9/22/2011

Cold Heavy Oil Production with Sand Workshop Calgary September 21, 2011

For More information



Visit The OTS (Oilfield Technical Society) Heavy Oil Science Center 

  

Lloydminster

Visit www.lloydminsterheavyoil.com References are on the CD Visit www.kirbyhayes.com

Recon CHOPS Workshop Calgary Sept 21, 2011

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

Kirby Hayes 

 

runs his own company, Kirby Hayes Incorporated (KHI), which represents several corporations offering services and productions primarily involved in heavy oil production extensive background in cased hole wireline has co-authored several technical papers, patent applications, conducted seminars, short courses, workshops and presentations on wide-ranging topics of interest to heavy oil producers

Recon CHOPS Workshop Calgary Sept 21, 2011

4

Recon CHOPS Workshop Calgary Sept 21, 2011

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





Integrated Production Services Recon Petrotechnologies Ltd. Wavefront Technology Solutions Inc.

 



Ace Oilfield Endurance Technologies Alberta Innovates Technology Futures

Recon CHOPS Workshop Calgary Sept 21, 2011

Thank you Presentation contributions:          

Ron Sawatzky, ARC Bob Mottram, Weatherford Rob Morgan, Harvest Murray Tluchak, Bonavista Ryan Rueve, Nexen Floyd Isley, CNRL Rick Walker, Devon Jerry Schoenroth, Husky Mike Kremer, Husky Cedric Gal, CAG Consulting

         

Dave Love John Newman Janelle Irwin Maurice Dusseault, U of W Ace Oilfeild Schlumberger G-Chem IPS Wavefront And others

Recon CHOPS Workshop Calgary Sept 21, 2011

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Outline       

 

CHOPS – an overview Perforating for heavy oil – the issues Break Alternate completions Interventions examples Lunch Next steps prior to thermal or solvent EOR processes Interesting log examples Discussion Recon CHOPS Workshop Calgary Sept 21, 2011

Cold Production “Other things being equal, the maximum recovery of oil from an unconsolidated sand is directly dependent upon the maximum recovery of the sand itself” William H. Kobbe, in Trans. A.I.M.E., Vol. LVI, pp. 799-830 February, 1917 (New York)

Recon CHOPS Workshop Calgary Sept 21, 2011

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How Big Is It?  

  

Canada & US consume ~ 20 MBOD ~ 2,600,000,000,000 barrels in place (heavy oil and oil sands) in Canada If we achieve 30% recovery… 100% of current consumption for 100 years So…  

why fight over Middle East Oil? production problems are being solved

Recon CHOPS Workshop Calgary Sept 21, 2011

SAGD

CSS CHOPS

Before 1990

Cost per Barrel ($)

Operating Costs

}

}

cold

+ steam

Recon CHOPS Workshop Calgary Sept 21, 2011

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Recovery Efficiency 60 50

20 10

SAGD

}

}

0

CSS

30

CHOPS

Before 1990

Recovery (%)

40

cold

+ steam

Recon CHOPS Workshop Calgary Sept 21, 2011

Could we get there? 1,200,000

Production (bopd)

1,000,000

800,000

600,000

400,000

200,000

0 Jan-70

Jan-75

Jan-80

Jan-85

Jan-90

Jan-95

Jan-00

Jan-05

Jan-10

Jan-15

Jan-20

Recon CHOPS Workshop Calgary Sept 21, 2011

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Technology is the Key 

What are the technologies? 

Thermal Processes 

steam, SAGD, electrical heating 



Chemical Processes 

solvent, upgrading 



full value chain enhancement

Displacement Processes 



need to manage energy equation

enhanced floods

water, polymer, chemical

Pink Smoke and Marbles???

Recon CHOPS Workshop Calgary Sept 21, 2011

35 Billion Barrel Resource The industry needs to improve recovery factors

6.5%

17.6%

2.1%

73.8% Cumulative Recovery

Remaining Recoverable

Remaining Resource

Incremental Technology Wedge

Slides courtesy of Rob Morgan, Harvest

Recon CHOPS Workshop Calgary Sept 21, 2011

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Heavy Oil & Bitumen Production Western Canadian Crude Oil Production Source

Production (bbl/day)

Oil Sands Mining

760,000

Oil Sands In Situ

330,000

Conventional Heavy

500,000

(Cold Production)

(230,000)

Conventional Light

500,000

TOTALS

2,190,000

Production statistics at December, 2006 Sources: Alberta Dept. of Energy, NEB

Recon CHOPS Workshop Calgary Sept 21, 2011

Deltaic Depositional Environment

The Mississippi Delta

A satellite photo of the Ganges Delta in India

Recon CHOPS Workshop Calgary Sept 21, 2011

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Exploration





   

In general exploration for CHOPS is easy in Lloydminster Best tool is offset mapping and production – high existing well density lends itself to good mapping 3D seismic is the norm Success rate is high (> 85%) Large regional sands are dependable and predictable Channels are a bit more tricky in terms of traps and water content – but big prizes

Recon CHOPS Workshop Calgary Sept 21, 2011

Heavy Oil Leases 

There are three basic configurations for a CHOPS well   

Vertical Slant Directional

Recon CHOPS Workshop Calgary Sept 21, 2011

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Cold Production Field Examples Producer

PanCanadian

Mobil

Suncor

Amoco

Texaco

Formation

Mannville

Mannville

Clearwater

Clearwater

Mannville

Field

Lindbergh, Frog Lake

Celtic

Burnt Lake

Elk Point

Frog Lake

80

87

70-80

10

5-11

11-15.2

10

1,200 to 3,000

40,000 (dead)

2,000 to 55,000

20,000 to 50,000

3.8

2.8-3.4

Oil Saturation (%) Gas/Oil Ratio (std m 3/m 3) Live Oil Viscosity (mPa s) Pressure (MPa)

3,000 to 10,000 4

3.3

3.3

Permeability (darcy)

1.5-2.5

0.5-4.0

2.0

API gravity

12-14

Net pay (m)

14

Porosity (%)

32



1.0-5.0

12

11

3-5

20

11-14

4-11

33

34

34

33

5 – 25 m3/day

Typical field oil production rates

Recon CHOPS Workshop Calgary Sept 21, 2011

Cold Production Lloydminster-Area Cold Production Blocks Block

Producing Well Count #

Oil Production (m3/day)

Avg Rate per Well (m3/day)

