DRILSMOOTH FLUID SYSTEM
1
FEATURES AND APPLICATIONS
Applications
Features









Highly shear thinning
Exceptional hole cleaning and
suspension
Improved solids removal efficiency
vs. competitive systems
Zero flow at wellbore face
Low reservoir damage and easy
cleanup
System stable to ~400°F
Viscosity easily destroyed (e.g., for
displacement procedures)
Cost effective vs. polymer muds
High LC50 numbers

Unconsolidated formations
Loss zones (porous and fractured)
Milling
Horizontal open hole completions
Stabilizing surface holds against
collapse
Coiled tubing drilling
Deepwater

High ROPs






2
WHAT THE DRILSMOOTH SYSTEM IS:
The DrilSmooth system is a unique, water-based drilling fluid developed
for fractured and stabilizing mechanically weak or poorly consolidated
formations and drilling high-angle or horizontal wells
Complementary Additives
Basic makeup
 ID-MMH FL fluid loss control additive
 Non-treated bentonite
 Temperature stabilizers (ID-PTS)
 MMO mixed metal oxide
 AS-Y Shale inhibitor
 Water
 Selected ancillary products
 Soda ash
 Weight material
 Caustic soda
3
SYSTEM DESCRIPTION
What is MMO?
A small cationic crystal . . .
 A dimension smaller than a bentonite
platelet (face dimension ~0.05 m)

Flat with high specific surface area (narrow edge of ~0.0008 m)

Charge density 6 to 7 times that of a bentonite platelet

Acid soluble

“Synthesized Structure”
4
SYSTEM DESCRIPTION
•
Attachment of the MMO crystal
to the bentonite platelet
produces an entirely new
chemical structure
 PV is very low
 YP, Fann 6 and 3, and gels are
abnormally high
New Adduct Formed by Chemical Reaction
• The gels are formed by
electrostatic attraction - which is
why they are instant, but fragile
5
WHAT DOES DRILSMOOTH OFFER?
 Instantaneous and very effective suspension
 Excellent hole cleaning
 Resistance to movement along fractures
 Totally external filter cake if properly treated
 Minimal washout due to dead zone at wellbore wall
 Environmental peace of mind
 Temperature stability
6
MMO SYSTEM INHIBITION
IMPROVEMENT PROJECT
7
BACKGROUND
Challenge:
• To improve MMO system’s inhibition and expand its
applications
Solution:
• IDEC received cuttings from different troublesome formations
in North Iraq region and sent to our R&D Center in Houston
for testing
• Several tests were done comparing different inhibitors and
their impact on system’s rheology and inhibition performance
• Lab test matrix was set for the project
8
BACKGROUND
Project #
Lab Tests
XRD-Minerology
HOU-0092
HOU-0103
Shale Control
TT-27Z Cuttings
Additives for MMO
HOU-0109
Gasplus
Cuttings
✓
✓
CST
Linear Swelling
Clay Recovery
Bulk Hardness
✓
✓
✓
✓
HOU-0107
Shale Inhibition
Using Silicate Fluids
✓
On-going
✓
✓
✓
9
TT-27Z CUTTINGS
10
GASPLUS CUTTINGS
SHEWSHAW-2A well in Tanjero
SH-2A well in Kolosh
11
MINERALOGY: TT-27Z WELL IN KOLOSH T3
12
MINERALOGY: SHEWSHAW-2A WELL IN TANJERO
13
MINERALOGY: SH-2A WELL IN KOLOSH
14
MINERALOGY
Formation0
Well
Depth (m)
NON-CLAYS
Quartz
Feldspar
Plagioclase
Calcite
Dolomite
Siderite
Halite
Pyrite
Total non-clays
CLAYS
Kaolinite
Smectite
Illite
Chlorite
Muscovite
Total clays
TOTAL
Kolosh T3
TT-27Z
Tanjero
