HiWAY
Putting Your Production into the Fast Lane
Place
Date
HiWAY
Putting Your Production into the Fast Lane
Conventional Treatment
HiWAY Flow-Channel Treatment
Place
Date
HiWAY: A Paradigm Shift in Hydraulic Fracturing
1950
1960
1970
1947 First hydraulic fracturing job
1950 Fracturing using gelled oil
1960 Water-based, non crosslinked fluids
1968 Borate crosslinked fluids
1973 Crosslinked derivatized guars (HPG, CMHPG, etc)
1980
1977 High-strength ceramic proppants
1980 Foamed fracturing
1990
1988 Encapsulated breakers
1990 Fiber based flowback control
1994 Low polymer loadings
1997 Viscoelastic surfactants (VES)
2000
2001 Micro-seismic used to monitor frac jobs
2003 Horizontal well, multistage fractures
2005 Fiber based proppant transport
2010
2010 HiWAY* Flow-Channel Fracturing
2011 Complex fracture modeling
3
HiWAY® Presentation
HiWAY is Applicable in a Broad Range of
Reservoirs
Oil, condensate-rich and gas wells
Competent rock –
Sandstone/carbonate/shale (E/σMIN > 275)
Requires the use of viscous fluids
Cased hole, open hole, vertical and
horizontal wells
BHST < 345 oF (< 174+ oC)
4
HiWAY® Presentation
Conventional Job – Blender Operation
Sand
Chemicals
& Water
5
HiWAY® Presentation
HiWAY Job – Blender Operation
Sand
Chemicals
& Water
Fiber
6
HiWAY® Presentation
High Pressure Pumping
7
HiWAY® Presentation
HiWAY Execution
Schematic pump schedule
Sand Concentration
Conventional
HiWAY
Pad
Time
Clean Fluid (clean) pulse
Proppant (dirty) pulse
Cycle
8
HiWAY® Presentation
Tail-in stage
HiWAY Execution
Actual pump schedule in typical HiWAY job
600
4
3
2
1
0
Sand Concentration, kg added/m3
Sand Concentration, PPA
5
480
360
240
120
0
11:39:43
11:46:23
11:53:03
9
HiWAY® Presentation
11:59:43
High Pressure Pumping
Flow in treating lines:
Rate: 18 BPM
Length: 600 ft
3” treating line
concentration, PPA
Qualification Tests: Yard Scale
No significant dispersion
5
Initial
After flow
4
3
2
1
0
0
Linear velocity: 1 ft/sec
Length: 110 ft
Tube ID: 0.8” (2 cm)
No significant dispersion under
presence of fibers
10
15
Time, seconds
10
Concentration, PPA
Flow in the pumps, perfs
and fracture:
5
20
25
With fibers
8
Without fibers
6
4
2
0
0.0
10
50.0
100.0
150.0
Time of Experiment, sec
HiWAY® Presentation
200.0
Perforation Scheme
Vertical Well
Cluster perforations
Standard perforating
equipment
Limited entry type
scenario
1-2 bpm / perf target
Horizontal Well
Cluster perforations
Existing technique
usually applicable
11
HiWAY® Presentation
Downhole Placement
Frac geometry
Similar to conventional jobs
Perforations
Break up proppant pulses
Pulses form hetereogenous
placement within the
formation
Tail in
Critical stage at end of job
to connect to wellbore
12
HiWAY® Presentation
Downhole Placement
Conventional
SPE # 155684
Conventional
13
HiWAY® Presentation
HiWAY
HiWAY
Production Path
Conventional
Proppant Pack
Mesh Size
Proppant Strength
HiWAY
Channels
Infinte conductivity
Tail-in is critical
Clean-up
HiWAY requires less time
HiWAY flows back more
14
HiWAY® Presentation
Production Path
Conductivity: Model vs. Experiment
15
HiWAY® Presentation
Effective Half-Length
Conventional
Xeff = 50% of Xpropped
Gel damage
Non-darcy effects
Crushing effects
HiWAY
Xeff = 85% of Xpropped
Clean-up longer interval due to
conductivity
Lower pressure drop across
fracture
Channels connect fracture
16
HiWAY® Presentation
Benefits
Production Increase
Usually 20% in tight
rock
Increase effective
fracture half length
Lowering screen out risk
to near zero
Lower pressure drop
across fracture
Fast clean out and
decreased turnaround
