U.S. patent application number 16/886961 was filed with the patent office on 2020-09-17 for divalent brine fluids having improved rheology and multifunctional properties.
This patent application is currently assigned to Baker Hughes, a GE company, LLC. The applicant listed for this patent is Gaurav Agrawal, Mohammed Al-Rabah, Prahlad Yadav. Invention is credited to Gaurav Agrawal, Mohammed Al-Rabah, Prahlad Yadav.
Application Number | 20200291284 16/886961 |
Document ID | / |
Family ID | 1000004857325 |
Filed Date | 2020-09-17 |
United States Patent
Application |
20200291284 |
Kind Code |
A1 |
Yadav; Prahlad ; et
al. |
September 17, 2020 |
DIVALENT BRINE FLUIDS HAVING IMPROVED RHEOLOGY AND MULTIFUNCTIONAL
PROPERTIES
Abstract
A method of improving rheological properties of a divalent brine
based downhole treatment fluid at an elevated temperature comprises
adding to the divalent brine based downhole treatment fluid a
rheological modifier, which comprises a carboxylic acid ester, or a
phosphate ester blended with an ethoxylated glycol, or a
combination comprising at least one of the foregoing in an amount
effective to improve the rheological properties of the divalent
brine based downhole treatment fluid at a temperature of greater
than about 200.degree. F. The divalent brine based downhole
treatment fluid comprises calcium bromide, calcium chloride, zinc
bromide, zinc chloride, or a combination comprising at least one of
the foregoing.
Inventors: |
Yadav; Prahlad; (The
Woodlands, TX) ; Al-Rabah; Mohammed; (Al Qatif,
SA) ; Agrawal; Gaurav; (Aurora, CO) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Yadav; Prahlad
Al-Rabah; Mohammed
Agrawal; Gaurav |
The Woodlands
Al Qatif
Aurora |
TX
CO |
US
SA
US |
|
|
Assignee: |
Baker Hughes, a GE company,
LLC
Houston
TX
|
Family ID: |
1000004857325 |
Appl. No.: |
16/886961 |
Filed: |
May 29, 2020 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
15825480 |
Nov 29, 2017 |
10711174 |
|
|
16886961 |
|
|
|
|
62429942 |
Dec 5, 2016 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
C09K 8/04 20130101; C01G
9/04 20130101; C01F 11/34 20130101; C01P 2006/22 20130101; C09K
8/86 20130101; C01F 11/24 20130101; E21B 43/16 20130101; C09K
2208/34 20130101; C09K 8/58 20130101; C09K 8/06 20130101; C09K
8/035 20130101 |
International
Class: |
C09K 8/035 20060101
C09K008/035; C09K 8/06 20060101 C09K008/06; C09K 8/58 20060101
C09K008/58; C09K 8/86 20060101 C09K008/86; E21B 43/16 20060101
E21B043/16; C09K 8/04 20060101 C09K008/04 |
Claims
1. A divalent brine based downhole treatment fluid comprising:
about 10 to about 18 pounds per gallons of a divalent brine
comprising calcium bromide, calcium chloride, zinc bromide, zinc
chloride, or a combination comprising at least one of the
foregoing; about 1 to about 12 pounds of a rheological modifier per
barrel of the divalent brine based downhole treatment fluid, the
rheological modifier comprising a carboxylic acid ester, or a
phosphate ester blended with an ethoxylated glycol, or a
composition comprising at least one of the foregoing; and a pH
stabilizer comprising a diamine.
2. The divalent brine based downhole treatment fluid of claim 1,
wherein the carboxylic acid ester has a formula I or II
##STR00006## wherein R.sup.1 and R.sup.2 are each independently a
C.sub.6-20 alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl
group.
3. The divalent brine based downhole treatment fluid of claim 1,
wherein the ethoxylated glycol comprises ethoxylated ethylene
glycol, ethoxylated propylene glycol, ethoxylated glycerin,
ethoxylated polyethylene glycol, ethoxylated polypropylene glycol,
or a combination comprising at least one of the foregoing; and the
phosphate ester is a hydrocarbyl polyether phosphate ester
optionally comprising one or two hydroxyl groups directly attached
to phosphorus.
