CA2673866C - Low permeability cement systems for steam injection application - Google Patents
Low permeability cement systems for steam injection application Download PDFInfo
- Publication number
- CA2673866C CA2673866C CA2673866A CA2673866A CA2673866C CA 2673866 C CA2673866 C CA 2673866C CA 2673866 A CA2673866 A CA 2673866A CA 2673866 A CA2673866 A CA 2673866A CA 2673866 C CA2673866 C CA 2673866C
- Authority
- CA
- Canada
- Prior art keywords
- cement
- polymer
- steam injection
- well
- wax
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related
Links
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
-
- 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
- C04B2103/0065—Polymers characterised by their glass transition temperature (Tg)
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Inorganic Chemistry (AREA)
- Ceramic Engineering (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Life Sciences & Earth Sciences (AREA)
- Structural Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
- Soil Conditioners And Soil-Stabilizing Materials (AREA)
- Manufacture Of Porous Articles, And Recovery And Treatment Of Waste Products (AREA)
- Processes Of Treating Macromolecular Substances (AREA)
Abstract
A cement slurry composition comprising a plugging agent polymer with a low Tg point.
Description
, , Description Low permeability cement systems for steam injection application Technical field [0001] This invention relates to a cement additive for the use in cementing oil wells or the like, in particular the invention relates to a low glass transition point (Tg) polymer as a plugging agent for a cement composition.
Background art
Background art
[0002] In a general well cementing operation, a cement slurry is prepared at the surface and pumped into the well to fill the annulus between the casing and the borehole wall to provide zonal isolation and mechanical support.
Interest in the recovery of heavy oil is increasing because of the huge reserves of heavy oil existing whereas reserves of light oil are decreasing.
Thermal recovery processes are one of the main means of recovering heavy oils. Thermal methods work by increasing the temperature of the oil which will decrease the viscosity of the oil. One of the main thermal methods used is steam injection. However one of the issues for zonal isolation is the permeability of cement after steam injection operations.
When initially set, the cement can provide a good seal, however changes in pressure and temperature during repeated steam injection procedures can induce stresses and affect the integrity of the cement.
Interest in the recovery of heavy oil is increasing because of the huge reserves of heavy oil existing whereas reserves of light oil are decreasing.
Thermal recovery processes are one of the main means of recovering heavy oils. Thermal methods work by increasing the temperature of the oil which will decrease the viscosity of the oil. One of the main thermal methods used is steam injection. However one of the issues for zonal isolation is the permeability of cement after steam injection operations.
When initially set, the cement can provide a good seal, however changes in pressure and temperature during repeated steam injection procedures can induce stresses and affect the integrity of the cement.
[0003] Systems used for such application are typically conventional low density cement which become highly permeable after a few steam injection cycles.
It is common that temperatures around 300 C are reached within the cement sheath and generally the set cement will lose strength and gain permeability after regular steam injection. This can cause zonal isolation to be lost and induce cored casing and/or steam leakage. As such the lifetime of thermal recovery wells is shortened by all these stresses the cement is placed under.
It is common that temperatures around 300 C are reached within the cement sheath and generally the set cement will lose strength and gain permeability after regular steam injection. This can cause zonal isolation to be lost and induce cored casing and/or steam leakage. As such the lifetime of thermal recovery wells is shortened by all these stresses the cement is placed under.
[0004] Lost circulation problems often occur due to weak and unconsolidated formations of such wells therefore low density cement systems are required however this is detrimental in terms of set cement properties, as water permeability of set cement is inversely proportional to the density of conventional cement. Heavy oil wells exposed to thermal recovery processes belong mainly to the low tier markets where low slurry pricing is a key point to be competitive.
[0005] One cement system developed, FlexSTONE (Schlumberger), maintains high compressive and tensile strengths compared to conventional cements, and is used in steam flood operations. However the permeability of the cement is still a problem at 300 C.
[0006] Therefore the object of the invention is to provide a cost effective additive to increase the long-term permeability performances of set cement.
Summary of invention
Summary of invention
[0007] A cement slurry composition is disclosed that comprises a plugging agent polymer with a low Tg point.