time
17
HiWAY® Presentation
The Four Components That Deliver HiWAY Reliability
Delivering
Channel
Structure
Engineering
Design
HiWAY
Completion
Technique
18
HiWAY® Presentation
Ensuring
Structure
Stability
The Four Components That Deliver HiWAY Reliability
SuperPOD or PODFloat (SBF(SBF-624)
624
Single Side
60 bpm @ 4 ppa
50 bpm @ 8 ppa
100% Redundancy
PodSTREAK (SBT(SBT-615/616/625/626)
Single Side
50 bpm @ 3 ppa
40 bpm @ 8 ppa
PODPOD-IV (SBTSBT-618)
Single Side
50 bpm @ 3 ppa
40 bpm @ 8 ppa
100% Redundancy
19
HiWAY® Presentation
Delivering
Channel
Structure
The Four Components That Deliver HiWAY Reliability
Delivering
Channel
Structure
20
HiWAY® Presentation
The Four Components That Deliver HiWAY Reliability
Delivering
Channel
Structure
Engineering
Design
HiWAY
Completion
Technique
21
HiWAY® Presentation
Ensuring
Structure
Stability
The Four Components That Deliver HiWAY Reliability
J622
< 200 oF
J579
200 oF – 345 oF
Under Development
> 345 oF
Ensuring
Structure
Stability
22
HiWAY® Presentation
The Four Components That Deliver HiWAY Reliability
Delivering
Channel
Structure
Engineering
Design
HiWAY
Completion
Technique
23
HiWAY® Presentation
Ensuring
Structure
Stability
The Four Components That Deliver HiWAY Reliability
Completion
Technique
24
HiWAY® Presentation
The Four Components That Deliver HiWAY
Reliability
Delivering
Channel
Structure
Engineering
Design
HiWAY
Completion
Technique
25
HiWAY® Presentation
Ensuring
Structure
Stability
The Four Components That Deliver HiWAY
Reliability
1 ft
Engineering
Design
26
HiWAY® Presentation
The Four Components That Deliver HiWAY
Reliability
Build
Geomechanical
and Reservoir
Models
Design perforation
Designand
strategy
perforation
pumping
schedule
for strategy
optimum and
channel
distribution
pumping
schedule for
optimum
channel
distribution
Evaluate
Evaluate
channel profile
channel
and fracture
profile and
conductivity
fracture
conductivity
Engineering
Design
27
HiWAY® Presentation
HiWAY: Worldwide Footprint (through October 31, 2012)
878 wells, 9,560 stages, 6 screen-outs (99.94% placement) in 15 countries
HiWAY activity
New fields under discussion
HiWAY is used in 1 out of every 4 SLB fracturing jobs in September
28
28
HiWAY® Presentation
2010-2012 HiWAY Activity
7000
12000
6000
10000
Stages per Year
8000
4000
6000
3000
4000
2000
2000
1000
0
0
2010
2011
29
2012 YTD
HiWAY® Presentation
Cumulative stages
5000
2010 – 2012 HiWAY Activity (through August 31, 2012)
Reservoir Lithology
Sandstone
Lance/Pinedale (USA)
Wamsutter (USA)
Granite wash (USA)
Yegua (Burgos basin, Mexico)
Eocene (Chicontepec, Mexico)
Sierras Blancas (Argentina)
AS & BS – (Russia)
Abrar, West Qarun (Egypt)
Gazhal (Saudi Arabia)
Others
Reservoir Fluid
Shale
466
Barnett (USA)
Haynesville (USA)
Utica (USA)
Marcellus (USA)
Bossier (USA)
Avalon (USA)
2154
Oil
Condensate +
Gas
1978
1555
6023
Carbonate
Dry Gas
Eagle Ford (USA)
Bakken (USA)
Clear Fork (USA)
6936
Completion Type
Well Orientation
1147
Vertical
1383
8173
8409
Horizontal
Cased hole
30
HiWAY® Presentation
Open hole
Conventional Oil Case Study: Rosneft
HiWAY Delivers 15% increase in Oil Recovery and Stable
Production over 2 + years from Conventional Reservoir
Challenge
Improve oil production from low-pressure sandstone,
conventional reservoir in Western Siberia
Solution
Enhance fracture conductivity with HiWAY flow-channel
fracturing technique (4 HiWAY vs. 16 conventional)
Results
Formation type
15% increase in oil recovery over 2 years
Stable production. Solution amenable for use of
injectors wells and ESP.
