CA2517093C - Compositions and methods of cementing in subterranean formations using a swelling agent to inhibit the influx of water into a cement slurry - Google Patents
Compositions and methods of cementing in subterranean formations using a swelling agent to inhibit the influx of water into a cement slurry Download PDFInfo
- Publication number
- CA2517093C CA2517093C CA2517093A CA2517093A CA2517093C CA 2517093 C CA2517093 C CA 2517093C CA 2517093 A CA2517093 A CA 2517093A CA 2517093 A CA2517093 A CA 2517093A CA 2517093 C CA2517093 C CA 2517093C
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- CA
- Canada
- Prior art keywords
- swelling agent
- subterranean formation
- water
- cement slurry
- cement
- Prior art date
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Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 118
- 229910001868 water Inorganic materials 0.000 title claims abstract description 118
- 230000008961 swelling Effects 0.000 title claims abstract description 115
- 239000004568 cement Substances 0.000 title claims abstract description 113
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 97
- 239000002002 slurry Substances 0.000 title claims abstract description 70
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 53
- 238000000034 method Methods 0.000 title claims abstract description 44
- 239000000203 mixture Substances 0.000 title claims abstract description 27
- 238000005755 formation reaction Methods 0.000 title abstract description 23
- 230000004941 influx Effects 0.000 title description 15
- 239000012530 fluid Substances 0.000 claims abstract description 42
- 238000010521 absorption reaction Methods 0.000 claims abstract description 5
- 229920000642 polymer Polymers 0.000 claims description 44
- 239000000243 solution Substances 0.000 claims description 25
- XZPVPNZTYPUODG-UHFFFAOYSA-M sodium;chloride;dihydrate Chemical compound O.O.[Na+].[Cl-] XZPVPNZTYPUODG-UHFFFAOYSA-M 0.000 claims description 23
- 239000000654 additive Substances 0.000 claims description 17
- 239000013505 freshwater Substances 0.000 claims description 16
- 238000005086 pumping Methods 0.000 claims description 11
- 230000000996 additive effect Effects 0.000 claims description 10
- 230000009974 thixotropic effect Effects 0.000 claims description 10
- 229920002401 polyacrylamide Polymers 0.000 claims description 6
- 230000008569 process Effects 0.000 claims description 6
- PQUXFUBNSYCQAL-UHFFFAOYSA-N 1-(2,3-difluorophenyl)ethanone Chemical group CC(=O)C1=CC=CC(F)=C1F PQUXFUBNSYCQAL-UHFFFAOYSA-N 0.000 claims description 4
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 4
- 150000003839 salts Chemical class 0.000 claims description 4
- 229940047670 sodium acrylate Drugs 0.000 claims description 4
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 3
- -1 carboxyalkyl polysaccharide Chemical class 0.000 claims description 3
- 229920006037 cross link polymer Polymers 0.000 claims description 3
- 230000007423 decrease Effects 0.000 claims description 3
- 230000003111 delayed effect Effects 0.000 claims description 3
- 239000007800 oxidant agent Substances 0.000 claims description 3
- 229920002134 Carboxymethyl cellulose Polymers 0.000 claims description 2
- 239000005708 Sodium hypochlorite Substances 0.000 claims description 2
- 229920002472 Starch Polymers 0.000 claims description 2
- 239000001768 carboxy methyl cellulose Substances 0.000 claims description 2
- 235000010948 carboxy methyl cellulose Nutrition 0.000 claims description 2
- 125000004181 carboxyalkyl group Chemical group 0.000 claims description 2
- 125000002057 carboxymethyl group Chemical group [H]OC(=O)C([H])([H])[*] 0.000 claims description 2
- 239000008112 carboxymethyl-cellulose Substances 0.000 claims description 2
- 239000001913 cellulose Substances 0.000 claims description 2
- 229920002678 cellulose Polymers 0.000 claims description 2
- 229930195733 hydrocarbon Natural products 0.000 claims description 2
- 150000002430 hydrocarbons Chemical class 0.000 claims description 2
- 229920000058 polyacrylate Polymers 0.000 claims description 2
- 229920002239 polyacrylonitrile Polymers 0.000 claims description 2
- 229920001282 polysaccharide Polymers 0.000 claims description 2
- 239000005017 polysaccharide Substances 0.000 claims description 2
- 239000001103 potassium chloride Substances 0.000 claims description 2
- 235000011164 potassium chloride Nutrition 0.000 claims description 2
- SUKJFIGYRHOWBL-UHFFFAOYSA-N sodium hypochlorite Chemical group [Na+].Cl[O-] SUKJFIGYRHOWBL-UHFFFAOYSA-N 0.000 claims description 2
- 239000008107 starch Substances 0.000 claims description 2
- 235000019698 starch Nutrition 0.000 claims description 2
- 239000004215 Carbon black (E152) Substances 0.000 claims 1
- 230000001010 compromised effect Effects 0.000 abstract description 3
- 239000011148 porous material Substances 0.000 abstract description 2
- 229910003460 diamond Inorganic materials 0.000 description 25
- 239000010432 diamond Substances 0.000 description 25
- 238000012360 testing method Methods 0.000 description 16
- 239000012267 brine Substances 0.000 description 8
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 8
- 238000005553 drilling Methods 0.000 description 7
- 239000007788 liquid Substances 0.000 description 7
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 6
- 239000011398 Portland cement Substances 0.000 description 4
- 239000000440 bentonite Substances 0.000 description 4
- 229910000278 bentonite Inorganic materials 0.000 description 4
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 4
- 230000036571 hydration Effects 0.000 description 4
- 238000006703 hydration reaction Methods 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- 108091006629 SLC13A2 Proteins 0.000 description 3
- 239000013078 crystal Substances 0.000 description 3
- 230000006866 deterioration Effects 0.000 description 3
- 230000003068 static effect Effects 0.000 description 3
- 230000008719 thickening Effects 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- NIXOWILDQLNWCW-UHFFFAOYSA-N acrylic acid group Chemical group C(C=C)(=O)O NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 2
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 239000001110 calcium chloride Substances 0.000 description 2
- 235000011148 calcium chloride Nutrition 0.000 description 2
- 230000015556 catabolic process Effects 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 230000001143 conditioned effect Effects 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 239000011396 hydraulic cement Substances 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003921 oil Substances 0.000 description 2
- 229910052760 oxygen Inorganic materials 0.000 description 2
- 239000001301 oxygen Substances 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 238000000518 rheometry Methods 0.000 description 2
- 239000012266 salt solution Substances 0.000 description 2
- 235000011121 sodium hydroxide Nutrition 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000007704 transition Effects 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- 239000004971 Cross linker Substances 0.000 description 1
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 1
- 239000004115 Sodium Silicate Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 230000002745 absorbent Effects 0.000 description 1
- 239000002250 absorbent Substances 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 229910052782 aluminium Inorganic materials 0.000 description 1
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 239000007844 bleaching agent Substances 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000003750 conditioning effect Effects 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 239000008367 deionised water Substances 0.000 description 1
- 229910021641 deionized water Inorganic materials 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000012631 diagnostic technique Methods 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- 239000002270 dispersing agent Substances 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 150000002148 esters Chemical class 0.000 description 1
- ZZUFCTLCJUWOSV-UHFFFAOYSA-N furosemide Chemical compound C1=C(Cl)C(S(=O)(=O)N)=CC(C(O)=O)=C1NCC1=CC=CO1 ZZUFCTLCJUWOSV-UHFFFAOYSA-N 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 150000004676 glycans Chemical class 0.000 description 1
- 239000010440 gypsum Substances 0.000 description 1
- 229910052602 gypsum Inorganic materials 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000005304 joining Methods 0.000 description 1
- 230000000670 limiting effect Effects 0.000 description 1
- 238000002595 magnetic resonance imaging Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 239000000178 monomer Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000008439 repair process Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 150000004760 silicates Chemical class 0.000 description 1
- 229910052710 silicon Inorganic materials 0.000 description 1
- 239000010703 silicon Substances 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- NTHWMYGWWRZVTN-UHFFFAOYSA-N sodium silicate Chemical compound [Na+].[Na+].[O-][Si]([O-])=O NTHWMYGWWRZVTN-UHFFFAOYSA-N 0.000 description 1
- 229910052911 sodium silicate Inorganic materials 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 238000012549 training Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
- C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B2103/00—Function or property of ingredients for mortars, concrete or artificial stone
- C04B2103/0045—Polymers chosen for their physico-chemical characteristics
- C04B2103/0049—Water-swellable polymers
Abstract
Methods of cementing in subterranean formations, cement compositions, and methods for making the compositions are provided. A cement slurry is passed into a subterranean formation, and a swelling agent is passed into the subterranean formation to reduce an amount of water flowing into the cement slurry. The swelling agent may be combined with a carrier fluid before being displaced into the subterranean formation. Alternatively, the swelling agent may be pre-mixed with the cement slurry to form a new cement composition, followed by displacing the cement composition into the subterranean formation.
The swelling agent is present in an amount effective to, upon absorption of water and swelling to form a gel mass, substantially block the flow path of the water into the cement composition or reduce losses to low pore pressure intervals, thereby preventing the integrity of the cement composition from being compromised or lost to voidage, fractures, fissures, etc.