[0008] The polymer can have a Tg point below 150 C. Having a low Tg point means that the polymer will melt at temperatures reached during thermal operations in the well, and flow into the pores of the cement matrix.
[0009] Preferably the polymer in the cement slurry composition is a wax. In a preferred composition the polymer is a polyethylene wax emulsion, polypropylene wax emulsion, carnauba wax emulsion or a scale wax emulsion. Waxes are a cost efficient additive that can be used.
[0010] A cement slurry composition can be a low density cement.
[0011] An aspect of the invention comprises a method for plugging the porosity of a cement matrix in a well comprising pumping the cement slurry comprising a plugging agent polymer with a glass transition point below 150 C into the well;
setting the cement in the well; heating the cement above the glass transition point of the plugging agent; and cooling the cement so that the additive will solidify.
setting the cement in the well; heating the cement above the glass transition point of the plugging agent; and cooling the cement so that the additive will solidify.
[0012] Preferably the method comprises performing a steam injection operation to heat the cement.
[0013] A method for lowering the permeability of a cement composition in a well comprising: adding a polymer with a glass transition point below 150 C to a cement slurry; and pumping the cement slurry into the well.
2a/7 Brief description of the drawings
2a/7 Brief description of the drawings
[0014] Figure 1 shows the dimensional range of solids and pores in hydrated cement paste;
Figure 2 shows a SEM of a capillary pores in a hardened cement paste;
and Figure 3 shows a graph of pore diameter (nm) versus penetration volume (cm3/g).
Mode(s) for carrying out the invention
Figure 2 shows a SEM of a capillary pores in a hardened cement paste;
and Figure 3 shows a graph of pore diameter (nm) versus penetration volume (cm3/g).
Mode(s) for carrying out the invention
[0015] When the cement is hydrated, interconnected pores of different sizes are formed, as shown in Figure 1. Pores in the cement matrix are formed by interparticle spacing between C-S-H sheets 1, capillary voids 2, hexagonal crystals of Ca(OH)2 or low sulphate in cement paste 3, aggregation of C-S-H particles 4, entrained air bubbles 5, entrapped air voids 6. The pores can be divided into macropores, capillary pores and gel pores. The interlayer spacing between C-S-H (gel pores) typically have a volume equal to about 28% of the gel and dimensions ranging from a few fractions of nm to several nm. These types of pores do not affect the durability of the material because they are too small to allow significant transport of aggressive species. The capillary pores are the voids not filled by the solid products of hydration of hardened cement paste. Figure 2 shows a cement consisting of micro-capillaries between the plate shaped crystals, a macro-capillary is also visible. The capillary pores typically have the dimensions of 10nm to 1 micron, depending on the curing time and on the water to cement ratio. Figure 3 depicts the pore diameter versus penetration volume. The capillary pores govern the durability of the material. To prevent interzonal communication, the permeability to water should not exceed 0.1mD. Therefore the invention provides cement slurries having solid particles that will fill the marcopores and when melted can flow through the smaller pores to reduce the pore interconnections, and therefore the permeability of the cement.
[0016] Solid particles of the additive are introduced into the cement slurry.
The particles have a size that allows the particles to be inserted into the macropores when the cement is hydrated, then when the temperature goes above the melting of these particles (during steam injection), the melted fluid flows through smaller pores reducing the pores interconnections.
The particles have a size that allows the particles to be inserted into the macropores when the cement is hydrated, then when the temperature goes above the melting of these particles (during steam injection), the melted fluid flows through smaller pores reducing the pores interconnections.
[0017] When the formation temperature is higher than the Tg of the polymer, such as during steam injection operation, the polymer will melt. Once the steam injection is over, temperature will cool down and the organic additive will solidify. Once the polymer is melted it is able to flow through the cement matrix, thus the polymer mobility will increase, and plug the microporosity of the cement. The formation fluids will first be blocked by the liquid state of the polymer during the steam injection operation and then by the resolidified polymer once the thermal recovery process is stopped and the cement matrix has cooled down. Water permeability of the set cement will be reduced because of the build up of plugs in the connected porosity.
Only a few different areas in the connected porosity need to be plugged to be efficient and to maintain a low cement permeability.