4. The divalent brine based downhole treatment fluid of claim 1,
wherein the fluid has a pH of greater than about 7.5.
5. The divalent brine based downhole treatment fluid of claim 1,
wherein the divalent brine based downhole treatment fluid comprises
about 1 to about 12 pounds of the rheological modifier per barrel
of the divalent brine based downhole treatment fluid.
6. The divalent brine based downhole treatment fluid of claim 1,
wherein the divalent brine based downhole treatment fluid comprises
about 0.5 to about 4 pounds of the rheological modifier per barrel
of the divalent brine based downhole treatment fluid.
7. The divalent brine based downhole treatment fluid of claim 1,
wherein the divalent brine based downhole treatment fluid comprises
about 10 to about 18 pounds per gallons of calcium bromide, calcium
chloride, or a combination thereof.
8. The divalent brine based downhole treatment fluid of claim 1,
further comprising one or more of the following additional
component: a fluid loss control agent; a lubricant; a viscosifier;
a pH modifier; or a weighting agent.
9. The divalent brine based downhole treatment fluid of claim 1,
wherein the divalent brine based downhole treatment fluid is a
drilling or servicing fluid.
10. The divalent brine based downhole treatment fluid of claim 1,
wherein the fluid has a yield point of about 20 lb/100 ft.sup.2 to
about 40 lb/100 ft.sup.2 and a plastic viscosity of 26 cP to 38 cP,
each determined by OFITE 900 viscometer at 120.degree. F., after
hot rolled the fluid at 250.degree. F.
11. The divalent brine based downhole treatment fluid of claim 1,
having a low shear rate viscosity of greater than 10,000 cP
measured by Brookfield viscometer using spindle S62 at 0.5 rpm.
12. The divalent brine based downhole treatment fluid of claim 1,
having a lubricity coefficient of less than 0.13 measured by an
OFITE Lubricity Meter.
13. A method of conducting a wellbore operation in a subterranean
formation, the method comprising: employing in the wellbore
operation a divalent brine based downhole treatment fluid of claim
1.
14. A method of improving rheological properties of a divalent
brine based downhole treatment fluid at an elevated temperature,
the method comprising: adding to the divalent brine based downhole
treatment fluid a rheological modifier comprising a carboxylic acid
ester, in an amount effective to improve the rheological properties
of the divalent brine based downhole treatment fluid at a
temperature of greater than about 200.degree. F., and a pH
stabilizer comprising a diamine, the divalent brine based downhole
treatment fluid comprising calcium bromide, calcium chloride, zinc
bromide, zinc chloride, or a combination comprising at least one of
the foregoing.
15. The method of claim 14, wherein the carboxylic acid ester has a
formula ##STR00007## wherein R.sup.1 and R.sup.2 are each
independently a C.sub.1-26 alkyl, C.sub.2-26 alkenyl, or C.sub.2-26
alkynyl group.
16. The method of claim 15, wherein R.sup.1 is a C.sub.6-20 alkyl,
C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl group; and R.sup.2 is
methyl.
17. The method of claim 14, wherein the rheological modifier is
added to the divalent brine based downhole treatment fluid in an
amount of about 1 to about 12 pounds of the rheological modifier
per barrel of the divalent brine based downhole treatment
fluid.
18. The method of claim 14, wherein the divalent brine based
downhole treatment fluid comprises about 10 to about 18 pounds per
gallons of calcium bromide, calcium chloride, or a combination
thereof.
19. The method of claim 14, further comprising adding one or more
of the following additional component to the divalent brine based
downhole treatment fluid: a fluid loss control agent; a lubricant;
a viscosifier; a pH modifier; or a weighting agent.
20. The method of claim 14, wherein the rheological properties
comprise yield point, low-shear-rate-viscosity, or a combination
comprising at least one of the foregoing.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application is a divisional of U.S. application Ser.
No. 15/825,480 filed Nov. 29, 2017, which claims priority to U.S.
