• Under-balanced well bore cleanout and
production evaluation technology.
Presentation Overview
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Why This Technology is Required
How It Works
Applications
Benefits
Case Histories & Successes
Why is This Technology Required
• Under-pressured reservoirs
• Horizontal and extended reach well
designs
• Velocities in liners allow for solids
settling
• Hz section is not 100% utilized
• Liquid loading of shallow to medium
depth well bores
• Cleanout damage is becoming more
of a problem each and every day
Why This Technology is Required
• Alternative processes such as fluid
circulation, swabbing, gas cleanouts and
bailing or pump to surface technology
have limitations and can no longer be
generally applied.
– Adds pressure to formation (over-balanced)
– Does not work in Hz
– Costly to deploy
– Slow process ---› expensive
How it Works
• This systems utilizes two unique technologies to
revolutionize the well bore cleanout operations. Our
JetPak™ system utilizes FlatPak™ coiled tubing
technology as well as specifically engineered jet pump to
remove solids and liquids from well bores. The primary
function of this technology is to create a low pressure
environment in the well bore to pump the fluid and/or
solids to surface.
Venturi principle, applies to JetPak & JetVak
Power Fluid
Injection
Pressure
Velocity
Surface Returns
Pressure
Gas
Flow
Pump
Intake
Fluid
Returns
Pump Discharge
Velocity
Suction
Pressure
Formation
Fluid
Advancements in Jet Pump modeling
Jet Pump Performance
2100 m dual 1.5" FlatPak at 1,000 m TVD
JetPak™ Pump Efficiency Curve
40
BB:2 Prod. Rate (lpm)
Production Rate (lpm)
A:2 Prod. Rate (lpm)
A:3 Prod. Rate (lpm)
35
A+:2 Prod. Rate (lpm)
A+:3 Prod. Rate (lpm)
B:2 Prod. Rate (lpm)
30
B:3 Prod. Rate (lpm)
B:4 Prod. Rate (lpm)
25
20
15
10
5
0
0
1000
2000
3000
BHP (kPa)
4000
5000
6000
Applications
• Class I and II vertical, deviated, slant or
horizontal well bore cleanouts
• Produced or frac sand cleanouts
• Acid frac/stimulation cleanup
• Drilling fluid recovery
• Production testing/evaluation
Text Book “Cleanout Damage”
Typical Well Response
From Conventional
CT Cleanout:
Conventional
Cleanout
Event
Conventional
Cleanout
Damage
Conventional
Cleanout
Event
JetPak™ Cleanout Comparison
Benefits
• Production Testing - This is an
excellent system to evaluate wells that
are sub-pressured in nature and do not
flow. The subject well may be a
candidate for Artificial Lift or an
abandonment candidate. None the
less, the JetPak™ will remove the fluid
so accurate well data can be collected.
Vertical heavy oil (10 API) well production test
BH recorder data
Well is pumped off, pressure changes are from
moving the FlatPak and BH pump
TM
JetPak Cleanout Performance
BHA Pressure & Temperature Job Data:
Run To TD
1,000 kPa / 145 psi
Tool at Wellhead:
160 kPa / 23 psi
Tool at Wellhead:
135 kPa / 20 psi
Gas Column while RIH:
165 kPa / 24 psi
Run In Hole
On Bottom
Pull Out of Hole
TM
JetPak Cleanout Performance
BHA Pressure & Temperature Job Data:
∆P : 13 kPa (2 psi)
0.7 m3 in ½ Hour
Run In Hole
On Bottom
Pull Out of Hole
JetPak versus JetVak?
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JetPak system alternates between Jetting and vakking (shiftable while down
hole)
JetVak system facilitates simultaneous jetting and vakking operations, a
“clean as you go approach.
The FlatPak coiled tubing string is bonded and contains dual 1¼” or1½”
carbon steel coils.
The length of the string ranges from 900 to 3100 meters, and is deployed by
Technicoil’s rig 2006 based out of Red Deer, supported by Quantum.
Areas of Application
Lower Amaranth SW Manitoba
Viking
Manville and Colorado group
CHOPS Vertical & Hz Lloyd. Slave Lk. And Wabasca
Shaunovan, Bakken and Cardium
Banff
Dina
Quantum JetVak video final.wmv
Case Histories & Successes
Husky CHOPS Hz under pressure well cleanout with JetPak
•0.8m3 sand
•Up to 30% sand - avg. 6% through job
•3.5m3 of fluid
•740TVD
•1550MD
•114mm guide string in 137mm
liner
This well was 1yr old and did not produce,
unknown problem.