Lloyd

3,667

21,757

5.9

Lindbergh

1,322

8,348

6.3

Cold Lake

600

4,486

7.5

SW Sask

306

2,220

7.3

TOTALS

5,895

36,811

6.2

Production statistics at December, 2001

Recon CHOPS Workshop Calgary Sept 21, 2011

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Cold Production Oil Production Rate Estimates 100 5 m net pay 2,500 kPa draw down 7 in wellbore diameter 200 m far-field radius

with sand

Oil Rate (m3/day)

10 without sand

1 Effective Permeability 1 darcy

3 darcy

10 darcy

30 darcy

100 darcy

300 darcy

0.1

0.01 100

1,000

typical for cold production

10,000

100,000

Oil Viscosity (mPa.s)

Recon CHOPS Workshop Calgary Sept 21, 2011

CHOPS continued sand production at cuts 0.5%

depth ~ 400 - 600 m thickness ~ 2-7m









Development of high permeability channels – “wormholes” much greater reservoir access Large, local drawdowns at ends of channels high pressure gradients – gas exsolution Substantial increase in oil rates Successful commercial process Recon CHOPS Workshop Calgary Sept 21, 2011

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Example of a Wormhole on Surface

Recon CHOPS Workshop Calgary Sept 21, 2011

Far Field Reservoir Drainage

Andrew Squires and Earl Jensen

Recon CHOPS Workshop Calgary Sept 21, 2011

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Stimulating Sand Production 

Where does new failure occur?

Near well 

In reservoir 



at tip of wormhole network

enhances drainage

Near well 

Reservoir

at edge of cavity

neutral or negative impact on inflow

Recon CHOPS Workshop Calgary Sept 21, 2011

Completion Objectives 

To initiate sanding: Initial sand production history of a well affects its long term productivity

Recon CHOPS Workshop Calgary Sept 21, 2011

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Cold Production Field Oil Production Rates 25

Oil Rate (m3/day)

20 with sand

15

10 without sand

5

0 0

360

720

1,080

1,440

Production Time (days)

Recon CHOPS Workshop Calgary Sept 21, 2011

Field Behavior Typical Good Well 25

1.0 Field Oil Rates Field Water Rates Field Sand Rates

0.8

15

0.6

10

0.4

5

0.2

0 0

360

720

1,080

Sand Rate (m3/day)

Oil Rate (m3/day)

20

0.0 1,440

Production Time (days)

Recon CHOPS Workshop Calgary Sept 21, 2011

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25

Aggressive Sand Production

1.0 Field Oil Rates Field Water Rates Field Sand Rates

0.8

15

0.6

10

0.4

5

0.2

Sand Rate (m3/day)

Oil Rate (m3/day)

20

Foam Job for 6-33 Series1

100%

90%

0 0

360

720

1,080

80%

Series2

Series3

Series4

0.0 1,440

Production Time (days)

Achieved during a stable foam operation on a new complletion In 40 hours produced: 117m3 sand 222m3 oil 90m3 water

Percentage Recovered (%)

70%

60% 50%

40%

30%

20%

10%

0% 07/11/19 07/11/19 07/11/19 08/11/19 08/11/19 08/11/19 08/11/19 08/11/19 09/11/19 09/11/19 09/11/19 09/11/19 99 9:36 99 14:24 99 19:12 99 0:00 99 4:48 99 9:36 99 14:24 99 19:12 99 0:00 99 4:48 99 9:36 99 14:24

Recon CHOPS Workshop Calgary Sept 21, 2011

Stages of Development   

Sand Matrix Failure Wormhole Growth Sand and Fluid Transport matrix failure when: p

pc

inflow Imposed

wormholes partially filled with sand

p

wormholes filled with sand

Recon CHOPS Workshop Calgary Sept 21, 2011

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Sand and Fluid Transport  

Tip of wormhole network to well EITHER: Plug flow in filled wormholes 

high produced sand cut ~ 20-40%

Mobile Sand

Recon CHOPS Workshop Calgary Sept 21, 2011

Sand and Fluid Transport 

OR: Stratified flow in open wormholes 

low produced sand cut ~ 1-2% Flowing Oil

Mobile Sand

Immobile Sand

Recon CHOPS Workshop Calgary Sept 21, 2011

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Wormhole Growth

Recon CHOPS Workshop Calgary Sept 21, 2011

Wormhole Growth

Recon CHOPS Workshop Calgary Sept 21, 2011

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Field Predictions Dynamic Wormhole Growth

Recon CHOPS Workshop Calgary Sept 21, 2011

Wormhole Growth Wormhole Structure wormhole cast after removal

imprint left when cast was removed

loose sand 20 cm

10 cm

Tensile failure bands

Recon CHOPS Workshop Calgary Sept 21, 2011

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Wormhole Growth Wormhole Configuration

36 cm

Top Orifice Sand Pack

30 cm

Bottom Orifice

80 cm

Recon CHOPS Workshop Calgary Sept 21, 2011

Wormhole Growth Wormhole Configuration

24 cm Top Orifice Sand Pack

30 cm

Bottom Orifice

80 cm

Recon CHOPS Workshop Calgary Sept 21, 2011

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Wormhole Growth Wormhole Configuration

44 cm

Top Orifice Sand Pack

30 cm

Bottom Orifice

80 cm

Recon CHOPS Workshop Calgary Sept 21, 2011

Wormhole Growth



Critical Pressure Gradient 



expansion of gas bubbles

Growth Rate 



reduced by foamy oil

increases with pressure gradient

Diameter  

increases with drained region open (sand-free) area likely less than 10 cm in diameter

Recon CHOPS Workshop Calgary Sept 21, 2011

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Wormhole Growth



Interaction  

wormholes compete for drainage Darwinian behaviour some grow, some wither

Recon CHOPS Workshop Calgary Sept 21, 2011

Sand Matrix Failure



Formation Strength     

unconsolidated sand low cohesive strength 5 – 20 kPa fines content increases strength capillary pressure capillary cohesion high oil viscosity dynamic strengthening slight cementation substantial strength increase

Recon CHOPS Workshop Calgary Sept 21, 2011

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Field Implications









Operate wells at low enough pressure to allow continuing sand production Wormholes tend to grow first and predominantly in weakest sand and toward highest pressure gradient Wormholes don‟t necessarily grow from each perforation – dependant on sand strength Wormholes usually stable

