WO1994021886A1 - Method for isolating a wellbore formation zone - Google Patents
Method for isolating a wellbore formation zone Download PDFInfo
- Publication number
- WO1994021886A1 WO1994021886A1 PCT/US1994/003273 US9403273W WO9421886A1 WO 1994021886 A1 WO1994021886 A1 WO 1994021886A1 US 9403273 W US9403273 W US 9403273W WO 9421886 A1 WO9421886 A1 WO 9421886A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- wellbore
- zone
- solid
- casing
- solidifiable
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 36
- 230000015572 biosynthetic process Effects 0.000 title claims description 35
- 239000000203 mixture Substances 0.000 claims abstract description 36
- 239000007787 solid Substances 0.000 claims abstract description 32
- 239000003822 epoxy resin Substances 0.000 claims abstract description 21
- 229920000647 polyepoxide Polymers 0.000 claims abstract description 21
- 239000003795 chemical substances by application Substances 0.000 claims description 30
- 239000012530 fluid Substances 0.000 claims description 27
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 17
- 239000003085 diluting agent Substances 0.000 claims description 11
- 229920005989 resin Polymers 0.000 claims description 11
- 239000011347 resin Substances 0.000 claims description 11
- PXKLMJQFEQBVLD-UHFFFAOYSA-N bisphenol F Chemical compound C1=CC(O)=CC=C1CC1=CC=C(O)C=C1 PXKLMJQFEQBVLD-UHFFFAOYSA-N 0.000 claims description 10
- 239000000945 filler Substances 0.000 claims description 10
- 239000011343 solid material Substances 0.000 claims description 10
- 239000004593 Epoxy Substances 0.000 claims description 9
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 9
- 239000001569 carbon dioxide Substances 0.000 claims description 8
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 8
- 238000010795 Steam Flooding Methods 0.000 claims description 6
- 238000006073 displacement reaction Methods 0.000 claims description 6
- 150000002118 epoxides Chemical class 0.000 claims description 6
- KUBDPQJOLOUJRM-UHFFFAOYSA-N 2-(chloromethyl)oxirane;4-[2-(4-hydroxyphenyl)propan-2-yl]phenol Chemical compound ClCC1CO1.C=1C=C(O)C=CC=1C(C)(C)C1=CC=C(O)C=C1 KUBDPQJOLOUJRM-UHFFFAOYSA-N 0.000 claims description 5
- BRLQWZUYTZBJKN-UHFFFAOYSA-N Epichlorohydrin Chemical compound ClCC1CO1 BRLQWZUYTZBJKN-UHFFFAOYSA-N 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 5
- 238000011084 recovery Methods 0.000 claims description 5
- 230000002209 hydrophobic effect Effects 0.000 claims description 4
- 239000011800 void material Substances 0.000 claims description 4
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 claims description 3
- 125000001931 aliphatic group Chemical group 0.000 claims description 3
- GYZLOYUZLJXAJU-UHFFFAOYSA-N diglycidyl ether Chemical compound C1OC1COCC1CO1 GYZLOYUZLJXAJU-UHFFFAOYSA-N 0.000 claims description 3
- 230000007613 environmental effect Effects 0.000 claims description 3
- 239000007789 gas Substances 0.000 claims description 3
- 229920000768 polyamine Polymers 0.000 claims description 3
- 238000002955 isolation Methods 0.000 abstract description 7
- 239000004033 plastic Substances 0.000 abstract description 5
- 238000005755 formation reaction Methods 0.000 description 29
- 239000012260 resinous material Substances 0.000 description 14
- 239000000463 material Substances 0.000 description 12
- 239000000499 gel Substances 0.000 description 8
- 239000003921 oil Substances 0.000 description 8
- 239000012267 brine Substances 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 6
- 239000002253 acid Substances 0.000 description 5
- 230000005484 gravity Effects 0.000 description 5
- 229910052751 metal Inorganic materials 0.000 description 5
- 239000002184 metal Substances 0.000 description 5
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 4
- 239000000654 additive Substances 0.000 description 4
- 230000000996 additive effect Effects 0.000 description 4
- 239000002981 blocking agent Substances 0.000 description 4
- 238000004132 cross linking Methods 0.000 description 4
- 238000005553 drilling Methods 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000000700 radioactive tracer Substances 0.000 description 4
- 230000000246 remedial effect Effects 0.000 description 4
- INQOMBQAUSQDDS-UHFFFAOYSA-N iodomethane Chemical compound IC INQOMBQAUSQDDS-UHFFFAOYSA-N 0.000 description 3
- FVAUCKIRQBBSSJ-UHFFFAOYSA-M sodium iodide Chemical compound [Na+].[I-] FVAUCKIRQBBSSJ-UHFFFAOYSA-M 0.000 description 3
- 239000002904 solvent Substances 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- ZCYVEMRRCGMTRW-UHFFFAOYSA-N 7553-56-2 Chemical compound [I] ZCYVEMRRCGMTRW-UHFFFAOYSA-N 0.000 description 2
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 2
- 150000008064 anhydrides Chemical class 0.000 description 2
- GZUXJHMPEANEGY-UHFFFAOYSA-N bromomethane Chemical compound BrC GZUXJHMPEANEGY-UHFFFAOYSA-N 0.000 description 2