The swelling agent is present in an amount effective to, upon absorption of water and swelling to form a gel mass, substantially block the flow path of the water into the cement composition or reduce losses to low pore pressure intervals, thereby preventing the integrity of the cement composition from being compromised or lost to voidage, fractures, fissures, etc.
Description
COMPOSITIONS AND METHODS OF CEMENTING IN SUBTERRANEAN
FORMATIONS USING A SWELLING AGENT TO ]NMIT THE INFLUX OF
WATER INTO A CEMENT SLURRY
FIELD OF THE INVENTION
This invention generally relates to compositions and methods for cementing in subterranean formations. More specifically, the invention relates to introducing a swelling agent to a subterranean formation to reduce the amount of water flowing into a cement slurry placed in the subterranean formation, thereby preventing the integrity of the cement slurry from being compromised.
BACKGROUND OF THE INVENTION
Well cementing is a process used in penetrating subterranean formations that produce oil and gas. In well cementing, a well bore is drilled while a drilling fluid is circulated through the well bore. The circulation of the drilling fluid is then terminated, and a string of pipe, e.g., casing, is run in the well bore. The drilling fluid in the well bore is conditioned by circulating it downwardly through the interior of the pipe and upwardly through the annulus, which is located between the exterior of the pipe and the walls of the well bore. Next, primary cementing is typically performed whereby a slurry of cement in water is placed in the annulus and permitted to set, i.e., harden into a solid mass, to thereby attach the string of pipe to the mfalls of the well bore and seal the annulus. Subsequent secondary cementing operations, i.e., any cementing operation after the primary cementing operation, may also be performed. One example of a secondary cementing operation is squeeze cementing whereby a cement slurry is forced under pressure to areas of lost integrity in the annulus to seal off those areas.
One problem commonly encountered during primary and secondary cementing operations is the movement of water from the subterranean formation into the well bore, resulting in the influx of water into cement slurries that have been placed in the well bore. In particular, the influx of water occurs during a transition phase in which the cement slurry changes from a true hydraulic fluid to a highly viscous mass showing some solid characteristics. When first placed in the well bore, the cement slurry acts as a true liquid and thus transmits hydrostatic pressure. During the transition phase, certain events occur that cause the cement slurry to lose its ability to transmit hydrostatic pressure. One of those events is the loss of fluid from the slurry to the subterranean zone. Another event is the development of static gel strength, i.e., stiffness, in the slurry. When the pressure exerted on the formation by the cement slurry falls below the pressure of the water in the formation, the water begins to flow into and through the cement slurry. This influx of water can occur during dynamic and static states of the cement slurry.
As a result of water influxes into and crossflows through the cement slurry, flow channels form therein that remain after the cement slurry has completely set.
Those flow channels allow the water to flow from one subterranean zone to another such that zonal isolation is no longer achieved. Further, the water intermixes with and dilutes the cement slurry, causing deterioration of the cement properties such as its density, its final compressive strength, and its rheology. As such, the water adversely affects the integrity of the cement.
Secondary cementing is often used to repair the lost integrity of the cement placed in the annulus during primary cementing. However, the cement slurries employed during secondary cementing also become deteriorated due to the continued influx of water. The secondary cementing operation therefore may fail to perform as designed in forming a sealing or blocking mechanism.
Repairing the deteriorated cement can be both time consuming and costly. As such, various chemicals have been used to attempt to prevent the influx of water into the cement. For example, silicates such as sodium silicate have been added to the cement or injected ahead of the cement to react with it, hydrate it, and cause it to set more quickly.
Other chemicals have been added to the cement to increase its Ascosity and make it less permeable to water.
However, such chemicals often become diluted and dispersed before they can effectively inhibit the influx of water. It would therefore be desirable to develop improved processes for protecting cement slurries against deterioration caused by the influx of water.
The present invention includes methods for performing well cementing.
According to an embodiment, a cement slurry is passed into a subterranean formation, and a swelling agent is also passed into the subterranean formation to reduce an amount of water flowing into the cement slurry. The swelling agent may be combined with a carrier fluid that is displaced into the subterranean formation before the cement slurry is displaced therein.
Alternatively, the swelling agent may be pre-mixed with the cement slurry, followed by concurrently displacing the swelling agent and the cement slurry into the subterranean formation.
After passing into the subterranean formation, the swelling agent absorbs water therein. As the swelling agent absorbs water, it swells to form a gel mass that substantially blocks the flow path of water into the cement slurry placed in the subterranean formation. Accordingly, the swelling agent helps prevent the integrity of the cement slurry from being compromised by the influx and crossflows of water.
The present invention further includes cement compositions and methods for making the cement composition. The cement compositions comprise cement combined with a swelling agent that is capable of absorbing water and of swelling as it absorbs the water. The swelling agent is also insoluble in water and thus resists dilution by water in the subterranean formation. The swelling agent is preferably a crosslinked polyacrylamide.
DETAILED DESCRIPTION OF THE PREFERRED EIVIBODIMENTS
According to the present invention, well cementing methods are performed in which an effective amount of one or more swelling agents is passed into a well bore to reduce the influx of water into a cement slurry placed in the well bore. The presence of the swelling agent in the well bore serves to reduce the amount of water available to intemiix with and dilute the cement slurry. The swelling agent may be placed into the well bore before the cement is passed into the well bore, concurrent with the passing of cement into the well bore, or after the cement is passed into the wellbore.
According to preferred embodiments, a primary cementing process is carried out according to standard well cementing practices. The primary cementing process includes drilling a well bore down to a, subterranean zone while circulating a drilling fluid through the well bore. A string of pipe, e.g., casing, is then run in the well bore. The drilling fluid is conditioned by circulating it downwardly through the interior of the pipe and upwardly through the annulus, which is located between the exterior of the pipe and the walls of the well bore. A
carrier solution containing the swelling agent and a carrier fluid may then be displaced into the well bore, followed by displacing a cement slurry down through the pipe and up through the annulus in the well bore. Alternatively, the swelling agent may be combined with the cement slurry before concurrently displacing the swelling agent and the cement slurry into the well bore.
Any secondary cementing operations known in the art may also be performed using the swelling agent. For example, the cement sheath formed in the annulus as a result of primary cementing may contain permeable areas such as fractures, fissures, high permeability streaks, and/or annular voids through which water can flow. Channels of water thus may undesirably flow behind the casing. A cement squeezing technique may be employed to force cement into the permeable areas or voidage so as to seal or block the flow paths of water.
Before performing cement squeezing, a swelling agent may be displaced into the well bore via a carrier fluid, or alternatively, it may be combined with a cement slurry before the slurry is displaced into the well bore.
In an embodiment, the well bore is monitored to detect and locate sources of water (such as fissures, cracks, fractures, streaks, flow channels, voids and the like) that are suitable for plugging via introduction of the swelling agent. Any suitable means or methods for locating such sources of water may be used as known to those of skill in the art. For example, prior to injecting the swelling agent into the well bore, production logs such as temperature, fluid density, hydro, and flowmeter logs can be used singly or in combination to detect where water is flowing into the well bore. In addition, a magnetic resonance imaging log (MRIL) tool may be employed to analyze the well bore to determine where mobile water is present.
Additional disclosure regarding MRIL tools can be found in U.S. Patent No.
6,283,210.
Another diagnostic technique that may be utilized to locate flowing water in the well bore involves exciting oxygen molecules. In addition, a 360 depth of view tool may be used to examine the well bore for fractures, fissures, streaks, and voids.
Detecting the locations of flowing water in the well bore allows the swelling agent to be strategically placed in close proximity to the source of the flowing water.
For example, the swelling agent can be placed in fractures, fissures, streaks, and voids found in the rock surrounding the well bore or in the cement sheath located in the annulus of the well bore.
Preferably, the swelling agent does not immediately absorb water but begins to absorb water after there has been sufficient time to place it downhole in close proximity to the water source. While downhole, the swelling agent begins to absorb the water and swell into a gel mass that is substantially resistant to the flow of water therethrough, thereby effectively plugging the fractures, fissures, streaks, and voids through which the water could otherwise pass for at least a period of time sufficient to allow the cement to set up, harden, and thus become impervious to further degradation with a potential form influx or flow of water from formation sources.
The swelling agent is defined as and may be any suitable material that absorbs water and swells, (i.e., expands) as it absorbs the water. Preferably, the swelling agent is insoluble in water and thus avoids becoming diluted and washed away by the water flowing through the well bore. More preferably, the swelling agent forms a gel mass upon swelling that can be effective for blocking a flow path of the water into the cement slurry. Most preferably, the gel mass has a relatively low permeability to water and thus creates a barrier between the water and cement slurries placed in the well bore. A gel is herein defined as a crosslinked polymer network swollen in a liquid. Preferably, the crosslinker is part of the polymer and thus will not absorb out of the polymer. Suitable swelling agents include those known as superabsorbents, which are commonly used in absorbent products such as diapers, training pants, and feminine care products. Superabsorbents are swellable crosslinked polymers, which have the ability to absorb and store many times their own weight of aqueous liquids by forming a gel. The superabsorbents retain the liquid that they absorb and typically do not release the liquid, even under pressure. Examples of superabsorbents are sodium acrylate-based polymers having three dimensional, network-like molecular structures. The polymer chains are formed by the reaction/joining of millions of identical units of acrylic acid monomer, which have been substantially neutralized with sodium hydroxide (caustic soda). Crosslinking chemicals tie the chains togetller to form a three-dimensional network, enabling the superabsorbents to absorb water or water-based solutions into the spaces in the molecular network, and thus forming a gel and locking up the liquid.