SHEWSHAW-2A
1800237523851805
2380
2390
13641370
14001405
Kolosh
SH-2A
17451800
17801785
17851790
Sample #1
Sample #2
2.2
7.3
5.9
9.3
4.4
1.9
0.1
0.9
32.1
0.1
6.8
7.5
5.5
2.6
2.2
0.0
1.1
25.8
0.8
12.3
8.5
5.8
2.9
2.8
1.4
1.5
35.9
2.6
7.3
9.6
9.9
3.1
2.2
1.9
1.3
37.8
2.8
8.2
11.0
9.3
3.1
1.7
2.2
1.3
39.7
1.6
8.1
10.2
3.8
3.1
2.2
2.1
1.4
32.6
4.2
7.7
11.6
6.9
3.6
1.7
0.9
1.5
38.1
0.9
6.9
15.7
3.3
2.7
1.8
0.9
1.2
33.4
1.6
6.4
10.5
3.2
2.7
2.2
1.0
1.3
28.9
1.3
8.1
14.2
3.0
2.2
1.7
0.9
1.4
32.9
3.2
15.5
7.0
40.5
1.6
67.9
100.0
5.6
17.1
11.0
40.6
0.0
74.2
100.0
4.9
20.1
3.5
35.6
0.0
64.1
100.0
3.5
13.5
1.3
40.6
3.2
62.2
100.0
3.2
13.6
1.8
40.8
0.9
60.3
100.0
4.0
19.5
3.8
40.1
0.0
67.4
100.0
3.9
14.0
2.0
42.0
0.0
61.9
100.0
4.8
16.3
3.9
41.7
0.0
66.6
100.0
5.0
20.4
2.8
42.9
0.0
71.1
100.0
4.8
20.1
3.0
39.3
0.0
67.1
100.0
15
BULK HARDNESS: TT-27Z
Fluid
Bulk hardness, in-lb
Unexposed
DI Water
MMO
3% MMO-AS
3% Glymax
4
1
1
1
2
16
CST: GASPLUS CUTTINGS
Sample
Tanjero
Kolosh
Fluid
CST #1 (s)
CST #2 (s)
CST #3 (s)
Avg. CST (s)
DI water
73.9
57.0
84.1
71.7
MMO + 1 lb/bbl MMO-AS
2734.7
2973.3
>3000
>3000
1 lb/bbl MMO-AS in DI water
21.6
21.3
21.1
21.3
2 wt% QmaxDrill
17.8
18.2
18.8
18.3
55 lb/bbl sodium silicate
127
153.8
134.2
138.3
DI water
32.8
35.4
37.2
35.1
MMO + 1 lb/bbl MMO-AS
3187.3
3146.5
>3000
>3000
1 lb/bbl MMO-AS in DI water
15.0
16.1
15.8
15.6
2 wt% QmaxDrill
15.7
15.8
13.4
15.0
55 lb/bbl sodium silicate
54.7
64.9
49.2
56.3
17
LINEAR SWELLING: GASPLUS CUTTINGS
SH-2A well in Kolosh
SHEWSHAW-2A well in Tanjero
18
FLUID RHEOLOGY
Fluid
MMO
Water, bbl
Bentonite, lb
Soda Ash, lb
PAL FC, lb
PRIMO MMO-D, lb
PRIMO MMO-AS, lb
KCl, lb
Glymax, lb
Liquid Gilsonite, lb
Mud weight, lb/gal
0.9899
5.5
0.5
2
0.55
----------------8.46
MMO+3%
MMO-AS
0.9899
5.5
0.5
2
0.55
10.8
------------8.46
θ 600 / θ 300 @ 120°F
31/25
62/49
MMO+1 lb/bbl
MMO-AS
0.9899
5.5
0.5
2
0.55
1
------------8.46
Rheology
23/16
θ 200 / θ 100
θ6/θ3
Plastic viscosity, cP
Yield point, lb/100 ft²
10-sec Gel, lb/100 ft²
10-min Gel, lb/100 ft²
30-min Gel, lb/100 ft²
22/18
11/11
6
19
12
11
12
42/34
20/20
13
36
20
21
20
14/12
6/6
7
9
7
8
10
MMO+3% KCl
0.9899
5.5
0.5
2
0.55
----10.8
--------8.46
MMO+3%
Glymax
0.9899
5.5
0.5
2
0.55
--------10.8
----8.46
MMO+3% Liquid
Gilsonite
0.9899
5.5
0.5
2
0.55
------------10.8
8.46
22/18
35/33
20/21
17/14
6/3
4
14
3
3
4
32/30
17/16
2
31
15
14
16
20/16
3/2
-1
22
2
1
1
19
CLAY RECOVERY TEST
Fluid
DI Water
MMO
MMO+3% MMO-AS
MMO+1 lb/bbl MMO-AS
MMO+3% KCl
MMO+3% Glymax
MMO+3% Liquid Gilsonite
55 lb/bbl Na silicate
55 lb/bbl Na silicate+3% K2CO3
55 lb/bbl Na silicate+0.5 lb/bbl IDCAP
Original weigh, g
20.87
21.05
20.55
20.23
20.49
20.64
20.38
20.99
20.1
20.44
Recovered weight, g
<0.01
<0.01
8.45
0.03
5.78
1.01
<0.01
13.53
10.56
16.66
Amount recovered
<0.05 wt%
<MMO+0.05 wt%
41.1 wt%
0.15 wt%
28.2 wt%
4.9 wt%
<0.05 wt%
64.5 wt%
52.5 wt%
81.5 wt%
MMO-based
Silicate-based
20
LINEAR SWELLING: BENTONITE PELLETS
21
MMO INHIBITION IMPROVEMENT – EAST AFRICA
• DrilSmooth was used on one well in East
Africa to drill the top-hole section since
previous wells in the same field have
experienced severe lost of circulation.