- 239000004568 cement Substances 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 230000005251 gamma ray Effects 0.000 description 2
- 150000002430 hydrocarbons Chemical group 0.000 description 2
- 229910052740 iodine Inorganic materials 0.000 description 2
- 239000011630 iodine Substances 0.000 description 2
- 239000003915 liquefied petroleum gas Substances 0.000 description 2
- 230000035939 shock Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000010959 steel Substances 0.000 description 2
- 239000012808 vapor phase Substances 0.000 description 2
- 239000011345 viscous material Substances 0.000 description 2
- MWSKJDNQKGCKPA-UHFFFAOYSA-N 6-methyl-3a,4,5,7a-tetrahydro-2-benzofuran-1,3-dione Chemical compound C1CC(C)=CC2C(=O)OC(=O)C12 MWSKJDNQKGCKPA-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- LGRFSURHDFAFJT-UHFFFAOYSA-N Phthalic anhydride Natural products C1=CC=C2C(=O)OC(=O)C2=C1 LGRFSURHDFAFJT-UHFFFAOYSA-N 0.000 description 1
- 239000004952 Polyamide Substances 0.000 description 1
- 230000002378 acidificating effect Effects 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 150000001350 alkyl halides Chemical class 0.000 description 1
- RDHPKYGYEGBMSE-UHFFFAOYSA-N bromoethane Chemical compound CCBr RDHPKYGYEGBMSE-UHFFFAOYSA-N 0.000 description 1
- JHIWVOJDXOSYLW-UHFFFAOYSA-N butyl 2,2-difluorocyclopropane-1-carboxylate Chemical compound CCCCOC(=O)C1CC1(F)F JHIWVOJDXOSYLW-UHFFFAOYSA-N 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 230000003197 catalytic effect Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000001010 compromised effect Effects 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000006866 deterioration Effects 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 235000013312 flour Nutrition 0.000 description 1
- LNEPOXFFQSENCJ-UHFFFAOYSA-N haloperidol Chemical compound C1CC(O)(C=2C=CC(Cl)=CC=2)CCN1CCCC(=O)C1=CC=C(F)C=C1 LNEPOXFFQSENCJ-UHFFFAOYSA-N 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000002452 interceptive effect Effects 0.000 description 1
- 238000009533 lab test Methods 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 229940102396 methyl bromide Drugs 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000012188 paraffin wax Substances 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 125000000951 phenoxy group Chemical group [H]C1=C([H])C([H])=C(O*)C([H])=C1[H] 0.000 description 1
- 229920002647 polyamide Polymers 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 230000001681 protective effect Effects 0.000 description 1
- 230000002285 radioactive effect Effects 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 235000009518 sodium iodide Nutrition 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 150000003512 tertiary amines Chemical class 0.000 description 1
- 230000004580 weight loss Effects 0.000 description 1
Classifications
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/502—Oil-based compositions
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
- E21B29/00—Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
- E21B29/10—Reconditioning of well casings, e.g. straightening
-
- 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
- E21B33/138—Plastering the borehole wall; Injecting into the formation
Definitions
- This invention is directed to a method for isloating a zone of a formation or reservoir penetrated by a wellbore. More particularyl, the invention related to a method for the repair or replacement of a damaged or corroded section of wellbore casing located in a subterranean formation.
- a wall of a wellbore being drilled is generally sealed and stabilized by means of a protective steel casing which is lowered through a wellbore. Afterwards, the casing is cemented in place after retrieval of the drilling assembly. Setting a steel casing in a well is a time consuming and expensive procedure. Since the wellbore is essential to removing desired fluids from a subterranean formation, it is necessary that the wellbore casing remains intact to make for a more efficient operation and avoid the loss of wellbore fluids into the formation.
- the wellbore becomes damaged or corroded.
- the damage may be caused by excessive pressure within the wellbore which will cause a section of wellbore casing to fail thereby interfering with its integrity.
- wellbores which are located at levels below about 5,000 ft (1524 m) will often have an environment where high temperatures, high pressures, and corrosive chemicals are encountered. When these chemicals, pressures and temperatures combine, casing corrosion often occurs thereby necessitating the repair of a section of the casing so as to maintain its integrity thereby avoiding a loss of desired fluids into the formation.
- the wellbore is filled with fluids, particulary brine, which interfere with the integrity of many gel systems utilized for zone isolation.
