completion, workover and salt tables
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Completion, Workover Fluids and Salt Tables
I. Drill-In Applications
Prior to entering the productive interval, the conventional
drilling fluid (mud) is replaced with a secondary, “Drill-In”
fluid.
The purpose of the “Drill-In” fluid is to promote the drilling
process, while minimizing the potential for formation damage.
II. Completions
The “Completion Fluid” is used to control wellbore pressures
during operations subsequent to drilling.
III. Workover (WO)
Used during later remedial operations
The objectives vary from pressure control to solids removal.
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Completion, Workovers Fluids and Salt Tables
Objectives
a) Solids Free Brines
1) Control wellbore pressures
2) Remove cuttings or other debris
3) Protect production capacity
b)Polymer
1) Remove cuttings or other debris
2) Restrict fluid loss
3) Reduce friction pressures
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Wellbore Pressure Control
The completion, workover fluid and salt tables are used to
balance the pressures inside the wellbore with that in the
reservoir.
pH = [0.0519] x D
where:
pH = Hydrostatic Head, psi/ft
D = Brine Density, lbs/gal
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Mixing the HE® Polymers
in The Lighter Brines
Dry Powders: Dissolution is rapid
Proper dispersion of the polymers requires
shear conditions similar to that used for other
polymers (eg., Drispac, Flowzan, etc) in order
to avoid lumping.
Emulsion Polymers: Getting the polymer into solution requires
inverting the emulsion. Under low shear
conditions, this can pose problems.
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HE® Polymer Emulsions
These are oil-outside phase emulsions, having droplets (micells) of
water and polymer dispersed through a continuous phase of oil.
Building viscosity in brine requires inverting the emulsion, putting
the water into the outside phase and allowing dispersion of the
polymer into solution.
Oil
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HE® Polymer Emulsions
Under low shear mixing conditions in light brine, incomplete
inversion may occur, resulting in;
a) Lower than expected fluid viscosity.
b) Soft, white mass of partially hydrated polymer separating to
the fluid surface.
Solution:
a) Increase the amount of shear
b) Add a surfactant
c) Add the polymer to fresh water, before adding the salt.
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HE®
Polymer Emulsions
Inversion
Shear Brine
Composition
Surfactant
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Mixing the HE® Polymers
In The Heavier Brines
Dry Powders: Dispersion is rapid and easy
Dissolution is slow, and may require:
Advanced Formulating
Heating
Emulsion Polymers: Tends to invert easier in the heavy brines thanin the less dense fluids. That is, the emulsion
is less stable in the more concentrated salt
solutions.
Shear
Surfactant
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Dissolution
In the process of “dissolving”, the smaller unit (ion or
Polymer strand) is extracted from the larger crystal or
granule by “free” water
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Hydration
In dissolving, each and every ion takes on one or more layers
of water. This “water of hydration” allows separation of the
ions.
In the more concentrated brine systems, much of theavailable water is used simply in this manner.
As the concentration of dissolved salts increases,
progressively less water is available for hydrating the
polymers.
Ca++
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Water Content in Various Brines
20%
30%
40%
50%
60%
70%
80%
90%
100%
110%
8 10 12 14 16
Brines Density, ppg
W a t e r C o n t e n t , W
t %
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3% KCl + HE® Polymers
concentration, lb/BBl = 1 2 3 4 5 6
HE®100 Powder PV = 6 11 14 19 - 35
YP = 2 6 11 19 - 43
HE®100 Emulsion PV = 7 12 16 21 30 -
YP = 1 8 19 31 35 -
HE®100 Powder PV = 5 8 12 17 29 37
YP = 0 2 3 11 17 23
HE®100 Emulsion PV = 5 8 15 21 33 38
YP = 0 7 16 28 42 69
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10 ppg NaCl + Polymer
concentration, lb/BBl = 1 2 3 4 5 6 7
HE®100 Powder PV = 8 13 21 28 35 40 -
YP = 1 4 4 10 21 29 -
HE®100 Emulsion PV = 8 13 18 25 32 38 41
YP = 2 6 13 19 28 43 61
HE®100 Powder PV = 6 9 12 16 20 25 40
YP = -1 1 2 3 6 8 10
HE®100 Emulsion PV = 6 9 14 19 25 34 37
YP = 0 2 6 13 21 34 36
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10.7# CaCl2 + Polymer
concentration, lb/BBl = 1 2 3 4 5 6 7
HE®100 Powder PV = 9 14 20 28 39 48 54
YP = 0 2 7 11 15 24 42
HE®100 Emulsion PV = 10 14 21 25 38 47 56
YP = -1 2 5 13 15 26 41
HE®100 Powder PV = 7 10 14 17 22 27 34
YP = 1 2 2 4 7 10 12
HE®100 Emulsion PV = 7 10 15 22 29 39 46
YP = 1 3 6 11 20 28 47