• The section was drilled successfully with
no losses and the casing was set at the
bottom.
• Due to the presence of highly reactive
clays, it was decided to work on
boosting the system’s inhibition to be
able to use it on future wells.
22
MMO INHIBITION IMPROVEMENT – FURTHER STUDIES
Due to the continued success of the DrilSmooth system in other
areas, further tests were performed in Houston to boost system’s
inhibition using a combination of regular and new inhibitors
Cuttings samples from East Africa were sent to the lab in Houston
to check on the best combination of inhibitors to use in the field
and stabilize these formations
23
XRD AND CED RESULTS
Mineralogy (wt%)
Ngamia-3: 790
– 800 ft
Etom-2: 150 –
160 ft
Etom-2: 160 –
170 ft
Etom-2: 460 –
465 ft
Amosing-5:
560 – 570 ft
Amosing-5: 570
– 580 ft
NON-CLAYS
Sample
CEC (meq/100 g)
Ngamia-3: 790 – 800 ft
14
Etom-2: 150 – 160 ft
29
Etom-2: 160 – 170 ft
32
Quartz
2.6
0.5
1.1
4.1
8.2
5.2
Feldspar
15.6
12.2
16.5
19.3
17.9
19.8
Plagioclase
6.0
9.6
10.2
8.7
14.3
8.1
Calcite
4.9
5.6
7.5
4.7
3.0
1.9
Etom-2: 460 – 465 ft
21
Dolomite
4.4
3.0
3.1
3.2
2.6
2.6
Siderite
Amosing-5: 560 – 570 ft
17
1.6
1.7
1.7
1.1
1.3
1.1
Halite
0.2
0.1
0.2
0.3
0.2
0.2
Amosing-5: 570 – 580 ft
16
Pyrite
0.9
0.9
0.9
0.6
0.7
0.9
Total non-clays
36.0
33.7
41.4
42.0
48.1
39.8
CLAYS
Kaolinite
5.2
4.9
5.0
4.2
3.4
6.5
Smectite
9.9
14.2
13.5
14.4
11.7
11.1
Illite
3.2
5.4
3.2
4.4
3.3
2.1
Chlorite
42.0
39.4
36.7
35.0
33.2
36.9
Muscovite
3.7
2.5
0.3
0.0
0.3
3.5
Total clays
64.0
66.3
58.6
58.0
51.9
60.2
TOTAL
100.0
100.0
100.0
100.0
100.0
100.0
24
Shale Inhibition with shale cuttings for 14 ppg fluid at 250°F
with ID-MMO HIB and ID- MMO THERM
14 ppg Base Mud with MMO- HIB, PRIMO
THERM, and 10 ppb Shale Cuttings
Materials
Base Mud
Sample 14 Sample 14*
Fresh Water, bbl
0.509
0.507
0.507
Soda Ash, ppb
0.25
0.25
GEL, ppb
8.0
MMO - D, ppb
14 ppg fluid rheologies before and after hot roll at
250°F.
