The first total drilling fluid in a single sack.
Environmentally Friendly
Whole in One
Description
Whole in One is a blend of anionic and
nonionic polymers, fibers, and minerals for a
complete high performance water-based
drilling fluid system that is specially
formulated to drill lateral and directional
wells and can tolerate contamination and
provide excellent lubricity and shale
inhibition.
Advantages
 The stability, speed and performance of an oil-based fluid system
 Overall well bore integrity by minimizing shale problems and hole
enlargement
 Penetrates and seals micro fractures
 Minimizes mud losses
 Resistance to chemical contamination
 Provides lubricity and reduces metal to metal contact
 Excellent Hole Cleaning
 Can be re-used but there are no disposal problems (passed microtox EC50
Bioassay) LC50
 Reduce health, safety and environmental harm to rig personnel
 Lower costs due to clean up, disposal and transportation of oil based
cuttings
Economics
Significantly lower total cost per barrel
Lower transportation cost
No environmental clean-up cost
Availability of fresh or seawater as base fluid
No cuttings transportation cost
Low maintenance cost
Reduced inventory cost on location by 75%
Mixing Procedure
 Whole in One can be mixed in any type of available
water on location; i.e. fresh, saturated salt, drill or
seawater
 Fill the pits with the desired volume of water
 Mix 7.0 ppb Whole in One through the mud hopper
 Agitate the pits for 30 minutes
 Continue to shear the mud through the hopper until
the funnel viscosity is 33 sec/qt or more
 Add the weighting agent to the desired mud weight
 The fluid is now ready for displacement
Daily Maintenance
 Keep the mud hydrated
 Maintain 7.0 ppb Whole in One
 Track dilution and volumes
DESCRIPTION
NFS-EXP2020 test report
TEST DATE
02/29/2012
TESTED BY
Sam Khosh
SAMPLE VOLUME 350 ml
SAMPLE COMPOSITION
PRODUCT
UNITS
Freshwater
ml
NFS- 1 sack mix
g
Rev Dust
g
Barite
g
premixed Bentonite
Bentonite water
7 PPB
7 PPB
ml
Saturated salt water 5%
ml
Seawater
ml
Shalecapsule
ml
PERIOD AGED
TEMPERATURE
DYNAMIC/STATIC
RHEOLOGY:
TEMP.
600 RPM
300 RPM
200 RPM
100 RPM
6 RPM
3 RPM
GELS 10"
GELS 10'
APPARENT VISC.
PLASTIC VISC.
YIELD POINT
Erosion
Lubricity
API FLUID LOSS
HPHT Filtration at250 °F
pH
COMMENTS:
1
288
7.0
27.0
190.0
2
3
4
5
7.0
27.0
190.0
280.0
7.0
27.0
190.0
280.0
7.0
27.00
190.0
280.0
17.5
7.0
27.0
190.0
6
288
7.0
lbs/100ft2
lbs/100ft2
cP
cP
lbs/100ft2
%
5in
5 Min
ml
8
1a
288
7.0
27.0
190.0
2a
3a
4a
5a
7.0
27.0
190.0
280.0
7.0
27.0
190.0
280.0
7.0
27.00
190.0
280.0
17.5
7.0
27.0
190.0
288.0
6a
288
7.0
288.0
7.0
HOURS
°F
D/S
°F
7
7.0
16
250
D
16
250
D
16
250
S
16
250
D
16
250
D
16
150
D
120
62
43
34
23
5
4
5
7
120
79
54
44
32
9
8
9
12
120
79
54
44
32
9
8
9
12
120
60
39
32
21
7
6
6
12
120
55
36
28
19
5
4
5
7
120
23
15
11
8
4
3
4
5
120
38
24
17
11
4
3
4
5
120
53
32
25
16
4
3
4
9
120
54
33
28
19
4
3
4
8
120
51
33
25
17
6
5
6
14
120
22
13
9
7
3
2
3
5
120
22
14
11
9
4
3
4
5
20
22
25
29
25
29
21
18
19
17
8
7
14
10
21
11
21
12
18
15
9
4
0.09
3.5
7
9.2
0.1
3.8
0.09
4.1
0.011
4.3
0.01
3.9
8
6
5
0.09
4.1
9
9
8.8
9
8.5
9.2
9
9
1: Freshwater mud 12 lb with 27 PPB Rev Dust no Bentonite
2: Premixed Bentonite water 7PPB with 27 PPB Rev Dust Hot Roll @ 250 F° Dynamic aging
3: Premixed Bentonite water 7 PPB with 27 PPB Rev Dust Hot Roll 250 F˚ Static aging
4: Sturated salt water 5% by volume added
5:Seawater
6: 2% by volume Shalecapsule
Shale Erosion Test of Whole in One
Before Shale Exposure
After Hot Roll and Drying
Sample from Arkansas
Date: 08/02/2013
Subject: Shale Erosion Test
Mud
% Erosion Pierre
Shale
% Erosion Eagle
Ford Shale
7 PPB EXP-2020
7 PPB EXP-2020 with
2% by volume
Shalecapsule
7 PPB EXP-2020 with 4
PPB asphalt
7.3
7.00
7.4
3.2
3.0
3.3
Shale Erosion Test Procedure:
Grind shale sample and sieve through the No. 5 and No. 10 screens.
