Post on 12-Jun-2018
Primary funding is provided by
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
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Managed Pressure Drilling:
Drill the Un -Drillable
Lecturer’s Name: Hani Qutob
Reservoir Engineering & UBD/MPD Advisor
Senergy GB Limited – Dubai, UAE
Society of Petroleum Engineers
Distinguished Lecturer Programwww.spe.org/dl
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• Reservoir Engineering & Advanced Drilling Technolog y
• Advanced Drilling Technology Variations
• What is Managed Pressure Drilling?
• Optimal Redefined Time/Cost line
• Variables that can be Manipulated during MPD
Presentation Outlines
• Variables that can be Manipulated during MPD
• What Are the Main MPD Benefits?
• Managed Pressure Drilling Variations.
• Health, Safety and Environment Issues
• Case Histories obtained worldwide.
• Conclusions
• Acknowledgement
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Advanced Drilling Technology® (ADT®) & Reservoir Benefits
How ADT® can increase reserves and improve recovery
� Minimizes Formation Damage - UBD.
� Accesses Challenging Reservoirs - MPD.
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� Improves Reservoir Characterization - UBD
� Identifies Missed Pay – UBD.
� Increases Production & Enhances Recovery
- UBD / MPD
By: Accessing Challenging Reservoirs
The single biggest reserve contribution of MPD is found to be access to reservoirs that could not be drilled conventionally.
In almost all cases, MPD is used in challenging or partially depleted reservoirs, only after conventional wells prove
How Managed Pressure Drilling – MPD Benefits the Reservoir?
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depleted reservoirs, only after conventional wells prove expensive, unsuccessful or un-drillable
Some reservoirs that could be difficult to access using conventional drilling techniques are:
1. Low pressure & depleted reservoirs2. Vuggy/fractured carbonates where OB circulation is
impossible3. Reservoirs with a narrow margin between fracture
pressure and pore pressure - kicks/losses cycles
ADT® Variations
ADT® is an adaptive drilling process which enables a more precise control of wellbore pressures through the use of
engineered equipment & processes.
Advanced Drilling Technology® (ADT®)
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Air DrillingImprove Drilling Economics - Intent is to invite surface flowPrimarily non-liquid hydrocarbon formations
Underbalanced Drilling:Maximize Reservoir Value - Intent is to invite surface flow
Managed Pressure Drilling:Optimize Drilling Process - Intent is not to invite surface flow
What is Managed Pressure Drilling?
A closed and pressurizablemud-return system, a Rotating Control Rotating Control Head, and choke.
operations provide precise control of the wellbore pressure profile.
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Reactive vs Proactive MPD
Effective on “standby” basis as an enhanced form of passive well
Used to mitigate drilling hazards and reduce NPT by changes to fluid,
Reactive Proactive
form of passive well control to help manage unexpected downhole pressure.
by changes to fluid, casing and open-hole programs
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Collapse
Fracture
Overburden
Dep
thWe like prospects with big drilling windows…
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CollapsePore
Pressure
Dep
th
EMW Must Stay Within Drilling Window For Drilling To Progress
Remaining prospects not cooperating very wellVery narrow or relatively un-known margins
Difficult or impossible to drill conventionally
When MPD is used?
