CA2669400A1 - Insulating fluid and methods for preparing and insulating concentric piping - Google Patents
Insulating fluid and methods for preparing and insulating concentric piping Download PDFInfo
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- CA2669400A1 CA2669400A1 CA002669400A CA2669400A CA2669400A1 CA 2669400 A1 CA2669400 A1 CA 2669400A1 CA 002669400 A CA002669400 A CA 002669400A CA 2669400 A CA2669400 A CA 2669400A CA 2669400 A1 CA2669400 A1 CA 2669400A1
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- 239000012530 fluid Substances 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims description 16
- 229920000642 polymer Polymers 0.000 claims abstract description 19
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 15
- 239000012267 brine Substances 0.000 claims abstract description 11
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims abstract description 11
- 238000004519 manufacturing process Methods 0.000 claims abstract description 10
- 239000002904 solvent Substances 0.000 claims abstract description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 10
- LYCAIKOWRPUZTN-UHFFFAOYSA-N ethylene glycol Natural products OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 18
- -1 ethylene glycol ethers Chemical class 0.000 claims description 9
- DNIAPMSPPWPWGF-UHFFFAOYSA-N monopropylene glycol Natural products CC(O)CO DNIAPMSPPWPWGF-UHFFFAOYSA-N 0.000 claims description 9
- 239000011324 bead Substances 0.000 claims description 5
- 244000007835 Cyamopsis tetragonoloba Species 0.000 claims description 4
- 125000002887 hydroxy group Chemical group [H]O* 0.000 claims description 4
- GJCOSYZMQJWQCA-UHFFFAOYSA-N 9H-xanthene Chemical compound C1=CC=C2CC3=CC=CC=C3OC2=C1 GJCOSYZMQJWQCA-UHFFFAOYSA-N 0.000 claims description 3
- 239000011521 glass Substances 0.000 claims description 3
- 229910052751 metal Inorganic materials 0.000 claims description 3
- 239000002184 metal Substances 0.000 claims description 3
- 150000002739 metals Chemical class 0.000 claims description 3
- 229920005862 polyol Polymers 0.000 claims description 3
- 150000003077 polyols Chemical class 0.000 claims description 3
- 229920001285 xanthan gum Polymers 0.000 claims description 3
- 229910052726 zirconium Inorganic materials 0.000 claims description 3
- BTBUEUYNUDRHOZ-UHFFFAOYSA-N Borate Chemical compound [O-]B([O-])[O-] BTBUEUYNUDRHOZ-UHFFFAOYSA-N 0.000 claims description 2
- 229920002134 Carboxymethyl cellulose Polymers 0.000 claims description 2
- 229920002907 Guar gum Polymers 0.000 claims description 2
- 229920002472 Starch Polymers 0.000 claims description 2
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 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
- 239000008112 carboxymethyl-cellulose Substances 0.000 claims description 2
- 229940105329 carboxymethylcellulose Drugs 0.000 claims description 2
- 239000001913 cellulose Substances 0.000 claims description 2
- 229920002678 cellulose Polymers 0.000 claims description 2
- 239000000835 fiber Substances 0.000 claims description 2
- 239000000665 guar gum Substances 0.000 claims description 2
- 229960002154 guar gum Drugs 0.000 claims description 2
- 235000010417 guar gum Nutrition 0.000 claims description 2
- 239000008107 starch Substances 0.000 claims description 2
- 235000019698 starch Nutrition 0.000 claims description 2
- 229910052719 titanium Inorganic materials 0.000 claims description 2
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims 3
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 claims 1
- 125000001033 ether group Chemical group 0.000 claims 1
- 239000004005 microsphere Substances 0.000 claims 1
- 239000010936 titanium Substances 0.000 claims 1
- 239000000203 mixture Substances 0.000 description 12
- 239000000463 material Substances 0.000 description 7
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 6
- JHJLBTNAGRQEKS-UHFFFAOYSA-M sodium bromide Chemical compound [Na+].[Br-] JHJLBTNAGRQEKS-UHFFFAOYSA-M 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 238000009472 formulation Methods 0.000 description 3
- 238000009413 insulation Methods 0.000 description 3
- 238000012546 transfer Methods 0.000 description 3
- 239000004971 Cross linker Substances 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000004132 cross linking Methods 0.000 description 2
- 230000008021 deposition Effects 0.000 description 2
- 230000002401 inhibitory effect Effects 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000012188 paraffin wax Substances 0.000 description 2
- QQONPFPTGQHPMA-UHFFFAOYSA-N propylene Natural products CC=C QQONPFPTGQHPMA-UHFFFAOYSA-N 0.000 description 2
- 125000004805 propylene group Chemical group [H]C([H])([H])C([H])([*:1])C([H])([H])[*:2] 0.000 description 2
- 229910000809 Alumel Inorganic materials 0.000 description 1
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 229910001179 chromel Inorganic materials 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 229920006037 cross link polymer Polymers 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000009422 external insulation Methods 0.000 description 1
