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September, 2010
© 2009 Baker Hughes Incorporated. All Rights Reserved.1
Shale Gas Challenges / Technologies Over the Asset Life Cycle
U.S.–China Oil and Gas Industry Forum
Robert ‘Bobby’ Kennedy – Baker Hughes inc
AGENDA
•Shale Gas Reservoir and U.S. Shale Gas Basics
•Challenges / Technologies Over the Shale Gas Asset Life Cycle
EXPLORATION
APPRAISAL
DEVELOPMENT
PRODUCTION
REJUVENATION
© 2009 Baker Hughes Incorporated. All Rights Reserved.2
The Shale Gas ‘Reservoir’• Shale Gas - Unconventional natural gas ‘reservoir’ contained
in fine-grained sedimentary rocks, dominated by shalecontaining clay and other minerals like quartz, calcite
• Continuous Formation - No Trap - Not a true ‘Reservoir’ Gas Sourced and Remains in Same formation
• Total Organic Carbon, Thermal Maturity, Mineralogy,and Natural Fractures are Key- Porosity & micro/nanoDarcy-Permeability, secondary
• Gas stored in three ways:1. Free Gas
a. In Rock Matrix Porosityb. In Natural Fractures
2. Sorbed Gasa. Adsorbed on organic and mineral surfaces w/in Nat Fracturesb. Absorbed on organic and mineral surfaces w/in Matrix
3. Dissolved - In HC liquids present (bitumen)
Total Gas = Free + Sorbed + Dissolved
© 2009 Baker Hughes Incorporated. All Rights Reserved.3
Source: EIA
Key Reservoir Parameters
•Brittle Rock – Helps maximize extent of induced fracture network (Brittle Rock will Frac like Glass = better SRV)
•Stress Regime – Relates to pattern orientation and well spacing
•Over-pressure – May require high strength Frac proppants
•Local Lithology Variations •Faults, Karsts, Water•Organic Content•Micro-porosity •Thermal Maturity (Ro) - >Mature = Dry Gas <Mature = Wet Gas
© 2009 Baker Hughes Incorporated. All Rights Reserved.4
Relates to gas in placeTOC decreases at higher Ro
Relates to well productivity
Total Porosity increases at higher TOC
Gas Shale Basics (U.S. Basins)•Formation Thickness, 20 – 600 ft (net)
•Depth, 6,500 – 13,500 ft•Well IP’s, 2 – 10+ MMcfd•Primarily Dry Gas •Some produce small amounts of water•Typical Decline:
- Initial Flush Flow- 1st Yr Steep Decline (65-80 %)- Produces slowly over time, 25+ Yrs
© 2009 Baker Hughes Incorporated. All Rights Reserved.5
0
2
4
6
8
10
12
1 3 5 7 9 1113151719212325
Pro
duct
ion
, MM
CFD
Shale Gas Type Curves
Haynesville
Woodford
Barnett
Marcellus
Fayetteville
All Shales Are Not the Same (Geology Varies Even in
the Same Basin)
Developing Shale Gas
• Gas Shales must be Fracture stimulated to produce commercially– Artificial Reservoir is achieved by:
1. Multi-Stage Fracturing 2. Horizontal Wells
• Effectiveness of Hydraulic Fracturing determines:- Production rates- Drainage area - Recovery
• Vertical Wells to define play and collect reservoir data
• Horizontal Wells to develop– Laterals 3,000 - 6,000 ft
• Well Spacing Avg. 80 acres
‘All Shale Gas Reservoirs are Not the Same’
© 2009 Baker Hughes Incorporated. All Rights Reserved.6
How Many Wells for 1TCF (30 BCM) of Shale Gas?