The well is now producing at 10m3/day
yielding Husky a daily cash flow of over
$3000.00
Case Histories & Successes
INDIVIDUAL PRODUCTION
AMOCO CESSFORD 14-15-24-13
100/14-15-024-13W4/02
Status: Pumping Gas
Field: CESSFORD (0206)
Pool: COMMINGLED POOL 002 (0800260)
10
100
1000
1000
100
1000
10000
10000
Data As Of: 2011-04 (AB)
From: 1989-04
To: 2011-04
1
10
100
100
JetVak cleanout Oct. 15 2010, 0.7M3 sand
2009
10
11
2012
Time (years)
Prd-Day Avg GAS
Cumulative GAS
Monthly Hours
Mcf/day
MMcf
hrs
Cum GAS
Cum OIL
Cum WTR
4,008,933.7
14,248.3
8,567.1
Mcf
Bbl
Bbl
Ratio: WTR/GAS
Bbl/MMcf
Field Operations
INDIVIDUAL PRODUCTION
NEXEN WESTHAZEL HZ 2A16-5-1D14-4-51-22
191/14-04-051-22W3/00 (2325)
Status: Active Oil Well
Field: LLOYDMINSTER HEAVY (1H)
Pool: WESTHAZEL G.P. (232510)
10
1
10
100
10
100
1000
100
1000
Data As Of: 2011-02 (SK)
From: 2004-08
To: 2011-02
1
0.1
1
Cleanout Dec.18&19, 5.2m3 of sand
2004
05
Prd-Day Avg OIL
Percent: WTR Cut
Monthly Hours
06
Bbl/day
%
hrs
07
08
Time (years)
Cum GAS
Cum OIL
Cum WTR
64,392.7
83,679.4
59,498.6
09
Mcf
Bbl
Bbl
10
11
2012
PennWest Denzil Hz CO, BH rec data
3.2m3 of 2350kg/m3 of fine
sand 21% of liner volume.
BHP increases as we move
into slotted liner
Shell Canada CSS perf. Liner CO, BH rec data
Solids bridges indicated on either side of
Low pressure zone. Mid point of lateral
We call this guy Bituman
CHOPS polymer flood CO
Case Histories & Successes
Husky Hz Viking under-pressure well cleanout with JetVak
•1.1m3 sand
•Up to 45% sand - avg. 2-3% through job
•685TVD, 2216m TD
•114 mm guide string ran to 1 jt. Above 114mm
multi-frac liner
•Pump TD @2008M -6000daN
At mid point of the Hz section, many bridges
were encountered. Frac gel, sand, oil with
gas was evident in the returns. High oil cuts
were observed while POOH on this well.
E&P Company
Husky Energy
Date
Well Location
surface
CT company
Well Location
Bottom Hole
name of individual
filling out report
Pressure Truck
press.
Pressure Truck
fluid rate
RIH #1
corrected or uncorrected
time
depth
Sand%
Oil %
Steve Winkler
88lpm
open frac port
tank level
884
0
982
0
1125
0.5
3
96.5
1200
0
8
92
1260
0.25
10
89.25
10:33
1315
0.5
25
74.5
10:45
1355
1.5
10
88.5
2
20
78
10:50
Technicoil
18.6Mpa
Water %
20
Sept. 03, 2010
comments or notes
80
minimal gas
2% frac jell
wax in returns
foamy with gas
big gas kick in returns
16
small amounts of gas
10:54
1400
3
20
77
11:20
1446
0.2
20
79.8
11:40
1504
0.75
3
12:07
1535
1
3
96
2% frac jell
oil is jelling when sun in the centrifuge
12:50
1561
5
1
94
"
sand bridge
12:55
1584
15
1
84
1% frac jell
sand bridge
1:12
1590
1
0
99
1% frac jell
1:15
1595
18
0
81
1% frac Jell
1:30
1617
1
0
98
1% frac Jell
1:55
1655
1
10
89
1% frac Jell
sand bridge
2:25
1708
1
9
90
sand bridge
increase in gas in returns gren frac fluid
2:50
1702
45
10
45
30
10
60
2:55
88lpm returns
quite gassy returns
62
3:00
1692
1.5
0
98.5
3:15
1716
2
18
80
3:38
1713
10
20
70
3:48
1756
2.5
12
85.5
4:30
1850
2.5
12
85.5
4:50
32
gas rate dropping 86lpm returns
