the evolution of bakken horizontal completions

The Evolution of

Bakken Horizontal Completions

Clyde Findlay II

Petroleum Engineer

Midland, Texas

May 12, 2009

Major Points

• Long 10,000’ laterals are successful

• Single laterals work best

• Stage isolation works best

• More lateral refinement on horizon

MTMT

WYWY

SDSD

NDND

MBMBSKSKABAB

Richland

Richland

Co.

Co.

McKenzie &

McKenzie &

Dunn Co.

Dunn Co.

MTMT NDND

Williston Basin

The Evolution of Bakken Horizontal Completions

Bakken Horizontal Well Play (MT / ND)

CRI Drilling Rig

Challenging TerrainView from our location

Nesson Anticline trendEUR 288 Mboe per well

Richland dolomite trendEUR 450 Mboe per well

Cartoon Structural Geo–

section

Not to scale

N. Dakota

Upper Bakken

Lower Bakken

Middle Bakken

3-D Play Map

Montana

Up Dip Limit of Thermal MaturityFractured

dolomite trend

Permeability created by faults, tectonic

fractures & subtle structural features

related to basement horst & graben

blocks and by microfractures created

during maturation process.

COP Nesson Anticline Position

154,000 Net Acres

Marathon Bailey Field

EOG Parshall Field

Sanish

Sand

Fort Berthold

Reservation



North Dakota BakkenMontana Bakken

Upper Bakken ShaleUpper Bakken Shale

Middle Bakken Dolomite

Lower Bakken Shale

Lower Bakken Shale

Three Forks

Three Forks

Middle Bakken Dolomite

15’ Net Pay 40’ Net Pay

Bakken – Lower Mississippian

Three Forks - Devonian

NORTH DAKOTA• Net Pay 40’

• Avg Porosity 5% – 7%

• Perm <0.01 – 0.05 md

• Oil Gravity 42 API

• GOR 800 – 1500 scf/bbl

• Initial BHP 6000 – 8000 psi

• Bubble Point ~4000 psi

MONTANA• Net Pay 15’

• Avg Porosity 5% – 10%

• Perm <0.1 – 0.5 md

• Oil Gravity 42 API

• GOR 400 – 800 scf/bbl

• Initial BHP 4500 – 5000 psi

• Bubble Point ~1800 psi


Thinking in reverse for unconventional plays:

• What frac design will be utilized?

• What type of completion equipment will be needed?

• What dogleg and lateral length will my completion equipment allow?


• Success factors – Create large surface area in low perm reservoir and

optimize frac geometry – Orientation – Transverse vs. Longitudinal fracs – Segment well bore into defined intervals – Conductivity

• Design factors – Perforations – Proppant type/volume – Treating rate – Frac stages & diversion – Propped height of 200’

• Challenges – Financial limitations – Extreme lateral length – Inclement weather


Size Weight Grade Threads Depth

9-5/8" 32.3 #/ft H-40 STC 0' - 1,628'

9-5/8" Guide Shoe STC 1,628' - 1,630'


7" 29 #/ft HCL-80 LTC 0' - 2,452'

7" 29 #/ft P-110 LTC 2,452' - 6,160'

7" 32 #/ft HCL-80 LTC 6,160' - 7,642'

7" 32 #/ft P-110 LTC 7,642' - 8,835'

7 29 #/ft P-110 LTC 8,835' - 10,184'

7" Float Collar 10,184' - 10,185'

7" 29 #/ft P-110 LTC 10,185' - 10,248'

7" Guide Shoe 10,248' - 10,250'

Window Detail:

Cut Window @ 9,455' - 9,463' (Wireline Depth)

Size Weight Grade Threads Depth KOP = 9,571'

5" 18 #/ft L-80 STL 9,485 - 10,401'

5" Guide Shoe 10,401' - 10,404'

Southwest Lateral Detail: Northwest Lateral Detail:

TD = 15,125' MD (9,980' TVD) TD = 13,940' MD (10,014' TVD)

6” Open Hole Lateral Length = 4,875’ 6” Open Hole Lateral Length = 3,536’

Last Updated 7/20/04 by JLB

API # 25-083-22159

Wellbore Schematic

GL Elev. - 2,431' KB-GL = 20'

Surface Casing & Cement Detail:

Production Casing & Cement Detail:

Production Liner Detail:

Cemented 665 sx thru shoe to surface

Cemented 610 sx thru shoe. CBL TOC = 6,780'

Aerial View**Not to Scale

Bakken Dolomite

Bakken Shale

SW Lateral NW Lateral

N

Sec. 36

T-24N, R-54E

Sec.1

T-23N, R-54E

BR 21-

BR 44-36H


9-5/8" 32.3 #/ft H-40 STC 0' - 1,322'

9-5/8" Insert & Guide Shoe STC 1,322' - 1,323'


7" 29 #/ft L-80 LTC 0' - 6,240'

7" 32 #/ft HCL-80 LTC 6,240' - 6,979'

7" 32 #/ft P-110 LTC 6,979' - 7,905'

7" 29 #/ft L-80 LTC 7,905' - 10,190'

7 Float Collar N-80 LTC 10,190' - 10,192'

7" 29 #/ft L-80 LTC 10,192' - 10,263'

7" Guide Shoe N-80 LTC 10,263' - 10,264'

Window Detail:

Cut Window @ 9,678' - 9,687'

Southeast Lateral Detail: Southwest Lateral Detail:

TD = 15,121' MD (9,382' TVD) TD = 15,531' MD (9,295' TVD)


Sec. 4, T-24N, R-53E

BR 31-4H 43

Wellbore Schematic



Cemented With 440 Sacks - Circulated To Surface

Cemented With 905 Sacks. CBL TOC = 2,150'

Bakken Dolomite

Bakken Upper

Southeast Lateral

Bakken Lower Shale

Southwest Lateral

Section 4

T-24N, R-53E

N

Aerial View

Size Weight Grade Threads Depth, ft

9-5/8" 32.3 #/ft H-40 STC 0' - 1,319'

9-5/8" Insert & Guide Shoe STC 1,319' - 1,320'


7" 29 #/ft L-80 LTC 0' - 6,217'

7" 32 #/ft HCL-80 LTC 6,217' - 7,834'

7" 29 #/ft L-80 LTC 7,834' - 9,423'

7 Float Collar L-80 LTC 9,423' - 9,424'

7" 29 #/ft L-80 LTC 9,424' - 9,508'

7" Guide Shoe L-80 LTC 9,508' - 9,510'

Southwest Lateral Detail: Northwest Lateral Detail:

TD = 13,750' MD (9,216' TVD) TD = 15,320' MD (9,165' TVD)



Wellbore Schematic

Sec. 35, T-25N, R-52EBR 21-35H 52



Cemented With 480 Sacks

Aerial View

N

Sec. 35

T-25N,

R52E

Sec. 26

T-25N,

R52E

Middle Bakken Dolomite Pay

Upper Bakken Shale

Lower Bakken Shale

Note: Side Track is in open hole @ 9,624' SW Lateral

NW Lateral

Section 27, T24N, R53E

Richland, Montana


9-5/8" 32. #/f t H-40 STC 0' - 1317'

9-5/8" Insert & Guide Shoe K-55 Welded 1,317' - 1,318'


7" 29 #/ft L-80 LTC 0' - 6,126'

7" 32 #/ft HCL-80 LTC 6,126' - 6950'

7" 32 #/ft P-110 LTC 6,950' - 8,074'

7" 29 #/ft L-80 LTC 8,074' - 9,637'


7" 29 #/ft L-80 LTC 9,638' - 9,715'

7" Guide Shoe L-80 LTC 9,715' - 9,716'