0
200
400
600
800
1000
1200
1400
0.9 1.8 3.5 5.3 7.1 8.8 10.6
0.025 0.05 0.1 0.15 0.2 0.25 0.3
Wel
l Cou
nt
Ultimate Gas Recovery Per Well
BCM/Well
BCF/Well
Barnett-Fayetteville-Woodford-Marcellus-Haynesville-Horn River44 42 11 262 251 100
Typical Scenarios200 - 250 Wells/TCF
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Ultimate Gas Recovery Per Well, BCF (BCM)
Shale Gas Development Requires Large Number of Wells
Total TCF
7
© 2009 Baker Hughes Incorporated. All Rights Reserved.8
Shale Gas Asset Life Cycle
© 2009 Baker Hughes Incorporated. All Rights Reserved.9
Determine the Economic Value and Reservoir Potential
Understand Field Wide Well Placement and Architecture
Reservoir Characterization
EXPLORATIONChallenges / Technologies
TECHNOLOGIES -• Reservoir Analysis• Geomechanics• Formation Evaluation• Economic Evaluation
Reservoir Analysis• Conventional reservoir modeling/analyses Not effective for Shale Gas
- Complex reservoir characteristics and gas flow regime introduce difficulty in predicting GIP, recovery, production profiles, well placement, and design fracturing programs/completions
• An Integrated Multidicipline Approach is required to forecast production, recovery, design fracture stimulations, and well placement for use in Economic Evaluations
• BHI through Reservoir Development Services currently provides Integrated Approach and employs Shale Engineering to analyze/design optimized completions and stimulation for maximum
Producing Rates and Recovery used in determining Shale Reservoir Potential
© 2009 Baker Hughes Incorporated. All Rights Reserved.10
BHI Integrated Approach - Workflow
GeomechanicalModel
Better drilling and completion
design
Optimized Production
Better stimulation
Petrophysics:•Mineralogy•Rock Mechanics
CalibrationMonitoring (Microseismic)
C. Jenkins,2010Improved Predictions
•Where•Number of stages•Frac design
“Shale Engineering”
Disciplines: Geomechanics, Geochemistry, Petrophysics, Rock Properties, Seismology,Reservoir, Well, Stimulation Modeling
© 2009 Baker Hughes Incorporated. All Rights Reserved11
© 2009 Baker Hughes Incorporated. All Rights Reserved.12
Validate the Economics of the Reservoir Generate a Field Development Plan Refine and Optimize Completion Design
APPRAISALChallenges / Technologies
TECHNOLOGIES -• Reservoir Analysis• Geomechanics• Formation Evaluation• Economic Evaluation
Pre-Drill Modeling and Analysis for: Wellbore Stability Management
Pore Pressure Prediction
Determining In-Situ Stress
Comprehensive Well Planning
Geomechanics Models for Hydraulic Fracturing Design (propagation, stages, perfs), Well Placement, and Completion Design
13
Geomechanics Important in Exploration, Appraisal, and Development Phases of Life Cycle
@ 2009 Baker Hughes Incorporated. All Rights Reserved
Reservoir Characterization Challenge
PorosityPermeabilityWater SaturationMineralogyShale LithofaciesTotal Organic ContentMaturity Level (Thermal)GIP (adsorbed and free)
• Run in Vertical Wells
Fracture CharacterizationDynamic and Static Geomechanical Rock PropertiesPressure GradientStress RegimeSiliceous IndexSWC Analysis
© 2009 Baker Hughes Incorporated. All Rights Reserved.14
• No single Log or Core provides all the Answers• Conventional Log Suites can Not provide all characterization data required for Shale Gas
Solution - BHI Shale Gas Evaluation Suite Provides:
An Integrated Petrophysical Approach Using Logs and Analyses to Characterize Highly Complex Shale Gas Reservoirs
IntelliFracMicro-seismic
15 © 2009 Baker Hughes Incorporated. All Rights Reserved
Log & Analyses Identifies: Optimum “Fracturable”
Intervals Formations to Drill
Horizontal LateralsPotential Barriers for
Frac Containment
300+ Evaluation Suites run in US Shale Gas, 40+ in Canada
BHI Shale Gas Evaluation Suite
Lithology
Mineralogy
Th/U for Carbonclassification
Minimize Drilling Costs Optimize Completion and Fracturing
Design Minimize Environmental Impact
© 2009 Baker Hughes Incorporated. All Rights Reserved.16
DEVELOPMENTChallenges / Technologies
TECHNOLOGIES -• Well Design / Drilling• Hydraulic Fracturing• Well Completion• Environmental
Reducing Days on Well by Drilling Optimization
© 2009 Baker Hughes Incorporated. All Rights Reserved.17
Downhole Tools, Analytical Tools and
Modeling
Structured Processes & Engineering
Training
Offset Well and Dull Bit Analysis
RPM change
Stabilizer in this section at RPM change
RPM near critical speed,
then BHA enters hard formation
Appears to result from stabilizers
hanging on ledges and allowing bit to
side cut
Fria
ble
Form
atio
nFr
iabl
e Fo
rmat
ion
BHA Modeling
Torque, Drag, Hydraulics Modeling
AXIAL LATERAL TORSIONAL
Downhole dynamics measurement
DF Designs & ECD
Reducing Risk/Cost (Additional Trips)
•Drill Bits– Quantec™ PDC & Tricone
Bits specifically designed for Shale Gas - Vertical, Curve, and Laterals
•Directional Services– Custom BHA’s– Ultra™ Motor Technology– Rotary Steerable – AutoTrak
eXpress™– TeleTrak™ (MWD) & MWD
Tools
© 2009 Baker Hughes Incorporated. All Rights Reserved.18
Goal – Drill the Curve & Lateral with Single Bit and BHA Trip
Optimizing Wellbore Placement –Reservoir Navigation Services (RNS)
RNS - Real-time LWD to detect adjacent formations (AziTrak™ & GR)
- Ensure optimal reservoir entry- Maintain optimal position
within reservoir- Avoid reservoir exit- Steer to ‘sweet spot’
• Reduced Number Wells/ST’s
• Reduced overall Costs
• Increased Production & EUR
© 2009 Baker Hughes Incorporated. All Rights Reserved.19
Deep Resistivity Image
Well Path
Cap Rock
Reservoir
Top
Top
Bottom
Distance to Bed Boundary
Depth of Detection
Reservoir Navigation Services
• Decrease risk– Improves borehole quality for
lower risk associated with running casing in long laterals
• Reduce rig time– Eliminates orientation and slide
time associated with steerable motor drilling
– Improves overall effective ROP
20
Steerable MotorRotary Steerable
Rotate
Slide
High Efficiency Rotary Steerable Systems
© 2010 Baker Hughes Incorporated. All Rights Reserved.
