wft ubd dti 020416
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7/27/2019 WFT UBD DTI 020416
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© 2002 Weatherford. All rights reserved.
Weatherford U nder Balanced S ervices
General Underbalance Presentation
to the DTI M.O.S.T.
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Presentation Content
– Underbalance Overview
– Candidate Selection – Reservoir Effects & Flow Potential
– Ultimate Recovery Factor
– Compressible Fluids
– Underbalance Equipment and Technology
– Environment & Safety
– QHSE - Systems and Processes
– Developing Technology
– Summary
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E&P Business Drivers and Value Creation
E&P DRIVERS CREATE VALUEWITH UBS
• Increase Productivity
• Enhance Well Evaluation
• Increase Reserves: (Add andRecovery/Well)
• Improve NPV (EarlyProduction)
• Reduce Drilling Cost (ROP,Fluid Losses, Diff. Sticking)
• Increase BOE Production
• Improve Cashflow - AdvanceTime
• Reduce Life Time Cost
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UB - Global Market Players
UB Market in 2002 = $500 million?
HAL
<5%
<5%
<5%
WFT
40%
50%
60%2002(est.)
Northland
40%
30%
20% 5%
~
Slb (MI)
2000
2001
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Weatherford U nder Balanced S ervicesOrganization and Foundations
INTERNATIONAL
INS
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26GLOBAL UBSGLOBAL UBS
© 2001 Weatherford. All rights reserved.
Click to edit Master title style
USA
• Corporate Office with
Center Team (10)
• Offices: Houston, Casper,Farmington, Midland
• Engrs: 10
• Total Staff: 100
• Tech. Sales In: Houston,
Casper, Farmington, Midland• Logistics Center: Houston
• Offices: Caracas, Rio, Buenos Aires, Bogota
• Engrs: 10
• Total Staff: 100
• Tech. Sales In: Colombia, Venezuela,
Brazil, Argentina, Mexico
Latin America
WFT UBS Global Infrastructure - 2002
N. America
Canada
• Offices: Calgary,Nisku
• Engrs: 10
• Total Staff: 100• Tech. Sales In: Calgary,Nisku
Eastern Hemisphere
• Office: Dubai
• Engrs: 20
• Total Staff: 200
• Tech. Sales In: UK, Europe,Algeria, Dubai, Jakarta, Lithuania
• Logistics Center: Dubai
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Underbalanced TeamBlends Software and Hardware
CompressedGases
UBSTeam
ProjectEngineering
Planning andExecution
WellControl
CompressibleFluids and
Chemistry
SpecialtyServices
Well FlowDynamics
Simulation
Real TimeData
Acquisition
SeparationSystems andWell Testing
INFORMATIONAL
MECHANICAL
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Underbalance Overview
Where, When, Why?
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1992 - present
• 10 Variations of UBD have developed
– Air and natural gas drilling
– Flow Drilling to atmosphere (flare) – Flow Drilling to Closed System
– Mist Drilling
– Foam Drilling
– Aerated Fluid Drilling
– Mud-Cap Drilling – Snub Drilling
– Production Drilling
– Offshore use of UBD tools and technology
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Impact Of Innovation
EstimatedReduction of
Development
Costs ($/b)
TechnologyYear broadly
accepted
3D Seismic 1990 30%
DirectionalDrilling
1995 50%
Underbalanced TBD 75%
Pre-3D Seismic 0%
+20%
+25%
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WHERE• Hard Rock Formations
• Areas of Loss Circulation
• Depleted Reservoirs and Zones
• Deviation Control
• Water Sensitive Zones
• Application is Not Necessarily Just for Pay Zones
WHERE NOT
• Excessive Water Flows
• Highly Unconsolidated Formations
• Plastic Flowing Salts
• Tectonically Stressed Shales
Underbalanced Drilling
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Underbalanced Drilling
BENEFITS - MORE OIL & GASIncrease Well Productivity
Increase Well InjectivityReduce Formation Damage
Reduce Well Stimulation
Reservoir Fluid Sensitivity
Reduce Well Costs
Potential to Reduce Porosity cut-off,leading to increased recoverable andbookable reserves
UBD can only solve skin damage and fracture plugging, it cannot change the
reservoir properties
Fracture Plugging
Pore Plugging Skin Damage
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Formation Damage
Overbalanced Drilling
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Underbalanced Drilling- HORIZONTAL
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Real Time Reservoir Investigation
• Underbalanced drilling can assist in locating andidentifying geologic features such as: fractures; tightzones; pinch outs; discontinuities; water zones; etc.