5" 18. #/f t P-110 STL 8974'-10,002'

Frac Assembly

Top Pkr @ 8936'

Bottom Pkr @ 8978' with pump out plug

South Lateral Detail: 2nd Southeast Lateral Detail: 3rd East Lateral Detail: 1st

TD = 13,644' MD (9,375' TVD) TD = 14,807' MD (9,438' TVD) TD= 13,150' MD (9,453' TVD)

Kick off south lateral at 9726' Kick off southeast lateral at 9,790' Top of Window 8950'

6” Open Hole Lateral Length = 3,918’ 6” Open Hole Lateral Length = 5017’ 6" Open Hole Lateral Length = 4,200'

5" Liner in East Lateral

BR 11-27H 43Section 27, T24N, R53E

Wellbore Schematic




Cemented With 480 Sacks -- TOC surface

Plan View **Not to Scale


Upper Bakken Shale

Lower Bakken Shale

East Lateral

South Lateral

Southeast Lateral

Section 29, T24N, R53E

Size Weight Grade Threads Depth, ft Richland, Montana

9-5/8" 32. #/ft H-40 STC 0' - 1360'

7" 29 #/ft L-80 LTC 0' - 6,163'

7" 32 #/ft HCL-80 LTC 6,163' - 6,986'

7" 32 #/ft P-110 LTC 6,986' - 8,017'

7" 29 #/ft L-80 LTC 8,017 - 9,567'


7" 29 #/ft L-80 LTC 9,569' - 9,655'

7" Guide Shoe L-80 LTC 9,655' - 9,656'

Northeast Lateral Detail: 2nd East Lateral Detail: 3rd North Lateral Detail: 1st

TD = 15,072' MD (9,341' TVD) TD = 13,590' MD (9362' TVD) TD= 13,706' MD (9,328' TVD)

side track south lateral F10,044' side track west lateral F9760-9797' Drilled from shoe joint

6” Open Hole Lateral Length = 5,028’ 6” Open Hole Lateral Length = 3830’ 6" Open Hole Lateral Length = 4050'

Cemented With 790 Sacks. CBL TOC = 2280'

Casing & Cement Detail:

Cemented With 480 Sacks -- TOC surface

BR 14-29H 43Section 29, T24N, R53E

Wellbore Schematic


Upper Bakken Shale

Lower Bakken Shale

North LateralEast Lateral

Northeast Lateral

Evolution of Well Designs w/ Various Lateral Configurations


Size Weight Grade Threads Depth (top) Depth (btm)

9-5/8" 36 #/ft J-55 STC 0 2,532'

7" 29 #/ft L-80 LTC 20 (KB) 6,620'

7" 32 #/ft HCL-80 LTC 6,620' 8,732'

7" 32 #/ft P-110 LTC 8,732' 9,710'

7" 29 #/ft L-80 LTC 9,710' 11,715'

7 Float Collar L-80 LTC 11,715' 11,717'

7" 29 #/ft L-80 LTC 11,717' 11,803'

7" Guide Shoe L-80 LTC 11,803' 11,805' 11,132' TVD

HAL Versaflex Liner Hanger = 10,560'

KOP = 10,710'

Southeast Lateral Detail:

Casing & Cement Detail:

COLTER 44-14HSection 14, T147N, R96W, Dunn County, North Dakota

Wellbore Schematic

Cemented with 855 Sacks. CBL TOC = 2,785'

Cemented with 750 Sacks -- TOC surface

Section 14, T147N - R96W

Dunn County, North Dakota

6” Open Hole Lateral Length = 8,530’

Drilled from 7" shoe joint

TD = 20,335' MD (11,132' TVD)


Upper Bakken Shale

Lower Bakken Shale

North Lateral (see liner tally for details)