Recon CHOPS Workshop Calgary Sept 21, 2011

44 Petrovera, Elk Point Battery

Recon CHOPS Workshop Calgary Sept 21, 2011

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Foamy Oil





Large numbers of persistent gas bubbles in oil Generated by depressurization of live heavy oils

Recon CHOPS Workshop Calgary Sept 21, 2011

Bubble Growth and Gas Transport Dynamic Partitioning Oil Phase Dissolved Gas

Small Bubbles

Immobile

Gas Phase

Large Bubbles

Connected Bubbles

Recon CHOPS Workshop Calgary Sept 21, 2011

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Bubble Growth and Gas Transport and/or expansion

Increasing time,

Microbubbles Small bubbles ( pore throat)

Flow with oil

Large bubbles ( pore throat)

Immobile

Interconnected bubble clusters

Free gas flow

Recon CHOPS Workshop Calgary Sept 21, 2011

Field Implications







Operate wells at low enough pressure to obtain rapid local gas exsolution Surprisingly high ultimate recoveries, due to high apparent critical gas saturations Large blasts of gas when growing wormhole network and growing zones of interconnected bubble clusters connect

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Conclusions Courtesy of Ron Sawatzky AITF 

Gas Production  



Oil Production 



dissolved gas likely only source of produced gas for 2 wells additional external gas source may exist in 2 wells (petrophysics indicates source present, flow path uncertain) reasonable rates can be maintained at fairly high producing GOR: i.e. ~ 10-20 initial GOR

Draw Down 

oil production rates and recovery enhanced by rapid draw down

Recon CHOPS Workshop Calgary Sept 21, 2011

When Cold Production Fails 

Well 



  



perforation plugging shale / coal failure collapse or blockage casing failure

Reservoir    



well bore sands off

Near well

wormholes plug, collapse, stop growing watering out gas breakthrough permeability reduction from fines, formation debris, wax precipitation and wasted solution gas

Important to understand for diagnosis

Recon CHOPS Workshop Calgary Sept 21, 2011

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Complex Flow  

Phases - gas, water, oil , sand and solids Variables     

Mobility Cuts - time Viscosity (oil) – time – depth Sources of water and gas in the drainage geometry Sources (gas) – free or solution?

Recon CHOPS Workshop Calgary Sept 21, 2011

Where Blockage Can Happen

Recon CHOPS Workshop Calgary Sept 21, 2011

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Debris Causing Blockage Material 

Formation       



Pyrite Shale Coal Chert Asphaltenes Waxes Complex sands, silts and clays



Other   



Drilling mud Cement Perf debris

Possible to remedy with workover/s

Will probably re-occur

Recon CHOPS Workshop Calgary Sept 21, 2011

Example of Debris

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Sand plugging, bridging and arching 

From gravel pack literature: 

Tendency for bridging = k Dsand grain/Dgravel



Capacity for unrestricted flow = k` Dperf/Dsand grain

Dr.Tariq Schlumberger 

Studies concluded ratios from 3:1 to 16:1 hole size to flowing solid size

Recon CHOPS Workshop Calgary Sept 21, 2011

Coal

Can Be a water source, check offsets

28

9/22/2011

Carbonate Example

Note SP and Pe response Recon CHOPS Workshop Calgary Sept 21, 2011

Recon CHOPS Workshop Calgary Sept 21, 2011

29

9/22/2011

Recon CHOPS Workshop Calgary Sept 21, 2011

Gamma Ray (GR)  

Can be useful to identify shale collapse Warning: GR is statistical… don‟t read too much into subtleties if the logs show different character - the borehole has changed (casing & cement)

Recon CHOPS Workshop Calgary Sept 21, 2011

30

9/22/2011

Compensated Neutron Log (CNL) Diagnostic Log Note GR and N Porosity Differences CNL Diagnostic Log Open Hole Log

Cased Hole Neutron Logs (CNL)  

Can be useful to identify coal shifts Warning: N is statistical… don‟t read too much into subtleties if the logs show different character - the borehole has changed (casing & cement)

Recon CHOPS Workshop Calgary Sept 21, 2011

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50/50 Deep Penetrator(DP) / Big Hole (BH) or eXtra Big Hole (XBH)  



 

Politically correct – why didn‟t you use …? How thick is the cement sheath? – use manufacturer‟s model to determine penetration through the sheath – usually the cement sheath is not that thick Can you shoot through drilling fluid loss damage? Increased volume of traumatized zone? Sacrifice of flow area

Recon CHOPS Workshop Calgary Sept 21, 2011

Traumatized zone DP vs. XBH

Damaged zone XBH DP

Recon CHOPS Workshop Calgary Sept 21, 2011

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A New (Better) Configuration Than 50/50 

26 Shots Per Meter (SPM) – 20 XBHs and 6 DPs 1/3 DP by 2/3 XBH 26spm Or  2:1 

  

Less sacrifice of flow area Consistent with production performance data New - suppliers need lead time

Recon CHOPS Workshop Calgary Sept 21, 2011

Penetration versus compressive strength Penetration increases Charge

Target Steel

Rock < + -1000 psi compressive strength

Unconsolidated sand

Jet dispersion increases - penetration decreases Recon CHOPS Workshop Calgary Sept 21, 2011

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Recon CHOPS Workshop Calgary Sept 21, 2011

Recon CHOPS Workshop Calgary Sept 21, 2011

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Recon CHOPS Workshop Calgary Sept 21, 2011

Recon CHOPS Workshop Calgary Sept 21, 2011

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Casing and Cement Issues 



Un-supported casing and cement is more likely to fail Do you perforate through collars?  