Examples of suitable swelling agents include, but are not limited to, polyacrylamide, polyacrylate, hydrolyzed polyacrylonitrile, carboxyalkyl cellulose, carboxymethyl starch, salts of carboxymethyl cellulose, carbw~yalkyl polysaccharide, and combinations thereof. The swelling agent is preferably a crystalline polymer that has been dehydrated, more preferably a crosslinked polyacrylamide, and most preferably a crosslinked polyacrylamide in the form of a hard crystal.
A crosslinked polyacrylamide known as DIAMOND SEAL polymer may be purchased from Baroid Drilling Fluids, Inc. The DIAMOND SEAL polymer is available in grind sizes of 1 mm, 4 nun, and 14 mm and may be ground even smaller if needed. For example, a smaller grind size may be required to allow its crystals to enter very small fractures, fissures, and so forth. The DIAMOND SEAL polymer possesses certain qualities that make it an exceptional swelling agent. For example, the DIAMOND SEAL polymer is water-insoluble and is resistant to deterioration by carbon dioxide, bacteria, and subterranean minerals.
Further, the DIAMOND SEAL polymer can withstand temperatures up to at least 250 F without experiencing breakdown and thus may be used in the majority of locations where well bores are drilled. Other suitable swelling agents are described in European Patent No.
0566118.
The swelling agent is preferably hydrophilic and is thus physically attracted to water molecules. In the case where the swelling agent is a crystalline polymer, the polymer chain deflects and surxounds the water molecules during water absorption. In effect, the polymer undergoes a change from that of a dehydrated crystal to that of a hydrated gel as it absorbs water.
Once fully hydrated, the gel preferably exhibits a high resistance to the migration or water therethrough. That is, the molecules of the gel are sufficiently packed together to substantially inhibit water from passing through the gel. Further, the gel can plug permeable areas of the well bore or the cement sheath because it can withstand substantial amounts of pressure without being dislodged or extruded.
As the swelling agent undergoes hydration, its physical size increases by about 10 to 400 times its original volume. The amount and rate by which the swelling agent increases in size vary depending upon its temperature, its grain size, and the ionic strength of the carrier fluid. The temperature of a well bore generally increases from top to bottom such that the rate of swelling increases as the swelling agent passes downhole. The rate of swelling also increases as the grain size of the swelling agent increases and as the ionic strength of the carrier fluid increases. For example, the mass of a DIAMOND SEAL polymer having a 14 mm grind size increases by 0% in 20 minutes after contacting water at 80 F, 150% in 35 minutes after contacting the water, and 400% in 45 minutes after contacting the water. The mass of the DIAMOND SEAL
polymer increases by 0% in 15 minutes after contacting water at 145 F, 200% in 25 minutes after contacting the water, and 400% in 35 minutes after contacting the water. The mass of the DIAMOND SEAL polymer increases by 0 lo in 45 minutes after contacting 9.2 pounds/gallon (ppg) brine water at 80 F, 25% in 60 minutes after contacting the brine water and 50% in 75 minutes after contacting the brine water. The mass of the DIAMOND SEAL polymer increases by 0% in 30 minutes after contacting 9.2 ppg brine water at 145 F, 25% in 45 minutes after contacting the brine water, and 50% in 60 minutes after contacting the brine water.
The amount by which the swelling agent increases in size as it swells decreases as an ionic strength of the carrier fluid increases.
According to some embodiments, the swelling agent may be combined with a carrier fluid to form a carrier solution before being placed in a well bore. The carrier fluid may be any suitable fluid for moving the swelling agent to desired locations in the well bore. The swelling agent is incorporated therein in an effective amount for plugging a source of water upon being placed down hole and the effective amount may vary depending on factors such as the type of the carrier fluid, the amount of mobile water flow in the well bore, the size of the water source (i.e., size of a fracture, fissure, etc.), and the like. The carrier fluid is preferably a pumpable fluid. Examples of carrier fluids with which the swelling agent may be combined include but are not limited to fresh water, deionized water, brine water of varying salinity, chloride solutions such as calcium dichloride and potassium chloride solutions, hydrocarbons such as produced oil and diesel oil, and synthetic fluids such as ester or polymer based fluids. The amount of swelling agent that may be combined with the carrier fluid depends on a number of factors including the type of carrier fluid, the volume capacities of the well's tubulars in conjunction with the placement rate logistical timing, the flow rate and pressure from the mobile water in and intruding into the well bore, and diagnostics performed to define the apparent voidage or communicating areas. Because swelling of the swelling agent may be delayed until the swelling agent is placed downhole, preferably the carrier fluid contains relatively high concentrations of the swelling agent and remains sufficiently non-viscous in order to be pumped downhole. In general, the swelling agent may be present in the carrier fluid in an amount of from about 0.001 to about 5.0 ppg, more preferably from about 0.01 to about 2.0 ppg. The carrier fluid containing the swelling agent is displaced into the well bore before cement slurries are displaced into the well bore. The designed placement procedure may address sucli conditions as loss circulation (fluid within the wellbore lost to particular portions of the formations and depth intervals), encountered intervals with crossflowing water, and influxes of water. As a result, the viscosities and rheologies of the subsequently placed cement slurries are less likely to be altered by the carrier fluid.
According to alternative embodiments, the swelling agent may be combined with a cement composition before being placed in a well bore. Cement compositions of the present invention may contain cements such as hydraulic cement composed of calcium, aluminum, silicon, oxygen, and/or sulfur which sets and hardens by reaction with water.
Examples of hydraulic cements are Portland cements, pozzolan cements, gypsum cements, high alumina content cements, silica cements, and high alkalinity cements. The cement is preferably a Portland cement, more preferably a class A, B, C, G, or H Portland cement, and most preferably a class C or H Portland cement. A sufficient amount of fluid may also be added to the cement to form a pumpable cementitious slurry. The fluid is preferably fresh water or salt water, e.g., an unsaturated aqueous salt solution or a saturated aqueous salt solution such as brine or seawater. An effective amount of swelling agent is combined with such cement compositions to plug a source of water upon placing the cement down hole, and the effective amount may vary depending on factors such as the type of cement, the amount of mobile water flow in the well bore, the pore pressure and influx rate of the water source (i.e., size of a fracture, fissure, etc.), and the like. In general, the cement compositions may contain from about 1 to about 50 % by weight swelling agent per total weight of a cement composition such that a density of the cement composition ranges from about 9.0 to about 12.0 pounds per gallon.
As deemed appropriate by one skilled in the art, additional additives may be added to the cement compositions for improving or changing the properties of the cement composition.
Examples of such additives include, but are not limited to set, fluid loss control additives, de-foamers, dispersing agents, set accelerators, and formation conditioning agents. Such cement compositions may be made by any suitable method as known to those of skill in the art.
If desired, the swelling agent may be removed from the well bore or area of its placement after it has been used for its intended purpose. If the swelling agent is a polymer, the backbone structure of the polymer may be broken down such that it becomes more like a liquid.
Any known means may be used to break down or collapse the polymer. For example, the polymer may be contacted with an oxidizer such as sodium hypochlorite (i.e., bleach), or combinations thereof to eliminate the polymer from the well bore, preferably by pumping such compounds down the well bore and contacting the swollen swelling agent in situ.
The invention having been generally described, the following examples are given as particular embodiments of the invention and to demonstrate the practice and advantages hereof. It is understood that the examples are given by way of illustration and are not intended to limit the specification or the claims to follow in any manner.
Different grind sizes of the DIAMOND SEAL polymer (DS) were mixed with various carrier solutions at different concentrations to form several test samples.
These carrier solutions were fresh water, field produced brine water, NaCI brine made by adding NaC1 to fresh water, and CaCl2 aqueous solution made by adding CaC12 to fresh water.
The test samples were then subjected to different temperatures and observed to determine the swelling time and the amount of swelling of the DIAMOND SEAL polymer. Table 1 below shows the results of this example.