Only a few different areas in the connected porosity need to be plugged to be efficient and to maintain a low cement permeability.
[0018] The additive can be products such as D600 (styrene-butadiene latex), D700, D181 (polypropylene), or waxes. Preferred products are water based wax emulsions, as they contain a high content of solid for a low viscous fluid, as for a latex, but will not form a film during the hydration of cement, contrary to latex. Waxes are also cost effective. Preferred products include:
Material Commercial name Particle Melting size point Polyethylene Wax Emulsion Michem Emulsion 39235 0.35p 139 C
Polypropylene Wax Emulsion Michem Emulsion 43040 0.45p 157 C
Camauba Wax Emulsion Micheal Emulsion 67135 0.150p 82 C
Scale Wax Emulsion Michem Emulsion 0.500p 50 C
70750.E
Examples
Material Commercial name Particle Melting size point Polyethylene Wax Emulsion Michem Emulsion 39235 0.35p 139 C
Polypropylene Wax Emulsion Michem Emulsion 43040 0.45p 157 C
Camauba Wax Emulsion Micheal Emulsion 67135 0.150p 82 C
Scale Wax Emulsion Michem Emulsion 0.500p 50 C
70750.E
Examples
[0019] A water permeability set-up working around 60-70 C is used. Candidate polymer additives with a Tg around 40-50 C are selected. Three heavy oil cement systems are prepared:
[0020] 1. Reference system:
13.3ppb with Class A
40% BWOC D066 (silica flour) D047 (antifoam - polypropylene glycol) 0.2% BWOC D065 (TIC dispersant) 2% BWOC D020 (extender - bentonite) This formulation is labelled "thermal 40% in Canada"
13.3ppb with Class A
40% BWOC D066 (silica flour) D047 (antifoam - polypropylene glycol) 0.2% BWOC D065 (TIC dispersant) 2% BWOC D020 (extender - bentonite) This formulation is labelled "thermal 40% in Canada"
[0021] 2. Thermal 40% with 2 gal/sk of scale wax emulsion (Michem Emulsion 7050 0.5 microns SVF=52`)/0 melting point 500C):
1% D020 (extender - bentonite) 0.7%D065 (TIC dispersant) 0.05gps D175 (antifoam additive)
1% D020 (extender - bentonite) 0.7%D065 (TIC dispersant) 0.05gps D175 (antifoam additive)
[0022] 3. 12.75 ppg slurry with an oil and water emulsion - SVF is 30% Class A
cement with 40% BWOC D066 (silica flour) 28% by volume of slurry of oil 42% by volume of slurry of water 2.5% by weight of oil of D701 (gas-control agent) a few grams of D065 (TIC dispersant)
cement with 40% BWOC D066 (silica flour) 28% by volume of slurry of oil 42% by volume of slurry of water 2.5% by weight of oil of D701 (gas-control agent) a few grams of D065 (TIC dispersant)
[0023] Sample preparation
[0024] The sample are mixed and undergo a first curing of 1 week at 40 C. A
few cores of 2-inch length/1 inch diameter are extracted from each system.
Then the samples are cured at 275 C (525 F) for 6 hours. Maximum temperatures is maintained for 45 hours, then cool down gently.
few cores of 2-inch length/1 inch diameter are extracted from each system.
Then the samples are cured at 275 C (525 F) for 6 hours. Maximum temperatures is maintained for 45 hours, then cool down gently.
[0025] The curing time at 275 C is repeated for 1 week and then the samples are cooled down gently. This ensures that the reference system has deteriorated sufficiently (permeability >0/1mD).
[0026] Water permeability measurements of the three samples are taken at room temperature, and over 60 C (> melting point of the wax emulsion) and at 140 C for the reference and wax systems.