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11.5 ppg NaBr + Polymer
concentration, lb/BBl = 1 2 3 4 5 6 7
HE®100 Powder PV = 6 9 13 16 21 27 45
YP = 0 2 4 9 15 22 30
HE®100 Emulsion PV = - 12 15 19 24 31 36
YP = - 3 9 16 23 28 43
HE®100 Powder PV = 5 7 10 14 18 23 30
YP = 0 1 2 4 9 14 19
HE®100 Emulsion PV = 5 8 11 17 25 32 36YP = 0 1 6 12 15 25 37
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7 lb/BBl HE®300 (Dry) in CaCl2
Brine Density = 10.6 10.8 11.0 11.2 11.4 11.6
PV = 40 45 73 75 95 80
YP = 30 17 19 25 21 30
7 lb/BBl HE® 300 in CaCl2
0
10
20
30
40
50
60
70
80
90
100
Brine Density, ppg
P l a s t i c V i s
c o s i t
10.6 11.611.411.211.010.8
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13.0 ppg CaBr Brine
concentration, lb/BBl = 1 2 3 4 5 6 7
HE®100 Powder PV = 15 22 23 60 141 - -
YP = 0 1 12 -3 -6 - -
HE®100 Emulsion PV = 9 15 22 34 51 71 98
YP = 1 1 3 3 8 15 19
HE®100 Emulsion PV = 13 15 19 25 33 45 64
YP = -1 0 1 2 4 8 10
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16.0 ppg CaBr/ZnBr Brine
concentration HE®100 Emulsion HE®300 Emulsion
lb/BBl PV YP PV YP
1 15 0 - -
2 26 4 - -
3 40 7 14 2
4 59 14 18 4
5 80 20 27 4
6 112 26 37 6
7 186 4 51 13
8 - - 77 20
9 - - 97 33
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3% KCl + 6 lb/BBl HE100d
Fann 50 Data - 2500F Equivalent
rpm
Shear Shear Viscosity Fann 35 n' 0.4683
Rate Stress cp Dial Reading K' 0.0221
sec-1 dyne/cm2 degress
3 5.11 24 470 4.7 Visc = 69
6 10.22 32 313 6.3 (170 sec-1)
100 170.3 117 69 22.9
200 340.7 162 48 31.7 PV = 23
300 511.0 196 38 38.4 YP = 15
Equivalent Fann 35 Reading = (Shear Stress) / 5.107
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3% KCl + 6lb/BBl HE100d
0
50
100
150
200
Temperature,0F
V i s c o s i t y ,
c p ( 1 7 0 s e c
- 1 )
75 85300300250250200150100
1 Hr 1 Hr
With Stabilizer
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3% KCl + 7 lb/BBl HE®300 (d)
0
20
40
60
80
100
Temperature,0F
V i s c o s i t y , c p ( 1 7 0 s e c
- 1 )
75 300300250250200200150100 85
I Hr
I Hr I Hr
With Stabilizer
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3% KCl + 5 lb/BBl HE®100 Emulsion
0
20
40
60
80
100
120
140
Temperature,0F
V i s c o s i t y ,
c p ( 1 7 0 s e c
- 1 )
75 75300300250250200200150100
I Hr
I Hr
I Hr
With Stabilizer
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3% KCl + 5 lb/BBl HE®300 Emulsion
0
20
40
60
80
100
120
Temperature,0F
V i s c o s i t y
, c p ( 1 7 0 s e c
- 1 )
I Hr
I Hr
Hr
75 75300300250250200200150100
With Stabilizer
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10 ppg NaCl + 6 lb/BBl HE®100 Emulsion
0
20
40
60
80
100
120
140
Temperature,0F
V i s c o s i t y ,
c p ( 1 7 0 s e c
- 1 )
85
1 Hr
300250250200200150100 300 85
1 Hr
1 Hr
With Stabilizer
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10.7 ppg CaCl2 + 7 lb/BBl HE®100 Emulsion
0
20
40
60
80
100
120
Temperature,0F
V i s c o s i t y , c p ( 1 7 0 s e c
- 1 )
150
1 Hr
7730030025025020020010075
1 Hr
1 Hr
With Stabilizer
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13 ppg CaBr2 + 6 lb/BBl HE®100 Emulsion
0
50
100
150
200
Temperature,0F
V i s c o s i t y , c
p ( 1 7 0 s e c - 1 )
150
1 Hr
7830030025025020020010578
1 Hr 1 Hr
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16 ppg ZnBr2 + 6 lb/BBl HE®100 Emulsion
0
50
100
150
200
Temperature,0F
V i s c o s i t y , c p ( 1 7 0 s e c - 1 )
78 7830 030 025025 020020015 5110
1 Hr
1 Hr
1 Hr
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10# NaCl + 5 ppb HE100 (e) + 1 ppb NaHCO3
Temp = 740F After Aging for 15 Hours at 3500F
RPM
Percent
Viscosity Viscosity of Original
cp cp Viscosity 3 380 299 79%
6 304 185 61%
101 94 61 64%
201 71 50 70%
301 61 47 76%
502 52 42 80%
pH = 8 7.7
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13 ppg CaBr2 + 9 lb/BBl HE300 Emulsion
0
50
100
150
200
0 5 10 15
Time at 3500F, hrs
V i s c o s i t y , c p ( 4 0 s e c
- 1 )
0
100
200
300
400
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14.2 ppg CaBr2 + 6 lb/BBl HE®100 Emulsion
+ 2.5 lb/BBl Starch + 20 lb/BBl CaCO3
0
20
40
60
80
100
120
0 5 10 15 20
Time at 2000F, Hrs
V i s c o s i t y , c p ( 1 7 0 s e c - 1 )
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5 lb/BBl HE®300 Emulsion in 16 ppg ZnBr2
0
50
100
150
200
Temperature,0F
V i s c o s i t y , c p ( 1 7 0 s e c - 1 )
80 80350350300300250250200200
1 Hr 1 Hr
1 Hr
1 Hr
HE® Polymers in Brines
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Conclusions
A. The HE® Polymers are effective viscosifiers for brines in Drill-in, Completions or
Workover applications.
B. The HE® Polymers provide a number of potential benefits, including:
Thermal Stability
Carrying Capacity
Restricted fluid invasion
Friction Reduction
C. The powdered forms of the HE® Polymers are most applicable in the lighter brines,
including KCl, NaCl, CaCl2, and NaBr.
D. The HE Emulsion Polymers are applicable in all the compositions.