• Kick -Loss ScenariosFracture
Overburden
Collapse
• Kick -Loss Scenarios
• High mud bill
• Excessive casing string(s)
• Drilling NPT – Exceeding AFE
• Environmental issues
• Failure to reach TD with large enough hole for optimum well production
• Or…simply ….“not drillable”12
Pressure
Dep
th
Pore
Bot
tom
Hol
e C
ircul
atin
g P
ress
ure
Small Drilling “Window”
Fluid Losses Fluid Losses
Constant Bottom Hole Pressure
Fracture Pressure
Bot
tom
Hol
e C
ircul
atin
g P
ress
ure
Time
Influx – Tight Hole Influx – Tight Hole
Pore Pressure – Collapse Boundary
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5000000
5500000
6000000
6500000
0 1 2 3 4 5 6 7 8 9 10 1112 13 1415 16 17 1819 20 2122 23 2425 26 2728 29 30 3132 33 3435 36
Time (days)
Acc
umul
taed
cos
t
2100
2200
2300
Mea
sure
d D
epth
(m
)
Cost
Time - Depth
10.3% of total cost
Stuck pipeFishing
MPD VALUE - VISUALIZATION
Real Well – Case 1
LossesCement squeeze
6500000
7000000
7500000
8000000
8500000
Acc
umul
taed
cos
t
2400
2500
2600
2700
0 1 2 3 4 5 6 7 8 9 10 1112 13 1415 16 17 1819 20 2122 23 2425 26 2728 29 30 3132 33 3435 36
Time (days)
Mea
sure
d D
epth
(m
)
11.0% of total cost
Stuck pipeWell flowing
Well control, 10%
Circulating, 23%
POOH, 3%
RIH, 4%
Reaming, 5%
Stuck pipe, 55%
NPT distribution
900000
1400000
1900000
0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64
Time (days)
Mea
sure
d D
epth
(m
)
1800
1900
2000
Acc
umul
ated
cos
t
10.5%
2.3% Time - Depth
Real Well – Case 2
MPD VALUE - VISUALIZATION
Cost
2400000
2900000
3400000
3900000
Mea
sure
d D
epth
(m
)
2100
2200
2300
2400
0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64
Time (days)
Acc
umul
ated
cos
t
17.7% of total cost
20.9% total costLossesCement squeeze
Gas kick, well controlCement plugSidetrack
LossesCement plug
Total lossesGas flow
Effective time, 55%
NPT, 45%
Time distribution (well)
Optimal Redefined Time/Cost line
Optimal time
Conventional drilling (NPT)
Con
vent
iona
l cos
t due
to h
igh
NP
TMPD application is focused on achieving
0
100
200
300
400
500
600
Pore P. Frac. P.Saving in Drilling Time
Sav
ing
in D
rillin
g C
ost
Opt
imal
Cos
t
Con
vent
iona
l cos
t due
to h
igh
NP
T
Dep
th
Case
focused on achieving the well construction
“Optimal time and Cost” as objective
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
$ vs NPT
$ vs NPT
Sav
ing
in D
rillin
g
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Conventional DrillingBottom hole circulating pressure is manipulated by only two variables.
BHCPconventional = Hydrostatic Pressure
+ ∆∆∆∆Pfriction
Affected by Density
Affected by density and flow rate
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Managed Pressure Drilling.
BHCPMPD = Hydrostatic Pressure Affected by density
+ ∆∆∆∆pfriction
+ Choke
Affected by density and flow rate
Manipulatedfrom surface
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Variables that can be Manipulated
Mud density
Mud viscosity Rotating Control HeadChoke Manifold
Variable Equipment
Mud viscosity
Flow rate
Trapped Pressure
Friction Pressure
Choke ManifoldMud pumpsDownhole pump
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In what cases can MPD add value?
�Drilling Exploratory, Appraisal or Challenging Development wells
Drill to the target
� Drill conventionally “Un -drillable” tight Pore
/Collapse /Fracture pressure gradients
� Drill “Un -drillable” vuggy/ fractured carbonates
where Over Balanced circulation is impossible
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What Are MPD Benefits?
• Reduced number of loss/kick occurrences
• Reduced time spent dealing with well control events
• Earlier kick / losses detection
Cost Saving
• Earlier kick / losses detection
• Optimized number of casing strings
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• Trip safely
• Remove H2S hazard from rig floor
• Drill HPHT wells safely
Improved Safety
MPD Variations – Visualization
Constant Bottom Hole Pressure (CBHP)
Returns-flow -control (HSE )
MPDPressurized mud -cap drilling
Dual gradient MPD
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An adaptive drilling process used to precisely control the annular pressure profile throughoutthe wellbore. The objectives are to ascertain the downhole pressure environment limits and tomanage the annular hydraulic pressure profile accordingly. MPD is intended to avoidcontinuous influx of formation fluids to the surface. Any influx incidental to the operation willbe safely contained using an appropriate process.
Drilling Connection Drilling – Change in required BHP
Required BHP (Pore Pressure + Margin)
Drilling Connection Drilling – Change in required BHP
Required BHP (Pore Pressure + Margin)
MPD Official Definition
Hydrostatic
Pressure
Circulating
Friction
Hydrostatic
Pressure
Reduction
in BHP
Circulating
Friction
Hydrostatic
Pressure
New
Hydrostatic
Pressure
New
Circulating
Friction
Hydrostatic
Pressure
Circulating
Friction
Hydrostatic
Pressure
Circulating
Friction
Hydrostatic
Pressure
Same
Hydrostatic
Pressure
Same
Circulating
Friction
Surface
Backpressure Modified
Surface
Backpressure
Surface
Backpressure
New
Surface
Backpressure
Required BHP (Pore Pressure + Margin)
Time / Depth
Equ
ival
ent C
ircul
atin
g D
ensi
ty (
ppg)
Conventional Drilling PracticesTime / Depth
Required BHP (Pore Pressure + Margin)
Managed Pressure Drilling
Risk Management
With all MPD operations a detailed risk assessment as well as a HAZID and HAZOP should be carried out with the rig crew supervisors and the relevant service providers and operator staff.