Provisional Patent Application No. 62/429,942, filed Dec. 5, 2016,
the disclosure of which is incorporated by reference herein in its
entirety.
BACKGROUND
[0002] This disclosure relates to methods of improving the rheology
properties of divalent brine based fluids. The disclosure also
relates to divalent brine based fluids having improved rheology and
multifunctional properties and methods of using such fluids.
[0003] Divalent brines are mainly used to prepare drill-in fluids.
Drill-in fluids are designed to be essentially non-damaging to the
producing formation. Ideally, drill-in fluids can also provide
superior hole cleaning property, allow easy clean-up, and are cost
effective.
[0004] In conventional drill-in fluids, organic polymers are often
used to control rheological and fluid loss properties. While
organic polymers are normally stable in fresh water, they can
rapidly degrade in a divalent salt environment resulting in system
instability, especially at an elevated temperature. Accordingly,
the art would be receptive to alternative additives that are
effective to enhance the rheological profile of a divalent brine
based fluid at elevated temperatures. It would be a further
advantage if such additives could also enhance fluid loss control
or lubricity of the divalent brine based fluid.
BRIEF DESCRIPTION
[0005] A method of improving rheological properties of a divalent
brine based downhole treatment fluid at an elevated temperature
comprises adding to the divalent brine based downhole treatment
fluid a rheological modifier, which comprises a carboxylic acid
ester, or a phosphate ester blended with an ethoxylated glycol, or
a combination comprising at least one of the foregoing in an amount
effective to improve the rheological properties of the divalent
brine based downhole treatment fluid at a temperature of greater
than about 200.degree. F. The divalent brine based downhole
treatment fluid comprises calcium bromide, calcium chloride, zinc
bromide, zinc chloride, or a combination comprising at least one of
the foregoing.
[0006] A method of conducting a wellbore operation in a
subterranean formation comprises: employing in the wellbore
operation a divalent brine based treatment fluid comprising a
divalent brine comprising calcium bromide, calcium chloride, zinc
bromide, zinc chloride, or a combination comprising at least one of
the foregoing; and an rheological modifier comprising a carboxylic
acid ester, or a phosphate ester blended with an ethoxylated
glycol, or a composition comprising at least one of the
foregoing.
[0007] A divalent brine based downhole treatment fluid comprises
about 10 to about 18 pounds per gallons of a divalent brine
comprising calcium bromide, calcium chloride, zinc bromide, zinc
chloride, or a combination comprising at least one of the
foregoing; and about 1 to about 12 pounds of an rheological
modifier per barrel of the divalent brine based downhole treatment
fluid, the rheological modifier comprising a carboxylic acid ester,
or a phosphate ester blended with an ethoxylated glycol, or a
composition comprising at least one of the foregoing.
DETAILED DESCRIPTION
[0008] It has been found that rheological modifiers described
herein impart desirable properties to a variety of downhole
treatment fluids, especially divalent brine based drilling fluids,
completion fluids, or servicing fluids. In particular, a carboxylic
acid ester or a phosphate ester blended with an ethoxylated glycol
is effective to enhance the rheological properties of the divalent
brine based fluids such as yield point and
low-shear-rate-viscosity. In a further advantageous feature, the
rheological modifiers are effective to enhance the fluid loss
control and lubricity of the divalent brine based fluids.
[0009] The divalent based fluids comprise calcium bromide, calcium
chloride, zinc bromide, zinc chloride, or a combination comprising
at least one of the foregoing. Monovalent brine can optionally be
present. Exemplary fluids contain about 10 to about 18 pounds per
gallons of calcium bromide, calcium chloride, or a combination
thereof.
[0010] The carboxylic acid ester has a formula
##STR00001##
wherein R.sup.1 and R.sup.2 are each independently a C.sub.1-26
alkyl, C.sub.2-26 alkenyl, or C.sub.2-26 alkynyl group.
Specifically R.sup.1 is a C.sub.6-20 alkyl, C.sub.6-20 alkenyl, or
C.sub.6-20 alkynyl group; and R.sup.2 is methyl. In another
embodiment, R.sup.1 is a C.sub.8-14 alkyl; and R.sup.2 is a
C.sub.6-20 alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl group.
