MPD Fundamentals DPA Rio

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PD Fundamentals - Calgary, AB. Dec10

MPD Fundamentals

Rio de Janeiro, BrazilFeb 2011

2010 Schlumberger. All rights reserved.

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.


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?


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


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


How is ittriedto be done conventionally inNarrowMud Weight Window?

PorePressure

FractureGradient

Pressure

D e p

t h

Dynamic PressureGradient (ECD)

Static PressureGradient (ESD)



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)



BHP is constantat all times

Case 1. Narrow Mud Weight Windows


Conventional vs. MPD Approach

Pressure

D e p

t h

PorePressure

FractureGradient

Gradient werelosses areobserved

2. Diesel Gradient

1. Water Gradient



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)


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


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


MPD Equipment Diagram

Rig Pumps

Mud Pits

Shakers

Flow Line

BOPStack

BellNipple

Standpipe

Equipment for Conventional Operations


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PD Fundamentals - Calgary, AB. Dec10 1


MPD ChokeManifold

PrimaryLine

BOPStack

RotatingFlowHead

Standpipe

Rig Pumps

Mud Pits

Shakers

Separator

To RigsPoor Boy

Equipment for MPD OperationsMPD Equipment Diagram


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.


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


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


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)


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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MPD Fundamentals DPA Rio