Table 1 DIAMON Carrier Fluid Concentration of Temp., Initial Final Swelling D SEAL DS in Carrier F Hydrati Hydration Increase, Polymer Fluid on, , hr.:min. % By Grind Size hr.:m.in. Volume 425 - 1000 Fresh Water 0.2 lb/gal (ppg) 80 0:09 0:15 400 microns 0.4 ppg 80 0:09 0:15 400 0.5 ppg 80 0:09 0:15 400 425 - 1000 Fresh Water 0.2 ppg 120 0:03 0:09 400 microns 0.4 ppg 120 0:03 0:09 400 0.5 ppg 120 0:03 0:09 400 4 mm Fresh Water 0.2 ppg 80 0:18 0:25 500 0.4 ppg 80 0:18 0:25 500 0.5 ppg 80 0:18 0:25 450 4 mm Fresh Water 0.2 ppg 120 0:14 0:20 500 0.4 ppg 120 0:14 0:20 450 0.5 ppg 120 0:14 0:20 400 14 mm Fresh Water 0.2 ppg 80 0:20 0:30 500 0.4 ppg 80 0:20 0:25 450 0.5 ppg 80 0:20 0:25 400 14 Ynrn Fresh Water 0.2 ppg 120 0:17 0:25 500 0.4 ppg 120 0:16 0:25 450 0.5 ppg 120 0:16 0:25 400 425 - 1000 Brine Water, 0.2 ppg 80 0:25 0:28 150 microns 9.5 0.4 ppg 80 0:20 0:28 125 425 - 1000 Brine Water, 0.2 ppg 120 0:15 0:25 150 microns 9.5 ppg 0.4 ppg 120 0:15 0:25 125 4 mm Brine Water, 0.5 ppg 80 0:20 0:33 150 9.5 p a 1.0 ppg 80 0:20 0:30 100 4 mm Brine Water, 0.5 ppg 120 0:18 0:30 175 9.5 1.0 ppg 120 0:18 0:27 150 14 mm Brine Water, 0.5 ppg 80 0:25 0:40 150 9.5 ppg 1.0 ppg 80 0:25 0:45 100 14 mm Brine Water, 0.5 ppg 120 0:20 0:35 150 9.5 ppg 1.0 ppg 120 0:20 0:35 125 425 - 1000 Brine Water, 0.2 ppg 80 0:35 0:40 125 microns 10.0 ppg 0.4 ppg 80 0:30 0:40 100 425 - 1000 Brine Water, 0.2 ppg 120 0:20 0:35 150 microns 10.0 ppg 0.4 ppg 120 0:20 0:35 100 4 mm Brine Water, 0.5 ppg 80 0:25 0:45 100 10.0 ppg 1.0 ppg 80 0:25 0:45 50 4 mm Brine Water, 0.5 ppg 120 0:30 0:55 100 10.0 ppg 1.0 ppg 120 0:30 0:55 50 14 mm Brine Water, 0.5 ppg 80 0:25 0:45 100 10.0 ppg 1.0 ppg 80 0:25 0:45 50 14 min Brine Water, 0.5 ppg 120 0:25 0:55 100 10.0 ppg 1.0 ppg 120 0:25 0:55 50 4 mm 1 wt.% NaCI 4 lbs/barrell (ppb) Ambient 0:30 0:60 300 Brine (11.43 kg/m3) (-20 C) 14 mm l wt.% NaC1 4 ppb Ambient 0:30 0:60 275 Brine (11.43 kg/m3) -20 C
4 mm 2 wt.% NaCI 4 ppb Ambient 0:40 0:60 250 Brine (11.43 kg/m3) -20 C
14 mm 2 wt.% NaC1 4 ppb Ambient 0:40 1:20 235 Brine (11.43 kg/m3) -20 C
4 mm 3 wt. oo NaCI 4 ppb Ambient 0:45 1:45 215 Brine (11.43 kg/m3) (-20 C
14 mm 3 wt.% NaCI 4 ppb Ambient 0:45 1:45 200 Brine (11.43 kg/m3) -20 C
4 mm 8.5 ppg 0.2 ppg Ambient > 1 hr. 2:0 200 CaC12 solution -20 C
4 mm 9.0 ppg 0.2 ppg Ambient 1:30 3:0 100 CaC12 solution -20 C
4 mm 9.5 ppg 0.2 ppg Ambient 2:0 4:0 125 CaC12 solution -20 C
4 mm 10.0 ppg 0.2 ppg Ambient 2:30 5:0 50 CaC12 solution -20 C
4 ixim 10.2 ppg 0.2 ppg Ambient 5:30 7:0 25 CaC12 solution -20 C
4 mm 10.3 ppg 0.2 ppg Ambient 7:0 9:0 10 CaC12 solution -20 C
4 mm 10.5 ppg 0.2 ppg Ambient 13:0 24:0 10 CaC12 solution (-20 C) 4 mm 11.0 ppg 0.2 ppg Ambient did not CaC12 solution -20 C swell Based on these results, the swelling time of the DIAMOND SEAL polymer varied depending on the ionic strength of the carrier fluid being used. In particular, the time required for the DIAMOND SEAL polymer to swell, i.e., the swelling time, increased as the carrier fluid changed from fresh water to brine water and from brine water to a CaC12 solution. In contrast, the DIAMOND SEAL polymer experienced the most amount of swelling in the fresh water and the least amount of swelling in the CaC12 solution, indicating that it absorbs more water when in fresh water than in water containing salts.
Further, the amount of swelling generally decreased as the concentration of the DIAMOND
SEAL
polymer in the carrier fluid increased. In addition, the swelling time generally increased as the grind size of the DIAMONI3 SEAL polymer increased, whereas the swelling time generally decreased as the temperature increased.
The DIAMOND SEAL polymer was mixed with fresh water such that the water contained 0.2 lbs. DS/gallon water. Several samples (samples 1-4) of the resulting mixture were then allowed to hydrate at room temperature (70 F) and at 110 F to determine the expansion rate of the DIAMOND SEAL polymer at the different temperatures.
Table 2 below shows the results of this example.
Table 2 Sample Temperature, F Expansion in Size 1 70 100% in 30 min.
2 110 100% in 30 min.
3 70 200% in 2 hours 4 110 200% in 1 hour Based on the results shown in Table 2, the expansion rates of the DIAMOND SEAL
polymer were initially the same at room temperature (70 F) and at the bottom hole test temperature (110 F). In particular, samples 1 and 2 both expanded by 100% for the first 30 minutes. However, the expansion rate of the DIAMOND SEAL polymer at the higher temperature, i.e., the bottom hole test temperature, later became greater than that of the DIAMOND SEAL polymer at room temperature. In particular, sample 3 took 2 hours to expand in size by 200%, whereas sample 4 took 1 hour to expand in size by 200%.
The DIAMOND SEAL polymer was mixed with different amounts of PRENIIUM
cement (class H) or PREMICJM PLUS cement (class C), both of which are commercially available from Southdown, Inc. Different amounts of water were then added to the resulting slurries, thereby forming various test samples. Additives manufactured by Halliburton, Inc.
were added to some of the samples. Each test sample was subjected to a thickening time test, whereby an atmospheric consistometer was used to determine the thickening time of the sample at 80 F in accordance with American Petroleum Institute (API) Recommended Practice, Specification lOB, 22nd Ed., Dec. 1997. According to API standards, a consistency of 70 Bearden Units (Bc) is not pumpable. Each sample was also subjected to a hydration test, whereby it was observed in a static state at room temperature. The results of these tests are shown below in Table 3.
Table 3 Cement H20 Slurry DIAMON Other Thickening Hydration Slurry Added, Yield, D SEAL Additives, Time Test, Test Density, mL ft.3/941b Polymer in wt.% based Bc @ hr.:min.
ppg sack the Sluny, on the total ppg weight of the cement composition 11.00 17.53 3.04 10 None 60 Bc @ Unpourable @ 1 0:05 10.50 22.77 3.74 10 None 60 Bc @ Unpourable @ 5 0:15 min.
10.00 31.14 4.86 10 None 70 Bc @ Unpourable @ 10 0:45 min.
10.00 31.14 4.86 20 None 70 Bc @ Unpourable @ 5 0:15 9.50 46.65 6.93 20 None 70 Bc @ Unpourable @ 8 0:20 9.50 46.65 6.93 10 None 28 Bc @ Unpourable @ 1 hr., 4:00 some free water 9.50 46.65 6.93 5 None 15 Bc @ Unpourable @ 1 hr 4:00 30 min., some free water 9.00 85.26 12.09 10 1 ./ 50 vol. / free water, THUgSET 20% size increase in A 1 hour thixotropic additive, 0.25%
THIXSET
B
tlhixot-ropic additive 9.00 85.26 12.09 10 1% 25 vol. /o free water, VERSASE 40% size increase in T 1 hour thixotropic additive 9.50 46.65 6.93 10 1% 10 vol.% free water, THIXSET 70% size increase in A 1 hour thixotropic additive, .25%
THIXSET
B
thixotropic additive 9.50 46.65 6.93 10 1% 0% free water, VERSASE 100% size increase T in l hour, thixotropic unpourable additive 9.00 86.92 12.33 10 2% 0% free water, no bentonite size increase @ 20 min.
As shown in Table 3, when no additional additives were employed, the presence of the DIAMOND SEAL polymer in the test samples allowed the samples to thicken in a reasonable amount of time by absorbing the water added to the samples. In the test samples containing THEKSET thixotropic additives, a percentage (based on the total volume of the water) of the water in the samples floated out as free water that had not been absorbed by the DIAMOND
SEAI, polymer. Likewise, when 85.26 mL of water was added to a test sample containing a VERSASET thixotropic additive, free water floated out of the saniple. However, when less water i.e., 46.64 mL, was added to another test sample containing the VERSASET
thixotropic additive, all of the water was absorbed, allowing the sample to thicken. In the test sample containing bentonite, the bentonite rather than the DIAMOND SEAL polymer absorbed the water. This was due to the immediate absorption potential of the bentonite and the delayed potential for absorption witli the Diamond Seal.
While the preferred embodiments of the invention have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of the invention. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the invention disclosed herein are possible and are within the scope of the invention. Use of the term "optionally" with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim.
Accordingly, the scope of protection is not limited by the description set out above, but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated- into the specification as an embodiment of the present invention. Thus the claims are a further description and are an addition to the preferred embodiments of the present invention. The discussion of a reference in the Description of Related Art is not an admission that it is prior art to the present invention, especially any reference that may have been a publication date after the priority date of this application.