Optimizing Drilling Fluid Programs For Increased ROP and Reduce Environmental Impact
•Drilling Fluid– Barnett: WBM, OBM/Brines (some cases)– Haynesville: WBM to KOP, then OBM– Marcellus: Air/Mist to KOP, then WBM or SBM– Eagle Ford: Fresh Water for Surface, then OBM
•Density– Barnett: < 10.0 ppg– Haynesville: 12.0 – 16.5 ppg– Marcellus: 11.5 – 14.0 ppg– Eagle Ford: 11.0 – 12,0 ppg
•Environmentally Friendly Fluids- BHI TERRA MAX™ ‘Environmentally Acceptable Alternative to OBM’ - NEXT-DRILL™ ‘Synthetic Invert Emulsion’
21 @ 2009 Baker Hughes Incorporated. All Rights Reserved
Reduce Cost and Environmental Risk with Centralized Dewatering• Recycle processed water for drill or wash water• More efficient disposal after dewatering• Remove suspended solids in WBM
BHI can help make operation Green:.- Reduce fluid waste, disposal costs, transportation fees, environmental impact
- Reuse fluid in future well operations
22 @ 2009 Baker Hughes Incorporated. All Rights Reserved
23
Shale Gas Drill Pads – Logistics & Environment(Shale Gas Factory)
DRILL PAD
Developing a “Shale Gas Factory”• 10 + wells from a single pad• Shared rig access, mud pits• Skid-mounted Frac-pumps• Gas conditioning & compression• Gas export • Minimize Environmental Impact
- Footprint- Fit for Purpose Eco-Centre™for Solids and Waste
• Alliance with service provider (BHI) to capture learning curve benefits
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Eco-Centre™
23
Hydraulic Fracturing Process 1. Pump Pad
- Causes rock to fracture- Creates fractures to accept Proppant
2. Pump SlurryProppant (size-graded particles, spherical white sand / man-made) mixed into fluid Slurry; pumped in to prop open created fractures
3. FlushClean fluid to clear surface lines & well tubulars of proppant; pumps shut down
4. Bleed Off well pressure to allow fractures to close on proppant
5. Recover injected fluid by flowing/lifting well (Typically recover <30% of frac fluid)
© 2009 Baker Hughes Incorporated. All Rights Reserved.24
Fracturing FluidFracturing Fluid = Base Fluid + Additives + Proppant Base fluid – water or oil Additives – Gelling Agents, Crosslinkers (polymers), Friction
Reducers, Breakers, Surfactants & Non-emulsifiers, BiocidesProppants – White Sand (for Shales), Brown Sand, Low Density
Ceramics, Resin-coated Sand, Sintered Bauxite
© 2009 Baker Hughes Incorporated. All Rights Reserved.25
SHALE STAGES*Xf COMPLETION FLUID TYPE
FLUID VOLUME
PROPPANT PROPPANT
ft METHOD Bbls/Stage TYPE Total Lbs.
