hiway: the quest for infinite conductivity - … · hiway: the quest for infinite conductivity ......

HiWAY: The Quest For Infinite Conductivity Innovation for a step-change in Hydraulic Fracturing

Presentation prepared for Jornada De Maxi-Fracturas May 2012

2010

2000

1990

1980

1970

1960

1950

HiWAY: A Paradigm Shift in Hydraulic Fracturing 1947 First hydraulic fracturing job

2011 Complex fracture modeling

1950 Fracturing using gelled oil

1960 Water-based, non crosslinked fluids

1968 Borate crosslinked fluids

1973 Crosslinked derivatized guars (HPG, CMHPG, etc)

1980 Foamed fracturing

1988 Encapsulated breakers

1994 Low polymer loadings 1997 Viscoelastic surfactants (VES)

1977 High-strength ceramic proppants

2001 Micro-seismic used to monitor frac jobs 2003 Horizontal well, multistage fractures 2005 Fiber based proppant transport

1990 Fiber based flowback control

2010 HiWAY* Flow-Channel Fracturing

Ensuring Structure Stability

Engineering Design

Completion Technique

Delivering Channel Structure

The Four Components That Deliver HiWAY Reliability

1 ft

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)

Reliable Design and Execution

Engineered candidate selection Design via FracCADE*

HiWAY module Thorough peer reviews and

design certification Optimized process control

using SLB standard fracturing equipment

7






8






9

Reservoir-Focused HiWAY Design Workflow

Build Geomechanical and

Reservoir Models

Design perforation strategy and

pumping schedule for optimum channel

distribution

Evaluate channel profile and fracture

conductivity

Design perforation strategy and

pumping schedule for optimum channel

distribution

Evaluate channel profile and fracture

conductivity

HiWAY Execution – From Concept To Reality Schematic pump schedule

Conventional HiWAY

Sand

Con

cent

ratio

n

Pad

Proppant (dirty) pulse Clean Fluid (clean) pulse

Cycle Tail-in stage

Time

Actual pump schedule in typical HiWAY job

11:39:43 11:46:23 11:53:03 11:59:43 0

120

240

360

480

600 Sa

nd C

once

ntra

tion,

kg ad

ded/

m3

0

1

2

3

4

5

Sand

Con

cent

ratio

n, P

PA

HiWAY Execution – From Concept To Reality

New fields under discussion HiWAY activity

HiWAY: Extensive Worldwide Experience

>5000 jobs, >99.95% jobs with proppant placed without screen-outs

2010-2012 HiWAY Activity Cumulative stages St

ages

per Q

uarte

r

0

1000

2000

3000

4000

5000

6000

0

200

400

600

800

1000

1200

1400

1600

1800

Q1'10 Q2'10 Q3'10 Q4'10 Q1'11 Q2'11 Q3'11 Q4'11 Q1'12

1203

4259

392

5070

583

1397

3482

229

3627

1606

2010 – 2012 HiWAY Activity – Treatment (Stage) Count

Sandstone Lance/Pinedale (USA)

Wamsutter (USA) Granite wash (USA)

Yegua (Burgos basin, Mexico) Eocene (Chicontepec, Mexico)

Sierras Blancas (Argentina) AS & BS – (Russia)

Abrar, West Qarum (Egypt) Gazhal (Saudi Arabia)

Others Carbonate Eagle Ford (USA) Bakken (USA) Clear Fork (USA)

Shale Barnett (USA) Haynesville (USA) Utica (USA) Marcellus (USA) Bossier (USA) Avalon (USA)

Reservoir Lithology Reservoir Fluid

Well Orientation Completion type

Oil Condensate + Gas

Dry Gas

Horizontal

Vertical

Cased hole

Open hole

Formation type Sandstone/shale TVD 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

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 flow-

channe fracturing technique (13-well campaign)

Results 24% increase in gas production 17% increase in expected recovery after 2

years Reduction in screen-out rate from 5% to 0% +700 fracturing treatments performed to date

with significant footprint reduction SPE Paper 140549

Proppant/stage (Klbm) Fluid/stage (Kgal)

HiWAY Conventional ∆ HiWAY Conventional ∆

162 297 -45% 94 104 -10%

SPE Paper 145403

Challenge Improve production in multi-stage horizontal

wells

Solution Improve fracture conductivity with HiWAY

flow-channel fracturing technique (2 HiWAY vs. 8 conventional wells)

Results Heim #2H: +4 MMcfd (37%) increase in

initial gas production rate (gas window) Dilworth #1H: +200 BOPD (32%) increase

in initial oil production rate (oil window) 2000+ stages, 100+ wells pumped to date

with significant footprint reduction

Case Study: BHP-Petrohawk, Eagle Ford Shale HiWAY Increases Production from Horizontal Well by 37%

Formation type Carbonate/shale TVD 3300 – 3500 m 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

Proppant/stage (Klbm) Fluid/stage (Kgal)