Not recommended for thermal operations Depends on how thick the zone is 

many don‟t

Recon CHOPS Workshop Calgary Sept 21, 2011

Current Trend Is Not To Shoot Through Collars Overburden

Probable casing failures

Completely failed region Do not perforate on the same horizontal plane in environments where this occurs

Recon CHOPS Workshop Calgary Sept 21, 2011

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Example of perforation damage to unsupported casing

Recon CHOPS Workshop Calgary Sept 21, 2011

Before

After

No severe damage from perforating

37

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Re-perforating Trends 

 

 

Not popular ‟70s Bob Hayes “ Do we need more holes or are we just shaking things up?” Early ‟80s +- 10% successful Mid ‟90s optimizations with PCPs – 90% successful 2000 – casing and cement damage!! 2005 – missed pay and stimulation

Recon CHOPS Workshop Calgary Sept 21, 2011

Perforating Debris 



Perforating debris from a 127mm 6 meter 26 spm DP / XBH gun Debris magnets are recommended

Recon CHOPS Workshop Calgary Sept 21, 2011

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Questions and Discussions

77

Extending Cold Production Applications 

Stepping out from core heavy oil region   



NW ~ sands weaker, oil more viscous SE ~ sands stronger, oil less viscous Kuwait, Alaska, Venezuela, Columbia, Albania, Argentina

Broader variation in reservoirs  

heavy oil sands are not uniform differences occur over many scales   

field to field pool to pool zone to zone 



interval to interval

well to well

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Heavy Oil Completions

Can we throw out the cookie cutters? Alternate cookie cutters (methods)

Methods specific to the reservoir

Recon CHOPS Workshop Calgary Sept 21, 2011

The cookie cutter: 

Perforate aggressively under balanced  





Tight phasing, big hole, high shot density Most of the zone

Rapidly clean out with Pump To Surface (PTS), bailer or put on production with a Progressive Cavity Pump (PCP) Produce aggressively with PCP with as low as possible fluid level

30% of CHOPS wells fail Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Shale Spalling  De-pressurized shale from large draw down causes tiny particulate shale debris Buffer Layer



Establish a buffer layer Recon CHOPS Workshop Calgary Sept 21, 2011

Minimize shale spalling 

Strategy for reducing risk  



identify a buffer layer below shale to be not perforated thickness of buffer layer may depend on thickness of zone maintain a conservative draw down and avoid well bore trauma

Recon CHOPS Workshop Calgary Sept 21, 2011

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Shale Collapse

Recon CHOPS Workshop Calgary Sept 21, 2011

Casing Failure and Shale Collapse

Stable pillars

Recon CHOPS Workshop Calgary Sept 21, 2011

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Casing Failure and Shale Collapse 

Strategy for reducing risk    

 

perforate balanced or slightly under balanced perforate less aggressively with no more than 120 ,180 or 0 phasing slowly increase pressure draw down until production is initiated produce at a constant draw down until risk of destabilizing near well region becomes small (i.e. wormhole network is growing away from well) stable pillars harder to establish and maintain in thicker zones and are easy to establish between laminations steady draw down propagates worm hole growth of the weakest sands

Recon CHOPS Workshop Calgary Sept 21, 2011

Laminate pay example

Shale

$400k in rubble workovers Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Laminate Pay Collapse

4.0 m perforations -104 shots

Recon CHOPS Workshop Calgary Sept 21, 2011

Laminate Pay Collapse Fragmentation

Extraneous water path

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Laminate Pay Collapse •17 SPM •0 degree phasing •Or just perforate the permeable lenses

Less density/number and fewer vertical planes less break up of shale laminations or alternate perforating means

Recon CHOPS Workshop Calgary Sept 21, 2011

Penetrators   

 

Mill a 25.4mm window in casing Drill a 25.4mm, 2 meter horizontal hole Tool is controlled and activated by changing circulation rates and presuures Minimizes cement and shale fragmentation Overcomes drilling and fluid loss damage

Recon CHOPS Workshop Calgary Sept 21, 2011

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Example #2

Penetrated 8 x 1” holes at 90 o

Recon CHOPS Workshop Calgary Sept 21, 2011

Example #2 Production

Well watered out Discontinuous shale?

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Penetrator conclusions 



Sustained production was achieved with a minimum of holes and flow area Proper clean up was achieved with chemicals and 24 -36 hour PTS operations

Recon CHOPS Workshop Calgary Sept 21, 2011

Cost Comparison Courtesy of Ryan Rueve, Nexen Pump to Surface (PTS) (with Tubing Conveyed Perforating (TCP) vs Perforating While Foaming (PWF) (TCP)     

PTS (4 days with Rig) Rig (38 hrs) $13,680 Consultant $3,000 PTS Tool $2,500 Pressure/Vac $1,500



   



Total PTS costs $20,680



PWF (3 days with Rig)  Patented Rig (29 hrs) $10,440 Consultant $2,250 Foam Unit $8,000 Pressure/Vac $2,200 Total PWF costs $22,890

 Extra cost to PWF is approx $2,200. This is saved by less workovers caused by sand in months after the completion.  Costs not included above are: perforating, tubing, rods, pump, etc. These items are the same in both scenarios.

Recon CHOPS Workshop Calgary Sept 21, 2011

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9/22/2011

Nexen Cactus Lake Field R28

R27W3 E

F

8

Located 130km South of Lloyd in SK Reservoir Properties 9

10

11

S

12

8

G

G

FI E

E U

A

S

T36

S U

G

G

5

4

E I

E J

D

E E S U E M

E

A

29

G E

S

E

E E

S

J E E E

S

E

E

E

S E

E

S

S E

E

E

S

E

UE

S

6

S

S

E

E

E

E

S D

E

E

E

J E

S

E

I

I

E

E

S

E

S

G

S

E

K J

E

E

S

E

E

E

E

E E E

S

E

S

E

E

E E

E

S

E

E

E

G

E

S

E

E

27

E

E S

S

E

E

I

E

S

E

S

E

E S

S

G

I

E

S

E

E

G

S

U E

32

31

E

G

A

E A

G

L G

A

E F

I

26

D E A

E

E

E

•Density @ 15ºC = 965kg/m3 E

5

S

E

T36

S

E

36

S

E

E

S

S

35

DD D E ED

S

S

25

29

30

G

K J

G

T35

G

•Viscosity @ 30ºC = 500cP E

S

S

E

E

E

A

K

E

I

K

I

E

G

E

•Porosity: 30-33% 22

A

U

23

24

K 20

19

E

S

E I

S

•Gravity: 16API E

E

S

E

E

E

I

21

E

JU

S

J

E

I

E

E

S

E

J

G

E

1

E

S

E

S

D E

E S

EE

S

E

20

G

SS

S

E S E

S

E

E

E 28

E

S

E S

S

E

A

34

G

E S

I

E

E

E

•~850 mKB (80m Sub Sea)

A

33

I

E

EUE

S

G

A

S E E

UI

E

E

E

E

E

E

E

E

S

2

G

A

T35

E

•Bakken/Basal Mannville

F

I

G

E

3

I

F

32

E

G

E

E

E

7

E

E

E

G

K

G

•Permability: 2,000-4,000 md

A

I A

G

U R28

R27W3 Map Software by IHS Energy

Recon CHOPS Workshop Calgary Sept 21, 2011

Sand Cut Comparison of PTS & PWF

30

Sand Cut (%)