Hot Roll at 250°F
Rheology at 120°F
Base Mud
BHR
AHR
Sample 14
BHR
AHR
Sample 14*
BHR
AHR
600
157
268
272
142
228
153
0.25
300
108
191
223
87
205
90
8.0
8.0
6
20
47
78
17
73
19
0.8
0.8
0.8
3
20
46
77
16
72
18
THERM, ppb
2.0
2.0
2.0
PV
49
77
49
55
23
63
MMO - HIB, ppb
-
0.5
0.5
YP
59
114
174
32
182
27
MMO - AS, ppb
-
1.0
1.0
10’ gel
22
38
51
13
50
17
Drill Cuttings GS# 31458, ppb
10.0
10.0
10.0
10” gel
44
121
70
52
83
83
Barite, ppb
298.11
297.52
297.52
Initial pH
11.66
9.82
11.28
9.53
11.56
9.57
Caustic Soda, ppb
0.3
0.3
0.3
Adjusted pH
-
11.19
-
11.29
-
11.9
Mud Weight, ppg
14.0
14.0
14.0
API Fluid Loss
-
6.4
-
6.6
-
9.0
Seawater, % v/v
-
-
10%
HTHP Fluid Loss@ 250°F
-
27.0
-
26.0
-
35.2
Shale Inhibition with shale cuttings for 14 ppg fluid at 250°F
with ID-MMO HIB and ID- MMO THERM
Remarks:
1. Low temp and high temp fluid loss look very good with only 2 ppb ID-THEM in the system.
2. Significant increase in rheology of the base mud with powdered shale cuttings added to the
fluid.
3. With the inclusion of MMO-HIB and AMMO-AS in Sample 14, a significant drop in AND
rheology is noticed, indicative of inhibition of shale.
4. Even with the contamination of 10% seawater by volume in Sample 14*, the rheological
profile appears fairly similar to that of Sample 14.
Conclusion:
The MMO - HIB and the MMO-AS definitely inhibit the swelling of the drilled solids (cuttings). The
base mud AHR showed the low end and YP doubled and the Gels almost tripled. The fluid losses
are also acceptable at 250°F. With seawater, the mud was still stable AHR at 250°F for 96 hours.
Shale Erosion with shale cuttings for 14 ppg fluid at 250°F with
MMO – HIB and ID-THERM
. Base
Mud plus Shale Cuttings
Materials
Rheologies before and after hot roll at
Hot Roll at 250°F
Base Mud
Sample 15
150°F
.
BHR
AHR
BHR
Rheology at 120°F
Base Mud
Sample 15
Fresh Water, bbl
0.514
0.507
Soda Ash, ppb
0.25
0.25
8.0
8.0
PRIMO MMO - D, ppb
0.8
0.8
PRIMO THERM, ppb
2.0
2.0
-
0.5
PRIMO MMO - AS, ppb
-
1.0
Barite, ppb
306.33
297.52
Caustic Soda, ppb
0.3
0.3
Weight of Cuttings, grams
Mud Weight, ppg
14.0
14.0
% Erosion
PRIMO MMO - GEL, ppb
PRIMO MMO - HIB, ppb
600
185
300
129
TTTM
AHR
230
280
233
163
196
6
28
103
33
65
3
27
102
32
64
PV
56
-
67
84
YP
73
-
96
10’ gel
24
104
32
10” gel
45
116
42
11.85
Initial pH
9.5
11.35
Adjusted pH
20.33
-
0.37
98.18
11.69
112
60
114
9.6
-
11.66
20.08
0.69
-
96.6
Remarks:
1. The +10-mesh shale cuttings were very fragile to touch and appeared to be dried gumbo in granular
form.
2. 98% of the cuttings in the base mud eroded away through a 10-mesh screen and significantly increased
mud viscosity.
3. 97% of the cuttings in Sample 15 also eroded away, however the rheology was significantly lower with
the incorporation of MMO-HIB and MMO-AS, which is indicative of significant shale inhibition.
KURDISTAN CASE HISTORY
28
KURDISTAN CASE HISTORY-1: GULF KEYSTONE WELL (2014-15)
 Witnessing very significant success of DRILSMOOTH (MMO) system in drilling 26’’ and 17 ½’’ sections of
the well, 12 ¼” hole was also drilled through, Sarmond, Garagu, Chia Gara and Barsarin up to the 9 5/8”
casing point 1965m / 1610m TVD with 56º inclination.
 There was significant control of formation losses (as depicted in following slides) and absolutely no hole
cleaning issues.
 Several runs of well Logging over a long time, enhanced the well exposure time and the casing running
faced obstructions in Garagu shales which needed higher inhibition levels.
 In MMO system the inhibition level could be attained with 2-3% KCl (< 20,000 chloride limit to use it)
and with up to 3% ID-FURY.