• This information can be used to determine:
– degree of reservoir heterogeneity
– optimum horizontal wellbore length
– number and orientation of future development wells
– anticipated production rates
– optimum lateral length
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0
0.25
0.5
0.75
1
1.25
1.5
1.75
2
4000 4500 5000 5500 6000 6500 7000Measured Depth (ft)
G a s P r o d u c
t i o n ( M M s c f d )
3300
3350
3400
3450
3500
3550
3600
3650
3700
T V D
( f t )
Gas Inflow
True Vertical Depth
Real-Time Inflow Mapping
Gas Production & True Vertical Depth vs. Measured Depth
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0
2
4
6
8
10
12
3700 4000 4300 4600 4900 5200 5500 5800 6100 6400Measured Depth (ft)
G
a s P r o d u c t
i o n ( M M s c f
d )
3690
3700
3710
3720
3730
3740
3750
T V
D ( f t )
Indicators of Fracture-Related Gas Inflow
Cumulative Gas Inflow
True Vertical Depth
Identification of Fracture Inflow
Gas Production & True Vertical Depth vs. Measured Depth
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• Increase Drilling Efficiency Through
Higher Rates of Penetration
• Reduce Well Costs
• Less Bit Trips
• Extends Bit Life
• Differential Sticking
• Reduce Mud Bills
Underbalanced Drilling
BENEFITS - DRILL FASTER
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Effect of Differential Pressure on Drilling Rate
70
60
50
40
30
20
10
0
-50 0 +150
AUSTIN CHALK
MANCOS SHALE
COLTON SANDSTONE
7-7/8 TRICONE BIT30,000 # WOB
60 RPM
p p
b
p
R a
t e f t / h r
Differential Pressure PSI
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Candidate Reservoirs
• High-permeability (>1000 md) lithified sands andcarbonates
• High-permeability unconsolidated or poorly-consolidated
sands
• Macro- or micro-fractured reservoirs
• Highly-depleted reservoirs• Reservoirs prone to wetting-phase reversal
• Reservoirs with hydratable clay minerals
• Reservoirs bearing fluids that may form precipitates or emulsions
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Po
tentia lF
orm
ation
Damag e
Mech an
ism
s
(after
Benno
in,19
96)
DamageMechanism
FormationType
F l u i d - F l u i d
I n c o
m p a t i b i l i t y
R o
c k - F l u i d
I n c o
m p a t i b i l i t y
S o l i d s
I n
v a s i o n
P h a s e
T
r a p p i n g
C h e m i c a l
A b
s o r p t i o n
F i n e s
M
i g r a t i o n
B i o l o g i c a l
D
a m a g e
E f f e
c t O f H i g h
O v e r b a l a n c e
Homogeneous Sand -Clean Π Π Π Π Π Ο Π ΠHomogeneous Sand -Dirty Π Ρ Π Π Ρ Ρ Π ΠLaminated Sand - Clean Π Π Π Π Π Ο Π ΠLaminated Sand - Dirty Π Ρ Π Π Ρ Ρ Π ΠUnconsolidated Sand Π Π Ρ Ο Π Π Π ΡFractured SandPermeable Matrix Π Π Ρ Π Π Π Π ΡFractured SandLow Permeability Matrix Π Ο Ρ Π Π Ο Π ΡHomogeneous Carbonate Ρ Ο Π Ρ Π Ο Π ΠFractured Carbonate
Impermeable Matrix Ρ Ο Ρ Π Ο Ο Π ΡFractured CarbonatePermeable Matrix Ρ Ο Ρ Π Π Ο Π ΡVugular Carbonate Ρ Ο Ρ Ο Ο Ο Π Ρ
Ρ - Probable damagemechanism under most
conditions
Π - Possible damagemechanism under specific
conditions
Ο - Unlikely damagemechanism under majority
of conditions
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Reservoir Effects and Flow Potential
Overbalanced Rate + >50%?