trace of frac jell
sand bridge
trace of frac jell
from bridge at 1706
0.5
0
99.5
clear returns in cellar
5:30
1700
0.5
18
81.5
POOH
6:05
1280
0.25
20
79.75
POOH
6:30
1005
0.5
18
81.5
POOH
7:45
0
on surface blow coil dry rig out
1000
100
100
INDIVIDUAL PRODUCTION Status: Active Oil Well
HUSKY PLATO HZ 4B12-18-3A9-18-26-18
Field: KINDERSLEY/KERROBERT LIGH (2L)
191/09-18-026-18W3/00 (2273) Pool: VIKING (227337)
100
10
10
Data As Of: 2011-02 (SK)
From: 2009-11
To: 2011-02
10
1
1
Cleanout August. 25&26, 1.1m3 of sand
2009
10
11
Time (years)
Prd-Day Avg OIL
Percent: WTR Cut
Monthly Hours
Bbl/day
%
hrs
Cum GAS
6,662.1
Cum OIL
16,625.1
Cum WTR
931.5
Mcf
Bbl
Bbl
2012
Viking Elrose Hz cleanout
Well Information
Company:
Efficient Resource
Well Name: Elrose Hz
25-15 W3
Surface:
025-15W3
LSD
Bottom Hole:
025-15W3/0
Well Licence #: ????
Well Data
KB Elevation:
GL Elevation:
KB-CF:
PBTD:
TVD:
KOP:
45°:
90°:
Liner Top:
BHP
BHT
Liner Specs
626 mSL
622.1 mSL
3.5 m
2001.32 mKb
Size
ID
Landed At
Size
ID
Landed To
854 mKb
~5000+ kPa
~32 °C
Volume
114.3 mm
101.6 mm
1984 mKb
FlatPak Frictioned -4daN 1698 m
3
0.008107 m /m Liner volume
929
929
Jetvac
Nozzle Mixing tube size
Orfice Size
Jets size
# of Jets
Pump Rate/Pressure
Expected Return Rate
A+:3 venturie volume
0.069" orifice and jet volume
0.052"
Zone:
Viking
2 total pump rate
24 mPa pump pressure
115 Actual return rate
Gross return rate
Comments:
Net return rate
Prior to Quantum job client did a cleanout with jointed pipe, max depth pipe could RIH
was 1989.91 mKB, could not work pipe deeper, frictioning out
#1
1.2 M3
13.80%
8.78 m3
Tool Data
17 stages
Perfs:
sand volume
% of liner volume
Wax plugs in returns
Casing Specs
652 mKb
390 mKb
590.52 mKb
887 mKb
#17
Job Data
114.3 mm
101.6 mm
857 mKB
Radia Green EBL mechanical friction reducer was used on Quantum job
65 lpm
27 lpm
92 lpm
24 mPa
120 lpm
55 lpm
28 lpm
October 02 cleanout recorder data
October 03 cleanout recorder data
Re-stimulation candidate
Husky Lloydminster
•4.5m3 sand
•Up to 35% sand - avg. 7-8% through job
•660TVD, 1785m TD
•114 mm guide string ran 1jt into 139mm liner
•Pump TD @1530M -6000daN.
•10 year old well with production issues
•635 TVD 1635 TD
•114mm guide string landed into 139mm liner
•600 meters of drilling fluid encountered
•Well is on prod. with 40% increase in volume
INDIVIDUAL PRODUCTION
HUSKY 4B HZT MORGAN 4-9-52-4
100/04-09-052-04W4/00
Status: Pumping Crude Oil
Field: MORGAN (0619)
Pool: COMMINGLED POOL 001 (0800160)
10
1
10
100
10
100
1000
100
1000
Data As Of: 2011-04 (AB)
From: 1997-06
To: 2011-02
1
0.1
1
Cleanout Dec.18&19, 4.5m3 of sand
2007
08
09
10
Time (years)
Prd-Day Avg OIL
Percent: WTR Cut
Monthly Hours
Bbl/day
%
hrs
Cum GAS
Cum OIL
Cum WTR
171,597.9
237,484.1
56,468.7
Mcf
Bbl
Bbl
11
2012
CHOPS
With high viscosity
oils we are mixing a
water based polymer
called JetFlux into our
power fluid. The high
pressure jets blast the
heavy oil, the result is
a uniform non-viscous
water like return fluid.