HiWAY Conventional ∆ HiWAY Conventional ∆

203 340 -40% 207 273 -24%

0.20.40.60.81.01.21.41.6

00 30 60 90 120 150 180

Time, days

HiWAYConventional (best offset)Cu

mulat

ive G

as Pr

oduc

tion (

Bcf)

0 30 60 90 120 150 180Time, days

120,000

100,000

80,000

60,000

40,000

20,000

0

Cumu

lative

Oil P

rodu

ction

(bbl)

HiWAYConventional (best offset)

Gas Area Oil Area

Eagle Ford Completion History

2008 – 2009, Slickwater treatments 2009 – 2010, Frac cost elevated rapidly 2010 (July), Hybrid treatments 2010 and 2011, Channel fracturing treatments Past Direction: Lower rate, Lower pressure, Higher Viscosity Smaller stage lengths Sand (4 to 5 PPA) (85% -20/40 & 15% 40/70) Reduce acid and supply water footprint Future Direction: Increase viscosity Increase contact area while minimizing cost Lower rate, lower treating pressure Reduce supply water footprint

Mexico Gulf of Mexico

Texas, United States

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

Hawkville Well Completions

• Well Type: Horizontal, cased hole (5½” and 4 ½” OD)

• Depth (TVD): 10,000 - 12,000 ft

• Depth (MD): 15,000 - 20,000 ft

• Horizontal Section: 4,000 - 7,000 ft

• Staging: Plug & Perf, 12 - 22 stages

• Perforation Strategy:

• SPF: 4 - 6; Phasing: 60º • Cluster length: 1 - 2 ft • Clusters per stage: 4 - 8 • Cluster spacing: 30 - 100 ft

Channel Fracturing (Hybrid) Treatment Plot

Distribution of Wells in the Hawkville Field

22

McMullen CountyLaSalle County

HiWAY Channel FracturingConventional – HybridConventional - Slickwater

Hawkville Field Production Data 2

510

20304050607080

90

95

98

0.1 0.5 1.0 2.090-day cumulative production (Bcfe)

Cumu

lative

Proba

bility

Fracturingtechnique

Average (Bcfe)Range

(Bcfe)

Channel fracturing (12wells)

0.660.43 – 1.10

Hybrid(8 wells) 0.50

Slickwater(30 wells)

0.39

Heim 2H

Dilwortth1H

Offset C

Offset A

Offset B

Offset D

0.11 – 0.68

0.36 – 0.65

23

0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

90 days 250 days

HiWAY

XL (Hybrid)

Slickwater

P 50 C

umul

ative

pro

duct

ion

(Bcf

e)

Basic completion data (Average per well) KPIs - 90 days KPIs - 250 days

Fracturing technique Lateral length (ft)

Frac fluid (Mbbl)

Proppant (Mlbm)

Average cum.

production (MMcfe)

Production / 1000 ft Lateral

Production / Mbbl

Frac Fluid

Production / Mlbm

proppant

Average cum.

production (MMcfe)

Production / 1000 ft Lateral

Production / Mbbl

Frac Fluid

Production / Mlbm

proppant

HiWAY (12 wells) 5755 87 3668 659 115 7.6 0.18 1,341 233 15.4 0.37

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

XF

2LN + LC

2XF

H

LN LC LN

Completion & Stimulation Parameters*

3D Formation Simulator

Calibrated Model

341

175 160

225

0

50

100

150

200

250

300

350

400

18

0-d

ay n

orm

aliz

ed

cu

mu

lative

ga

s

pro

du

ctio

n (M

Mscf/

10

00

ft)

Heim 2H (Channel Fracturing)

Offset A Offset B Offset C

Normalized production at

equivalent BHP

*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

Productivity Normalization via Reservoir Simulations

Dry Gas Area

0

200,000

400,000

600,000

800,000

1,000,000

1,200,000

1,400,000

1,600,000

0 30 60 90 120 150 180

Cum

ulat

ive p

rodu

ctio

n (M

scf)

Time, days

Heim 2H (Channel fracturing)Offset AOffset BOffset C

180-day Cumulative Gas Production

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

0 30 60 90 120 150 180

Wel

lhea

d flo

win

g pr

essu

re (p

si)

Time, days

Heim 2H (Channel fracturing)Offset AOffset BOffset C 0

2468

101214161820222426

0 30 60 90 120 150 180

Chok

e siz

e

Time, days

Heim 2H (Channel fracturing)Offset AOffset BOffset C

6.6 mi

Heim 2H Offset A

Offset B

Offset C

180-day Wellhead Flowing Pressure and Choke Size

Dry Gas Area History Matches Heim 2H

Gas

Water

BHP

Dry Gas Area 180-day Normalized Gas Production at Equivalent BHP

341

175 160

225

0

50

100

150

200

250

300

350

40018

0-da

y nor

mal

ized c

umul

ative

gas

prod

uctio

n (M

Msc

f/100

0 ft)

Heim 2H (Channel Fracturing)