 Seeing the inhibition limitations of the MMO system, the whole system was easily broken down to KClPolymer system and re-conditioned the well for successful running of the casing.
KURDISTAN CASE HISTORY-1: GULF KEYSTONE WELL (2014-15)
Advantages recorded using MMO mud in SH-11 vis-à-vis SH-10 drilled from the same pad
• Overall losses were 33% less using MMO mud in 26’’, 17 ½’’ and 12 ¼’’ holes.
• Total well mud cost was 18% less vis-à-vis previous well drilled.
• For SH-11, planned well depth was 2157 with 43.41º inclination, actual was 2348m with 62.9º, an 8 %
longer well bore with higher inclination.
• Planned drilling-cum-completion days were 75 whereas the well was completed in 65 days, saving 13%
rig time and money.
• Incurred 18% less mud and Engineering cost.
KURDISTAN CASE HISTORY-1: GULF KEYSTONE WELL (2014-15)
Pictorial presentation of the comparison of three wells drilled by the same client in the same block:
SH-10
VS. SH-11 (MMO)
SH-10
SH-11
98940
65
1 700 650
148 051
90
2 077 784
2348
2255
DEPTH (M)
LOSSES(BBL)
DAYS
COST
KURDISTAN CASE HISTORY-2: TOTAL E&P WELL (2014-15)
 TOTAL planned to use the MMO system for first two
intervals (26” and 17 ½”) only, then due to its excellent
performance and trouble-free operations, decided to
use it on the 12 ¼” and 8 ½” hole sections as well.
 The 7” liner was just set and drilling resumed with
KCl/Polymer mud just for one reason, to reduce the ECD
due to low fracture gradient.
 Inhibition to the MMO system was provided by using
0.5% v/v AS-Y and 2% v/v ID-FURY.
 Lubricity provided by using Graphite powder, ID-FURY
and ID-LUBE XL.
KURDISTAN CASE HISTORY-2: TOTAL E&P WELL (2014-15)
Interval 1
Bit Size (inches)
Interval 2
Interval 3
Interval 4
Interval 5
Interval 5
26”
17.5”
12.25”
12.25” S.T.
8.5”
6”
MMO Mud
MMO Mud
MMO Mud
MMO Mud
MMO Mud
KCl/Glycol/Poly
mer mud
Top of Interval (m)
30 m
777 m
1548 m
1548 m
3000 m
3740 m
Bottom of Interval (m)
782 m
1548 m
2214 m
3000 m
3740 m
4435 m
1.08
1.21
1.50
1.55
1.79
1.74
8
14
9
19
12
13
1285.10
219.2
520.8
839.7
946.2
527.7
0
6
11.2
9
65
396.6
Mud Type
Maximum Mud Weight (SG)
Drilling Days
Vol. Mud Built (m3)
Formation Losses (m3)
KURDISTAN CASE HISTORY-2: TOTAL E&P WELL (2014-15)
Drilling curve is ahead of planned, and if not for the many rig equipment failure and geological side-track, more time
could have been saved:
Spud Baranan-1
Baranan-1 Planned
Baranan-1.G1 Realized
Baranan-1.G1_6'' Deepening_Planned
Geological Side Track
0
2.5d TDS electrical fault
250
26'' Drilling
2.1d Over-torqued Drill string
500
20'' Casing
750
Geological
side-track
1000
17 1/2'' Drilling
1.2d Generator failure
1250
1.9d Downhole motor
failure #01
1500
Motor failure #02 no NPT
(Early TD)
1750
1.8d Waiting on geological
sidetrack approvals
2000
Measured Depth (m)
13 3/8 '' Casing
12 1/4'' Drilling
2250
0.9d Troubleshoot
Drawwork
2500
2750
9 7/8'' x 9 5/8'' Casing
0.7d POOH due to
wash pipe
8 1/2'' Drilling
3000
2d Full Inspection BHA due
to drill string early wear
3250
1.4d Flowline
connexion to RCD
3500
0.8d TDS electrical
fault
3750
2.1d Downhole motor
failure
7'' Liner
6'' Drilling
4000
0.7d Drawworks
electrical failure
4250
4500
0
10
20
30
40
50
60
70
80
90
100
110
Duration (Days)
120
130
140
150
160
170
180
190
200
210
220
KURDISTAN CASE HISTORY-2: TOTAL E&P WELL (2014-15)