Understanding the sequence of events and when to initiate MPD operations and discussing the rig up, pressure testing and operational aspects of a job together with all of the procedures will help to ensure the maximum success for an MPD operation.
Health, Safety and Environment Issues
• HAZOPs and HAZIDs are both systematicprocesses to identify hazards.
• “You cannot manage what you don’t know .”26
Case History 1 – Middle East
8 3/8” Section Performance
Offset Well
MPD Well
Total days spent on drilling the 65 40
�To reach the target depth with minimum NPT�To avoid uncontrolled event by maintaining a
constant bottom hole pressure
Objectives
on drilling the section
65 40
Total days spent on well control events (NPT)
7.6 1.1
Total days spent on tight hole/reaming
2.8 days
19 hours Saudi Arabia
(Onshore)28
Case History 2 – North AfricaAlgeria – drilling through high fractured zone
Un-drillable Reservoir Drilled
A total of 191 m weredrilled with a very smalldrilling window .drilling window .
Zero LTI’s or near missesrecorded on this well.
Avoided kick/loss cycles &Improved ROP.
MPD Added Value
NPT reduced to 1 daycompared to 10 daysexperienced in the threeprevious wells drilled.
Case History 3: Offshore India
LOC & Fluid lossesminimized to 290 BBLcompared to 4000 BBLon previous wells.
Avoided kick/loss cycles& Improved ROP.
Case History 4 – South AmericaPetrobras Colombia Limited,
MPD Added Value�No Loss of Circulation �significant cost savings
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Case History 5 – CanadaNortheastern British Columbia,
MPD Added ValueReduced AFE by approximately 19% (saving Can$ 2 Million).
Drilling efficiency was improved by lowering the mud weight and by lowering the mud weight and doubling the ROP .
Considered MPD techniques to increase drilling effectiveness in this field.
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MPD application in VietnamBIEN DONG POC HPHT Gas Condensate Development
BLOCK 05-2 & 05-3 Offshore -Vietnam
Why MPD on this project? �Narrow margin of PP/FG pressure in both fields.
�Early kick detection & control. �Early kick detection & control.
�Better well control in HPHT wells.
�Drill wells to target depth and eliminate additional casing string.
�Providing CBHP during static and dynamic conditions which mitigates stress caging (SC). 33
Project Overview
Phase-1: total sixteen (16) wells:�6 wells in block 05-3 (Moc Tinh)�10 wells in block 05-2 (Hai Thach)�10 wells in block 05-2 (Hai Thach)
Contract status: singed for 4.5 years + potential extension.
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Conclusions
The challenging hydraulics of the world’s remaining prospects indicate MPD will evolve to become a key enabling technology.
Managed Pressure Drilling technology is increasingly being applied in reservoirs that are difficult to drill conventionally (Un-drillable), deep water and High Pressure, High Temperature (HPHT) wells to access HC reserves, enhance operational safety and efficiency.
All “first adopters” of MPD offshore plan future wells.35
Conclusions (cont’d)Managed Pressure Drilling can reduce well costs as a result of;– Reduced number of casings = Smaller
casings = smaller rig – Less consumables (mud and cement)– Less materials and logistics cost– Less materials and logistics cost
Additional Benefits of MPD:– Faster drilling– Reduced formation damage– Improved productivity = improved recovery– Reduced environmental impact
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Proper candidate screeningProper candidate screening is a deliberate process, and is a critical step in the design of a successful ADT ope ration.
Detailed economic analysis is an important step to determine the benefit that MPD could provide compar ed to competing conventional drilling & completion techno logies.
Wrap-Up
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Poor screening and planning results in an over-enthusiastic misapplication of the technology, and possibly fail ure.
Proper Project management , engineering and execution is a key factor for a successful MPD operation .
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Speaker contact details
Hani QutobReservoir Engineering & UBD-MPD AdvisorSenergy GB LimitedDir: + 971 4 387 3022 Dir: + 971 4 387 3022 BB: +971 5 0622 4513 M: +971 5 0657 7328F: +971 2 667 0408 E: Hani.Qutob@senergyworld.comW: www.senergyworld.com