Advanced Well Completion Technology to Reduce Methane Emissions and Use of Infared Cameras for Leak Detection

Phil SniderMarathon Oil Company

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How am I going to frac this???

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Conventional Industry Solutiona few years ago

• Common stimulation technique–“cherry pick” individual zones–Perforate and attempt to stimulate multiple intervals

–Flow back (venting gas)–Isolate lower intervals–(repeat process multiple times)–Remove all isolation devices and flow well.

• Not very effective–Inevitably bypass much pay–Compromise stimulation design–Time consuming and costly–Infrastructure issues in certain locations

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Conventional Well Completion

Time (days)

Water and Frac Fluid Rate

Gas Rate

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Casing Conveyed Perforating Completion

A A*

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Cross-Section of Gun Assembly

`

A A*

3½” casing2⅜” guns

boreholecontrol line

Other Charge Phasings,

Shot Densities Available

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Isolation Valve Below External Perforating Gun

• Firing the gun actuates a lower isolation valve.

• Valve actuates when a protective sleeve shifts.

– Compatible with cementing and fracturing operations

• Frangible; flapper valve removal is usually easy

–PAST: with coiled tubing.–NOW: DISAPPEARING

• Next firing removes the lower isolation valves

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Module PlacementModule Placement

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Pres

sure

Pres

sure

TimeTime

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Technical AchievementsMarathon Alaska

• Single Day Completion – 24 hour period–16 stages fracture stimulated– with well cleanout and isolation valve removal– gas to sales within 30 hours

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Excape Well Completion

Time (days)

Water and Frac Fluid Rate

Gas RateUnloading Rate

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Marathon Alaska Excape WellPost –Completion Production Data

KBU 23-7 Test DataAs of 0530 7/25/04

630

3789

346

0

250

500

750

1000

1250

1500

1750

2000

2250

2500

2750

3000

3250

3500

3750

4000

7/22/2004 0:00 7/22/2004 12:00 7/23/2004 0:00 7/23/2004 12:00 7/24/2004 0:00 7/24/2004 12:00 7/25/2004 0:00 7/25/2004 12:00

Date & Time

Flow

rate

, MC

FD

WHP GAS RATE H2O RATE

Place well in Sales

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How Much Gas Was Not Vented?Marathon Alaska Excape Wells

Excape Completion Process

Well NameLocation Depth Modules Completed

(Zones Competed) IP

Excape: Estimated

Venting Before Sales

Total Vent time

KBU 42-7 Alaska 7,500 feet 15 modules 3,150 MCFD 700 MCF

Conventional: Number of Frac

Stages

Conventional: Estimated Venting per day, per Stage

Conventional: Estimated Number of Venting Days Per Stage

Conventional: Total Vented

Volume

Reduction in Venting Volume

4 350 MCFD 3. days 4,200 MCF 3,500 MCF

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Estimated Gas Not Vented

Reduction in Venting Volume

MCF

1,000 MCF

2,000 MCF

3,000 MCF

4,000 MCF

5,000 MCF

6,000 MCF

7,000 MCF

8,000 MCF

9,000 MCF

KBU 42-7

KBU 24-6

KBU 44-6

Beave

r Cree

k 11

KBU 43-7X

Beave

r Cree

k 13

KBU 33-6X

Falls C

reek 4

Canne

ry Lo

op 8

KBU 23-7

KBU 11-8X

Beave

r Cree

k 12

Beave

r Cree

k 14

Canne

ry Lo

op 9

KBU 42-6

KBU 22-6

KBU 11-8Y

Canne

ry Lo

op #1

0KBU 41

-6KBU 11

-7GO 4

KBU 24-6R

DCLU

11KBU 24

-7x

•Sum of the amounts: ~150 MMSCF(Alaska Only)