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Skin Damage
k Permeability - md 25h Height - ft 25Pr Reservoir Pressure - psia 2500Pwf Flowing Well Pressure - psia 1200u Viscosity - cp .95r e Drainage Radius - ft 1500r w Wellbore Radius - ft .26
B Formation Volume Factor 1.5
UBD OBD OBD
S Skin Factor 0 +5 +1
Q STB/Day 510 312 22$/day Incremental Loss @ $25/BO 0 -$4,950 -$7,12
Skin
Formation Damage
Skin
Formation Damage
7.08 X 10-3 kh (Pr -Pwf )uB (ln r e /r w - 0.75 + S)
q =
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Effect of Skin Damage on Production Rates
0
200
400
600
800
1,000
BOPD
5 10-2 0 15-3 -1
Flow Efficiency = 8/(8+S)
SKIN (S)
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••
•
Skin Damage Effect on Productivity & CashFlow
• Difference between Skin of 0 & 30 = $150mm!!!!
• Typically Conventionally drilled wells are in the +/-10 range at best,this still equates to +/- $100mm left in the ground.
• Can we afford to leave this much value behind?
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The Key Underbalanced Benefit - Adding Value to the Well
2 4,900 $220 mm $20 mmUBS Well
BBL /Day
6,500
3,100
1,900
LostValue
--
$90 mm
$150 mm
SKINFACTOR
0
10
30
TypicalRangefor Over-BalancedWells
NPV
$240 mm
$150 mm
$90 mm
Based on a North Sea well -
Oil Price $18 / BBL, Lifting Cost $1/BBL
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Ultimate Recovery Factor
Overbalanced Value + >20%?
Increase Rf (Recovery factor)?
Porosity cut off and impact on reserves
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Increase Rate and Economics
Time >>>
Q , R a t e ( B O P D o r M C F / D ) > >
>
Simplified Reservoir Recovery
Maximum Rate - Reservoir Damage
Damaged Reservoir,
S = >0
Maximum Rate - NO Reservoir Damage
Undamaged Reservoir,S = <0
Incremental Rate
Incremental Time/OpEX
{
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If the results or potential are thisgood why isn’t the industry readily
embracing the technology now ?
THE DECISION MAKER
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THE DECISION MAKER - ENABLER/BLOCKER PYRAMID
Blockers / IssuesDecision MakersEnablers / Drivers
$$$s Public Benefit
NPV Energy Security↑ ProductionShare PriceReduced CostsAffordable Energy
↑ ProductivityPotential ↑ Rf
Access to Depleted Reservoirs↑ Field Life
↓ Lifting Costs
↑ ProductionFaster Drilling
Enhanced Performance
Reduced Costs
OPERATIONS
PRODUCTION MANAGERS, PRODUCTION ENGINEERS
DRILLING MANAGERS, DRILLING ENGINEERS ETC
RESERVOIR ENGINEERS
PRODUCTION TECHNOLOGISTSCOMPLETION ENGINEERS
GEOLOGISTS AND GEOPHYSICISTS
CEOsOWNERS
INVESTORSASSET MANAGERS
GOVERNMENT/AGENCIES
Cost Appreciation of Value
Safety, ↑ RiskLack of AwarenessDamage to CareersHigh Age of Decision Makers, TooClose to Retirement - No Changes
↓ Belief, No Time for New IdeasDifficult to Model ResultsCreates Attitude of ‘We can’t…’Difficult to Predict Productivity
Challenge to Basic FundamentalsSafety, Costs, EducationTraining,↑Complex, RiskLittle or no Steer FromAbove, Buried in Work,