FORMATIONS USING A SWELLING AGENT TO ]NMIT THE INFLUX OF
WATER INTO A CEMENT SLURRY
FIELD OF THE INVENTION
This invention generally relates to compositions and methods for cementing in subterranean formations. More specifically, the invention relates to introducing a swelling agent to a subterranean formation to reduce the amount of water flowing into a cement slurry placed in the subterranean formation, thereby preventing the integrity of the cement slurry from being compromised.
BACKGROUND OF THE INVENTION
Well cementing is a process used in penetrating subterranean formations that produce oil and gas. In well cementing, a well bore is drilled while a drilling fluid is circulated through the well bore. The circulation of the drilling fluid is then terminated, and a string of pipe, e.g., casing, is run in the well bore. The drilling fluid in the well bore is conditioned by circulating it downwardly through the interior of the pipe and upwardly through the annulus, which is located between the exterior of the pipe and the walls of the well bore. Next, primary cementing is typically performed whereby a slurry of cement in water is placed in the annulus and permitted to set, i.e., harden into a solid mass, to thereby attach the string of pipe to the mfalls of the well bore and seal the annulus. Subsequent secondary cementing operations, i.e., any cementing operation after the primary cementing operation, may also be performed. One example of a secondary cementing operation is squeeze cementing whereby a cement slurry is forced under pressure to areas of lost integrity in the annulus to seal off those areas.
One problem commonly encountered during primary and secondary cementing operations is the movement of water from the subterranean formation into the well bore, resulting in the influx of water into cement slurries that have been placed in the well bore. In particular, the influx of water occurs during a transition phase in which the cement slurry changes from a true hydraulic fluid to a highly viscous mass showing some solid characteristics. When first placed in the well bore, the cement slurry acts as a true liquid and thus transmits hydrostatic pressure. During the transition phase, certain events occur that cause the cement slurry to lose its ability to transmit hydrostatic pressure. One of those events is the loss of fluid from the slurry to the subterranean zone. Another event is the development of static gel strength, i.e., stiffness, in the slurry. When the pressure exerted on the formation by the cement slurry falls below the pressure of the water in the formation, the water begins to flow into and through the cement slurry. This influx of water can occur during dynamic and static states of the cement slurry.
As a result of water influxes into and crossflows through the cement slurry, flow channels form therein that remain after the cement slurry has completely set.
Those flow channels allow the water to flow from one subterranean zone to another such that zonal isolation is no longer achieved. Further, the water intermixes with and dilutes the cement slurry, causing deterioration of the cement properties such as its density, its final compressive strength, and its rheology. As such, the water adversely affects the integrity of the cement.
Secondary cementing is often used to repair the lost integrity of the cement placed in the annulus during primary cementing. However, the cement slurries employed during secondary cementing also become deteriorated due to the continued influx of water. The secondary cementing operation therefore may fail to perform as designed in forming a sealing or blocking mechanism.
Repairing the deteriorated cement can be both time consuming and costly. As such, various chemicals have been used to attempt to prevent the influx of water into the cement. For example, silicates such as sodium silicate have been added to the cement or injected ahead of the cement to react with it, hydrate it, and cause it to set more quickly.
Other chemicals have been added to the cement to increase its Ascosity and make it less permeable to water.
However, such chemicals often become diluted and dispersed before they can effectively inhibit the influx of water. It would therefore be desirable to develop improved processes for protecting cement slurries against deterioration caused by the influx of water.
The present invention includes methods for performing well cementing.
According to an embodiment, a cement slurry is passed into a subterranean formation, and a swelling agent is also passed into the subterranean formation to reduce an amount of water flowing into the cement slurry. The swelling agent may be combined with a carrier fluid that is displaced into the subterranean formation before the cement slurry is displaced therein.
Alternatively, the swelling agent may be pre-mixed with the cement slurry, followed by concurrently displacing the swelling agent and the cement slurry into the subterranean formation.
After passing into the subterranean formation, the swelling agent absorbs water therein. As the swelling agent absorbs water, it swells to form a gel mass that substantially blocks the flow path of water into the cement slurry placed in the subterranean formation. Accordingly, the swelling agent helps prevent the integrity of the cement slurry from being compromised by the influx and crossflows of water.
The present invention further includes cement compositions and methods for making the cement composition. The cement compositions comprise cement combined with a swelling agent that is capable of absorbing water and of swelling as it absorbs the water. The swelling agent is also insoluble in water and thus resists dilution by water in the subterranean formation. The swelling agent is preferably a crosslinked polyacrylamide.
DETAILED DESCRIPTION OF THE PREFERRED EIVIBODIMENTS
According to the present invention, well cementing methods are performed in which an effective amount of one or more swelling agents is passed into a well bore to reduce the influx of water into a cement slurry placed in the well bore. The presence of the swelling agent in the well bore serves to reduce the amount of water available to intemiix with and dilute the cement slurry. The swelling agent may be placed into the well bore before the cement is passed into the well bore, concurrent with the passing of cement into the well bore, or after the cement is passed into the wellbore.
According to preferred embodiments, a primary cementing process is carried out according to standard well cementing practices. The primary cementing process includes drilling a well bore down to a, subterranean zone while circulating a drilling fluid through the well bore. A string of pipe, e.g., casing, is then run in the well bore. The drilling fluid is conditioned by circulating it downwardly through the interior of the pipe and upwardly through the annulus, which is located between the exterior of the pipe and the walls of the well bore. A
carrier solution containing the swelling agent and a carrier fluid may then be displaced into the well bore, followed by displacing a cement slurry down through the pipe and up through the annulus in the well bore. Alternatively, the swelling agent may be combined with the cement slurry before concurrently displacing the swelling agent and the cement slurry into the well bore.
Any secondary cementing operations known in the art may also be performed using the swelling agent. For example, the cement sheath formed in the annulus as a result of primary cementing may contain permeable areas such as fractures, fissures, high permeability streaks, and/or annular voids through which water can flow. Channels of water thus may undesirably flow behind the casing. A cement squeezing technique may be employed to force cement into the permeable areas or voidage so as to seal or block the flow paths of water.
Before performing cement squeezing, a swelling agent may be displaced into the well bore via a carrier fluid, or alternatively, it may be combined with a cement slurry before the slurry is displaced into the well bore.
In an embodiment, the well bore is monitored to detect and locate sources of water (such as fissures, cracks, fractures, streaks, flow channels, voids and the like) that are suitable for plugging via introduction of the swelling agent. Any suitable means or methods for locating such sources of water may be used as known to those of skill in the art. For example, prior to injecting the swelling agent into the well bore, production logs such as temperature, fluid density, hydro, and flowmeter logs can be used singly or in combination to detect where water is flowing into the well bore. In addition, a magnetic resonance imaging log (MRIL) tool may be employed to analyze the well bore to determine where mobile water is present.
Additional disclosure regarding MRIL tools can be found in U.S. Patent No.
6,283,210.
Another diagnostic technique that may be utilized to locate flowing water in the well bore involves exciting oxygen molecules. In addition, a 360 depth of view tool may be used to examine the well bore for fractures, fissures, streaks, and voids.
Detecting the locations of flowing water in the well bore allows the swelling agent to be strategically placed in close proximity to the source of the flowing water.
For example, the swelling agent can be placed in fractures, fissures, streaks, and voids found in the rock surrounding the well bore or in the cement sheath located in the annulus of the well bore.
Preferably, the swelling agent does not immediately absorb water but begins to absorb water after there has been sufficient time to place it downhole in close proximity to the water source. While downhole, the swelling agent begins to absorb the water and swell into a gel mass that is substantially resistant to the flow of water therethrough, thereby effectively plugging the fractures, fissures, streaks, and voids through which the water could otherwise pass for at least a period of time sufficient to allow the cement to set up, harden, and thus become impervious to further degradation with a potential form influx or flow of water from formation sources.
The swelling agent is defined as and may be any suitable material that absorbs water and swells, (i.e., expands) as it absorbs the water. Preferably, the swelling agent is insoluble in water and thus avoids becoming diluted and washed away by the water flowing through the well bore. More preferably, the swelling agent forms a gel mass upon swelling that can be effective for blocking a flow path of the water into the cement slurry. Most preferably, the gel mass has a relatively low permeability to water and thus creates a barrier between the water and cement slurries placed in the well bore. A gel is herein defined as a crosslinked polymer network swollen in a liquid. Preferably, the crosslinker is part of the polymer and thus will not absorb out of the polymer. Suitable swelling agents include those known as superabsorbents, which are commonly used in absorbent products such as diapers, training pants, and feminine care products. Superabsorbents are swellable crosslinked polymers, which have the ability to absorb and store many times their own weight of aqueous liquids by forming a gel. The superabsorbents retain the liquid that they absorb and typically do not release the liquid, even under pressure. Examples of superabsorbents are sodium acrylate-based polymers having three dimensional, network-like molecular structures. The polymer chains are formed by the reaction/joining of millions of identical units of acrylic acid monomer, which have been substantially neutralized with sodium hydroxide (caustic soda). Crosslinking chemicals tie the chains togetller to form a three-dimensional network, enabling the superabsorbents to absorb water or water-based solutions into the spaces in the molecular network, and thus forming a gel and locking up the liquid.