- 230000004907 flux Effects 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 150000004677 hydrates Chemical class 0.000 description 1
- 230000036571 hydration Effects 0.000 description 1
- 238000006703 hydration reaction Methods 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 229920003088 hydroxypropyl methyl cellulose Polymers 0.000 description 1
- 125000005647 linker group Chemical group 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 229910021645 metal ion Inorganic materials 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000009972 noncorrosive effect Effects 0.000 description 1
- 230000010355 oscillation Effects 0.000 description 1
- 150000002978 peroxides Chemical class 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000010802 sludge Substances 0.000 description 1
- 238000007655 standard test method Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 229920000247 superabsorbent polymer Polymers 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 125000000383 tetramethylene group Chemical group [H]C([H])([*:1])C([H])([H])C([H])([H])C([H])([H])[*:2] 0.000 description 1
- 239000011800 void material Substances 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
-
- E—FIXED CONSTRUCTIONS
- E04—BUILDING
- E04B—GENERAL BUILDING CONSTRUCTIONS; WALLS, e.g. PARTITIONS; ROOFS; FLOORS; CEILINGS; INSULATION OR OTHER PROTECTION OF BUILDINGS
- E04B1/00—Constructions in general; Structures which are not restricted either to walls, e.g. partitions, or floors or ceilings or roofs
- E04B1/62—Insulation or other protection; Elements or use of specified material therefor
- E04B1/74—Heat, sound or noise insulation, absorption, or reflection; Other building methods affording favourable thermal or acoustical conditions, e.g. accumulating of heat within walls
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/003—Insulating arrangements
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Architecture (AREA)
- Electromagnetism (AREA)
- Civil Engineering (AREA)
- Structural Engineering (AREA)
- Acoustics & Sound (AREA)
- Compositions Of Macromolecular Compounds (AREA)
- Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
- Thermal Insulation (AREA)
- Rigid Pipes And Flexible Pipes (AREA)
Abstract
The present inventions include an insulating fluid comprising a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates. The insulating fluid may be produced by performing the following steps in any order: adding a non-particulate viscosifying polymer to a brine, adding a cross-linking agent, adding insulating particulates, and optionally adding a solvent. The insulating fluid may be injected into an annulus surrounding a pipe such as production tubing, casing, surface pipelines, subsea pipelines, or risers.
Description
INSULATING FLUID AND METHODS FOR PREPARING AND INSULATING
CONCENTRIC PIPING
Field of Invention The present inventions relate to an insulating fluid, a method for preparing the insulating fluid, and a method for insulating concentric piping using the insulating fluid.
Background Annular fluids or packer fluids are liquids that are pumped into an annular opening between a casing and a wellbore wall or between adjacent, concentric strings of pipe extending into a wellbore. The main functions of a packer fluid are to provide hydrostatic pressure in order to lower differential pressure across a sealing element, to lower differential pressure on the wellbore and casing to prevent collapse, and to protect metals in the completion from corrosion.
Packer fluids are prepared according to the requirements of the given completion.
Generally, they should be of sufficient density to control the producing formation, solids-free and resistant to viscosity changes over long periods of time, and non-corrosive to the wellbore and completion components.
Special well conditions may require a packer fluid to also serve an insulating function. In high temperature wells, hot fluid flowing inside the production tubing can cause the packer fluid to expand, rapidly building up pressure in the sealed annulus. In extreme circumstances, this build-up could potentially collapse the tubing or burst the casing, a result that would be catastrophic to the well. In addition, heat loss from the production tubing may cause a variety of low-temperature problems including hydrate build-up, paraffin deposition, and precipitation of salts.
Deepwater wells face a similar problem related to flow assurance.
Undesired heat loss from production tubing to outer annuli can lead to the deposition of sludge, paraffin and asphaltene materials, the formation of gas hydrates, and cause severe flow assurance problems and loss of productivity.
In recent years, thermal insulation fluids have been successfully applied in wellbore and deepwater risers to prevent undesired heat loss. Other alternatives include external insulation or injection of nitrogen gas for risers. Thus, many wells could benefit from the use of an insulating fluid capable of use in completions and risers.