No Time for New Design
E di th UBD M k t
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Expanding the UBD Market
Economic withconventionaltechniques
Knownhydrocarbonresources Economic with
Hydraulic Fracturing
ExpandedUBD
Market
KnownUBDPlays
More risk Less risk
Performance of Shell
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North Sea Field Horizontal Wells(overbalanced )
0
1000
2000
3000
4000
5000
A B C D E F G H I J K L M
Well Name
O
i l P r o d u c t i o n
b / d
Forecast
Ac tual
• Actual results 14% higher than initial forecasts
• Only 8 out of 13 producerswith actual results within±50% of the forecasts
• Random nature of theerrors:
– well F expected to be5th best of 13, is the
worst producer
– well J expected to rank11th of 13, is the bestproducer
Ref: SPE 30745, D. Beliveau, Heterogeneity, Geostatistics, Horizontal
Wells, and Blackjack Poker,
1995 SPE Annual Technical Conference and Exhibition,
Dallas. Oct 22-25
Performance of early Weyburn
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Performance of early WeyburnHorizontal wells
0
100
200
300
400
500
600
1 1 H z
- 0 2
0 1 H z
- 1 4
1 2 H z
- 1 1
0 3 H z
- 1 3
1 5 H z
- 2 1
0 9 H z
- 0 7
1 1 H z
- 1 0
0 3 H z
- 1 0
1 3 H z
- 1 1
0 5 H z
- 0 7
1 1 H z
- 0 1
0 7 H z
- 1 2
0 1 H z
- 2 3
0 9 H z
- 1 4
0 7 H z
- 2 4
A v e r a g
e
Well Name
O
i l P
r o d u c t i o n b
/ d
Forecast
Actual
• 100% “accuracy” over thetotal program : coincidenceand hazard
• Average error of 47% on anindividual Weyburn H-well
• Only 16 out of 29 producerswith actual results within±50% of the forecasts
Ref: SPE 30745, D. Beliveau, Heterogeneity, Geostatistics, Horizontal
Wells, and Blackjack Poker,
1995 SPE Annual Technical Conference and Exhibition,
Dallas. Oct 22-25
Many fields or plays exhibit a
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y p ylog-normal distribution of well productivity
F r e q u e
n c y
( n u m b e r o f w e l l s )
Field average (“mean”)
Most likely (“mode”)
Well production rateÆ
Non-productive
wellsProductive wells
“The laws of well productivity”
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The laws of well productivity
F r e q u e
n c y
( n u m b e r o f w e l l s )
Field average(“mean”)
Most likely (“mode”)
Well production rateÆ
Non-productive
wells
Marginal or
sub-economic wellsThe 20% to 30% of wells that make the field economic
1. 20% to 30% of wells will
make the field economic
2. The chances of the first well
being “above average” is 1/3or less.
3. Statistically, any single well
has a 60+% chance of being
below average or non-productive
4. You need 5+ wells to achieve
the average.
Implications for Underbalance of
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Implications for Underbalance of “The laws of well productivity”
• A good first well does not prove the viability of the play;conversely, a bad first well does not condemn it.
• On average, it takes several wells to prove/disprove a concept.