Examples of suitable swelling agents include, but are not limited to, polyacrylamide, polyacrylate, hydrolyzed polyacrylonitrile, carboxyalkyl cellulose, carboxymethyl starch, salts of carboxymethyl cellulose, carbw~yalkyl polysaccharide, and combinations thereof. The swelling agent is preferably a crystalline polymer that has been dehydrated, more preferably a crosslinked polyacrylamide, and most preferably a crosslinked polyacrylamide in the form of a hard crystal.
A crosslinked polyacrylamide known as DIAMOND SEAL polymer may be purchased from Baroid Drilling Fluids, Inc. The DIAMOND SEAL polymer is available in grind sizes of 1 mm, 4 nun, and 14 mm and may be ground even smaller if needed. For example, a smaller grind size may be required to allow its crystals to enter very small fractures, fissures, and so forth. The DIAMOND SEAL polymer possesses certain qualities that make it an exceptional swelling agent. For example, the DIAMOND SEAL polymer is water-insoluble and is resistant to deterioration by carbon dioxide, bacteria, and subterranean minerals.
Further, the DIAMOND SEAL polymer can withstand temperatures up to at least 250 F without experiencing breakdown and thus may be used in the majority of locations where well bores are drilled. Other suitable swelling agents are described in European Patent No.
0566118.
The swelling agent is preferably hydrophilic and is thus physically attracted to water molecules. In the case where the swelling agent is a crystalline polymer, the polymer chain deflects and surxounds the water molecules during water absorption. In effect, the polymer undergoes a change from that of a dehydrated crystal to that of a hydrated gel as it absorbs water.
Once fully hydrated, the gel preferably exhibits a high resistance to the migration or water therethrough. That is, the molecules of the gel are sufficiently packed together to substantially inhibit water from passing through the gel. Further, the gel can plug permeable areas of the well bore or the cement sheath because it can withstand substantial amounts of pressure without being dislodged or extruded.
As the swelling agent undergoes hydration, its physical size increases by about 10 to 400 times its original volume. The amount and rate by which the swelling agent increases in size vary depending upon its temperature, its grain size, and the ionic strength of the carrier fluid. The temperature of a well bore generally increases from top to bottom such that the rate of swelling increases as the swelling agent passes downhole. The rate of swelling also increases as the grain size of the swelling agent increases and as the ionic strength of the carrier fluid increases. For example, the mass of a DIAMOND SEAL polymer having a 14 mm grind size increases by 0% in 20 minutes after contacting water at 80 F, 150% in 35 minutes after contacting the water, and 400% in 45 minutes after contacting the water. The mass of the DIAMOND SEAL
polymer increases by 0% in 15 minutes after contacting water at 145 F, 200% in 25 minutes after contacting the water, and 400% in 35 minutes after contacting the water. The mass of the DIAMOND SEAL polymer increases by 0 lo in 45 minutes after contacting 9.2 pounds/gallon (ppg) brine water at 80 F, 25% in 60 minutes after contacting the brine water and 50% in 75 minutes after contacting the brine water. The mass of the DIAMOND SEAL polymer increases by 0% in 30 minutes after contacting 9.2 ppg brine water at 145 F, 25% in 45 minutes after contacting the brine water, and 50% in 60 minutes after contacting the brine water.
The amount by which the swelling agent increases in size as it swells decreases as an ionic strength of the carrier fluid increases.
According to some embodiments, the swelling agent may be combined with a carrier fluid to form a carrier solution before being placed in a well bore. The carrier fluid may be any suitable fluid for moving the swelling agent to desired locations in the well bore. The swelling agent is incorporated therein in an effective amount for plugging a source of water upon being placed down hole and the effective amount may vary depending on factors such as the type of the carrier fluid, the amount of mobile water flow in the well bore, the size of the water source (i.e., size of a fracture, fissure, etc.), and the like. The carrier fluid is preferably a pumpable fluid. Examples of carrier fluids with which the swelling agent may be combined include but are not limited to fresh water, deionized water, brine water of varying salinity, chloride solutions such as calcium dichloride and potassium chloride solutions, hydrocarbons such as produced oil and diesel oil, and synthetic fluids such as ester or polymer based fluids. The amount of swelling agent that may be combined with the carrier fluid depends on a number of factors including the type of carrier fluid, the volume capacities of the well's tubulars in conjunction with the placement rate logistical timing, the flow rate and pressure from the mobile water in and intruding into the well bore, and diagnostics performed to define the apparent voidage or communicating areas. Because swelling of the swelling agent may be delayed until the swelling agent is placed downhole, preferably the carrier fluid contains relatively high concentrations of the swelling agent and remains sufficiently non-viscous in order to be pumped downhole. In general, the swelling agent may be present in the carrier fluid in an amount of from about 0.001 to about 5.0 ppg, more preferably from about 0.01 to about 2.0 ppg. The carrier fluid containing the swelling agent is displaced into the well bore before cement slurries are displaced into the well bore. The designed placement procedure may address sucli conditions as loss circulation (fluid within the wellbore lost to particular portions of the formations and depth intervals), encountered intervals with crossflowing water, and influxes of water. As a result, the viscosities and rheologies of the subsequently placed cement slurries are less likely to be altered by the carrier fluid.
According to alternative embodiments, the swelling agent may be combined with a cement composition before being placed in a well bore. Cement compositions of the present invention may contain cements such as hydraulic cement composed of calcium, aluminum, silicon, oxygen, and/or sulfur which sets and hardens by reaction with water.
Examples of hydraulic cements are Portland cements, pozzolan cements, gypsum cements, high alumina content cements, silica cements, and high alkalinity cements. The cement is preferably a Portland cement, more preferably a class A, B, C, G, or H Portland cement, and most preferably a class C or H Portland cement. A sufficient amount of fluid may also be added to the cement to form a pumpable cementitious slurry. The fluid is preferably fresh water or salt water, e.g., an unsaturated aqueous salt solution or a saturated aqueous salt solution such as brine or seawater. An effective amount of swelling agent is combined with such cement compositions to plug a source of water upon placing the cement down hole, and the effective amount may vary depending on factors such as the type of cement, the amount of mobile water flow in the well bore, the pore pressure and influx rate of the water source (i.e., size of a fracture, fissure, etc.), and the like. In general, the cement compositions may contain from about 1 to about 50 % by weight swelling agent per total weight of a cement composition such that a density of the cement composition ranges from about 9.0 to about 12.0 pounds per gallon.
As deemed appropriate by one skilled in the art, additional additives may be added to the cement compositions for improving or changing the properties of the cement composition.
Examples of such additives include, but are not limited to set, fluid loss control additives, de-foamers, dispersing agents, set accelerators, and formation conditioning agents. Such cement compositions may be made by any suitable method as known to those of skill in the art.
If desired, the swelling agent may be removed from the well bore or area of its placement after it has been used for its intended purpose. If the swelling agent is a polymer, the backbone structure of the polymer may be broken down such that it becomes more like a liquid.
Any known means may be used to break down or collapse the polymer. For example, the polymer may be contacted with an oxidizer such as sodium hypochlorite (i.e., bleach), or combinations thereof to eliminate the polymer from the well bore, preferably by pumping such compounds down the well bore and contacting the swollen swelling agent in situ.
The invention having been generally described, the following examples are given as particular embodiments of the invention and to demonstrate the practice and advantages hereof. It is understood that the examples are given by way of illustration and are not intended to limit the specification or the claims to follow in any manner.
Different grind sizes of the DIAMOND SEAL polymer (DS) were mixed with various carrier solutions at different concentrations to form several test samples.
These carrier solutions were fresh water, field produced brine water, NaCI brine made by adding NaC1 to fresh water, and CaCl2 aqueous solution made by adding CaC12 to fresh water.
The test samples were then subjected to different temperatures and observed to determine the swelling time and the amount of swelling of the DIAMOND SEAL polymer. Table 1 below shows the results of this example.