25 20 15

PTS

10

PWF

5 0 D1 621

C927

D727

B733

A836

C531

D522

Recon CHOPS Workshop Calgary Sept 21, 2011

48

9/22/2011

Filtered data 3 vs 3 wells – first month Average Monthly Oil Production for Fields By Completion Nexen PWF Wells

Nexen PTS Wells

Offset Wells

900

Cumulative Monthly Oil Production (m 3)

800

700

600

500

400

300

200

100

0 0

5

10

15

20

25

30

Months Since Completion

Recon CHOPS Workshop Calgary Sept 21, 2011

31/09 PTS

Recon CHOPS Workshop Calgary Sept 21, 2011

49

9/22/2011

21/07 PWF

Recon CHOPS Workshop Calgary Sept 21, 2011

Economics of more aggressive completions: 



3 wells verses 3 wells for the 8 months after the first month The aggressive competed wells produced 4850 m3 more oil

Recon CHOPS Workshop Calgary Sept 21, 2011

50

9/22/2011

Observations From Data 

 



Take it with a grain of salt especially the filtered data Excellent period of production PWF wells are to the outside of the pool (good and bad) PTS well 3.1 meters of perforations did quite well

Recon CHOPS Workshop Calgary Sept 21, 2011

Perturbation 

Definition:  



Positive or negative pressure change Can be as minute as varying the hydrostatic head from reciprocating pumps OR As large as massive pressure changes from foaming and the use of propellants (i.e. 60 MPa)

Recon CHOPS Workshop Calgary Sept 21, 2011

51

9/22/2011

Pressure Perturbation Limits 

 

Dissipates rapidly as it propagates from the wellbore Viscosity prolongs pressure rise and fall time Friction losses occur along permeability channels

Recon CHOPS Workshop Calgary Sept 21, 2011

Drainage Geometry Conformance Average Daily CSE Sand Production / Well 25 Well Sample 0.35

0.3

0.25

m3

0.2

0.15

0.1

0.05

0

Why Do Continuous Sand Extraction (CSE) (CPTS) Pumps Produce More Sand ??? 1

2 Before

During

3 After

Recon CHOPS Workshop Calgary Sept 21, 2011

52

9/22/2011

CSE surge pump CSES

Canadian Patent 2,232,948

Recon CHOPS Workshop Calgary Sept 21, 2011

De-stabilizing sand bridges Negative well bore pressure perturbation

Overburden pressure

Perforation

or pore throat

Recon CHOPS Workshop Calgary Sept 21, 2011

53

9/22/2011

De-stabilizing sand bridges Positive well bore pressure perturbation

Overburden pressure

Perforation or pore throat

Recon CHOPS Workshop Calgary Sept 21, 2011

CSES

3 Mth Cumulative M3 of Oil

Comparison of 8 Wells Showing Production 3 Mths Before and 3 Mths after Tool Installation 3000 2500

2000 Includes 3 wells that were Shut In Prior to insertion Avg 4m3/d

1500 1000

500 0 1 Before

and

2 After

Recon CHOPS Workshop Calgary Sept 21, 2011

54

9/22/2011

Drainage Geometry Conformance Steady draw down worst case scenario

Lower pressure gradient laterally more stability

Greatest pressure gradient at tip

Steady pressure gradient

Intact formation

Drainage Geometry Conformance Intact formation

Fluctuating pressure gradient

Perturbed draw down

Intact formation

55

9/22/2011

Drainage Geometry Control  

Perturbations conforms drainage Steady draw down propagates worm hole growth of the weakest sands

Recon CHOPS Workshop Calgary Sept 21, 2011

Drainage Geometry Control 

Perturbations conforms drainage  

Perturbations dissipate rapidly Employ immediately after completion

Recon CHOPS Workshop Calgary Sept 21, 2011

56

9/22/2011

Continuous Sand Extraction with surge Tool (CSES) Applied on Completion – Drainage Geometry Conformance 

Advantages   



Needs to be applied upon completion 



Pumping equipment is capitalized The pumps can economically rebuilt in extreme sand cut environments The surge action enhances sand failure – conforming wormhole initiation and destabilises bridging Surge action only effects near well

Study in progress 3 new completions are being equipped with CSESs

Recon CHOPS Workshop Calgary Sept 21, 2011

Example of Downhole Pressure Perturbation With CSES

Recon CHOPS Workshop Calgary Sept 21, 2011

57

9/22/2011

35.00

30.00

Well 06D-20 Average production - 3.46m3/d

Pump Change

Completion PCP

Offset PCP example – 3.46m3/d average 100 90

80

60

20.00

50 15.00

40 30

10.00

20 5.00

BS&W (%) & Sand Cut (%)

70

Gross Fluid (m³/d)

Gross Oil (m³/d)

30-Jan-2011

1-Mar-2011

0

30-Dec-2010

30-Nov-2010

30-Oct-2010

10 -

30-Sep-2010

Production And Load Fluid (m³/d)

25.00

Net Oil (m³/d)

Recon CHOPS Workshop Calgary Sept 21, 2011

100 90 80

25.0

20.0

15.0

70 60 50 40 30

10.0

BSW (%) & Sand Cut (%)

Production And Load Fluid (m³/d)

Pump Change CSES

30.0

Pump Change PCP

CTU

35.0

CTU CTU

Completion

CSES Applied on Completion – 7.33m3/d average 20% sand cut Well 10B-20

20

5.0

Gross Fluid (m³/d)

Gross Oil (m³/d)

0 1-Mar-2011

30-Jan-2011

30-Dec-2010

30-Nov-2010

30-Oct-2010

-

30-Sep-2010

10

Net Oil (m³/d)

Recon CHOPS Workshop Calgary Sept 21, 2011

58

9/22/2011

CSES Applied on Completion - 6.74m3/d avg 66 % sand cut

35.00 30.00

100

80

25.00

60

20.00

BS&W (%)

Production And Load Fluid (m³/d)

40.00

120 Pump Service

Completion Pump Change CTUCTU Pump Change

45.00

Pump Change CSES

Pump Change - Temp PTS

Well 11B-20 50.00

40

15.00 10.00

20

Net Oil (m³/d)

0 1-Mar-2011

30-Jan-2011

30-Dec-2010

Gross Oil (m³/d)

30-Nov-2010

30-Oct-2010

Gross Fluid (m³/d)

30-Sep-2010

31-Aug-2010

31-Jul-2010

1-Jul-2010

-

31-May-2010

5.00

Recon CHOPS Workshop Calgary Sept 21, 2011

Questions and Discussion Recon CHOPS Workshop Calgary Sept 21, 2011

59

9/22/2011

Pump Problems?