• Underbalance Industry’s challenge is to – Participate in projects that will prove/disprove the concept
with the least expenditure and lowest risk
– Help operators create a well-thought out plan to get the bestresults from the least expenditure
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Basic Operational Aspects and Systems
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G I j ti M th d
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Gas Injection Methods
Drillpipe Parasite String Concentric String
Degrees of Complexity - Underbalanced Operations
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HIGHMIDLOW
Operations
Compression Air
Nitrogen Membrane
Foam / Chemicals
4 Phase Separation /Data Acquisition
EquipmentRotating Control Heads
Deployment ValveWL Retrievable Float
PersonnelWellsite Supervision
Corrosion
OTHER
Low Complexity
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p y
Pr
SH
Yellow - Monitoring
Red - Safety Shut-Down
BOOSTER
COMPRESSION
High Complexity
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RCD
UBDCHOKE
MANIFOLD
WATER & OILMEASUREMENT
DRILL CUTTINGS DISPOSAL
RETURN MUD to PITS
DRILL CUTTINGS PROCESSING
GASMEASUREMENT
Yellow - Monitoring
Red - Safety Shut-Down
LIQUID NITROGEN
BOOSTERS
NITROGENMEMBRANES
4 PHASE
SEPARTOR
OIL / WATERPROCESSING
FACILITIES
COMPRESSORS
Rotating Control Heads
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Rotating Control Heads
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Compressible Fluids
Dynamic Area of New Research
Base Fluids Selection (Medley et al., 1995)
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ROTATING DIVERTER
SEPARATION
SOLID/LIQUID/GAS
COMPRESSOR / N2
COST
CORROSION
VIBRATIONS
HYDRAULIC CALCULATIONS
CUTTINGS LIFTING
FLUID INFLUX
COMPLETION
BOREHOLESTABILITY MWD TRANSMISSION
HIGH TORQUE/DRAG
UNDERBALANCEDFIRE/
EXPLOSIONS
Range of Available Drilling Fluids
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Range of Available Drilling Fluids
Compressible Fluids Technology
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Compressible Fluids Technology
• UBS Fluid Types:
– Recyclable FoamSystems
– Non-emulsifyingFoaming Agents
– CorrosionChemicals
– PotassiumFormate Drillingand CompletionFluids
– Non-aqueousFoams
– Stable 2-φ DrillingMedia99% - 100% 96% - 99% 55% - 99%< 55%
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QHSE - UBS PROCESSES &SYSTEMS
•Industry Organizationsand Regulatory Input
UB Technology Provides Additional Well C l
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Control
• Surface equipment required for UBD can be tested andcapability verified prior to drilling.
• UB wells are generally more thoroughly planned withcontingency plans in place.
• Formation influx is expected, eliminating the element of surprise.
• BOP stacks are tested more thoroughly because they areused more frequently when drilling UB.
• Redundant barrier protection can be achieved with dualstripper models of rotating control heads.
• Primary barrier of well control is not just a fluid column.
IADC
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IADC
• Underbalanced Operations Committee was formed in 1999
• Issues UBD Daily Tour Report to accompany daily rig
report• Defines Risk Levels and Classifications of UBD
• Setting up IADC WellCap™ accredited Well Control
School for underbalanced drilling
IADC UBO Committee Classification System for Underbalanced Wells
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U de ba a ced e s
• Level 0: Performance enhancement only; no hydrocarbon containing zones.
• Level 1: Well capable of natural flow to surface. Well is “inherently stable” and is low level risk
from a well control point of view.
• Level 2: Well capable of natural flow to surface but enabling conventional well kill methods and
limited consequences in case of catastrophic equipment failure.
• Level 3: Geothermal & non-hydrocarbon production. Maximum shut-in pressures less than UBD
equipment operating pressure rating. Catastrophic failure has immediate serious consequences.
• Level 4: Hydrocarbon production. Maximum shut-in pressures less than UBD equipmentoperating pressure rating. Catastrophic failure has immediate serious consequences.
• Level 5: Maximum projected surface pressures exceed UBO operating pressure rating but are
below BOP stack rating. Catastrophic failure has immediate serious consequences.