TVD
40% less proppant per stage. No screen-outs
11 wells completed to date. Additional wells
planned for 2012
2500 – 2700 m
Permeability
11,000 – 13,500 ft
1 to 3 mD
Young’s modulus
31x - 48x103 MPa
4.5 - 7 million psi
BHP
7– 10 Mpa
1,000 – 1,500 psi
BHST
93 ºC
200 ºF
SPE ATW Presentation
31
Sandstone
HiWAY® Presentation
Conventional Gas Case Study
HiWAY increases EUR per well by 15% for YPF, S.A
Challenge
Increase declining production in gas field.
Loma La Lata
Solution
Improve hydrocarbon deliverability HiWAY
flow-channel fracturing technique (7 HiWAY
wells vs. 8 conventional wells)
Increased average initial gas production by
53%.
Increased average Estimated Ultimate
Recovery per well by 15% (+1.0 Bcf/well)
Stable production for 2+ years
SPE Paper 135034
32
Formation type
TVD
Results
Neuquén
32
Sandstone
2900 – 3200 m
9,500 – 10,500 ft
Permeability
0.08 to 5 mD
Porosity
12% to 17%
Young’s modulus
28x - 48x103 MPa
4 - 7 million psi
BHP
24 – 31 Mpa
3,500 – 4,500 psi
BHST
112 - 118 ºC
235 – 245 ºF
Proppant/stage (Klbm)
Fluid/stage (Kgal)
HiWAY
Conventional
∆
HiWAY
Conventional
∆
74
133
-44%
49
45
+8%
HiWAY® Presentation
Case Study: IHSA, Nejo Field, Mexico North
HiWAY increases PI and cumulative production over 4 months
Challenge
Improve production of condensates/light oil from
S-shaped wells in overpressured layers
Solution
Apply HiWAY Flow Channel Fracturing to
increase fracture conductivity in pilot wells (4
HiWAY vs. 7 conventional)
Formation type
TVD
1500 – 2500 m
4,900 – 8,200 ft
Permeability
0.01 - 10 mD
Porosity
4% to 9%
Young’s modulus
24x - 28x103 MPa
2 - 4 million psi
BHP
24 – 41 Mpa
3,500 – 6,000 psi
BHST
65 - 80 ºC
150 – 176 ºF
Results
• Increase in average PI from 0.15 to 0.24
(bbl/d/psi)/mD.m
• New best producer in field – 77 Mbbl condensate
over 4 months (10% more than former best
producer and 86% above field average)
• Zero screen-outs
http://www.slb.com/resources/case_studies/stimulation/hiway_increases_nejo_cs.aspx
33
Sandstone / dirty sandstone
HiWAY® Presentation
Case Study: PEMEX, Palmito Field, Mexico North
HiWAY increases PI and cumulative production over 4 months
Challenge
Improve production of gas from depleted field
Formation type
TVD
Solution
Apply HiWAY Flow Channel Fracturing to
increase fracture conductivity in pilot wells (6
HiWAY vs. 6 conventional)
Results
900 – 1600 m
2,950 – 5,250 ft
Permeability
0.5 - 5 mD
Porosity
10% to 18%
Young’s modulus
14x - 28x103 MPa
2 - 4 million psi
BHP
15 – 22 Mpa
2,200 – 3,200 psi
BHST
65 - 75 ºC
150 – 170 ºF
• Increase in average PI from 160 to 220
Mscf/d/mD.ft
• Increase in cumulative production by 19% over 6
months
• Reduction in proppant from 240 to 124 Mlb/stage
using smaller mesh size (16/30 vs. 20/40) and
avoiding use of RCS
• Zero screen-outs
SPE Paper 152112
34
Sandstone/dirty sandstone
HiWAY® Presentation
Case Study: Chesapeake, Barnett Shale
HiWAY reduces water/proppant consumption by 40% and HHP by 33%
Challenge
Minimize footprint and simplify logistics for
fracturing treatments in the Barnett area without
compromising well productivity
Formation type
Shale
TVD
Solution
Increase fracturing efficiency with HiWAY flowchannel fracturing technique (4 HiWAY vs. 6
conventional wells)
2100 – 2400 m
7,000 – 7,900 ft
Permeability
200 to 600 nD
Porosity
5% to 8%
Young’s modulus
21x - 34x103 MPa
3 - 5 million psi
BHP
24 – 28 Mpa
3,500 – 4,000 psi
BHST
71 - 93 ºC
160 – 200 ºF
Results
• Reduction in water and proppant consumption per
stage by 39% and 44% while improving well
productivity by 10%
Normalized Gas
Production (MSCF/unit)
50
HiWAY
Conventional
40
30
20
10
0
•
per ft lateral
Reduction in horsepower requirements by 33%
Proppant/stage (Klbm)
• Zero screen-outs
SPE Paper 155684
35
per lb proppant
Fluid/stage (Kgal)
per gal fluid
Pumping Energy (HHP)
HiWAY
Conv.