[0027] Results:
Sample Identification Specific permeability, mD Core description Three 1" diameter cement plug samples, measurements at room temperature Ref 0.184 Med grey, fine-med mottled texture, good plug Wax 0.205 Med grey, fine-med mottled texture, good plug 0/E 0.715 It grey, fine-med mottled = CA 02673866 2009-06-25 texture, good plug Two 1" diameter cement plug samples, measurements at 1400C
Ref 0.236 Med grey, fine-med mottled texture, good plug Wax 0.092 Med grey, fine-med mottled texture, good plug
Sample Identification Specific permeability, mD Core description Three 1" diameter cement plug samples, measurements at room temperature Ref 0.184 Med grey, fine-med mottled texture, good plug Wax 0.205 Med grey, fine-med mottled texture, good plug 0/E 0.715 It grey, fine-med mottled = CA 02673866 2009-06-25 texture, good plug Two 1" diameter cement plug samples, measurements at 1400C
Ref 0.236 Med grey, fine-med mottled texture, good plug Wax 0.092 Med grey, fine-med mottled texture, good plug
[0028] Crush tests after curing - 1 cylinder/system 1. Ref = 3200 psi 2. Wax = 1900 psi 3. 0/E = 1800 psi After crushing a purple/blue colour in the matrix of system 2 is observed.
[0029] Although the oil droplets of the 0/E act as fine particles for the rheology/FL
testing, but do not block the water permeability. A ratio of 5 between wax and the reference systems is expected, and confirms that wax can be used as an additive to plug the gaps in the cement.
testing, but do not block the water permeability. A ratio of 5 between wax and the reference systems is expected, and confirms that wax can be used as an additive to plug the gaps in the cement.
[0030] The water permeabilities are similar at room temperature (0.18 and 0.20mD). This is expected and the value agrees with the extended system.
[0031] At 140 C, the water permeabilities are no longer similar between the reference and wax systems. The wax system has lower water permeability than the reference system, 0.09 compared to 0.236mD. The water permeability of the wax system at 140 C is lower than at room temperature, 0.09 compared to 0.205mD.
[0032] As can be seen from the comparative measurements of water permeability the melted polymer has the ability to lower the connected porosity of a cement matrix. Concentration, molecular weight and particle shape will also have an impact on the mobility of the melted polymer.
Claims (6)
1. A method for plugging the porosity of a cement matrix in a well comprising pumping a cement slurry comprising a plugging agent polymer with a glass transition point below 150°C into the well; setting the cement in the well; heating the cement above the glass transition point of the plugging agent; and cooling the cement so that the additive will solidify.
2. A method according to claim 1 comprising performing a steam injection operation to heat the cement.
3. A method for lowering the permeability of a cement composition in a well comprising:
adding a polymer with a glass transition point below 150°C to a cement slurry; and pumping the cement slurry into the well.
adding a polymer with a glass transition point below 150°C to a cement slurry; and pumping the cement slurry into the well.
4. A method according to claims 1 or 3 wherein the polymer is a wax.
5. A method according to claim 4 wherein the polymer is a polyethylene wax emulsion, polypropylene wax emulsion, carnauba wax emulsion or a scale wax emulsion.
6. A method according to any one of claims 1 to 5 wherein the cement is a low density cement.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP06127253A EP1939264B1 (en) | 2006-12-27 | 2006-12-27 | Low permeability cement systems for steam injection application |
| EP06127253.0 | 2006-12-27 | ||
| GB0701118A GB0701118D0 (en) | 2007-01-22 | 2007-01-22 | Low permeability cement systems for steam injection application |
| GBGB0701118.2 | 2007-01-22 | ||