- fluids particulary brine
- zone isolation the integrity of a subsequently formed gel or blocking agent is compromised by enhanched oil recovery (EOR) operations which employ water or carbon dioxide.
- EOR enhanched oil recovery
- Carbon dioxide can cause a gel or blocking agent to deteriorate in an acid environment which shortenes its life and minimizes its effectiveness.
- Low temperatures encountered in some formations also keep some gels or blocking agents from making effective gels or blocking agents.
- a method for isolating a zone of a formation or reservoir penetrated by a wellbore comprising: a) directing a solidifiable epoxy resin mixture admixed with a curing agent into a desired zone of said formation via the wellbore which solidifiable mixture is in an amount sufficient to fill said zone to a desired depth in said formation; b) allowing said resin and curing agent to remain in said zone for a time sufficient to form a hardened solid able to withstand environmental conditions existing in the zone while precluding fluid flow therethroug ; and c) removing any excess solid material from the wellbore so as to form a solid wall bonded to and having a diameter substantially similar to said casing thereby isolating said zone from fluid flow.
- the method is used for repairing a damaged or corroded wellbore section of casing located within said zone, in which case: in step (a) said solidifiable solid epoxy resin mixture is directed into the damaged or corroded section in an amount sufficient to fill a space or void within said damaged or corroded section; and the completion of step (c) results in the repair of the corroded or damaged section.
- the solidifiable mixture comprises additionally a diluent and a filler.
- the solidifiable mixture is directed or flowed into the space or void and wellbore adjacent thereto by a positive displacement dump-bailer or by a coiled tubing.
- the solid which is formed has a fracture toughness able to withstand perforations being placed therein.
- the hardened solid is able to preclude formation gases and liquids from flowing therethrough.
- step c) the solid wall desirably forms a liner with the undamaged or uncorroded casing.
- the solidifiable mixture can be directed into said zone by the placement of a mechanical packer below it.
- the solidifiable mixture is hydrophobic and forms a hardened solid at a temperature of about 80° F (27°C) which solid is able to withstand temperatures encountered in steam-flooding EOR operation.
- the solidifiable mixture desirably contains: a bisphenol-A epichlorohydrin epoxy resin with an epoxide equivalent weight of about 185 to about 192; or a bisphenol-F epichlorohydrin epoxy resin with an epoxide equivalent weight of about 166 to about 177.
- the solidifiable mixture contains: a bisphenol-A epichlorohydrin epoxy resin or a bisphenol-F epichlorohydrin epoxy resin; a monofunctional glycidyl ether diluent comprised of C 8 -C 10 alkyl groups; and a phenalkamine epoxy curing agent, or a Mannich base aliphatic polyamine attached to a phenol curing agent.
- the mixture further comprises a filler.
- the wellbore is a water containing wellbore, then it is desirable that the mixture is unaffected by said water.
- a steam-flooding, carbon dioxide flooding, water-flooding, miscible or immiscible EOR method is initiated in another zone of said formation.
- Figure l is a schematic representation of a cased wellbore where channels have been made in the casing thereby communicating the wellbore with a thief zone.
- Figure 2 is a schematic representation which details the formation of a solid material in the wellbore and also in the area of the wellbore where the casing has been removed and underreamed. Additionally, it shows the solid material in a thief zone which communicated previously with the wellbore.
- Figure 3 is a schematic representation which shows replacement of the damaged or corroded casing and cement behind the casing by the solid plastic after removing excess solid material from the wellbore.
- a wellbore penetrates formation 10, producing zone 12, and thief zone 14.
- the borehole contains cement 18 and casing 20.
- casing 20 During the removal of hydrocarbonaceous or other desired fluids from the formation, conditions existing at the lower portion of the wellbore have caused casing 20 to be damaged by channels 22. These channels 22 allow fluids to move from the wellbore into a thief zone 14. Ordinarily, it would be necessary to remove the entire casing 20 and replace it with a new casing.
- the casing is comprised of the remaining solid material that abuts the metal casing which was already in the wellbore. Any solidifiable material which flowed into thief zone 14 remains therein as a solid.
- the completed wellbore casing containing the repaired section comprising the solid material is shown in Figure 3.
- a drillable mechanical packer (not shown) can be placed below the portion of the casing which it is desired to repair or replace.
- the solidifiable mixture is flowed into the wellbore and is placed on the drillable packer whereupon it flows into channels which communicate with a thief zone or other zone of the formation. Subsequently, the solidifiable mixture will form a solid material which is subsequently drilled out along with the drillable packer. Once this has been done, the well can be produced as desired.
- the solidifiable material may comprise a resinous material.