Exemplary carboxylic acid esters have a formula I or II
##STR00002##
wherein R.sup.1 and R.sup.2 are each independently a C.sub.6-20
alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl group.
[0011] The ethoxylated glycol comprises ethoxylated ethylene
glycol, ethoxylated propylene glycol, ethoxylated glycerin,
ethoxylated polyethylene glycol, ethoxylated polypropylene glycol,
or a combination comprising at least one of the foregoing.
[0012] In an embodiment, the phosphate ester is a hydrocarbyl
polyether phosphate ester optionally comprising one or two hydroxyl
groups directly attached to phosphorus.
[0013] The rheological modifier can be added to the divalent brine
based downhole treatment fluid in an amount of about 1 to about 12
pounds or about 0.5 to about 10 pounds per barrel of the divalent
brine based downhole treatment fluid (ppb). In exemplary
embodiments, when the rheological modifier comprises a carboxylic
acid ester, the rheological modifier is added in an amount of about
3 to about 8 ppb, and when the rheological modifier comprises a
phosphate ester blended with an ethoxylated glycol, the rheological
modifier is added in an amount of about 0.5 to about 4 ppb.
[0014] The rheological modifiers as disclosed herein are effective
to enhance rheological properties particularly yield point,
low-shear-rate-viscosity, or a combination comprising at least one
of the foregoing of the divalent based downhole treatment fluids at
a temperature of greater than about 200.degree. F., specifically
about 200.degree. F. to about 300.degree. F. For example, the
rheological modifiers can increase the yield point of the fluids
for up to about 66%. The addition of the rheological modifier
further improves the fluid loss control and lubricity of the
divalent based downhole treatment fluids.
[0015] Known additives typically used in the treatment fluids
include but are not limited to fluid loss control agents,
lubricants, pH modifiers, pH stabilizers, viscosifiers, weighting
agents, or a combination comprising at least one of the foregoing.
Exemplary pH modifiers include magnesium oxide, magnesium
hydroxide, calcium oxide, calcium hydroxide, zinc oxide, zinc
hydroxide, and the like. Suitable pH stabilizers include diamines
such as ethylene diamine. In an embodiment, the pH stabilizer
comprises ethylene diamine and about 1 to about 5 wt. % of a
polyimidazoline, based on the total weight of the pH stabilizer.
Exemplary weighting agents include calcium carbonate, magnesium
carbonate, zinc carbonate, calcium magnesium carbonate, manganese
tetra oxide and the like.
[0016] The divalent brine based downhole fluids can include
drilling fluids, completion fluids, or servicing fluids. As used
herein, the drilling fluids include drill-in fluids, which are
specially designed for drilling through the reservoir section of a
wellbore.
[0017] The divalent brine based downhole treatment fluids can have
a yield point of about 20 lb/100 ft.sup.2 to about 40 lb/100
ft.sup.2 and a plastic viscosity of 26 cP to 38 cP, each determined
by hot rolled fluid at 250.degree. F., rheological measurement by
OFITE 900 viscometer at 120.degree. F. The divalent brine based
downhole treatment fluids can also have a lubricity coefficient of
less than 0.13 measured by an OFITE Lubricity Meter. In some
embodiments, the divalent brine based downhole treatment fluids
have a low shear rate viscosity of greater than about 10,000 cP
measured by Brookfield viscometer using spindle S62 at 0.5 rpm.
When a diamine pH stabilizer is used, the divalent brine based
downhole treatment fluids can have a pH of greater than about
7.5.
[0018] The downhole fluids can be used in various applications. A
method of conducting a wellbore operation in a subterranean
formation comprises employing the divalent brine based downhole
treatment fluid in the wellbore operation. In an embodiment, a
method of drilling a wellbore in a subterranean formation comprises
circulating a drilling fluid in the subterranean formation. The
circulation path of the drilling fluid typically extends from the
drilling rig down through the drill pipe string to the bit face and
back up through the annular space between the drill pipe string and
wellbore face to the wellhead and/or riser, returning to the rig.