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Modules Run Per Well

Modules Run Per Well

modules

5 modules

10 modules

15 modules

20 modules

25 modules

30 modules

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Well Depths Well

Excape Installations, Well Depth

Feet

2,000 Feet

4,000 Feet

6,000 Feet

8,000 Feet

10,000 Feet

12,000 Feet

14,000 Feet

16,000 Feet

18,000 Feet

20,000 Feet

3,000 M

5,000 M

4,000 M

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Mud Weights Encountered

Excape Installations, Mud Weights

. lb/gal

2. lb/gal

4. lb/gal

6. lb/gal

8. lb/gal

10. lb/gal

12. lb/gal

14. lb/gal

16. lb/gal

18. lb/gal

1.0 S.G.

2.0 S.G.

1.5 S.G.

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Well Deviations

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Excape: Technical Operating Efficiencies

Marathon Total Industry Horizontal

Modules Attempted to Install 501 modules 1001 modules 329 modulesModules Actually Installed 501 modules 984 modules 312 modulesModule Installation Success Statistics 100.0% 98.3% 94.8%

Modules Attempted to Fire 493 modules 946 modules 303 modules

Modules Successfully Fired 491 modules 923 modules 290 modules

Firing Success Statistics 99.6% 97.6% 95.7%

Successful Well Installation Count 44 wells 96 wells 32 wellsReview Date 10/4/2008

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Recent Marathon Horizontal WellDepth: 17,300 feet (5,300 meters)

• Cost Reduction

• Safety

4,374,500$

3,994,200$

380,300$

*note: extra tim e for drilling rig during com pletion is included

Conventional Completion Costs

Excape Completion Costs

Estimated Savings

Cana 1-15H Woodford Shale Well

MAN DAYS 205 man days MAN DAYS 321 man daysMan Hrs. 4,908 man hours Man Hrs. 7,692 man days

8 man days 51 man days192 man hours 1,224 man hours

2,784 man hoursPersonnel Exposure Reduction 36%

1,032 man hours84%

Man Hr. Reduction for Completion

High Risk Man Days

High Risk Personnel Exposure Reduction

Conventional - Cana 1-15H Well COMPLETION PhaseExcape - Cana 1-15 H Well COMPLETION Phase

High risk Man HoursHigh Risk Man DaysHigh risk Man Hours

High risk Man Hr. Reduction for Completion

Believed to be world’s first totally intervention-less completion

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ConclusionConclusion

This Technology is reliable, and has safety and This Technology is reliable, and has safety and environmental benefitsenvironmental benefits

(~50% reduction in man hours, less exposure)(~50% reduction in man hours, less exposure)

It has led to development of competing multiIt has led to development of competing multi--zone zone stimulation techniques, which is beneficial to industry stimulation techniques, which is beneficial to industry

as a whole. as a whole.

The amount of gas which can avoid being vented is The amount of gas which can avoid being vented is very significant.very significant.

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ThermaCAM GasFindIR Camera

• The hand-held infrared (IR) camera is a screening tool• Can detect emissions not visible to the naked eye• Provides actual images of the gas plume in real-time

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ThermaCAM GasFindIR Camera

• Can see natural gas & other volatiles:–Benzene–Butane–Ethane–Ethylbenzene–Ethylene–Heptane–Hexane–Isoprene–MEK–Methane

–Methanol–MIBK–Octane–Pentane–1-Pentane–Propane–Propylene–Toluene–Xylene

• Cannot detect H2S, CO2, CO, or NOx

• Cannot differentiate the gas components or quantify the emissions

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IR Survey: Total Gas Saved per Component per Year

5,164

1,515 1,364577 505

2 30 6 5 10-

1,000

2,0003,000

4,0005,000

6,0007,000

8,0009,000

10,000

Compressor Seal Tank Thief Hatch CompressorOther

CompressorValve

Other

Component Type

Tota

l Gas

Sav

ed p

er C

ompo

nent

(m

cf/y

ear)

Total Gas Saved per Component Total # of Leaks per Component Cumulative Gas Saved

Component Type Leaks:

•Valve (37)

•Tank Thief Hatch (30)

•Other (10)

•Compressor Other (6)

•Compressor Connector (2)

•Compressor Open Ended Line (2)

•Pressure Relief Valve (1)

•Compressor Pressure Relief Valve (1)

•Compressor Valve (5)

•Connection (4)

•Open Ended Line (3)

•Compressor Seal (2)

•Flange (2)

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Camera Video

• Video 1

• Video 2