- This solidifiable material can be used to isolate zones of a formation to prevent gravity override and for profile control. Gravity override and profile control are discussed in US-A-
- a positive displacement dump bailer This is a mechanical device, symmetrical in shape, which is filled with a mixture of resinous material and an acid or alkaline curing agent. It is lowered into the wellbore by a cable. The bailer is positioned at the desired depth above the damaged casing or packer and when activated, releases a metal bar in the top of the device. The bar falls downward inside the device and impacts the top of the fluid creating a downward- moving shock wave which travels through the fluid column contained in the bailer. The shock wave causes a shearing of metal pins in the bottom of the bailer and a subsequent downward movement of the small piston.
- This small piston uncovers ports to allow a release of the resinous material.
- the bar continues to fall through the bailer as fluid is released through the ports.
- the weight of the metal bar effectively adds to the weight of the fluid column being dumped.
- the cylindrical bailer is wiped clean of the resinous material containing an acid or alkaline curing agent.
- a coiled tubing may also be used to place the viscous resinous material at the site from which the damaged casing has been removed.
- the coiled tubing consists of a one-inch or other small pipe which is wound on a spool at the surface of borehole 16.
- the viscous resinous material and curing agent therein are placed in the end of the tubing and held in place by wiper balls at the top and at the bottom of the resinous material.
- the tubing is then uncoiled and lowered into the wellbore above the site where it is desired to replace the casing. Thereafter, the viscous resinous material with curing agent therein is pressured through the tubing and released into the wellbore where it flows into the thief zone via channels 22 and contacts casing 20.
- the resinous material enters thief zone 14 via channels 22. Because the resinous material with curing agent therein is fast acting, a solid is formed in the wellbore and thief zone 14. This material, of course, can be held in place by a drillable packer if required. The material is allowed to harden in thief zone 14 and the wellbore.
- the preferred resin for use herein comprises an epoxy resin, a curing agent, a reactive diluent, and a filler.
- An example of epoxy resin is Shell's EPON-828R, a bisphenol-A epichlorohydrin epoxy resin with an epoxide equivalent weight of 185-192.
- Another epoxy resin is Shell's EPON DPL-862, a bisphenol-F epichlorohydrin epoxy resin with an epoxide equivalent weight of 166-177.
- the epoxy resin is blended with a reactive diluent and a filler.
- An example of the reactive diluent is Scherling Berlin's Diluent 7, a monofunctional glycidyl ether based on alkyl groups of C 8 -C 10 .
- the diluent is used to increase pot life or gel time of the epoxy resin and to increase load capacity for the filler.
- a large amount of filler (up to 50% by weight relative to the epoxy resin) is added to the resin mixture. It serves to increase the specific gravity of the resin mixture for gravity dump-bailing applications and for application in deep wells.
- the filler is also used as a heat sink to allow more working time.
- An example of the filler is a fine powder of calcium carbonate or silica flour.
- a crosslinking or curing agent is then added to the resin mixture. This makes a fast-reacting gel which hardens in a short period of time.
- epoxy curing agents manufactured by Cardolite Inc. can be used for typical oil field applications such as injection profile control, remedial cementing, and casing repair. These curing agents are sold under the NC-540, NC-541, and NC-541 LV trademames and can be purchased from Cardolite Inc. which is located in Newark, New Jersey, U.S.A. These curing agents are phenalka ine compounds with a long hydrocarbon chain attached to a phenoxy group. This curing agent participates in the crosslinking mechanism and forms a hard resin. Phenalkamine curing agents display a a strongly hydrophobic behavior after mixing with an epoxy resin. Thus, they are suitable for downhole applications where the epoxy system may mix with the wellbore fluids, typically brine. Hydrophobic behavior of the epoxy system ensures that the epoxy system will form a hard solid even when some mixing with wellbore brine occurs.
- Samples of the hard solid sample above obtained from crosslinking the epoxy resin with the phenalkamine curing agent were tested for resistance to carbon dioxide and hydrochloric acid.
- One sample was placed in two autoclaves and tested at a temperature of 80°F and a pressure of about 1,700 psi (12 MPa) for three weeks.
- One autoclave contained a highly saturated carbon dioxide and brine environment.
- the other contained a 28 volume % solution of hydrochloric acid.
- the sample showed substantially no deterioration thereby demonstrating that the sample was chemically resistant to high pressure carbon dioxide and brine as well as being tolerant to a strong acid.
- the residual strength of the samples was at least about 6,000 psi (41 Mpa) .
- the integrity of the samples were substantially preserved.
- Schering Berlin's Euredur 3123 a polyamide epoxy curing agent
- Cardolite curing agents to increaase potlife.
- This curing agent contains a Mannich base aliphatic polyamine attached to a phenol group.
- a catalytic tertiary amine can also be blended with the aforementioned curing agents.
- an anhydride such as Ashland Chemical Company's phthalic anhydride or a liquid anhydride of methyl tetrahydrophthalic anhydride can be used.
- the concentration and volume of curing agent utilized must be customized according to the temperature of the well right before the dump-bailing operation. This allows the resin to have about twenty minutes of flow time and to gel in about 60 minutes.