The drilling fluid performs a number of functions as it circulates
through the wellbore including cooling and lubricating the drill
bit, removing drill cuttings from the wellbore, aiding in support
of the drill pipe and drill bit, and providing a hydrostatic head
to maintain the integrity of the wellbore walls and prevent well
blowouts. The drilling fluid also desirably prevents sloughing and
wellbore cave-ins when drilling through water sensitive formations.
Drill-in fluids can minimize damage and maximize production of
exposed zones. In addition, drill-in fluids can facilitate well
completion.
[0019] The beneficial effects of using carboxylic acid ester and a
blend of phosphate ester and ethoxylated glycol in downhole
treatment compositions are further illustrated in the following
examples.
EXAMPLES
[0020] The materials used in the Examples are described in Table
1.
TABLE-US-00001 TABLE 1 Component Description Source, Vendor Fluid
loss additive Non Ionic Starch TBC-BRINADD, LLC MgO Thermasal B
TBC-BRINADD, LLC PH Stabilizer Diamine, BAKER HUGHES INC. Mil Carb
45 Calcium carbonate BAKER HUGHES INC. Mil Carb Fine Calcium
carbonate BAKER HUGHES INC. REV DUST Drill solid material BAKER
HUGHES INC. Phosphate Ester A blend of phosphate ester and
ethoxylated glycol BAKER HUGHES INC. Carboxylic acid ester Fatty
esters, RADIGREEN EME salt product OLEON N.V. Viscosifier
Polysacride TBC-BRINADD, LLC
[0021] Components of drilling fluids were mixed using Multimixer
for one hour. The drilling fluids were poured into pressurized
aging cells and maintained at 250.degree. F. for 16 hours hot
rolled. Post hot rolled rheological properties were measured by
OFITE 900 viscometer in accordance with API testing procedures.
HPHT fluid loss cell was used for fluid loss measurement. OFITE
Lubricity Meter was used for measuring lubricity coefficient.
Fluids were designed with 20 ppb, solid contamination (REV DUST)
and tested at 250.degree. F. Low shear rate viscosity measured by
Brookfield viscometer using spindle S62 at 0.5 rpm. The
formulations of the drilling fluids and their properties are shown
in Tables 2-6.
TABLE-US-00002 TABLE 2 14.4 lb/gal drill-in fluid using CaBr.sub.2
as the base fluid Components (ppb) 1 2 3 4 5 6 Calcium bromide
brine 537 535.50 533.94 531.60 531.06 525.07 Fluid loss additive 8
8 8 8 8 8 MgO 5 5 5 5 5 5 PH Stabilizer 3 3 3 3 3 3 MIL CARB 45 15
15 15 15 15 15 MIL CARB FINE 20 20 20 20 20 20 Phosphate ester -- 1
2 3.5 Carboxylic acid ester 3.5 7 Fluid Properties After Hot Rolled
at 250.degree. F. 600 rpm 91 94 111 115 95 104 300 rpm 59 61 73 77
62 70 200 rpm 47 48 58 61 46 53 100 rpm 31 32 41 44 32 36 6 rpm 11
11 13 14 10 14 3 rpm 9 9 10 12 8 13 Plastic viscosity, cP 32 33 38
38 33 34 Yield point, lb/100 ft.sup.2 27 28 35 39 29 36 10 Sec gel,
lb/100 ft.sup.2 8 8 10 11 8 11 10 Min gel, lb/100 ft.sup.2 9 9 11
11 9 12 30 Min gel, lb/100 ft.sup.2 9 9 11 11 9 12 HPHT filtrate
(mL/30 min) 8 6.4 6.4 6.8 7.6 7.6 pH 8 8 8 8 7.9 7.74 Lubricity
Coefficient 0.16 0.13 0.12 0.12 0.11 0.10 Low Shear Rate Viscosity,