∆
HiWAY
Conv.
∆
HiWAY
Conv.
∆
429
766
-44%
470
768
-39%
8,827
13,192
-33%
HiWAY® Presentation
Case Study: Three Forks, Horizontal well
Challenge
Improve fracture placement along lateral by
reducing the risk of screen out
Obtain high end production results
Solution
Improve fracture conductivity with HiWAY
flow-channel fracturing technique (1 HiWAY
vs. 17 conventional wells)
Results
No screen out: Reduce screen out rate
from 10% to zero.
• HiWAY well: High end oil production:
Similar to best offsets and 26%
improvement than average of 17 wells with
less resources
36
Cumulative oil production (bbls)
HiWAY Provides Reduction Screen Out Risk and High End Production
70000
60000
∆ = +26%
50000
40000
30000
20000
10000
0
0
30
60
90 120 150 180 210 240
Producing days
Conventional (Avg 17 wells)
HiWAY (1 Well)
Average Completion Data per Well
Cumulative Oil
Production
(bbls)
Fracturing
Technique
Lateral
Length, ft
Fracturing
Fluid, bbl
Proppant,
lbm
240 days
HiWAY (1 well)
9598
21,723
819,220
67,706
Conventional (17
wells)
9293
25,665
1,745,167
53,748
Difference
+3.3%
-15%
-53%
+26 %
HiWAY® Presentation
Case Study: Encana, Rocky Mountains
HiWAY Delivers 24% More Production from Tight Gas Formation
Challenge
Improve production in multi-stage wells
Solution
Improve fracture conductivity with HiWAY flowchanne fracturing technique (13-well campaign)
Formation type
Results
24% increase in gas production
17% increase in expected recovery after 2
years
TVD
Reduction in screen-out rate from 5% to 0%
+700 fracturing treatments performed to date
with significant footprint reduction
3400 – 4100 m
11,000 – 13,500 ft
Permeability
0.5 to 10 µD
Porosity
6% to 9%
Young’s modulus
24x - 41x103 MPa
3.5 - 6 million psi
BHP
28 – 69 Mpa
4,000 – 10,000 psi
BHST
79 - 118 ºC
175 – 245 ºF
Proppant/stage (Klbm)
Fluid/stage (Kgal)
HiWAY
Conventional
∆
HiWAY
Conventional
∆
162
297
-45%
94
104
-10%
SPE Paper 140549
37
Sandstone/shale
HiWAY® Presentation
Hawkville Field - Eagle Ford Shale Formation
• Eagle Ford Characteristics
• 100 – 300 ft gross thickness
• High calcite (60 - 70%)
• Low quartz (< 20%)
• Closure stress: 9,500 - 11,000 psi
• Young’s modulus: 2.7 - 4.3 Mpsi
• BHST: 275 - 335 degF
• Upper Eagle Ford
• 1 – 2.5% TOC, 4 - 7% porosity
• 150 - 300 nD permeability
• Lower Eagle Ford
• 3 – 6.5% TOC, 6 - 12% porosity
• 350 – 700 nD permeability
38
HiWAY® Presentation
Case Study: Eagle Ford Shale, Eagleville Field
HiWAY Increases Condensate and Gas Production
Challenge
Improve production in multi-stage
horizontal wells (parallel wells with same
completion designs)
Solution
Improve fracture conductivity with HiWAY
flow-channel fracturing technique (2
HiWAY vs. 2 conventional wells)
Formation type
Carbonate/shale
TVD
3575 – 3700 m
11,800 – 12,200 ft
Permeability
200 to 600 nD
Porosity
7% to 10%
Young’s modulus
28x - 57x103 Mpa
4.1 – 8.4 million psi
BHP
55 – 69 Mpa
8,000 – 10,000 psi
BHST
137 - 154 ºC
280 – 310 ºF
Results
Increased condensate production by 43%
Increased gas production by 61%