| PCT/EP2007/010959 WO2008077501A1 (en) | 2006-12-27 | 2007-12-13 | Low permeability cement systems for steam injection application |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2673866A1 CA2673866A1 (en) | 2008-07-03 |
| CA2673866C true CA2673866C (en) | 2015-04-28 |
Family
ID=39562115
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2673866A Expired - Fee Related CA2673866C (en) | 2006-12-27 | 2007-12-13 | Low permeability cement systems for steam injection application |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US8251143B2 (en) |
| BR (1) | BRPI0722073A2 (en) |
| CA (1) | CA2673866C (en) |
| RU (1) | RU2475623C2 (en) |
| WO (1) | WO2008077501A1 (en) |
Families Citing this family (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7673687B2 (en) * | 2007-12-05 | 2010-03-09 | Halliburton Energy Services, Inc. | Cement compositions comprising crystalline organic materials and methods of using same |
| US10947437B2 (en) | 2016-09-20 | 2021-03-16 | Saudi Arabian Oil Company | Chemical composition of superabsorbent vesicles, method for mortar cement admixture, and applications of the same |
| US10947438B2 (en) | 2016-09-20 | 2021-03-16 | Saudi Arabian Oil Company | Method for monitoring cement using polymer-based capsules |
| US10377940B2 (en) | 2016-09-20 | 2019-08-13 | Saudi Arabian Oil Company | Cement having cross-linked polymers |
| AU2017358979A1 (en) * | 2016-11-11 | 2019-05-02 | Shell Internationale Research Maatschappij B.V. | Process to prepare a solid cement composition |
| JP2021508664A (en) | 2018-01-02 | 2021-03-11 | サウジ アラビアン オイル カンパニー | Composition of Encapsulated Chemical Additive and Method for Preparing It |
| JP2021508794A (en) | 2018-01-02 | 2021-03-11 | サウジ アラビアン オイル カンパニー | Coating design for reagent capture |
| CA3087375A1 (en) | 2018-01-02 | 2019-07-11 | Saudi Arabian Oil Company | Material design for the encapsulation of additives and release |
| CN115806674B (en) * | 2021-09-15 | 2023-09-08 | 中国石油天然气股份有限公司 | Polypropylene glycol bonding modified nano SiO 2 Preparation method and application thereof |
Family Cites Families (25)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3368623A (en) | 1965-05-03 | 1968-02-13 | Halliburton Co | Permeable cement for wells |
| US3998269A (en) | 1975-10-10 | 1976-12-21 | Shell Oil Company | Plugging a subterranean reservoir with a self-sealing filter cake |
| CA1080870A (en) | 1976-03-24 | 1980-07-01 | William J. Long | Water-resistant gypsum composition and products and process of making same |
| NO162810C (en) * | 1982-04-06 | 1992-08-13 | Schlumberger Cie Dowell | CEMENT SUSPENSION AND PROCEDURE FOR CEMENTATION OF OIL BROWNS AND GEOTHERMIC BURNS. |
| FR2573064B1 (en) * | 1984-11-15 | 1991-10-25 | Schlumberger Cie Dowell | IMPROVED LIGHT-DUTY CEMENT MILK COMPOSITION FOR CEMENTING OIL WELLS AND GASES |
| US4806928A (en) * | 1987-07-16 | 1989-02-21 | Schlumberger Technology Corporation | Apparatus for electromagnetically coupling power and data signals between well bore apparatus and the surface |
| SU1657620A1 (en) * | 1989-06-12 | 1991-06-23 | Ивано-Франковский Институт Нефти И Газа | Well cementing method |
| US4972906A (en) | 1989-09-07 | 1990-11-27 | Conoco Inc. | Method for selective plugging of a zone in a well |
| US5433276A (en) * | 1994-10-17 | 1995-07-18 | Western Atlas International, Inc. | Method and system for inserting logging tools into highly inclined or horizontal boreholes |
| DE19522723A1 (en) * | 1995-01-21 | 1996-07-25 | Bilfinger Berger Bau | Hydraulic binder-contg. sealing wall material |
| US6092416A (en) * | 1997-04-16 | 2000-07-25 | Schlumberger Technology Corporation | Downholed system and method for determining formation properties |
| DE19745736A1 (en) * | 1997-10-16 | 1999-04-22 | Wacker Chemie Gmbh | Process for the treatment of water-borne natural gas and natural gas storage wells |
| UA73121C2 (en) * | 1999-06-04 | 2005-06-15 | Лусайт Інтернешнл Юк Лімітед | Acryl material, method to make it and fire-proof article |
| FR2810661B1 (en) * | 2000-06-21 | 2003-06-06 | Rhodia Chimie Sa | CEMENT COMPRISING ANISOTROPIC POLYMER PARTICLES, CEMENT PASTE, CONSOLIDATED MATERIAL, PREPARATION AND USES |
