability Loss avoidance Pressure
environmentdetection (DynamicFlow-in/Leak-Off)
Kick detection Controlled losses Reservoir damage
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Examples of MPD Systems Applications
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MPD Equipment Diagram
Rig Pumps
Mud Pits
Shakers
Flow Line
BOPStack
BellNipple
Standpipe
Equipment for Conventional Operations
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MPD ChokeManifold
PrimaryLine
BOPStack
RotatingFlowHead
Standpipe
Rig Pumps
Mud Pits
Shakers
Separator
To RigsPoor Boy
Equipment for MPD OperationsMPD Equipment Diagram
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MPD ChokeManifold
Flare
PrimaryLine
BOPStack
RotatingFlow
Head
Standpipe
Line to shakers
Rig Pumps
Mud Pits
Shakers
Separator
Equipment for MPD OperationsMPD Equipment Diagram
NitrogenGeneration Unit
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Instructor Choke Operator to Set new
WHP(A dedicatedoperator is necessary)
F l o w t o
S h
a k
e r s
o r
S e p a r a
t o r
Conventional Offline HydraulicSimulator
(not updated in Real Time)
InformationInput by
user
Rig InfoInput by user
(updated manually)
Well GeometryBHA Geometry
BHCP (Set Point)
Calculate WHP
MWDepthFlow Rateetc
Yes
Constant Bottom Hole Pressure (CBHP) OperationsHow is it done manually?
Calculated WHP Actual WHP?
Drill ing Parameters are read and
entered manually into a hydraulicsimulator.
Simulations are run offline by atrained engineer, who needs toconstantly check the parameters andrun simulations if necessary.
There is an important time gapbetween any event and the adjustingtime to compensate for thoseevents.
A choke operator is necessary 24hours a day to adjust the chokevalve to keep the surface pressureat the desired value while drilling.
Used when MPD techniques arenecessary, but a very precisesurface control and bottomholepressure is not mandatory.
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Constant Bottom Hole Pressure (CBHP) OperationsHow is it done automatically?
Set newWHP
remotely
F l o w t
o S h
a k
e r s
o r
S
e p a r a
t o r
RT HydraulicSimulator
InformationInput byuser
Rig Info Inputvia WITS(continuously updated)
Well GeometryBHA Geometry
BHCP (Set Point)
Calculate WHP
MWDepthFlow Rateetc
CalculatedWHP Actual
WHP?No dedicated operator isnecessary
Drill ing Parameters are fed into areal-time hydraulic simulator.
Simulations are run continuously inreal time without human intervention.
The system reacts immediately toany event and adjusts the surfacebackpressure to compensate for those events with a very small lagtime.
No dedicated choke operator is
necessary to keep the surfacepressure at the desired value whendrilling or tripping.
Used when MPD techniques arenecessary and a very precisesurface control and bottomholepressure is mandatory
Yes
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Primary Line(flow from the well)
Line to shakers
Line to FlareMPDChoke Manifold Separator
RotatingControl Device
Actual Equipment DistributionEquipment used in MPD Operations
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Actual Equipment Distribution
ESD Primary Line (flowfrom well)
Nitrogen GenerationPackage
Nitrogen InjectionLine
Returns Line (toshale shakers)
Vertical Separator
MPD ChokeManifold
Flare Line(Blooie Line)
Equipment used in MPD Operations
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Automated System Process Diagram
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Automated MPD System Actual Set Up
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Flow Line
RCD
4/6 x 5000 Line to UBDChoke
Hydraulic Valve 7 1/16 x 5K
Weatherford
7100 7800
Optimal (Schlumberger)RCD5 RCD3
StrataSmith (SLB)
HOLD2500
Equipment used in MPD OperationsRotating Control Device (RCD)
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RCD5 Model2000 psi @ 100 rpm
RCD3 Model1000 psi @ 100 rpm
Rotating Control Device (RCD)Equipment used in MPD Operations
wi th bea ring without bearingpsi / MPa in / mm in / mm in / mm in / mm in / mm
RCD3 3,00020.68
11279.4
7 1/16179.4
11279.4
7 1/16179.4
40 1/21028.7
RCD5 5,00034.47
13 5/8346.1
9 1/16230.2
13 5/8346.1
Two: 7 1/16 & 2 1/16179.4 & 52.4
44 1/21130.3
Lateral outlet size HeightModelPressureRating
BottomFlange Size
Bore Diameter
Play Video
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Operational considerations when doing MPD
Space (height) for the RCD
MWD/LWD Signal Attenuation when Gas is Injected (Mud PulseSystems)
Connections Procedure
Equivalent Liquid Flow Rate Limit for Mud Motors
Hole Cleaning (Multiphase environments)
Layout (extra space for equipment)
BOP Stack / Rig MisalignmentDrill String condition
Crew Training
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