Table 1 DIAMON Carrier Fluid Concentration of Temp., Initial Final Swelling D SEAL DS in Carrier F Hydrati Hydration Increase, Polymer Fluid on, , hr.:min. % By Grind Size hr.:m.in. Volume 425 - 1000 Fresh Water 0.2 lb/gal (ppg) 80 0:09 0:15 400 microns 0.4 ppg 80 0:09 0:15 400 0.5 ppg 80 0:09 0:15 400 425 - 1000 Fresh Water 0.2 ppg 120 0:03 0:09 400 microns 0.4 ppg 120 0:03 0:09 400 0.5 ppg 120 0:03 0:09 400 4 mm Fresh Water 0.2 ppg 80 0:18 0:25 500 0.4 ppg 80 0:18 0:25 500 0.5 ppg 80 0:18 0:25 450 4 mm Fresh Water 0.2 ppg 120 0:14 0:20 500 0.4 ppg 120 0:14 0:20 450 0.5 ppg 120 0:14 0:20 400 14 mm Fresh Water 0.2 ppg 80 0:20 0:30 500 0.4 ppg 80 0:20 0:25 450 0.5 ppg 80 0:20 0:25 400 14 Ynrn Fresh Water 0.2 ppg 120 0:17 0:25 500 0.4 ppg 120 0:16 0:25 450 0.5 ppg 120 0:16 0:25 400 425 - 1000 Brine Water, 0.2 ppg 80 0:25 0:28 150 microns 9.5 0.4 ppg 80 0:20 0:28 125 425 - 1000 Brine Water, 0.2 ppg 120 0:15 0:25 150 microns 9.5 ppg 0.4 ppg 120 0:15 0:25 125 4 mm Brine Water, 0.5 ppg 80 0:20 0:33 150 9.5 p a 1.0 ppg 80 0:20 0:30 100 4 mm Brine Water, 0.5 ppg 120 0:18 0:30 175 9.5 1.0 ppg 120 0:18 0:27 150 14 mm Brine Water, 0.5 ppg 80 0:25 0:40 150 9.5 ppg 1.0 ppg 80 0:25 0:45 100 14 mm Brine Water, 0.5 ppg 120 0:20 0:35 150 9.5 ppg 1.0 ppg 120 0:20 0:35 125 425 - 1000 Brine Water, 0.2 ppg 80 0:35 0:40 125 microns 10.0 ppg 0.4 ppg 80 0:30 0:40 100 425 - 1000 Brine Water, 0.2 ppg 120 0:20 0:35 150 microns 10.0 ppg 0.4 ppg 120 0:20 0:35 100 4 mm Brine Water, 0.5 ppg 80 0:25 0:45 100 10.0 ppg 1.0 ppg 80 0:25 0:45 50 4 mm Brine Water, 0.5 ppg 120 0:30 0:55 100 10.0 ppg 1.0 ppg 120 0:30 0:55 50 14 mm Brine Water, 0.5 ppg 80 0:25 0:45 100 10.0 ppg 1.0 ppg 80 0:25 0:45 50 14 min Brine Water, 0.5 ppg 120 0:25 0:55 100 10.0 ppg 1.0 ppg 120 0:25 0:55 50 4 mm 1 wt.% NaCI 4 lbs/barrell (ppb) Ambient 0:30 0:60 300 Brine (11.43 kg/m3) (-20 C) 14 mm l wt.% NaC1 4 ppb Ambient 0:30 0:60 275 Brine (11.43 kg/m3) -20 C
4 mm 2 wt.% NaCI 4 ppb Ambient 0:40 0:60 250 Brine (11.43 kg/m3) -20 C
14 mm 2 wt.% NaC1 4 ppb Ambient 0:40 1:20 235 Brine (11.43 kg/m3) -20 C
4 mm 3 wt. oo NaCI 4 ppb Ambient 0:45 1:45 215 Brine (11.43 kg/m3) (-20 C
14 mm 3 wt.% NaCI 4 ppb Ambient 0:45 1:45 200 Brine (11.43 kg/m3) -20 C
4 mm 8.5 ppg 0.2 ppg Ambient > 1 hr. 2:0 200 CaC12 solution -20 C
4 mm 9.0 ppg 0.2 ppg Ambient 1:30 3:0 100 CaC12 solution -20 C
4 mm 9.5 ppg 0.2 ppg Ambient 2:0 4:0 125 CaC12 solution -20 C
4 mm 10.0 ppg 0.2 ppg Ambient 2:30 5:0 50 CaC12 solution -20 C
4 ixim 10.2 ppg 0.2 ppg Ambient 5:30 7:0 25 CaC12 solution -20 C
4 mm 10.3 ppg 0.2 ppg Ambient 7:0 9:0 10 CaC12 solution -20 C
4 mm 10.5 ppg 0.2 ppg Ambient 13:0 24:0 10 CaC12 solution (-20 C) 4 mm 11.0 ppg 0.2 ppg Ambient did not CaC12 solution -20 C swell Based on these results, the swelling time of the DIAMOND SEAL polymer varied depending on the ionic strength of the carrier fluid being used. In particular, the time required for the DIAMOND SEAL polymer to swell, i.e., the swelling time, increased as the carrier fluid changed from fresh water to brine water and from brine water to a CaC12 solution. In contrast, the DIAMOND SEAL polymer experienced the most amount of swelling in the fresh water and the least amount of swelling in the CaC12 solution, indicating that it absorbs more water when in fresh water than in water containing salts.
Further, the amount of swelling generally decreased as the concentration of the DIAMOND
SEAL
polymer in the carrier fluid increased. In addition, the swelling time generally increased as the grind size of the DIAMONI3 SEAL polymer increased, whereas the swelling time generally decreased as the temperature increased.
The DIAMOND SEAL polymer was mixed with fresh water such that the water contained 0.2 lbs. DS/gallon water. Several samples (samples 1-4) of the resulting mixture were then allowed to hydrate at room temperature (70 F) and at 110 F to determine the expansion rate of the DIAMOND SEAL polymer at the different temperatures.
Table 2 below shows the results of this example.
Table 2 Sample Temperature, F Expansion in Size 1 70 100% in 30 min.
2 110 100% in 30 min.
3 70 200% in 2 hours 4 110 200% in 1 hour Based on the results shown in Table 2, the expansion rates of the DIAMOND SEAL
polymer were initially the same at room temperature (70 F) and at the bottom hole test temperature (110 F). In particular, samples 1 and 2 both expanded by 100% for the first 30 minutes. However, the expansion rate of the DIAMOND SEAL polymer at the higher temperature, i.e., the bottom hole test temperature, later became greater than that of the DIAMOND SEAL polymer at room temperature. In particular, sample 3 took 2 hours to expand in size by 200%, whereas sample 4 took 1 hour to expand in size by 200%.
The DIAMOND SEAL polymer was mixed with different amounts of PRENIIUM
cement (class H) or PREMICJM PLUS cement (class C), both of which are commercially available from Southdown, Inc. Different amounts of water were then added to the resulting slurries, thereby forming various test samples. Additives manufactured by Halliburton, Inc.
were added to some of the samples. Each test sample was subjected to a thickening time test, whereby an atmospheric consistometer was used to determine the thickening time of the sample at 80 F in accordance with American Petroleum Institute (API) Recommended Practice, Specification lOB, 22nd Ed., Dec. 1997. According to API standards, a consistency of 70 Bearden Units (Bc) is not pumpable. Each sample was also subjected to a hydration test, whereby it was observed in a static state at room temperature. The results of these tests are shown below in Table 3.
Table 3 Cement H20 Slurry DIAMON Other Thickening Hydration Slurry Added, Yield, D SEAL Additives, Time Test, Test Density, mL ft.3/941b Polymer in wt.% based Bc @ hr.:min.
ppg sack the Sluny, on the total ppg weight of the cement composition 11.00 17.53 3.04 10 None 60 Bc @ Unpourable @ 1 0:05 10.50 22.77 3.74 10 None 60 Bc @ Unpourable @ 5 0:15 min.
10.00 31.14 4.86 10 None 70 Bc @ Unpourable @ 10 0:45 min.
10.00 31.14 4.86 20 None 70 Bc @ Unpourable @ 5 0:15 9.50 46.65 6.93 20 None 70 Bc @ Unpourable @ 8 0:20 9.50 46.65 6.93 10 None 28 Bc @ Unpourable @ 1 hr., 4:00 some free water 9.50 46.65 6.93 5 None 15 Bc @ Unpourable @ 1 hr 4:00 30 min., some free water 9.00 85.26 12.09 10 1 ./ 50 vol. / free water, THUgSET 20% size increase in A 1 hour thixotropic additive, 0.25%
THIXSET
B
tlhixot-ropic additive 9.00 85.26 12.09 10 1% 25 vol. /o free water, VERSASE 40% size increase in T 1 hour thixotropic additive 9.50 46.65 6.93 10 1% 10 vol.% free water, THIXSET 70% size increase in A 1 hour thixotropic additive, .25%
THIXSET
B
thixotropic additive 9.50 46.65 6.93 10 1% 0% free water, VERSASE 100% size increase T in l hour, thixotropic unpourable additive 9.00 86.92 12.33 10 2% 0% free water, no bentonite size increase @ 20 min.
As shown in Table 3, when no additional additives were employed, the presence of the DIAMOND SEAL polymer in the test samples allowed the samples to thicken in a reasonable amount of time by absorbing the water added to the samples. In the test samples containing THEKSET thixotropic additives, a percentage (based on the total volume of the water) of the water in the samples floated out as free water that had not been absorbed by the DIAMOND
SEAI, polymer. Likewise, when 85.26 mL of water was added to a test sample containing a VERSASET thixotropic additive, free water floated out of the saniple. However, when less water i.e., 46.64 mL, was added to another test sample containing the VERSASET
thixotropic additive, all of the water was absorbed, allowing the sample to thicken. In the test sample containing bentonite, the bentonite rather than the DIAMOND SEAL polymer absorbed the water. This was due to the immediate absorption potential of the bentonite and the delayed potential for absorption witli the Diamond Seal.
While the preferred embodiments of the invention have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of the invention. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the invention disclosed herein are possible and are within the scope of the invention. Use of the term "optionally" with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim.
Accordingly, the scope of protection is not limited by the description set out above, but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated- into the specification as an embodiment of the present invention. Thus the claims are a further description and are an addition to the preferred embodiments of the present invention. The discussion of a reference in the Description of Related Art is not an admission that it is prior art to the present invention, especially any reference that may have been a publication date after the priority date of this application.