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Management System Compatibility
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WeatherfordHSE Management
System
HSE
HSG 65
&
NPD
E&P
Forum
• Leadership & Commitment• Policy Strategy & Objectives• Organisation• Hazard & Effects Management• Planning & Procedures• Implementation & Monitoring• Audits
SEPCo• Leadership & Accountability• Risk assessment and management• People, Training and behaviours• Working with contractors• Operations and Maintenance• Management of Change• Customers and products• Community and stakeholder awareness• Crisis & emergency management
• Incidents , analysis and prevention• Assessment, assurance & improvement
Bp
ISO 14001
ISO 9001:2000OHSAS
18001
Engineering Planning
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g g g
• Flow Modeling
• Environmental Impact
• Conceptual Well Design
• Conceptual Basis of Design for Surface Equipment
• Conceptual Basis of Design for Sub Surface Equipment• Well Control / Barrier Philosophy
• Flaring Versus Re - Injection
Documentation
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• Project Execution Plan
• Risk Register
• HAZID• Quality Plan
• Equipment Integrity Assurance Scheme
• Detailed Well Program
• Manufacturing Schedule
• Certificates of Approval of Equipment
• Manuals / Procedures / Process
• Operations HAZOP
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Brief Summary of a comparativecase study of successful underbalanced drilling operations
Location - Western Lithuania,Operator - Minijos Nafta
Underbalanced Drilling SuccessUnderbalanced Drilling Success
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gg
• Onshore Multiple Well Project
• Gargzdai License
• Western Lithuania
• Cambrian Sandstone Reservoir
Underbalanced Drilling Operations
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Garg11 -1981.70
Garg12 -1939.10
Garg13 -2083.40
Garg14 -1964.40
Garg16 -1997.10
Garg17 -1983.60
Garg18 -1937.29
Garg4 -1991.70
Garg6 -1938.10
Garg7 -1940.83
-1938.53
-1933.53
-1937.50
PS1
-1929.70
PS2
PS3
PS4
6160000 6160000
6161000 6161000
6162000 6162000
6163000 6163000
6164000 6164000
6165000 6165000
6166000 6166000
4
5 2 6 0 0 0
4 5 2 6 0 0 0
4
5 2 7 0 0 0
4 5 2 7 0 0 0
4
5 2 8 0 0 0
4 5 2 8 0 0 0
4
5 2 9 0 0 0
4 5 2 9 0 0 0
4
5 3 0 0 0 0
4 5 3 0 0 0 0
4
5 3 1 0 0 0
4 5 3 1 0 0 0
Location Map Top Cambrian Structure Map.
Reservoir Details
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• Reservoir Formation: Middle Cambrian Sandstone.
• Reservoir Thickness: 70 -80m
• Ave. Reservoir Depth: 1940-2010m TVD.
• Initial Pressure: 3200 psi
• H2S+CO2: None.• BHT: 191 degF
• Porosity: 1 - 12 %
• Permeability: Over 0.1 mD (Range 0.1-0.5 mD).
• Viscosity: 0.63 cP in situ, 1.44 cP Dead (on surface).
Summary of - Region History
P t i ith d ti ll i thi h
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• Past experience with production wells in this area has
indicated high skin factors and reduced productivity, which hasbeen attributed to near well bore formation damage - using theconventional drilling method.
• Physical invasion of suspended mud solids duringoverbalanced drilling, completion, or kill operations resulting innear well bore plugging.
• The reservoir appears to be relatively sensitive to formation
damage effects associated with conventional overbalanceddrilling operations.
• The highly pressure depleted condition of the formation,combined with high mud weights utilised in the past, resultedin significant overbalanced pressures being exerted in thenear well bore matrix area. This problem will be greatlyexacerbated if conventional drilling practices is to be used infuture planned drilling operations.
• Skin Factor Range: 70-100+
Historical Overbalanced Drilling Problems &Issues
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Issues
Skin
Conclusion:- High skin factors are induced when drilling Overbalanced.
Example : While drilling well PS 1 the skin factor reached a value of 78- Where the first underbalanced well, PS 2 drilled, the skin factor was at avalue of -1.155
Production
While drilling well PS 1 overbalanced the completed well flowed atonly (10m3/day or 63 SBBL/Day)
The first underbalanced well Weatherford UBS drilled in the samefield came up to more than 30 fold that amount per day
(551.3m3/day or 3468 SBBL/Day)
PS2 PS3 PS4 Case Histories
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Underbalanced Completed Wells
PS 2 Case History PS 2 Case History
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• Close offset overbalanced well: G-7 Drilled in 1970’s using Soviet technology100m from PS-2&3 PAD.