The chemical has a
sand suspension
component to it add a
safety margin into the
operation. The mixing
rate is 75 l/m3 of
water.
INDIVIDUAL PRODUCTION
HUSKY HZ 106 SWIMMING 6-21-52-7
106/06-21-052-07W4/00
Status: Pumping Crude Oil
Field: SWIMMING (0888)
Pool: MCLAREN D (0268004)
100
10
100
1000
100
1000
Data As Of: 2011-04 (AB)
From: 2009-06
To: 2011-04
1
0.1
1
10
1
10
Cleanout Sept. 22&23, 2.0m3 of sand
2009
10
11
Time (years)
Prd-Day Avg OIL
Percent: WTR Cut
Monthly Hours
Bbl/day
%
hrs
Cum GAS
Cum OIL
Cum WTR
1,536.8
34,036.2
52,741.2
Mcf
Bbl
Bbl
2012
Alberta Research Counsel study on “tight Oil”
Moving Solids?
•Rule of thumb: Vertical well: 1 ft/s
Hz well: 3 ft/s
•Durand Equation (with Wasp correction for particle size)
Vt = F[2g(s-1)D]1/2 (dp/D)1/6
F, factor between 0.4 and 1.5
s = rsolid / rf luid
dp, Solids diameter, m
D, Pipe Diameter, m
Alberta Research Counsel study on “tight Oil”
6000
Gas
Oil
5000
4000
3000
2000
1000
45
65
55
75
60
85
0
100 mesh
40/70
20/40
Gas (mscfd) , Oil (bbld)
Production Rates through a 5/8" Perforation
Needed to Move Sand
7000
Production:
Production:
Gas (mscfd) , Oil (bbld)
Moving Solids?
Production Rates in 4" Hz Casing Needed
to Move Sand
7000
6500
6000
Gas
5800
Oil
4800
5000
4600
4100
4000
3500
3000
2000
1000
0
100 mesh
40/70
20/40
Questions Surrounding Horizontal Well designs
•
How long should the lateral section be in a
given formation?
•
Is drainage making it to the toe of the lateral?
•
Stimulation type, Ball frac vs. mono bore and
liner diameter choice
•
Optimize fracture size and type
•
What is the PBHP and inflow characteristics at
specific intervals or stages? How does this
correlate with frac type / volume and stip log.
•
Fluid and solids viscosity and velocity in the
lateral
Drainage Area
Conclusions
•In the mid 1990s, the SPE did a world wide study on the production
from Hz wells of all types. They found that, on average, 30% of the lateral
sections did not produce.
•Our findings reaffirms the out come of this study. During our tests the
majority of the Hz wells we have entered have offered the best production
from the mid point to the toe of the lateral section. Alternately the liner has
proof of non production since new, drilling fluid, drilling enzymes or the liner
entirely full of sand. We are running BH recorders on each and every
cleanout. This is another diagnosis tool we can use to identify issues or
potential upside.
•To make a horizontal well economically successful, it has to yield at
minimum 4 times what an offset vertical produces. Thus, we are still in our
infancy when it comes to completion and production of Hz wells.
•This information may help E&P companies design wells that will optimize
recovery of the given formation. Geology- Longer may not always be better.
Hz well information? How do we gather it?
High water cut
High oil cut $$
gas inflow
Commonly Asked Questions
• 400+ successful operations with, no safety incidents or stuck
pipe or plugged coil.
• Velocity on the return conduit of the FlatPak is 2m/sec. well
above hz sand settling velocity.
• Maximum amount of sand out of one well, 8.0m3 or 20,000
Kilograms
• Minimum tubing size the system can run through is 114mm
• Velocity string not required
• Clients, Husky, Shell, Devon, Statoil, Cenovus, Nexen,
PennWest, Paramount, ARC Res., Provident, CNRL,
Westfire, Harvest, Enerplus, Progress Energy, Fairborne,
Anderson, Suncor/Petro-Canada, Baytex Energy, Pengrowth,
LonePine Res.
Thank you for your time. I invite any questions.
Have a great day!
Presented by: Steven Winkler
Adding Value through Technology