| FR2815029B1 (en) * | 2000-10-09 | 2003-08-01 | Inst Francais Du Petrole | ALMOND CEMENT DAIRY |
| US6866306B2 (en) * | 2001-03-23 | 2005-03-15 | Schlumberger Technology Corporation | Low-loss inductive couplers for use in wired pipe strings |
| US6641434B2 (en) * | 2001-06-14 | 2003-11-04 | Schlumberger Technology Corporation | Wired pipe joint with current-loop inductive couplers |
| AR034075A1 (en) * | 2002-05-31 | 2004-01-21 | Servicios Especiales San Antonio | A MILK FOR THE CEMENTATION OF HYDROCARBON PRODUCTION WELLS AND WATER INJECTOR WELLS, AND PROCEDURES FOR CEMENTING THE WELLS USING THE SIDED MILK |
| US6938692B2 (en) * | 2002-12-17 | 2005-09-06 | Halliburton Energy Services, Inc. | Permeable cement composition and method for preparing the same |
| GB2399083B (en) * | 2003-03-07 | 2007-09-19 | Schlumberger Holdings | flexible cementing compositions and methods for high-temperature wells |
| US20070204765A1 (en) | 2003-05-14 | 2007-09-06 | Sylvaine Le Roy-Delage | Self-Adaptive Cement Systems |
| US7413021B2 (en) * | 2005-03-31 | 2008-08-19 | Schlumberger Technology Corporation | Method and conduit for transmitting signals |
| CN1718652A (en) | 2005-07-21 | 2006-01-11 | 王立华 | Fiber reinforced type polymer cement waterproof paint |
| US7530396B1 (en) * | 2008-01-24 | 2009-05-12 | Halliburton Energy Services, Inc. | Self repairing cement compositions and methods of using same |
| EP2199359A1 (en) * | 2008-12-16 | 2010-06-23 | Services Pétroliers Schlumberger | Compositions and methods for completing subterranean wells |
-
2007
- 2007-12-13 WO PCT/EP2007/010959 patent/WO2008077501A1/en active Application Filing
- 2007-12-13 RU RU2009128658/03A patent/RU2475623C2/en not_active IP Right Cessation
- 2007-12-13 US US12/520,421 patent/US8251143B2/en not_active Expired - Fee Related
- 2007-12-13 CA CA2673866A patent/CA2673866C/en not_active Expired - Fee Related
- 2007-12-13 BR BRPI0722073-1A2A patent/BRPI0722073A2/en not_active IP Right Cessation
Also Published As
| Publication number | Publication date |
|---|---|
| RU2475623C2 (en) | 2013-02-20 |
| RU2009128658A (en) | 2011-02-10 |
| BRPI0722073A2 (en) | 2014-04-08 |
| WO2008077501A1 (en) | 2008-07-03 |
| US20100065272A1 (en) | 2010-03-18 |
| CA2673866A1 (en) | 2008-07-03 |
| US8251143B2 (en) | 2012-08-28 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2673866C (en) | Low permeability cement systems for steam injection application | |
| US9903184B2 (en) | Consolidating spacer fluids and methods of use | |
| CA2178707C (en) | Cementing compositions and the application of such compositions to cementing oil or analogous wells | |
| US8555967B2 (en) | Methods and systems for evaluating a boundary between a consolidating spacer fluid and a cement composition | |
| US7470321B2 (en) | Cementing compositions and application thereof to cementing oil wells or the like | |
| CA2745992A1 (en) | Compositions and methods for completing subterranean wells | |
| US8834624B2 (en) | Modified cement composition, preparation and application thereof | |
| EP1939264B1 (en) | Low permeability cement systems for steam injection application | |
| WO2009074658A1 (en) | Squeeze composition for restoring isolation | |
| US20200109327A1 (en) | Cement with resilient latex polymer | |
| US11535789B1 (en) | Methods of making and using a high temperature cementitious composition | |
| US7832479B2 (en) | Polymeric extenders for flexible cement | |
| CA2918017C (en) | Liquid additive for cement resiliency | |
| NO20160830A1 (en) | Settable compositions and methods of use | |
| US20200002597A1 (en) | Process to prepare a solid cement composition | |
| Awl et al. | Experimental Investigation on The Effect of PolyVinyl Alcohol on Cement Fluid Loss in Oil Wells | |
| WO2014176491A1 (en) | Methods and systems for evaluating a boundary between a consolidating spacer fluid and a cement composition |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20181213 |