- the amount of various batches of the resinous material to be utilized depends on the hole size to be filled.
- the resin plugs the bottom of thief zone 14 and binds with the undamaged portion of casing 20.
- the resinous or solid plastic which forms should have a fracture toughness able to withstand perforations being placed therein so as to remove fluids from a producing zone. In addition to forming a solid liner, the resinous material or plastic should be able to preclude formation gases and liquids from flowing therethrough.
- a five to fifteen weight percent solution of a reactive diluent is utilized.
- Use of this concentration of diluent allows for efficient draining of the dump-bailer or for speeding up resin penetration into any cracks or channels behind the casing. It has also been determined that it is best to use a resin which is substantially fresh. Freshness can be determined by a measurement of the resinous material's viscosity. If the viscosity is over a recommended tolerance limit, i should be rejected. The preferred viscosity range is about 4,000 to 11,000 centipoise at 75°F (24°C) .
- a simple, rugged capillary viscometer is available to measure the viscosity obtained. This viscometer can be obtained from Baxter Scientific Products.
- the epoxy resin and crosslinking system above mentioned can be utilized in oil field workovers such as zone isolation or remedial cementing.
- a mechanical packer can be positioned in the wellbore so as to prevent solidifiable material from entering an undesired zone. Once the desired volume of solidifiable material has been placed into the zone or damaged area, placement of solidifiable material into that zone or area is terminated and the material is allowed to form a hardened solid. Excess hardened material can be removed from the wellbore by drilling to minimize damage to the productive zones. After removing excess hardened material from the wellbore, production can be commenced or an EOR can be initiated in a desired zone.
- the viscosity of the solidifiable material is tailored so as to flow into the zone desired to be isolated or repaired.
- a desired viscosity can be determined from core samples taken from the fomation, existing data, or by use of a survey of the vertical portion of the formation near the wellbore to determine the rate and volume of fluids entering various zones of the formation.
- spinner survey The first of these methods is known as a "spinner survey".
- a tool containing a freely rotating impeller is placed in the wellbore.
- steam passes the impeller, it rotates at a rate which depends on the velocity of the steam.
- the rotation of the impeller is translated into an electrical signal which is transmitted up the logging cable to the surface where it is recorded on a strip chart or other recording device.
- Radioactive tracer surveys are also used in many situations. With this method methyl iodide (131) has been used to trace the vapor phase. Sodium iodide has been used to trace the liquid phase. Radioactive iodine is injected into the steam between the steam generator and the injection well. Injected tracer moves down the tubing with the steam until it reaches the formation, where the tracer is temporarily held on the face of -li ⁇ the formation for several minutes. A typical gamma ray log is then run immediately following the tracer injection. The recorded gamma ray intensity at any point in the well is then assumed to be proportional to the amount of steam injected at that point.
- Vapor phase tracers have variously been described as alkyl halides (methyl iodide, methyl bromide, and ethyl bromide) or elemental iodine.
- a miscible or immiscible, a steam-flooding, C0 2 -flooding, or water-flooding EOR process can be initiated in either producing zone 20 or thief zone 14 of the formation after zone isolation or remedial cementing of a zone or casing.
- Miscible recovery operations are normally carried out by a displacement procedure in which the solvent is injected into the reservoir through an injection well to displace oil from the reservoir towards a production well from which the oil is produced.
- the solvent typically a light hydrocarbon such as liquid petroleum gas (LPG) or a paraffin in the C 2 to C 6 range
- LPG liquid petroleum gas
- a flooding process can be carried out under conditions of immiscibility or near-immiscibility by utilizing a displacing fluid such as carbon dioxide and an additive such as ethane which increases the solubility of the displacing fluid in reservoir oil.
- the additive is injected in a slug with the displacing fluid preferably followed by a slug of water to improve sweep. Afterwards,the displacing fluid alone may be injected to extract residual additive and oil. A number of slugs of displacing fluid, either by itself or with the additive may be injected, with intervening slugs of water and finally, water injection may be made to termination. This process is disclosed in US-A- 4617996.