cP 20580 23650 26330
TABLE-US-00003 TABLE 3 14.4 lb/gal drill-in fluid using calcium
bromide as the base fluid Components (ppb) 7 8 9 Calcium bromide
brine 539 536 533.64 Fluid loss additive 6 6 6 MgO 5 5 5 PH
Stabilizer 3 3 3 MIL CARB 45 15 15 15 MIL CARB FINE 20 20 20
Phosphate ester -- 2 3.5 Fluid Properties After Hot Rolled at
250.degree. F. 600 rpm 63 77 77 300 rpm 39 49 51 200 rpm 30 37 40
100 rpm 20 25 28 6 rpm 6 9 9 3 rpm 5 7 8 Plastic viscosity, cP 24
28 26 Yield point, lb/100 ft.sup.2 15 21 25 10 Sec gel, lb/100
ft.sup.2 4 5 7 10 Min gel, lb/100 ft.sup.2 5 7 7 30 Min gel, lb/100
ft.sup.2 6 8 8 HPHT filtrate (mL/30 min) 12 10 10.4 pH 8 8 8
Lubricity Coefficient 0.16 0.13 0.12
TABLE-US-00004 TABLE 4 14.4 lb/gal drill-in fluid using calcium
bromide as the base fluid with solid contaminations Components
(ppb) 1A 1B 1C Calcium bromide brine 537 526.84 531.97 Fluid loss
additive 8 8 8 Viscosifier 8 3.5 MgO 5 5 5 PH Stabilizer 3 3 3 MIL
CARB 45 15 15 15 MIL CARB FINE 20 20 20 Phosphate ester -- 3.5 3.5
REV DUST 20 20 20 Fluid Properties After Hot Rolled at 250.degree.
F. 600 rpm 84 104 91 300 rpm 53 68 61 200 rpm 42 52 46 100 rpm 28
35 32 6 rpm 8 12 11 3 rpm 7 10 10 Plastic viscosity, cP 31 36 30
Yield point, lb/100 ft.sup.2 22 32 31 10 Sec gel, lb/100 ft.sup.2 6
8 9 10 Min gel, lb/100 ft.sup.2 7 9 9 30 Min gel, lb/100 ft.sup.2 8
9 9 HPHT filtrate (mL/30 min) 7 7 7.2 pH 8 8 8
TABLE-US-00005 TABLE 5 12 lb/gal drill-in fluid using calcium
bromide and calcium chloride as the base fluid Components (ppb) 2A
2B CaBr.sub.2 (14.2 ppg ) + CaCl.sub.2 brine (11.6 ppg ) 465 461.5
Fluid loss additive 8 8 MgO 5 5 PH Stabilizer 3 3 MIL CARB 45 15 15
MIL CARB FINE 20 20 Phosphate ester -- 3.5 Fluid Properties After
Hot Rolled at 250.degree. F. 600 rpm 74 97 300 rpm 46 62 200 rpm 36
49 100 rpm 24 34 6 rpm 7 12 3 rpm 6 10 Plastic viscosity, cP 28 35
Yield point, lb/100 ft.sup.2 18 27 10 Sec gel, lb/100 ft.sup.2 5 9
10 Min gel, lb/100 ft.sup.2 6 10 30 Min gel, lb/100 ft.sup.2 7 11
HPHT filtrate (mL/30 min) 8.2 7.4 HPHT fluid loss, ml/30 mm
250.degree. F./500 psi using 55 4.8 3 pH 8.6 8.62 Lubricity
Coefficient 0.13 0.10 Low Shear Rate Viscosity, cP 14357 15125
TABLE-US-00006 TABLE 6 pH enhancement in divalent brine using
diamine based pH stabilizer Components (ppb) 3A 3B 3C Calcium
bromide brine, 14.2 lb/gal 537 534 534 Fluid loss additive 8 8 8
Viscosifier 10 10 10 MgO 5 5 5 PH Stabilizer -- 3 3 MIL CARB 45 10
10 10 MIL CARB FINE 20 20 20 Phosphate ester -- 3.5 Carboxylic acid
ester 3.5 Fluid Properties After Hot Rolled at 250.degree. F. 600
rpm 93 102 115 300 rpm 60 68 78 200 rpm 48 54 62 100 rpm 32 38 44 6
rpm 8 14 17 3 rpm 7 12 15 Plastic viscosity, cP 33 34 37 Yield
point, lb/100 ft.sup.2 27 34 41 10 Sec gel, lb/100 ft.sup.2 6 10 14
10 Min gel, lb/100 ft.sup.2 6 10 15 30 Min gel, lb/100 ft.sup.2 6
11 15 pH 7.4 8.30 8.10
[0022] After addition of the rheological modifier to divalent brine
based fluids, significant changes in plastic viscosity, yield
point, Low shear rate viscosity, fluid loss, and lubricity of the
fluids were observed.