Bridging in the Annulus Bridging in tubing

Plugged off inflow

Plug off at intake

Recon CHOPS Workshop Calgary Sept 21, 2011

Possible Solutions: 

Bridging in annulus    





Loading and continuous loading Reciprocating tubing pumps Coil tubing the annulus Others?

   

Plug off at intake     

            

Loading and continuous loading Flush by Scope flush by Scope foam head Service rig – circulate down, sand line bail , tubing bail or foam clean out Charge/booster pump Extended rotors Paddle rotors BHP landing Depth Gizmo’s Tail joints Perforated joints Perforated tag bars Hollow rods Hollow rotors Multi intake PCPs CSE – ETU through THIGK valves Others?

Bridging in tubing

  



Smaller ID tubing Sand suspension chemicals Loading and continuous loading Flush by Coil tubing clean out Downhole gas separators Others?

Inflow Blockage              

Loading Chemicals Stable foam stimulation Scope foam head Re-perforating Circulating Perforation wash Bailing / swabbing Sebree tool Propellant stimulation Abrasi-Jet, Penetrators Reciprocating tubing pumps CSES Others?

60

9/22/2011

Decline Rates for Diagnostics 

Catastrophic  





Mechanical Shale collapse Near well bridging

Gradual  



Loss of foamy oil drive Flow impairment from load fluid Formation bridging

A week to months

Hours to a week

Recon CHOPS Workshop Calgary Sept 21, 2011

Approaches to Cold Heavy Oil Production: Workover Practices and Strategies March 15th, 2000 Tropical Inn – Lloydminster AB

M. Dusseault, K. Hayes, M. Kremer, C. Wallin

Recon CHOPS Calgary Sept 21, 2011

61

9/22/2011

The Tools Reviewed in the Workshop    

   

  

Loading Continuous loading Circulating Flushes and superflushes Swabbing Sand line bailers Tubing bailers Select perf washes and perf cleaning Coil tubing and CTU flushes Pump to surface Portable PTS

   



   

Continuous PTS Re-perf Chemical treatments Propellant stimulation Stable foam clean outs (tubing) and stimulations Coil tubing foam clean outs Abrazi jet Proppant/Hydraulic fracturing Pressure pulsing

Recon CHOPS Workshop Calgary Sept 21, 2011

Stuff Not Reviewed in the Workshop         

Mechanical remedies list Sebree tool Scope tool CTU/ flush units Gas management Sand management CSE with surge tools Balls checks for PTS Others?



Completion strategies   





Shale strategies PAPWF Delayed water encroachment

Combined and staged approach Others?

Recon CHOPS Workshop Calgary Sept 21, 2011

62

9/22/2011

Staged Approach 

Minimize risk       

Diagnose, confirm, determine the extent of the problem Treat and evaluate treatment Re-treat or attempt a different treatment Evaluate Produce with a different production strategy Abort when necessary Example: Severe Inflow Blockage Program (SIBP) 

A work in progress

Recon CHOPS Workshop Calgary Sept 21, 2011

Post Workover Production Strategies  

   

Change production rates Change pumping fluid level and/or annular gas pressure Change pumping equipment Start or modify load program And so on, and so on … Congruent with workover strategy

Recon CHOPS Workshop Calgary Sept 21, 2011

63

9/22/2011

The Pitfalls: 

       

Cookie cutters and magic pills  Without proper diagnosis, too frequently  Flush Production Flavor of the week and trends The lure of the latest and greatest Successes – misplaced credit Too rapid or slow application – tracking Complacency Changing too many variables Lowered one servicing cost but increasing another Wrong diagnosis – wrong conclusion (that doesn‟t work)

Recon CHOPS Workshop Calgary Sept 21, 2011

The 80/20 Rule 



Spending 80% of the time working on 20% of the production Can we make good wells better?

Recon CHOPS Workshop Calgary Sept 21, 2011

64

9/22/2011

Canadian Patent 2,232,948

Recon CHOPS Workshop Calgary Sept 21, 2011

Dilation/failure by pressure Positive well bore pressure perturbation

Intact formation

Recon CHOPS Workshop Calgary Sept 21, 2011

65

9/22/2011

Dilation/failure by pressure Overburden pressure

Negative well bore pressure perturbation

Intact formation

Recon CHOPS Workshop Calgary Sept 21, 2011

Negative Perturbations Naturally More Conformed

Energy is virgin reservoir pressure More and stronger perturbations are better Recon CHOPS Workshop Calgary Sept 21, 2011

66

9/22/2011

Live Oil Viscosity 60,000

Viscosity (mPa.s)

50,000

40,000

30,000

20,000

10,000

0 0

1,000

2,000

3,000

4,000

5,000

6,000

Pressure (kPa g)

Recon CHOPS Workshop Calgary Sept 21, 2011

Loss of Solution Gas     

Reservoir heterogeneity Asymmetric drainage geometry from wormhole growth Blockages caused by formation debris Water and/or gas breakthrough Casing venting during production interruption or production suspension

While producing the more mobile portions of the reservoir, the less mobile become more so

Recon CHOPS Workshop Calgary Sept 21, 2011

67

9/22/2011

Near Well Bore Blockage Weakest sand

Viscosity increases

Oil and sand production

Ex-solving gas

Ex-solving gas

Recon CHOPS Workshop Calgary Sept 21, 2011

Near Well Bore Blockage

Depleted Zone

Treatment Path of Least Resistance and Fluid That Is NOT Where the Problem Is

SCHMAG Dead Oil Recon CHOPS Workshop Calgary Sept 21, 2011

68

9/22/2011

SIBP Example – 11-23   







Mid Oct „05 executed SIBP Cutter stock was pulsed to treat SCHMAG Fluid level rose Foam circulation and surging produced debris and oil operation continued for 3 days Installed CSES to de-stabilize debris and sand bridges Producing 9 m3/d with 16 joints of fluid