14

11

Transition to Single Lateral

Single Lateral –

OH or 4-1/2” Liner


• Open Hole – OH Diversion

• 4-1/2” Liner – TCP & Ball Sealers

• 4-1/2” Liner – Sliding Sleeves

• 4-1/2” Liner – Plug & Perf

• New Hybrid Design

Completion Methods in the Bakken Play for

Single Laterals


Tools of the Trade Versaflex

Liner Hanger

Rock Seal II

Hydraulic

Packer

Swell Packer

Composite

Bridge Plug

Delta Stim

Sleeve


OPEN HOLE COMPLETION

4-1/2" LINER W/SLIDING SLEEVE STAGES

4-1/2" LINER UTILIZING PLUG & PERF STAGES

7" Shoe

+/- 11,000'Swell Pkr Swell Pkr Swell Pkr Swell Pkr

TD

+/- 20,000'

4-1/2"

Shoe

+/-200'

off TD

Press

Operated

Vent

Pinned at +/-

4,200 psi

Sliding

Sleeve

1.5" Ball

Sliding

Sleeve

1.75" Ball

Sliding

Sleeve

2.0" Ball

4-1/2", 11.6#/ft, P-110 Liner w/4.0" ID

6" Hole

Sliding

Sleeve

2.25" Ball

Swell Pkr Swell Pkr Swell PkrSwell PkrSwell Pkr

7" Shoe

+/- 11,000'Swell Pkr Swell Pkr Swell Pkr Swell Pkr

TD

+/- 20,000'

4-1/2"

Shoe

+/-200'

off TD

4-1/2", 11.6#/ft, P-110 Liner w/4.0" ID 6" Hole

Swell Pkr Swell Pkr Swell PkrSwell PkrSwell Pkr

Sliding

Sleeve

2.5" Ball

Sliding

Sleeve

2.75" Ball

Sliding

Sleeve

3.0" Ball

Sliding

Sleeve

3.25" Ball

Sliding

Sleeve

3.50" Ball

TCP Perforate

the Toe Stage

7" Shoe

+/- 11,000'

TD

+/- 20,000'

6" Open Hole

0 40.00 80.00 120.00 160.00 200.00 240.000

1000

2000

3000

4000

5000

6000

7000

8000

0

10.0

20.0

30.0

40.0

50.0

60.0

70.0

80.0

90.0Treating Pressure(psi)

Slurry Rate(bbl/min)Proppant Conc(PPA)

Prop Conc (BH)(PPA)

Treatment Time(min)

Pre

ssure

(ps

i)R

ate

& P

roppant C

onc

++

Open Hole – Stress Induced Diversion

4-1/2” Liner – Sliding Sleeves

4-1/2” Liner – Plug & Perf

Fracture Mapping Project - Hybrid Liner Design

7" Shoe

11,805' Swell Pkr

12,436-452'

Swell Pkr

13,438-454'

Swell Pkr

14,144-160'

Swell Pkr

15,149-164'

Swell Pkr

16,143-159'

Hydraulic Pkr

17,653'

Pinned at 1,900 psi

Over Hydrostatic

Swell Pkr

17,150-165'

Hydraulic Pkr

18,669'

Pinned at 1,900 psi

Over Hydrostatic

TD

20,335'

4-1/2"

Shoe

19,974'

Press

Operated

Vent 19,700'

Pinned at

3,950 psi

Over

Hydrostatic

Sliding

Sleeve

19,156'

2.5" Ball

Sliding

Sleeve

18,180'

2.75" Ball

Sliding

Sleeve

17,425'

3.0" Ball

Encore's Branvic 11-1

Rigged with Pinnacle Technologies Seismic

Equipment

~900' to the Colter

Seismic View Window

~15,000' to 19,000'

4-1/2", 11.6#/ft, P-110 Liner w/4.0" ID

Six Perf & Plug Intervals

From 7" shoe to 17,150'

Separated with swell packers

Limestone sections

within seismic window

16,350' - 16,800'

17,010' - 17,100'