[0023] The results indicate that carboxylic acid esters or a
phosphate ester blended with ethoxylated glycol are effective to
enhance the rheological and multifunctional properties of divalent
based fluids including those contaminated with Rev Dust.
[0024] Set forth below are various embodiments of the
disclosure.
[0025] Embodiment 1. A method of improving rheological properties
of a divalent brine based downhole treatment fluid at an elevated
temperature, the method comprising: adding to the divalent brine
based downhole treatment fluid a rheological modifier comprising a
carboxylic acid ester, or a phosphate ester blended with an
ethoxylated glycol, or a combination comprising at least one of the
foregoing in an amount effective to improve the rheological
properties of the divalent brine based downhole treatment fluid at
a temperature of greater than about 200.degree. F., the divalent
brine based downhole treatment fluid comprising calcium bromide,
calcium chloride, zinc bromide, zinc chloride, or a combination
comprising at least one of the foregoing.
[0026] Embodiment 2. The method of any of the proceeding
embodiments, wherein the carboxylic acid ester has a formula
##STR00003##
wherein R.sup.1 and R.sup.2 are each independently a C.sub.1-26
alkyl, C.sub.2-26 alkenyl, or C.sub.2-26 alkynyl group.
[0027] Embodiment 3. The method of claim 2, wherein R.sup.1 is a
C.sub.6-20 alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl group;
and R.sup.2 is methyl. Alternatively, R.sup.1 is a C.sub.8-14
alkyl; and R.sup.2 is a C.sub.6-20 alkyl, C.sub.6-20 alkenyl, or
C.sub.6-20 alkynyl group.
[0028] Embodiment 4. The method of any of the proceeding
embodiments, wherein the ethoxylated glycol comprises ethoxylated
ethylene glycol, ethoxylated propylene glycol, ethoxylated
glycerin, ethoxylated polyethylene glycol, ethoxylated
polypropylene glycol, or a combination comprising at least one of
the foregoing.
[0029] Embodiment 5. The method of any of the proceeding
embodiments, wherein the phosphate ester is a hydrocarbyl polyether
phosphate ester optionally comprising one or two hydroxyl groups
directly attached to phosphorus.
[0030] Embodiment 6. The method of any of the proceeding
embodiments, wherein the rheological modifier is added to the
divalent brine based downhole treatment fluid in an amount of about
1 to about 12 pounds of the modifier per barrel of the divalent
brine based downhole treatment fluid.
[0031] Embodiment 7. The method of any of the proceeding
embodiments, wherein the divalent brine based downhole treatment
fluid comprises about 10 to about 18 pounds per gallons of calcium
bromide, calcium chloride, or a combination thereof.
[0032] Embodiment 8. The method of any of the proceeding
embodiments, further comprising adding one or more of the following
additional component to the divalent brine based downhole treatment
fluid: a fluid loss control agent; a lubricant, a pH modifier; a pH
stabilizer; a viscosifier; or a weighting agent. The pH stabilizer
comprises a diamine, and the divalent brine based downhole
treatment fluid with the diamine has a pH of greater than about
7.5.
[0033] Embodiment 9. The method of any of the proceeding
embodiments, wherein the rheological properties comprise yield
point, low-shear-rate-viscosity, or a combination comprising at
least one of the foregoing.