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU63691/94A AU6369194A (en) | 1993-03-19 | 1994-03-17 | Method for isolating a wellbore formation zone |
EP94911000A EP0688393A4 (en) | 1993-03-19 | 1994-03-17 | Method for isolating a wellbore formation zone |
NO953685A NO953685D0 (en) | 1993-03-19 | 1995-09-18 | Method of isolating a formation or reservoir penetrated by a borehole |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US035,101 | 1993-03-19 | ||
US08/035,101 US5404950A (en) | 1992-12-22 | 1993-03-19 | Low temperature underwater epoxy system for zone isolation, remedial cementing, and casing repair |
Publications (1)
Publication Number | Publication Date |
---|---|
WO1994021886A1 true WO1994021886A1 (en) | 1994-09-29 |
Family
ID=21880650
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US1994/003273 WO1994021886A1 (en) | 1993-03-19 | 1994-03-17 | Method for isolating a wellbore formation zone |
Country Status (6)
Country | Link |
---|---|
US (2) | US5404950A (en) |
EP (1) | EP0688393A4 (en) |
AU (1) | AU6369194A (en) |
CA (1) | CA2157409A1 (en) |
NO (1) | NO953685D0 (en) |
WO (1) | WO1994021886A1 (en) |
Cited By (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0898050A1 (en) * | 1997-08-18 | 1999-02-24 | Halliburton Energy Services, Inc. | Methods and compositions for sealing pipe strings in well bores |
EP0898049A1 (en) * | 1997-08-18 | 1999-02-24 | Halliburton Energy Services, Inc. | Remedial well bore sealing method |
EP0899417A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of modifying subterranean strata properties |
EP0899418A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Modifying subterranean strata |
EP0899416A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of sealing conduits in lateral well bores |
EP0899317A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Well drilling fluid |
EP0899415A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of sealing pipe string in well bores |
EP0903461A1 (en) * | 1997-08-18 | 1999-03-24 | Halliburton Energy Services, Inc. | Methods of sealing plugs in well bores |
EP1300545A1 (en) * | 2001-10-08 | 2003-04-09 | Services Petroliers Schlumberger | Borehole stabilisation |
US6802375B2 (en) | 2000-05-22 | 2004-10-12 | Shell Oil Company | Method for plugging a well with a resin |
US7059415B2 (en) | 2001-07-18 | 2006-06-13 | Shell Oil Company | Wellbore system with annular seal member |
EP2143874A1 (en) * | 2008-07-11 | 2010-01-13 | Welltec A/S | Sealing arrangement and sealing method |
WO2021181146A1 (en) * | 2020-03-12 | 2021-09-16 | Saudi Arabian Oil Company | Robotic pigging tool |
Families Citing this family (16)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6766854B2 (en) | 1997-06-02 | 2004-07-27 | Schlumberger Technology Corporation | Well-bore sensor apparatus and method |
US6213209B1 (en) * | 1998-12-02 | 2001-04-10 | Halliburton Energy Services, Inc. | Methods of preventing the production of sand with well fluids |
US6776236B1 (en) | 2002-10-16 | 2004-08-17 | Halliburton Energy Services, Inc. | Methods of completing wells in unconsolidated formations |
US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
CN101705808B (en) * | 2009-12-11 | 2012-05-30 | 安东石油技术(集团)有限公司 | Sectional flow control method for flow control filter pipe column of oil-gas well with bushing outside channel |
WO2012145488A2 (en) | 2011-04-20 | 2012-10-26 | Smith International, Inc. | System and method for deploying a downhole casing patch |
US10214988B2 (en) | 2015-08-12 | 2019-02-26 | Csi Technologies Llc | Riserless abandonment operation using sealant and cement |
US10378299B2 (en) | 2017-06-08 | 2019-08-13 | Csi Technologies Llc | Method of producing resin composite with required thermal and mechanical properties to form a durable well seal in applications |
US10428261B2 (en) | 2017-06-08 | 2019-10-01 | Csi Technologies Llc | Resin composite with overloaded solids for well sealing applications |
CA2972203C (en) | 2017-06-29 | 2018-07-17 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
CA2974712C (en) | 2017-07-27 | 2018-09-25 | Imperial Oil Resources Limited | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
CA2978157C (en) | 2017-08-31 | 2018-10-16 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
CA2983541C (en) | 2017-10-24 | 2019-01-22 | Exxonmobil Upstream Research Company | Systems and methods for dynamic liquid level monitoring and control |
CN111075393B (en) * | 2019-12-18 | 2021-11-30 | 中国石油天然气股份有限公司 | Oil-gas field casing damage well long well section plugging resin repair process |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2187275A (en) * | 1937-01-12 | 1940-01-16 | Amos N Mclennan | Means for locating and cementing off leaks in well casings |