Higher wellhead flowing pressure
Increased water recovery
Proppant/stage (Klbm)
39
Fluid/stage (Kgal)
HiWAY
Conventional
∆
HiWAY
Conventional
∆
160
247
-35%
245
579
-58%
HiWAY® Presentation
Case Study: BHPBHP-Petrohawk,
Petrohawk, Eagle Ford Shale
HiWAY Increases Production from Horizontal Well by 37%
Challenge
Improve production in multi-stage
horizontal wells
Formation type
Carbonate/shale
TVD
Solution
Improve fracture conductivity with HiWAY
flow-channel fracturing technique (2
HiWAY vs. 8 conventional wells)
SPE Paper 145403
40
10,900 – 11,500 ft
Permeability
200 to 600 nD
Porosity
6% to 8%
Young’s modulus
17x - 34x103 MPa
2.5 - 5 million psi
BHP
55 – 69 Mpa
8,000 – 10,000 psi
BHST
121 - 168 ºC
250 – 335 ºF
120,000
Gas Area
1.4
1.2
1.0
0.8
0.6
0.4
HiWAY
0.2
Conventional (best offset)
0
0
30
60
90
120
Time, days
150
180
Cumulative Oil Production (bbl)
1.6
Cumulative Gas Production (Bcf)
Results
Heim #2H:
#2H +4 MMcfd (37%) increase in
initial gas production rate (gas window)
Dilworth #1H:
#1H +200 BOPD (32%) increase
in initial oil production rate (oil window)
2000+ stages, 100+ wells pumped to date
with significant footprint reduction
3300 – 3500 m
100,000
Oil Area
80,000
60,000
40,000
20,000
0
HiWAY
Conventional (best offset)
0
Proppant/stage (Klbm)
30
60
90
120
Time, days
150
Fluid/stage (Kgal)
HiWAY
Conventional
∆
HiWAY
Conventional
∆
203
340
-40%
207
273
-24%
HiWAY® Presentation
180
Productivity Normalization via Reservoir
Simulations
Completion & Stimulation 3D Formation
Parameters*
Simulator
Calibrated
Model
Normalized
production at
equivalent BHP
XF
H
2X F
2L N + L C
LN
LC
LN
*Fan, L., Thompson, J., Robinson, J.R., 2010 Understanding Gas Production Mechanism and Effectiveness of Well Stimulation in the Haynesville Shale Through
Reservoir Simulation. Paper SPE 136696 presented at the Canadian Society for Unconventional Gas, Calgary 19 – 21 October
41
HiWAY® Presentation
Dry Gas Area
180-day Cumulative Gas Production
1,600,000
Heim 2H (Channel fracturing)
Offset A
1,400,000
Offset B
Cumulative production (Mscf)
Heim 2H Offset A
Offset B
Offset C
1,200,000
Offset C
1,000,000
800,000
600,000
400,000
6.6 mi
200,000
0
0
30
60
90
120
150
180
Time, days
180-day Wellhead Flowing Pressure and Choke Size
7,000
5,000
Choke size
Wellhead flowing pressure (psi)
6,000
4,000
3,000
2,000
Heim 2H (Channel fracturing)
Offset A
Offset B
Offset C
1,000
0
0
30
60
90
120
150
180
26
24
22
20
18
16
14
12
10
8
6
4
2
0
Heim 2H (Channel fracturing)
Offset A
Offset B
Offset C
0
30
60
Time, days
42
HiWAY® Presentation
90
Time, days
120
150
180
Dry Gas Well History Match Examples
Non-Channel Fracture Well
Channel Fracture Well
Production tubing
installed
Production tubing
installed
BHP
Match
CF well: smaller drawdown; higher rates
Gas
Rate
Match
Water
Rate
Match
43
HiWAY® Presentation
Dry Gas Area
180180-day Normalized Gas Production at Equivalent BHP
∆ = 51%
44
HiWAY® Presentation
Dry Gas Area Long Term Production
350
2,500
300
Gas Equivalent Production (MMscfe)