[0034] Embodiment 10. The method of any of the proceeding
embodiments, wherein the addition of the rheological modifier
further improves the fluid loss control and lubricity of the
divalent based downhole treatment fluid.
[0035] Embodiment 11. A method of conducting a wellbore operation
in a subterranean formation, the method comprising: employing in
the wellbore operation a divalent brine based drilling or servicing
fluid comprising a divalent brine comprising calcium bromide,
calcium chloride, zinc bromide, zinc chloride, or a combination
comprising at least one of the foregoing; and an rheological
modifier comprising a carboxylic acid ester, or a phosphate ester
blended with an ethoxylated glycol, or a composition comprising at
least one of the foregoing.
[0036] Embodiment 12. The method of any of the proceeding
embodiments, wherein the carboxylic acid ester has a formula I or
II
##STR00004##
wherein R.sup.1 and R.sup.2 are each independently a C.sub.6-20
alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl group.
[0037] Embodiment 13. The method of any of the proceeding
embodiments, wherein the divalent brine based downhole treatment
fluid comprises about 10 to about 18 pounds per gallons of calcium
bromide, calcium chloride, or a combination thereof; and about 1 to
about 12 pounds of the modifier per barrel of the divalent brine
based downhole treatment fluid.
[0038] Embodiment 14. A divalent brine based downhole treatment
fluid comprising: about 10 to about 18 pounds per gallons of a
divalent brine comprising calcium bromide, calcium chloride, zinc
bromide, zinc chloride, or a combination comprising at least one of
the foregoing; and about 1 to about 12 pounds of a rheological
modifier per barrel of the divalent brine based downhole treatment
fluid, the rheological modifier comprising a carboxylic acid ester,
or a phosphate ester blended with an ethoxylated glycol, or a
composition comprising at least one of the foregoing.
[0039] Embodiment 15. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments, wherein the carboxylic
acid ester has a formula I or II
##STR00005##
wherein R.sup.1 and R.sup.2 are each independently a
C.sub.6-20alkyl, C.sub.6-20 alkenyl, or C.sub.6-20 alkynyl
group.
[0040] Embodiment 16. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments, wherein the ethoxylated
glycol comprises ethoxylated ethylene glycol, ethoxylated propylene
glycol, ethoxylated glycerin, ethoxylated polyethylene glycol,
ethoxylated polypropylene glycol, or a combination comprising at
least one of the foregoing; and the phosphate ester is a
hydrocarbyl polyether phosphate ester optionally comprising one or
two hydroxyl groups directly attached to phosphorus.
[0041] Embodiment 17. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments further comprising a
diamine based pH stabilizer, and the fluid has a pH of greater than
about 7.5.
[0042] Embodiment 18. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments, wherein the fluid has a
yield point of about 20 lb/100 ft.sup.2 to about 40 lb/100 ft.sup.2
and a plastic viscosity of 26 cP to 38 cP, each determined by OFITE
900 viscometer at 120.degree. F., after hot rolled fluid at
250.degree. F.
[0043] Embodiment 19. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments, wherein the fluid has a
low shear rate viscosity of greater than 10,000 cP measured by
Brookfield viscometer using spindle S62 at 0.5 rpm.
[0044] Embodiment 20. The divalent brine based downhole treatment
fluid of any of the proceeding embodiments, wherein the fluid has a
lubricity coefficient of less than 0.13 measured by an OFITE
Lubricity Meter.
[0045] All ranges disclosed herein are inclusive of the endpoints,
and the endpoints are independently combinable with each other. As
used herein, "combination" is inclusive of blends, mixtures,
alloys, reaction products, and the like. All references are
incorporated herein by reference in their entirety.
[0046] The use of the terms "a" and "an" and "the" and similar
referents in the context of describing the invention (especially in
the context of the following claims) are to be construed to cover
both the singular and the plural, unless otherwise indicated herein
or clearly contradicted by context. "Or" means "and/or." The
modifier "about" used in connection with a quantity is inclusive of
the stated value and has the meaning dictated by the context (e.g.,
it includes the degree of error associated with measurement of the
particular quantity).
* * * * *