US3111991A (en) * | 1961-05-12 | 1963-11-26 | Pan American Petroleum Corp | Apparatus for repairing well casing |
US3121463A (en) * | 1962-01-22 | 1964-02-18 | Sinclair Research Inc | Method for decreasing well permeability using electrical conductive compositions |
US4189002A (en) * | 1978-07-07 | 1980-02-19 | The Dow Chemical Company | Method for rigless zone abandonment using internally catalyzed resin system |
US4756369A (en) * | 1986-11-26 | 1988-07-12 | Mobil Oil Corporation | Method of viscous oil recovery |
US5129458A (en) * | 1990-06-07 | 1992-07-14 | Shell Oil Company | Treating an underground formation |
Family Cites Families (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2734580A (en) * | 1956-02-14 | layne | ||
US2447629A (en) * | 1944-05-23 | 1948-08-24 | Richfield Oil Corp | Apparatus for forming a section of casing below casing already in position in a well hole |
US2495352A (en) * | 1945-12-12 | 1950-01-24 | Dow Chemical Co | Well repair |
US3199598A (en) * | 1962-07-02 | 1965-08-10 | Loomis Jean Doyle | Apparatus for testing and repairing well pipes |
US3844349A (en) * | 1973-01-26 | 1974-10-29 | Mobil Oil Corp | Petroleum production by steam injection |
US3960801A (en) * | 1973-06-18 | 1976-06-01 | Halliburton Company | Pumpable epoxy resin composition |
US3967681A (en) * | 1975-09-30 | 1976-07-06 | Phillips Petroleum Company | Repair of cement sheath around well casing |
US4489783A (en) * | 1982-12-07 | 1984-12-25 | Mobil Oil Corporation | Viscous oil recovery method |
US4489785A (en) * | 1983-07-19 | 1984-12-25 | Halliburton Company | Method of completing a well bore penetrating a subterranean formation |
US4617996A (en) * | 1985-02-22 | 1986-10-21 | Mobil Oil Corporation | Immiscible oil recovery process |
US4754810A (en) * | 1987-03-16 | 1988-07-05 | Conoco Inc. | Method for patching casing leaks |
US4844163A (en) * | 1987-12-29 | 1989-07-04 | Mobil Oil Corporation | In-situ foaming of polymer profile control gels |
US4972906A (en) * | 1989-09-07 | 1990-11-27 | Conoco Inc. | Method for selective plugging of a zone in a well |
US5178219A (en) * | 1991-06-27 | 1993-01-12 | Halliburton Company | Method and apparatus for performing a block squeeze cementing job |
US5195588A (en) * | 1992-01-02 | 1993-03-23 | Schlumberger Technology Corporation | Apparatus and method for testing and repairing in a cased borehole |
US5377757A (en) * | 1992-12-22 | 1995-01-03 | Mobil Oil Corporation | Low temperature epoxy system for through tubing squeeze in profile modification, remedial cementing, and casing repair |
US5295541A (en) * | 1992-12-22 | 1994-03-22 | Mobil Oil Corporation | Casing repair using a plastic resin |
US5314023A (en) * | 1993-01-19 | 1994-05-24 | Dartez Terry R | Method for selectively treating wells with a low viscosity epoxy resin-forming composition |
-
1993
- 1993-03-19 US US08/035,101 patent/US5404950A/en not_active Expired - Fee Related
-
1994
- 1994-03-17 EP EP94911000A patent/EP0688393A4/en not_active Withdrawn
- 1994-03-17 CA CA002157409A patent/CA2157409A1/en not_active Abandoned
- 1994-03-17 WO PCT/US1994/003273 patent/WO1994021886A1/en not_active Application Discontinuation
- 1994-03-17 AU AU63691/94A patent/AU6369194A/en not_active Abandoned
-
1995
- 1995-03-28 US US08/413,026 patent/US5531272A/en not_active Expired - Fee Related
- 1995-09-18 NO NO953685A patent/NO953685D0/en unknown
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2187275A (en) * | 1937-01-12 | 1940-01-16 | Amos N Mclennan | Means for locating and cementing off leaks in well casings |
US3111991A (en) * | 1961-05-12 | 1963-11-26 | Pan American Petroleum Corp | Apparatus for repairing well casing |
US3121463A (en) * | 1962-01-22 | 1964-02-18 | Sinclair Research Inc | Method for decreasing well permeability using electrical conductive compositions |
US4189002A (en) * | 1978-07-07 | 1980-02-19 | The Dow Chemical Company | Method for rigless zone abandonment using internally catalyzed resin system |
US4756369A (en) * | 1986-11-26 | 1988-07-12 | Mobil Oil Corporation | Method of viscous oil recovery |
US5129458A (en) * | 1990-06-07 | 1992-07-14 | Shell Oil Company | Treating an underground formation |
Cited By (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0898049A1 (en) * | 1997-08-18 | 1999-02-24 | Halliburton Energy Services, Inc. | Remedial well bore sealing method |
EP0899417A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of modifying subterranean strata properties |
EP0899418A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Modifying subterranean strata |
EP0899416A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of sealing conduits in lateral well bores |
EP0899317A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Well drilling fluid |