Cumulative Gas Equivalent Production (MMscfe)
400
3,000
2,000
250
Heim
2H
Heim 2H
200
1,500
Offset AA
Offset
Offset BB
Offset
150
Offset C
Offset C
1,000
100
500
50
00
30
30
60
60
90
90
120 150
150 180
180 210
210 240
240 270
270 300
300 330
330 360
360 390
390 420
420 450
450 480
480 510
510 540
540 570
570
120
Days
Days
45
HiWAY® Presentation
CondensateCondensate-Rich Area
180180-day Normalized Condensate Production at Equivalent BHP
∆ = 46%
46
HiWAY® Presentation
Condensate Well History Match Examples
Channel Fracture
Well
Non-Channel Fracture
Well
BHP Match
CF well: smaller drawdown; higher
rates
Gas Rate Match
Water Rate Match
Oil Rate Match
Oil-Gas Ratio
47
HiWAY® Presentation
Condensate Area Long Term Production
500
60
Cumulative Oil Equivalent Production (MBble )
Oil Equivalent Production (MBble)
450
400
50
350
40
300
250
30
Dilworth 1H
Dilworth 1H
OffsetA A
Offset
200
20
150
100
10
50
00
30
30
60
60
90
90
120
120
150
150
180
180
210
210
240
240
270
300
270
300
Days
Days
48
330
330
360
360
390
390
420
420
HiWAY® Presentation
450
450
480
480
510
510
540
540
Distribution of Wells in the Hawkville Field
49
49
HiWAY® Presentation
SPE 145403 (with BHP Billiton-Petrohawk)
50-well study. Eagle Ford Shale, Hawkville field (La Salle and McMullen Counties, Texas).
1600
HiWAY
Average cumulative production (Bcfe)
Cumulative probability
2
5
10
20
30
40
50
60
70
80
90
95
1400
1200
Hybrid
Slickwater
1000
800
32% 67%
600
400
200
98
0.1
0.5
1.0
2.0
3.0
90-day cumulative production (Bcfe)
Basic completion data
(Average per well)
50
KPIs - 90 days
Average
Production / Production / Production /
cum.
1000 ft
Mbbl Frac
Mlbm
production
Lateral
Fluid
proppant
(MMcfe)
659
115
7.6
0.18
Fracturing technique
Lateral length
(ft)
Frac fluid
(Mbbl)
Proppant
(Mlbm)
HiWAY (12 wells)
5755
87
3668
Hybrid (8 wells)
5382
99
5470
497
92
5.0
0.09
Slickwater (30 wells)
4403
176
3890
392
89
2.2
0.10
50
HiWAY® Presentation
0
90 days
250 days
SPE 145403 (with BHP Billiton-Petrohawk)
50-well study. Eagle Ford Shale, Hawkville field (La Salle and McMullen Counties, Texas).
1600
HiWAY
Average cumulative production (Bcfe)
Cumulative probability
2
5
10
20
30
40
50
60
70
80
90
95
1400
1200
37% 87%
Hybrid
Slickwater
1000
800
32% 67%
600
400
200
98
0.1
0.5
1.0
2.0
3.0
0
90 days
250 days
250-day cumulative production (Bcfe)
Basic completion data
(Average per well)
51
KPIs - 90 days
KPIs - 250 days
Average
Average
Production / Production / Production /
Production / Production / Production /
cum.
cum.
1000 ft
Mbbl Frac
Mlbm
1000 ft
Mbbl Frac
Mlbm
production
production
Lateral
Fluid
proppant
Lateral
Fluid
proppant
(MMcfe)
(MMcfe)
659
115
7.6
0.18
1,341
233
15.4
0.37
Fracturing technique
Lateral length
(ft)
Frac fluid
(Mbbl)
Proppant
(Mlbm)
HiWAY (12 wells)
5755
87
3668
Hybrid (8 wells)
5382
99
5470
497
92
5.0
0.09
979
182
9.9
0.18
Slickwater (30 wells)
4403
176
3890
392
89
2.2
0.10
717
163
4.1
0.18
51
HiWAY® Presentation
Public Customer Endorsements
• Groupement Sonatrach AGIP
• YPF, S.A.