Recon CHOPS Workshop Calgary Sept 21, 2011

Diagnostic Logs for 11-23 OH GR

Diagnostic GR

Recon CHOPS Workshop Calgary Sept 21, 2011

69

9/22/2011

Production Data for 11-23

Recon CHOPS Workshop Calgary Sept 21, 2011

Production Data for 11-23

20

Post CSES Oil Production Rate (m3/d)

16

12

8

4

0 0

1

2

3

4

5

Production Time (months)

Recon CHOPS Workshop Calgary Sept 21, 2011

70

9/22/2011

Another Staged Intervention C1-18 



Chemicals were placed by a perf wash tool to treat SCHMAG and left 7 days to soak Sebree tool and bailing were used to remove debris from the well bore and near well area over a 2 day period

Recon CHOPS Workshop Calgary Sept 21, 2011

Incremental Production for C1-18 During Intervention 25

Equivalent Calendar Day Production Rate 32.8 m3/d

Cum Oil Production (m3)

20

15

10

5

0 0

3

6

9

12

15

Production Time (hours)

Recon CHOPS Workshop Calgary Sept 21, 2011

71

9/22/2011

Production Data for C1-18 10

Oil Production Rate (m3/d)

8

Staged Intervention 6

4

2

0 0

6

12

18

24

30

Production Time (months)

Recon CHOPS Workshop Calgary Sept 21, 2011

Questions and Discussions

144

72

9/22/2011

Chemical and/or fluid stimulation 

Should be done with pressure perturbations    



Enhances formation access Adds energy to the reaction Dislodges blockage mechanisms Initiates particulate movement

Volumes should be relative to produced sand

Recon CHOPS Workshop Calgary Sept 21, 2011

Odyssey Tool

Recon CHOPS Workshop Calgary Sept 21, 2011

73

9/22/2011

Conventional Perf Wash Tool

Recon CHOPS Workshop Calgary Sept 21, 2011

148

Perf wash

Recon CHOPS Workshop Calgary Sept 21, 2011

74

9/22/2011

149

Perf wash

Recon CHOPS Workshop Calgary Sept 21, 2011

Just load chemical

Recon CHOPS Workshop Calgary Sept 21, 2011

75

9/22/2011

Chemical placed with positive perturbations

Recon CHOPS Workshop Calgary Sept 21, 2011

A Successful Odyssey Tool Job 13C-12-57-2: Production Rate of Oil/Water (m3) Versus Weeks from Before & After Usage of Pulsating Pulse Powerwave Tool 8

Pre-Powerwave Oil & Water Production Trends

7

Sparky Formation Zone

Stimulation Intervention (Approx. @ Week 6)

Production of Oil/Water (m3)

6

5

4 Post Powerwave Oil & Water Production Trends

3

2

1

0 0

5

10

15

20

25

30

# of Weeks (April 1/2010 - October 1/2010) Avg. Measured Oil (m3)

Avg. Measured Water (m3)

Linear (Avg. Measured Oil (m3))

Linear (Avg. Measured Water (m3))

Recon CHOPS Workshop Calgary Sept 21, 2011

76

9/22/2011

A successful perf wash Tool Job 9C-24-53-6: Production Rate of Oil/Water (m3) Versus Weeks from Before & After Perf Wash 25 Sparky Formation Zone Cum Oil After Intervention: 1179.01 m3 Cum Water After Intervention: 867.28 m3

Production of Oil/Water (m3)

20

Stimulation Intervention (Approx. @ Week 2)

15

10

5

0 0

1

2

3

4

5

6

7

8

9

# of Weeks (Aug 1/2010 - November30/2010) Avg.Measured Oil

Avg.Measured Water

Linear (Avg.Measured Water)

Linear (Avg.Measured Oil)

Recon CHOPS Workshop Calgary Sept 21, 2011

Odyssey Pulse Tool vs Perf Wash Tool Study 

Definitions :  



Technical success: Sustained production for 3 months or the limit of the data of at least half of prior peek production Pay out success: Can not be an economic success if not a technical success and has sustained production for 3 months or the limit of the data of 1.5m3/d Profitable success: Same as above but with sustained production of 5m3/d

Recon CHOPS Workshop Calgary Sept 21, 2011

77

9/22/2011

Odyssey Pulse Tool vs Perf Wash Tool Study 

All wells were relatively new (i.e. weeks to 2 months)

Recon CHOPS Workshop Calgary Sept 21, 2011

Odyssey Pulse Tool vs Perf Wash Tool Study Technical Perf wash 1 2 3 4 5 6 7 8 9 10 11 12 13 14 TTl

Fail

Payout

1 1 1

1 1 1 1 1

1 1 1

Fail Profitable

1 1 1 1 1 1 1 1 1 1 1

1 1 1 1

1

1 1 1 1

1 1

1 1

1

Fail

1

1 5

9

3

1 1 11

36%

64%

21%

79%

1

1 1 13

7%

93%

Recon CHOPS Workshop Calgary Sept 21, 2011

78

9/22/2011

Odyssey Pulse Tool vs Perf Wash Tool Study Odyssey Technical Fail 1 1 2 3 1 4 1 5 1 6 1 7 8 1 9 1 10 1 11 1 12 1 13 1 14 1 15 1 16 1 TTl 14

Payout

Fail

Profitable Fail 1 1 1

1

1 1 1

1

1 1

1 1 1 1 1

1 1

1 1 1 1 1 1 1 1

2

1 1 1

1 1 7

9

1 1 1 1 12

4

88% 13% 56% 44% 25% 75%

Recon CHOPS Workshop Calgary Sept 21, 2011

Odyssey Pulse Tool Different Well Set – older wells – public data Old wells Technical Fail 1 2 1 3 4 1 5 6 7 8 1 9 10 1 11 12 13 TTl 4 % 31%

Payout

Fail

1

Profitable Fail 1

1 1

1 1

1 1

1 1 1

1 1

1 1 1 1

1

1 1 1 1

1 1

1 1 1 9 69%

4 31%

1 1 1 9 69%

3 23%

1 1 1 1 1 10 77%

Recon CHOPS Workshop Calgary Sept 21, 2011

79

9/22/2011

Latest Study - ? 