BARNETT 7-9 300-400 Plug-N-Perf Acid, SW 14,000 Ottawa/Lite 550,000
FAYETTEVILLE 8-11 250-300 Plug-N-Perf/OH Acid, SW 6,500 Ottawa 300,000
HAYNESVILLE 8-11 300 Plug-N-Perf/OH Acid, SW /Poly 11,400 Other 330,000
MARCELLUS 6-8 300-400 Plug-N-Perf/OH Acid, SW 16,000 Ottawa 785,000
WOODFORD 8-10 250 Plug-N-Perf/OH Acid, SW 18,500 Bauxite/Other 255,000
EAGLE FORD 8-10 350 Plug-N-Perf Acid, SW 12,800 Ottawa/DC 300,000
Typical Shale Frac Basic Materials Per Stage
* Fracture half length estimated SW = Slickwater OH = Openhole
Fracture Treatment Monitoring Methods
• Conventional Temperature and Tracer Surveys- Data near well-bore vicinity- Fluids & proppants ‘traced’
• Distributed Temperature Sensing (DTS)
- Fiber Optic • Production Logging - Spinner surveys- Flow & Temperature
• Microseismic Monitoring- During fracture treatment / Near real-time- Managing treatment and post-treatment analysis
© 2009 Baker Hughes Incorporated. All Rights Reserved.26
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Typical Shale Gas Completion Options –(For Hydraulic Fracturing the Well)
•Cemented Liner– Plug-N-Perf Method
•Openhole Completion Systems– BHI FracPoint™– Others (Frac Sleeves & Isolation Packers)
27
Plug-N-Perf Method
© 2009 Baker Hughes Incorporated. All Rights Reserved.28
• Cased Hole - Perforate & Produce Multiple pay zones• Hydraulic Fracture each individual zone• Set Plugs for zonal isolation• Drill Out Plugs and Produce
8,000+ Composite Plugs run by BHI in Barnett
FracPoint™ Completion System
© 2009 Baker Hughes Incorporated. All Rights Reserved.
•One-trip system – Up to 24 stages•Continuous Multi-zone Frac (Shortest overall Time)
•Drop a Ball To: - Shift sleeve - Isolate previous Frac- Open new zone
•Versatile system- Eliminates perforating & liner cementing operations- Primary and Re-fracturing applications- Reduced Cost vs Plug-N-Perf
29
450+ InstallationsShale Gas & Bakken (oil)
Reduce Environmental Risk Maintain Production RatesReduce Scaling, Corrosion, and
Microbial ContaminationMeet Gas Pipeline Specifications
TECHNOLOGIES -• Frac Chemicals• Production Chemicals• Environmental
© 2009 Baker Hughes Incorporated. All Rights Reserved.30
PRODUCTIONChallenges / Technologies
Shale Fracturing (Fluid) Challenges• Large Slickwater Fracs: Water stored in lined/unlined earthen pits open
to atmosphere for days/months
• Frac Water Sources:– Fresh water supply wells, chlorinated city water, rain– Ponds, rivers, streams, lakes– Re-used frac flow back water
• Frac Process & Slurry allows Bacteria to form downhole• Different waters mixed - Scale formed & severe Bacteria/Algae• Frac water Not Treated, Problems:- Microbial Influenced Corrosion - Generation of Hydrogen Sulfide- Scale deposits (Radioactive)
31 @ 2009 Baker Hughes Incorporated. All Rights Reserved
© 2009 Baker Hughes Incorporated. All Rights Reserved.32
BHI AddFRAC™ Fracturing Chemical Program
1. Survey
2. Chemical Selection- Biocides- Scale Inhibitors- Corrosion Inhibitors- Oxygen Scavengers- Flow Stimulators & Friction Reducers - Surfactants- Clay Stabilizers
3. Implementation
AddFRAC™ Program- Monitoring - Testing - Reporting - Optimization
3,000+ AddFRAC Programs in Shale Gas
Production – Chemical Management
•During Production - Effective corrosion, scale, and bacteria monitoring and treatment are required
•Water Management and gas deliquification Necessary- BHI F.O.A.M.™ production stimulation / deliquification- BHI Continuous Optimization (Automation) of chemical injection rates
through effective Monitoring and Reporting - Chemicals for water treatment
© 2009 Baker Hughes Incorporated. All Rights Reserved.33
Reduce Production Decline Remediate Sub-Economic WellsDetermine Recompletion and
Workover Strategy
© 2009 Baker Hughes Incorporated. All Rights Reserved.34
REJUVENATIONChallenges / Technologies
TECHNOLOGIES -• Remediation• Restimulation• Recompletion
Rejuvenation Solutions
•Chemical and Mechanical Remediation•Coil Tubing Intervention and Recompletions•Restimulation/Re-Frac “Fracs Do Not last Forever”
Fractures Close, Proppants Fail, Stress Regime Changes w/Production
•Revised Field Development Plan •Re-entry and InFill Drilling, Multilaterals
© 2009 Baker Hughes Incorporated. All Rights Reserved.35
© 2009 Baker Hughes Incorporated. All Rights Reserved.36
Shale Gas Challenges/Technologies Over the Asset Life Cycle
THANK YOU谢谢
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