EP0899415A1 (en) * | 1997-08-18 | 1999-03-03 | Halliburton Energy Services, Inc. | Method of sealing pipe string in well bores |
EP0903461A1 (en) * | 1997-08-18 | 1999-03-24 | Halliburton Energy Services, Inc. | Methods of sealing plugs in well bores |
EP0898050A1 (en) * | 1997-08-18 | 1999-02-24 | Halliburton Energy Services, Inc. | Methods and compositions for sealing pipe strings in well bores |
US6802375B2 (en) | 2000-05-22 | 2004-10-12 | Shell Oil Company | Method for plugging a well with a resin |
US7059415B2 (en) | 2001-07-18 | 2006-06-13 | Shell Oil Company | Wellbore system with annular seal member |
EP1300545A1 (en) * | 2001-10-08 | 2003-04-09 | Services Petroliers Schlumberger | Borehole stabilisation |
WO2003031768A1 (en) * | 2001-10-08 | 2003-04-17 | Services Petroliers Schlumberger | Borehole stabilisation |
EP2143874A1 (en) * | 2008-07-11 | 2010-01-13 | Welltec A/S | Sealing arrangement and sealing method |
WO2010004035A1 (en) * | 2008-07-11 | 2010-01-14 | Welltec A/S | Sealing arrangement and sealing method |
CN102089494A (en) * | 2008-07-11 | 2011-06-08 | 韦尔泰克有限公司 | Sealing arrangement and sealing method |
WO2021181146A1 (en) * | 2020-03-12 | 2021-09-16 | Saudi Arabian Oil Company | Robotic pigging tool |
US11371319B2 (en) | 2020-03-12 | 2022-06-28 | Saudi Arabian Oil Company | Robotic pigging tool |
Also Published As
Publication number | Publication date |
---|---|
AU6369194A (en) | 1994-10-11 |
US5531272A (en) | 1996-07-02 |
CA2157409A1 (en) | 1994-09-29 |
EP0688393A1 (en) | 1995-12-27 |
NO953685L (en) | 1995-09-18 |
EP0688393A4 (en) | 1996-04-17 |
US5404950A (en) | 1995-04-11 |
NO953685D0 (en) | 1995-09-18 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US5377757A (en) | Low temperature epoxy system for through tubing squeeze in profile modification, remedial cementing, and casing repair | |
US5404950A (en) | Low temperature underwater epoxy system for zone isolation, remedial cementing, and casing repair | |
US5295541A (en) | Casing repair using a plastic resin | |
Khalifeh et al. | Introduction to permanent plug and abandonment of wells | |
US11905789B2 (en) | Helical coil annular access plug and abandonment | |
EP4012156B1 (en) | Two-material p&a plug | |
US4972906A (en) | Method for selective plugging of a zone in a well | |
EP3704345B1 (en) | Through tubing p&a with bismuth alloys | |
US4921047A (en) | Composition and method for sealing permeable subterranean formations | |
AU2005212638B2 (en) | Suppressing fluid communication to or from a wellbore | |
US20080277117A1 (en) | Surfaced mixed epoxy method for abandoning well | |
US11753898B2 (en) | PandA setting with exothermic material | |
Wu et al. | Sealant technologies for remediating cement-related oil and gas well leakage | |
US11739610B2 (en) | Methods and systems for water shut-off | |
US3487877A (en) | Controlling consolidation of permeable earth formations | |
Halvorsen | Plug and abandonment technology evaluation and field case study | |
Zheng et al. | Practical Resin Application to Well Intervention Operations for Migrating Sustainable Casing Pressure at Sichuan Basin, China | |
Talapatra | Qualifying Bismuth Plug Technology in Mozambique | |
Abdulqader et al. | The remedial design for 9 5/8” intermediate casing two-stage cement job for a deep gas well in Kurdistan region | |
Saaverdra et al. | Chemical wellbore plug for zone isolation in horizontal wells | |
Saavedra et al. | Water shutoff in horizontal wells using gel technology | |
Herndon et al. | Plugging wells for abandonment: a state-of-the-art study and recommended procedures | |
Tweeton et al. | Well Construction Information for In Situ Uranium Leaching | |
Boyd et al. | Drilling and completion plans for a geopressured well |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AK | Designated states |
Kind code of ref document: A1 Designated state(s): AT AU BB BG BR BY CA CH CN CZ DE DK ES FI GB HU JP KP KR KZ LK LU LV MG MN MW NL NO NZ PL PT RO RU SD SE SK UA US UZ VN |
|
AL | Designated countries for regional patents |
Kind code of ref document: A1 Designated state(s): AT BE CH DE DK ES FR GB GR IE IT LU MC NL PT SE BF BJ CF CG CI CM GA GN ML MR NE SN TD TG |
|
DFPE | Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101) |
Free format text: US |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application | ||
WWE | Wipo information: entry into national phase |
Ref document number: 1994911000 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2157409 Country of ref document: CA |
|
WWP | Wipo information: published in national office |
Ref document number: 1994911000 Country of ref document: EP |
|
REG | Reference to national code |
Ref country code: DE Ref legal event code: 8642 |
|
WWW | Wipo information: withdrawn in national office |
Ref document number: 1994911000 Country of ref document: EP |