Claims (29)
1. A cased-well cement composition comprising cement and a swelling agent wherein the swelling agent comprises a crosslinked polyacrylamide and wherein the cement composition further comprises water and a thixotropic additive.
2. The cement composition of Claim 1 wherein the swelling agent is capable of swelling to form a gel mass upon the absorption of the water.
3. The cement composition of Claim 1 wherein the swelling agent is insoluble in water.
4. A method of cementing in a subterranean formation comprising:
running a casing in a wellbore;
plugging a water source in the subterranean formation with a swelling agent comprising a superabsorbent to reduce an amount of water flowing into a cement slurry, wherein the superabsorbent is a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
running a casing in a wellbore;
plugging a water source in the subterranean formation with a swelling agent comprising a superabsorbent to reduce an amount of water flowing into a cement slurry, wherein the superabsorbent is a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
5. The method of Claim 4 wherein the swelling agent is insoluble in the water.
6. A method of cementing in a subterranean formation comprising;
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent comprises a superabsorbent, wherein the superabsorbent is a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent comprises a superabsorbent, wherein the superabsorbent is a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
7. A method of cementing in a subterranean formation comprising:
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent is selected from the group consisting of polyacrylate, hydrolyzed polyacrylonitrile, carboxyalkyl cellulose, carboxymethyl starch, salts of carboxymethyl cellulose, carboxyalkyl polysaccharide, and combinations thereof;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent is selected from the group consisting of polyacrylate, hydrolyzed polyacrylonitrile, carboxyalkyl cellulose, carboxymethyl starch, salts of carboxymethyl cellulose, carboxyalkyl polysaccharide, and combinations thereof;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set.
8. The method of Claim 7 wherein the swelling agent comprises a crosslinked polymer.
9. The method of Claim 4 wherein swelling of the swelling agent is delayed until the swelling agent is downhole.
10. The method of Claim 4 wherein said plugging a water source in the subterranean formation is performed before said pumping the cement slurry into the subterranean formation.
11. A method of cementing in a subterranean formation comprising:
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set;
wherein said passing the swelling agent into the subterranean formation is performed before said pumping the cement slurry into the subterranean formation; and wherein said passing the swelling agent into the subterranean formation comprises combining the swelling agent with a carrier solution and placing the carrier solution into a wellbore.
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry;
pumping the cement slurry into the subterranean formation; and allowing the slurry to set;
wherein said passing the swelling agent into the subterranean formation is performed before said pumping the cement slurry into the subterranean formation; and wherein said passing the swelling agent into the subterranean formation comprises combining the swelling agent with a carrier solution and placing the carrier solution into a wellbore.
12. The method of Claim 11 wherein the carrier solution has at least one component selected from a group consisting of fresh water, brine water, a potassium chloride solution, a calcium chloride solution, and a hydrocarbon.
13. The method of Claim 12 wherein the swelling agent is present in the carrier solution in an amount ranging from about 0.001 to about 5.0 pounds per gallon of the carrier solution.
14. The method of Claim 12 wherein the swelling agent is present in the carrier solution in an amount ranging from about 0.01 to about 2.0 pounds per gallon of the carrier solution.
15. A method of cementing in a subterranean formation comprising:
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent comprises a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation;
allowing the slurry to set;
wherein said passing the swelling agent into the subterranean formation is performed concurrently with said pumping the cement slurry into the subterranean formation.
running a casing in a wellbore;
passing a swelling agent into the subterranean formation to reduce an amount of water flowing into a cement slurry, wherein the swelling agent comprises a sodium acrylate-based polymer;
pumping the cement slurry into the subterranean formation;
allowing the slurry to set;
wherein said passing the swelling agent into the subterranean formation is performed concurrently with said pumping the cement slurry into the subterranean formation.
16. The method of Claim 15, further comprising combining the swelling agent with the cement slurry before pumping them into the subterranean formation.
17. The method of Claim 15 wherein the swelling agent is present in the cement slurry in an amount ranging from about 1 to about 10% by weight of the cement slurry.
18. The method of Claim 15, further comprising altering the thixotropy of the cement slurry by combining a thixotropic additive with the cement slurry and the swelling agent before pumping them into the subterranean formation.
19. The method of Claim 4 wherein the cement slurry is pumped into the subterranean formation during a primary cementing process.
20. The method of Claim 4 wherein the cement slurry is pumped into the subterranean formation during a secondary cementing process.
21. The method of Claim 4, further comprising determining a location of the water in the subterranean formation before said plugging a water source in the subterranean formation with a swelling agent.
22. The method of Claim 21, further comprising placing the swelling agent in close proximity to the location of the water.
23. The method of Claim 11 further comprising:
removing the swelling agent from the subterranean formation.
removing the swelling agent from the subterranean formation.
24. The method of Claim 23 wherein said removing the swelling agent from the subterranean formation comprises contacting the swelling agent with an oxidizer.
25. The method of Claim 24 wherein the oxidizer is sodium hypochlorite.
26. The method of Claim 11 wherein a swelling time of the swelling agent increases as an ionic strength of the carrier fluid increases.
27. The method of Claim 11 wherein an amount by which the swelling agent increases in size as it swells decreases as an ionic strength of the carrier fluid increases.
28. The method of Claim 11 wherein the amount by which the swelling agent increases in size as it swells decreases as a concentration of the swelling agent in the carrier fluid increases.
29. The method of Claim 4 wherein the superabsorbent has an original volume and is capable of increasing in volume from about 10 to 400 times the original volume.
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US10/375,183 US7866394B2 (en) | 2003-02-27 | 2003-02-27 | Compositions and methods of cementing in subterranean formations using a swelling agent to inhibit the influx of water into a cement slurry |
PCT/GB2003/005537 WO2004076808A1 (en) | 2003-02-27 | 2003-12-18 | Compositions and methods of cementing in subterranean formations using a swelling agent to inhibit the influx of water into a cement slurry |
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US7866394B2 (en) | 2003-02-27 | 2011-01-11 | Halliburton Energy Services Inc. | Compositions and methods of cementing in subterranean formations using a swelling agent to inhibit the influx of water into a cement slurry |
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US20040221990A1 (en) | 2003-05-05 | 2004-11-11 | Heathman James F. | Methods and compositions for compensating for cement hydration volume reduction |
US7441600B2 (en) | 2003-05-09 | 2008-10-28 | Halliburton Energy Services, Inc. | Cement compositions with improved mechanical properties and methods of cementing in subterranean formations |
WO2004101952A1 (en) | 2003-05-14 | 2004-11-25 | Services Petroliers Schlumberger | Self adaptive cement systems |
US7036588B2 (en) | 2003-09-09 | 2006-05-02 | Halliburton Energy Services, Inc. | Treatment fluids comprising starch and ceramic particulate bridging agents and methods of using these fluids to provide fluid loss control |
US7055603B2 (en) | 2003-09-24 | 2006-06-06 | Halliburton Energy Services, Inc. | Cement compositions comprising strength-enhancing lost circulation materials and methods of cementing in subterranean formations |
US7073584B2 (en) | 2003-11-12 | 2006-07-11 | Halliburton Energy Services, Inc. | Processes for incorporating inert gas in a cement composition containing spherical beads |
US20050113260A1 (en) | 2003-11-21 | 2005-05-26 | Wood Robert R. | Drilling fluids |
JP2005181193A (en) * | 2003-12-22 | 2005-07-07 | Tdk Corp | Pulse-wave radar apparatus |
US7204312B2 (en) | 2004-01-30 | 2007-04-17 | Halliburton Energy Services, Inc. | Compositions and methods for the delivery of chemical components in subterranean well bores |
US7156174B2 (en) | 2004-01-30 | 2007-01-02 | Halliburton Energy Services, Inc. | Contained micro-particles for use in well bore operations |
GB2428264B (en) | 2004-03-12 | 2008-07-30 | Schlumberger Holdings | Sealing system and method for use in a well |
US7316275B2 (en) | 2005-03-17 | 2008-01-08 | Bj Services Company | Well treating compositions containing water superabsorbent material and method of using the same |
US7891424B2 (en) | 2005-03-25 | 2011-02-22 | Halliburton Energy Services Inc. | Methods of delivering material downhole |
US7870903B2 (en) | 2005-07-13 | 2011-01-18 | Halliburton Energy Services Inc. | Inverse emulsion polymers as lost circulation material |
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2003
- 2003-02-27 US US10/375,183 patent/US7866394B2/en not_active Expired - Fee Related
- 2003-12-18 MX MXPA05009173A patent/MXPA05009173A/en active IP Right Grant
- 2003-12-18 CA CA2517093A patent/CA2517093C/en not_active Expired - Fee Related
- 2003-12-18 WO PCT/GB2003/005537 patent/WO2004076808A1/en not_active Application Discontinuation
- 2003-12-18 AU AU2003290276A patent/AU2003290276A1/en not_active Abandoned
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2004
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MXPA05009173A (en) | 2005-10-26 |
US7866394B2 (en) | 2011-01-11 |
CA2517093A1 (en) | 2004-09-10 |
US20040168802A1 (en) | 2004-09-02 |
WO2004076808A1 (en) | 2004-09-10 |
AR042837A1 (en) | 2005-07-06 |
AU2003290276A1 (en) | 2004-09-17 |
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