Use the shale that is collected on the No. 10 screen. 20 grams of the shale sample will be used in the test mud. The
test mud will then be hot rolled at 150°F for 16 hours and screened through the No. 10 screen; the solid retained on
the No. 10 screen will be washed, dried, and weighed. The initial moisture content is taken into account when
calculating the percentage of erosion. In this test the shale moisture content is = 5%.
Tested by: Sam Khosh
Date: 08/02/2013
Subject: 7 days Shale Erosion Test with Eagle Ford core shale sample:
Mud
%Shale Erosion
core sample
7 PPB EXP-2020
In fresh water
7 PPB EXP-2020 in
fresh water with 2% by
volume Shalecapsule
7 PPB EXP-2020 in fresh
water with 4 PPB asphalt
3.2
3.0
3.3
7 Days Shale Erosion Test Procedure:
Grind shale sample and sieve through the No. 5 and No. 10 screens.
Use the shale that is collected on the No. 10 screen. 20 grams of the shale sample will be used in the test mud. The
test mud will be:
123456-
Hot rolled at 150°F for 16 hours in rolling oven
Turn the oven off after 16 hours and leave it off for 8 hours
Turn the oven on after 8 hours
Repeat step 1- 3 for 7 days
Take the mud from the oven
Screen the mud through the No. 10 screen, the solid retained on the No. 10 screen will be washed, dried
and weighed.
Tested by: Sam Khosh
LC50 Results
Packaging
Whole in One is available in two
sizes:
25 lb. paper sacks
2000 lb. super sacks
Performance Profile
Case History #1 - Terryville Field, Haynesville Lateral, Lincoln Parish, LA
The surface hole was drilled to a depth of 1,878’ where the pits were mudded up with Whole in One and the well
was drilled to intermediate casing depth at 9,490’ with no problems. The curve was built and the lateral section
was drilled with Whole in One (replace conventional oil base mud) to 16,025’ with a 13.8 ppg mud weight. The
casing got stuck and the hole was sidetracked at 10,129’ with a 12.0 ppg mud weight. The lateral was re-drilled
using the same system, sweeps, etc. with a maximum mud weight of 15.8 ppg.
Case History #2 - Terryville Field, Haynesville Lateral, Lincoln Parish, LA
The surface hole was drilled to a depth of 1,872’ where the pits were mudded up with Whole in One. Anhydrite
was drilled at 4,452’ with no problems. Picked up directional tools at 4,826’, drilled to 9,270’ and had to weight up
to 10.8 ppg due to splintery shale. Drilled to 11,273’ with Whole in One and set intermediate casing. Built the
curve and drilled the lateral section with Whole in One (replaced conventional oil base mud) to 15,884’ with no
problems.
Case History #3 - Terryville Field, Haynesville Lateral, Lincoln Parish, LA
The surface hole was drilled and casing set with no problems. The pits were mudded up with Whole in One and
drilling resumed. Anhydrite was drilled at 5,276’ with no change in mud properties. Built the curve using Whole in
One, drilled to 11,487’ and ran intermediate casing with no problems. Drilled to total depth at 15,404’ with Whole
in One (replaced conventional oil base mud), ran production casing and cemented with no problems.
Performance Profile
Case History #4 - Webb Co., TX, Eagle Ford Lateral
The surface hole was drilled to a depth of 3,520’ where the pits were mudded up with Whole in One. The hole was
drilled to 14,493’ and while pulling out of the hole the pipe got stuck at 13,602’. TIH with whip stock and sidetracked the well with oil base mud. The problem wasn’t using Whole in One, because after displacing with oil base
mud they had to do a second side-track and eventually plug and abandoned the well due to frac sand
communication from another well.
Case History #5 - South Texas Eagle Ford Lateral
The surface hole was drilled to a depth of 2,160’. Drilled to 7,536’ where the pits were mudded up with Whole in
One. Drilled to 10,140’ and set intermediate casing with no problems. Cored from 10,140’ to 13,843’ with Whole
in One and started building the curve at 11,300’ and finished it at 12,945’. Drilled the extended reach lateral with
Whole in One (replaced conventional oil base mud) to TD at 17,250’.
Conclusion
This new and revolutionary single sack water based system is now
available. NFSI is excited, prepared, and anxiously
awaiting to help meet your drilling fluid needs.
For any additional information please contact:
Joe Morris
joe@newfluid.com
713-780-3600
www.newfluid.com
Questions?