Started with Severe Inflow Blockage Program and Inflow and Production Impairments from Loss of Solution Gas in Cold Production - Sawatzky and Hayes Chemical pill and chase fluid volume is relative to the produced sand (i.e. 20%) 

 



Combined intervention using Odyssey tool for chemical placement and Sebree swab tool to re-establish solution gas drive. 2 wells done to date. The first has 2 weeks of 9.3m/d production with 38.5% BS&W with 13 joint fluid level to chase. The second well operations were suspended due to extremely high sand cuts – a foam clean out is planned. 6+ jobs are in the works

Recon CHOPS Workshop Calgary Sept 21, 2011

Loss of Solution Gas      

Reservoir heterogeneity Asymmetric drainage geometry from wormhole growth Blockages caused by formation debris Water and/or gas breakthrough Casing venting during production interruption or production suspension Under balance events during drilling and/or completions

While producing the more mobile portions of the reservoir, the less mobile become more so

Recon CHOPS Workshop Calgary Sept 21, 2011

80

9/22/2011

Sebree Swab Stimulation on a Disposal Well   

In 9hrs recovered 158m3 of water and 25m3 of sand Prior injection was less than 300m3/d and inadequate Currently the well is taking 400m/d on vacuum

Recon CHOPS Workshop Calgary Sept 21, 2011

Sebree Swab Tool Current Initiative 

Rigless Completions:  



Manage completion and construction costs on new drills To ensure inflow is established from problems such as low pressure, drilling damage and reluctant gas break out. To enhance gas break out and conform sand failure; optimizing drainage geometry

Recon CHOPS Workshop Calgary Sept 21, 2011

81

9/22/2011

200

150

100

50

Pattern 1 Oil Rate

Pattern 2 Oil Rate

Pattern 3 Oil Rate

2.6 %/mo Harm. Decl.

Decline Match Points

Pattern 1 Powerwave

Pattern 2 Powerwave

Pattern 3 Powerwave

01/11/08

01/10/08

01/09/08

01/08/08

01/07/08

01/06/08

01/05/08

01/04/08

01/03/08

01/02/08

01/01/08

01/12/07

01/11/07

01/10/07

01/09/07

01/08/07

01/07/07

01/06/07

01/05/07

01/04/07

01/03/07

01/02/07

01/01/07

01/12/06

0 01/11/06

Oil Rate (bopd) - 3 Powerwave Patterns

250

Case History – Alberta Pressure Pulsed Water Flooding

Recon CHOPS Workshop Calgary Sept 21, 2011

Pulsed Polymer Flooding       

Conventional water flooding is expanding to more viscous reservoirs Pressure pulsed water flooding currently deployed in 500 – 1000cps reservoirs CNRL‟s polymer flooding experience is economically successful up to 10,0000cps or greater Pulsed polymer flooding will be able to increase flooding applications to - ? Its possible to implement pulsed polymer flooding very soon Pulsed polymer flooding is the least riskiest EOR option Imagine pressure supported production in the CHOPS region Recon CHOPS Workshop Calgary Sept 21, 2011

82

9/22/2011

Enormous Drainage Geometries

after Andrew Squires and Earl Jensen

Recon CHOPS Workshop Calgary Sept 21, 2011

.

Recon CHOPS Workshop Calgary Sept 21, 2011

83

9/22/2011

Recon CHOPS Workshop Calgary Sept 21, 2011

Dual induction and SFL curve example

84

9/22/2011

Recon CHOPS Workshop Calgary Sept 21, 2011

Potential Water Sources in Oil and Gas Wells

“Extraneous” Water Seal

Gas Cap

Oil

Wormhole Formation Water

Seal

“Extraneous” Water

Recon CHOPS Workshop Calgary Sept 21, 2011

85

9/22/2011

Production Water Origin and Isotopic Changes with Time/ Source 0

100%

Progressive incursion of water from non-producing zone (formation "B") results in intermediate compositions.

-20

Mass-Balance equations may determine how much of each water source is being produced.

-40 Formation "B" Water cut may or may not increase.

-60 % Water Cut

-80

Water Incursion (Behind Pipe)

Initial Production Water Composition (Sw)

-100 Formation "A" Water Coning Trend

0%

-120 0

2

4

6

8

10

12

14

16

Time Recon CHOPS Workshop Calgary Sept 21, 2011

Recon CHOPS Workshop Calgary Sept 21, 2011

86

9/22/2011

HDD Examples 133 Samples Per Meter (SPM)





Demonstrates value for picking intervals to avoid shale damage Demonstrates the potential for exploiting oil over water where vertical permeability impairments exist – current works in progress Ex 4

Recon CHOPS Workshop Calgary Sept 21, 2011

Ex. 1 Mini Plot

Perfs 535 -538 Of interest 547 -550 vertical permeability impairment may stop bottom water?

87

9/22/2011

Ex. 1

Perforated interval

Ex. 1

Permeability impairment

88

9/22/2011

Ex. 3 Mini Plot

Perfs 525 – 527.5 Of interest 534 -535 vertical permeability impairment may stop bottom water?

Ex. 3

Perforated interval

89

9/22/2011

EX 4

EX 4

Proposed perfs

Permeability impairments

Recon CHOPS Workshop Calgary Sept 21, 2011

90

9/22/2011

HDD Example 5 



Demonstrates value for picking gas interval permeability 442.3 – 442.5 over possible water ??? Demonstrates thin zone between carbonate lenses at 447.2 – 447.7

Recon CHOPS Workshop Calgary Sept 21, 2011

Ex 5

91

9/22/2011

Ex 5

Proposed perfs

Proposed perfs

Recon CHOPS Workshop Calgary Sept 21, 2011

High Resolution Example   



Schlumberger high definition log Demonstrates laminate cap rock Example well had severe inflow blockage (see pictures from intervention) Perforations 446.0 to 452.0

Recon CHOPS Workshop Calgary Sept 21, 2011

92

9/22/2011

Normal Resolution

Recon CHOPS Workshop Calgary Sept 21, 2011

High Resolution

Recon CHOPS Workshop Calgary Sept 21, 2011

93

9/22/2011

Recon CHOPS Workshop Calgary Sept 21, 2011

A Completion Example Proposed 8 meters of perforations

Recon CHOPS Workshop Calgary Sept 21, 2011

94

9/22/2011

A Completion Example High Definition Data (HDD) Log Suggested 3.4 meters of perforations Only shot 1.8 meters too much sand inflow rigless operation Well produced about 15m3/d

Recon CHOPS Workshop Calgary Sept 21, 2011

Top Water Example of Extreme Density Oil

Recon CHOPS Workshop Calgary Sept 21, 2011

95

9/22/2011

Questions and Discussions

Recon CHOPS Workshop Calgary Sept 21, 2011

96