Offset A Offset B Offset C

∆ = 51%

0

20,000

40,000

60,000

80,000

100,000

120,000

0 30 60 90 120 150 180

Cum

ulat

ive o

il pr

oduc

tion

(BBL

)

Time, days

Dilworth 1H (Channel fracturing)

Offset D

Condensate-Rich Area

0

1,000

2,000

3,000

4,000

5,000

6,000

0 20 40 60 80 100 120 140 160 180

Wel

lhea

d flo

wing

pre

ssur

e (ps

i)

Time, days

Dilworth 1H (Channel fracturing)

Offset D

02468

1012141618202224

0 30 60 90 120 150 180

Chok

e si

ze

Time, days

Dilworth 1H (Channel fracturing)Offset D

4.4 mi

Dilworth 1H

Offset D

180-day Cumulative Oil Production

180-day Wellhead Flowing Pressure and Choke Size

27.1

17.6

0

5

10

15

20

25

3018

0-da

y nor

mal

ized c

umul

ative

oil

prod

uctio

n (M

bbl/1

000 f

t)

Dilworth 1H(Channel Fracturing)

Offset D


180-day Normalized Condensate Production at Equivalent BHP

∆ = 46%

Effective Stimulated Index Comparison

Dry Gas Area

0.00

0.50

1.00

1.50

2.00

2.50

3.00

0.00

20.00

40.00

60.00

80.00

100.00

120.00

Offset A Offset B Channel Frac

Effe

ctiv

e St

imul

atio

n In

dex

per C

lust

er (f

t^3.

mD)

Flui

d an

d Pr

oppa

nt V

olum

e pe

r Clu

ster

(mga

ls,m

lbs)

Proppant Fluid ESI

0.00

0.40

0.80

1.20

1.60

2.00

2.40

2.80

3.20

3.60

4.00

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

40.00

45.00

50.00

Offset A Channel Frac

Effe

ctiv

e St

imul

atio

n In

dex

per C

lust

er (f

t^3.

mD)

Flui

d an

d Pr

oppa

nt V

olum

e pe

r Clu

ster

(mga

ls, m

lbs)

Prop Fluid ESI


ESI = ESV x Enhanced Permeability

ESV = 2 x PEA half-length x PEA width x thickness SPE Paper 149390

What Is The End Result? Better production: 90-day non-normalized cumulative production increased by: 32% (channel fracturing vs. hybrid) 68% (channel fracturing vs. slickwater). 180-day normalized cumulative production: > 51% in dry gas area; > 46% in condensate-rich area.

Gains in efficiency: Reduction in proppant and fluid volumes, allowing reductions in pumping time. Over 2300 treatments (140 wells) pumped to date. Zero screenouts.

• Channel fracturing improved well performance in the Hawkville field beyond conventional means.

• Additional completions continue to show channel fracturing treatments outperform slickwater and hybrid in the Hawkville Field.

Public Client Endorsements for HiWAY

• BHP -Petrohawk USA - Eagle Ford shale • Chesapeake USA - Barnett shale • Petrohunt USA - Bakken shale • Encana USA - Jonah field • YPF, S.A. Argentina • TNK-BP Russia • Rosneft Russia • PEMEX Mexico • ENI Algeria • SOG Egypt

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 (SPE UGC. Calgary, Canada. November 2011)

SPE 149390 (with Petrohawk) - Completion Evaluation of the Eagle Ford Formation with Heterogeneous Proppant Placement (SPE UGC. 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 ATW Presentation (with Rosneft)- Channel Fracturing: Experience and Applicability in Russia (Sep’10. Nizhnevartovsk, Russia)

Industry Articles Journal of Petroleum Technology Hart's E&P Magazine Petroleum (Spanish) New Technology (Canada) Several others

www.slb.com/hiway

Structure Lithology

DFN

Geomechanical Model

Staging & Perforating

Selectively placed perforation clusters

Rock quality legend

Stress legendHigh

LowRock quality

Stress

Complex Hydraulic Fracture Models with HiWAY

Microseismic Mapping

Automated Gridding

Reservoir Simulation

2012: Integration of HiWAY modeling with Mangrove

HiWAY StimMAP

HiWAY Channel Fracturing: More value, Less Resources • Fastest-growing new technology in the history of

Schlumberger

• > 5000 stages pumped (10 countries, 5 Areas)

• Significant impact on production – Typically > 20% increase

• Smaller footprint: Reductions in – water and proppant consumption per job of 25%

and 42%, respectively; – > 6 million barrels of water and 340,000 tons of

proppant saved so far; – > 33,000 proppant and water hauling road

journeys; – > 4 million pounds CO2 emissions

• Unprecedented proppant placement rate: – 99.96% placement success; – > 200 screen-outs prevented

HiWAY: The Quest For Infinite Conductivity Innovation for a step-change in Hydraulic Fracturing

Thank you for your attention

hiway: the quest for infinite conductivity - … · hiway: the quest for infinite conductivity ......

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