18,150' - 18,450'

18,550' - 18,820'

19,020' - 19,750'

Colter 44-14HBakken Horizontal Well Play

Fracture Mapping Project

7/10/2008

Robert Clark & Clyde Findlay II

Bakken Completions Team

500' Sleeve interval 1,000' Sleeve interval

Hydraulic Pkr

19,642'

Pinned at 2,500 psi

Over Hydrostatic

6" Hole

Observation Well

Treatment Well

Dunn Co., ND Test Well

Test Well Frac Design – Two Part

Sleeve Stages 1-4

• 20 ppt X-Link Borate

• 50 BPM

• 6600 psi Max Treat Press

• 1 - 4 ppg

• 378,000 lbs proppant in

formation

P&P Stages 5-10

• 20 ppt X-Link Borate

• 60 BPM

• 6700 psi Max Treat Press

• 1 - 6 ppg

• 758,000 lbs proppant in

formation


Prairie Rose 24-31H: 1 fracture

Fracture Penetration (ft)200 400 600 800

35.50 min

10800

ftTVD

11000

11200

Stress (psi)7500 8500 9500

Lim

esto

ne

Org

an

ic S

ha

le

0.000

0.100

0.200

0.300

0.400

0.500

0.600

0.700

0.800

0.900

1.000

Pro

pp

an

t C

overa

ge lb/f

t^2

Sliding Sleeve Stage – End of Pumping

Prairie Rose 24-31H: 5 fractures

Fracture Penetration (ft)200 400 600 800

35.50 min

10800

ftTVD

11000

11200

Stress (psi)7500 8500 9500

Lim

esto

ne

Org

an

ic S

hale

0.000

0.100

0.200

0.300

0.400

0.500

0.600

0.700

0.800

0.900

1.000

Pro

pp

an

t C

ove

rage

lb

/ft^

2

Plug & Perf Stage – End of Pumping

Microseismic Map & Side View – All StagesMicroseismic Map & Side View – All Stages

Science Well #1

18140 ft -T. D.

Modestly stimulated, high gas show toe section

Stim sleeve

Stim sleeve

Hydraulicpacker

Enhanced stimulation invicinity of hydraulic packer

Science Well #1

11100-13800 ft

Lateral vectoring of tracedproppant terminated at

casing shoe

Lateral vectoring of tracedproppant unimpeded by

swell packer

Perforated intervals treatedwith Sb-124 traced proppant

Swell packers

North Dakota Operated Production

ConocoPhillips & CRI Interest Wells BR

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

2/17/2005 9/5/2005 3/24/2006 10/10/2006 4/28/2007 11/14/2007 6/1/2008 12/18/2008

Date

Oil

bb

ls/d

ay

0

10

20

30

40

50

60

70

80

We

ll C

ou

nt

Gross Oil Well Count

Aggressively worked

down completion back

log & migrated to new liner completion

designs.

First Hybrid Well – 650 BOPD

First Plug & Perf Well – 725 BOPD


• Frac type - Simul-Frac, Zipper Frac, Sequential Frac as down spacing occurs

• Stronger proppant with higher conductivity

• Lower viscosity fluids

• Shorter laterals

• Proppant mesh variation

• Oriented perforating

• On the fly diversion techniques (fiber, balls, etc.)

• Real time microseismic to fine tune fracture geometry

Future Stimulation Technology


60º Phasing

6 Perfs @ 300°, 0°, 60°

60º Phasing6 Perfs @ 0°, 60°, 120°, 180°, 240°, 300°

Oriented Perfs Radial PerfsUsed to direct frac initiation upward

into the Bakken from the Three Forks.

Used to direct frac initiation radially

in the Bakken.


2000 ft

Well 1Well 2

Simul-Frac, Zipper Frac, Sequential Frac


TitleDave Cramer, Carl Montgomery, Clyde Findlay II & Robert ClarkQUESTIONS?