• G-7 currently producing 130 bbl/DAY. Maximum initial production was +/- 400bbl/DAY
• PS-2 drilled overbalanced to 7” shoe set just above reservoir section
• Well displaced from water based drilling fluid to dead crude oil from nearby G-7tank battery.
• 6” hole drilled underbalanced into upper reservoir section - not expected to beproducing
• Drilling suspended due to large influx of oil
• Decided to run completions due to testing
while drilling capability of separation package
• Production initially tested to +/- 4000bbl/DAY
-30 fold increase in productivity
• Production declining but still around 2400 bbl/DAY- 18 fold increase over G-7
Productivity Productivity - - OBD Vs UBD WellsOBD Vs UBD Wells
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0
100
200
300
400
500
600
0 50 100 150
Time in Days
P r o d u c t i o n m 3 / d a
y
4000
3000
2000
1000
500
3 UBD Wells
3 OBD WellsPS 2
PS 3
PS 4
S B B L / D a y
Well - ANSENAI Well No : 1 (AS-1)Overbalanced vs. Underbalanced Leg
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g
Overbalanced Leg.
• 1st Leg Drilled Overbalanced through reservoir.
• Low invasion Carbonate based “Blockador” type drilling fluid(Ground carbonate in suspension).
• Drilled through reservoir at +/- 45 deg. Inclination.
• Open hole drill stem test.
• Across entire reservoir section (25m at +/- 45º inclination
• DST Summary “ Suggests start of hydrocarbon producinginterval”.
AS-1 Drill Stem Results - Overbalanced Leg
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• DST ( sequence No T4 - 5 )
– Calculated Liquid Rate : 6.1 - 8.2 m3 / Day
( 38 - 52 BBL / Day ) – Rates calculated from liquid level increase of S.G of 1.18.
– Transmissivity determined to be 3mDm. – Permeability calculated to be 0.1mD ( across 25m zone)
– Simplest model with radial flow assumption used.
– PWF = 16.219 Bar
– PI = 0.0319 m3 / D / Bar
Results of Underbalanced Leg
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• Plugged overbalanced leg with cement plug AS-1 (ST)• Oriented 180º from overbalanced leg Azimuth & sidetracked well
• Drilled horizontally into reservoir section.
• Tracking top reservoir using MWD to steer and flow response -“Production Steering”.
• Produced (1811 BBL) (288 m3)on the 16th April including Bit Trip.
• Well choked back ( 950 PSI on manifold ).
• Production whilst drilling 8 - 10 m3 / hr (51 - 63BBL / HR)
• Production whilst tripping 20-23 m3 / hr (126- 145 BBL/HR)
• Estimated Production - before completion.
Open Flow = 500m3 / Day = 3145 BBL / Day
Lithuania UB OperationsLithuania UB Operations - - ConclusionsConclusions
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• Minijos Nafta increased production on a horizontal UB well by17-30 fold.
• Underbalanced Technology has dramatically improved
productivity in mature reservoirs.
• Operator has more than doubled daily production of 5 fieldswith 4 new wells.
• The UBD technique has proven to be of value in mature tightsandstone reservoirs.
• Underbalanced technology works well in low
porosity/permeability formations.• Efficient management systems have resulted in a safe UBD
operation.
In Summary...
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• Underbalanced Drilling technology can – improve well performance by reducing or eliminating
wellbore damage
– improve rate of penetration – eliminate drilling fluid losses
– eliminate and/or reduce stimulation costs
– provide real-time reservoir analysis & flow test while drilling(potential to generate revenue while drilling)
– greatly reduce environmental impact
– reduce wellbore construction costs
• Leading to improved NPV, IRR, etc. in a safe and efficient
manner with risk managed ALARP
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Conclusions, Questions & Answers
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