• PCOC
• SOG
• Petrosilah
• QPC
• ONGC
• IHSA
• PEMEX
• TNK-BP
• Rosneft
• Slavneft-Megionneftegaz
• Petrohunt
• Chesapeake
• BHP-Petrohawk
• Hess
• Comstock
• Encana
52
HiWAY® Presentation
Algeria
Argentina
China
Egypt
Egypt
Egypt
India
Mexico
Mexico
Russia
Russia
Russia
USA - Bakken shale
USA - Barnett shale
USA - Eagle Ford shale
USA - Eagle Ford Shale
USA - Haynesville shale
USA - Jonah field
HiWAY-Related Publications
Client-Endorsed SPE Activity
•
•
•
•
•
•
•
•
•
•
•
•
•
SPE 135034 (with YPF, S.A.) – A New Approach to Generating Fracture Conductivity (ATCE’10. Florence, Italy)
SPE 140549 (with Encana Oil and Gas USA) - Channel Fracturing - A Paradigm Shift in Tight Gas Stimulation (HFTC’11, The
Woodlands, USA)
SPE 145403 (with PetroHawk) - Channel Fracturing in Horizontal Wellbores: the New Edge of Stimulation Techniques in the
Eagle Ford Formation (ATCE’11. Denver, USA. Oct. 2011)
SPE 147587 (with Encana Oil and Gas USA) - Raising the bar in completion practices in Jonah Field: Channel fracturing
increases gas production and improves operational efficiency (CSUG/SPE CURC’11. Calgary, Canada. November 2011)
SPE 149390 (with Petrohawk) - Completion Evaluation of the Eagle Ford Formation with Heterogeneous Proppant Placement
(SP CSUG/SPE CURC’11. Calgary, Canada. November 2011)
SPE 152112 (with PEMEX) - Field Development Study: Channel fracturing increases gas production and improves polymer
recovery in Burgos Basin, Mexico North (HFTC’12. The Woodlands, February 2012)
SPE 153728 (with Petrohawk) – Understanding the Impact of Channel Fracturing in the Eagle Ford Shale through Reservoir
Simulations (LACPEC’12. Mexico City, Mexico, April 2012)
SPE 155684 – Field Development Study: Channel Fracturing Achieves both Operational and Productivity Goals in the Barnett
Shale (URNC’12. Pittsburgh, USA. June 2012)
SPE 159437 – First Channel Fracturing Applied in Mature Wells Increases Production from Talinskoe Oilfield in Western
Siberia (Russia Oct 2012)
SPE 160242 – The First Implementation of Elongated Proppant in Hydraulic Fracturing in Russia (Russia, Oct 2012)
SPE 160767 – Channel Fracturing in the Remote Taylakovskoe Oil Field: Reliable Stimulation Treatments for Significant
Production Increases (Russia, Oct. 2012)
SPE ATW Presentation (with Rosneft)- Channel Fracturing: Experience and Applicability in Russia (Sep’10. Nizhnevartovsk,
Russia)
53
HiWAY® Presentation
2012: Integration of HiWAY modeling with Mangrove
Structure Lithology
HiWAY
Staging &
Perforating
DFN
Geomechanical Model
Reservoir
Simulation
Microseismic
Mapping
Complex Hydraulic
Fracture Models
with HiWAY
Automated
Gridding
54
HiWAY® Presentation
StimMAP
HiWAY Service: More Value with Less Resources
Reliable service, proven solution
• > 9,500 treatments (> 870 wells) in 15 countries
• Variety of formations (carbonate, sandstone, shale)
• Unprecedented proppant placement rate (99.94%)
• ~475 screen-outs prevented to date
Significant impact on production
• >20% increase in tight formations
Significant reduction in logistics, safety risks and
environmental footprint. Reductions in:
• Water and proppant consumption per job of 25% and 42%,
respectively;
• > 375 million gallons of water and > 1.2 billion lbs of
proppant saved so far;
•
> 55,000 proppant and water hauling road journeys
• > 12 million lbs of CO2 emissions avoided
Paradigm shift in hydraulic fracturing technology
55
55
HiWAY® Presentation
9/5/2012
HiWAY
Driving Your Production to the Next Level
Visit us at:
http://www.slb.com/HiWAY
56
HiWAY® Presentation
HiWAY
Driving Your Production to the Next Level
Thank you for your attention!
Visit us at:
http://www.slb.com/HiWAY
57
HiWAY® Presentation