US Published Application 2004/0011990 Al (hereafter Dunaway) discloses a thermally insulating fluid comprising a glycol solvent for a viscosifier, a viscosifier, and optionally an aqueous brine. The glycol may be selected from a propelyne glycol, or under excessive heat temperatures, a butylenes glycol, which can be used with or without a viscosifier. Viscosifiers can be selected from hydroxyl propyl methyl cellulose, xanthan and hydroxyl propyl guar and combinations thereof. The Dunaway fluid is not as insulating as is often desired.
US Published Application 2005/0038199 Al (hereafter Wang) discloses a thermal insulating fluid containing water and/or brine, a crosslinkable viscosifying polymer, a crosslinking agent and an optional set retarder. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is such as to reduce the convection flow velocity within the annulus. Although the insulating fluid in Wang exhibits low convection, the Wang fluid is not as insulating as is often desired.
US Published Application 2004/0059054 (hereafter Lopez) discloses a thermal insulating fluid containing at least one water superabsorbent polymer and optionally water and/or brine, and a viscosifying polymer. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is sufficient to reduce the convection flow velocity within the annulus. One of the potential drawbacks of using the fluid in Lopez is that when a workover is necessary, The Lopez fluid is not as insulating as is often desired.
There is a need in the industry for the development of a insulating fluid that exhibits low thermoconductivity, low convection, and thermal stability.
Summary of the Invention The present inventions include an insulating fluid comprising a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates.
In some embodiments, the present inventions include a method for insulating concentric pipes having an annulus, comprising injecting an insulating fluid in the annulus; wherein the insulating fluid comprises a non-particulate viscosifying polymer, a water or a brine, a cross-linking agent, and insulating particulates.
In other embodiments, the present inventions include a method for producing an insulating fluid comprising the following steps: adding a non-particulate viscosifying polymer to a brine, adding a cross-linking agent, and adding insulating particulates. The adding may be performed by continuous mixing or batch mixing; and steps (a) through (c) may be performed in any order.
Brief Description of the Drawings The present invention is better understood by reading the following description of non-limitative embodiments with reference to the attached drawings, which are briefly described as follows:
Figure 1 illustrates the test setup used for measuring the thermal conductivity of the insulating fluid.
Figure 2 is a plot of the yield strength of the insulating fluid.
Detailed Description The invention relates to the application of a polymer-based fluid as an annular fluid (insulating fluid or packer fluid) for insulating production tubing or casing, insulating fluid during well treatment, or insulating fluid for risers for deepwater wells.
This fluid is non-convective and exhibits low thermal conductivity and high thermal stability. The insulating fluid comprises a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates.
Optionally, the insulating fluid may further comprise a solvent. The density of the fluid is adjustable to fit the downhole pressure requirement for the wells.
Preferred non-particulate viscosifying polymers are those having a high degree of molar substitution (MS) and are salt-tolerant. The hydroxyl groups enable better hydration in high concentration brines. Suitable non-particulate viscosifying polymers include cellulose, xanthan, starch, guar gum and a derivatives thereof.
Particularly suitable viscosifying polymer fluids include hydroxyl propryl guar, carboxymethyl hydroxypropyl, and carboxymethyl-cellulose. The non-particulate viscosifying polymer is preferably present in a quantity of 0.1 % to 5 % by weight.
The fluid can be crosslinked by metal ions such as Zr or Ti crosslinkers.
Crosslinking generally increases viscosity, which in turn reduces eliminates convection. If desired, the crosslinking can be delayed to ensure pumpability of the fluid during mixing and for an amount of time thereafter. Suitable cross-linking agents include borate, zirconium, and organic complexed metals. The cross-linking agent is present in a quantity of 0.01 % to 5% by weight.
To lower the thermal conductivity and increase viscosity, particulates such as hollow glass bubbles, beads, or fibers are added to the mixture. The insulating particulates can be suspended in the mixture because of its high viscosity.
Void spaces in the insulating particulates, if present, help reduce thermal conductivity of the mixture. The insulating particulates are preferably present in a quantity of 0.1 %
to 30% by weight.
Optionally, a solvent may be added to the insulating fluid to enhance the properties. Particularly suitable solvents include ethylene glycol ethers, propylene glycol ethers, and polyols.ethylene glycol ethers, propylene glycol ethers, and polyols. The solvent is preferably present in a quantity of 0.1 % to 99.9% by weight.
Preferred methods for producing the present insulating fluids generally include: adding a non-particulate viscosifying polymer to a water or brine, adding a cross-linking agent; and adding insulating particulates. The insulating fluid may be mixed in the lab or in the field using a batch mixing method or continuous mixing method. The components of the insulating fluid may be mixed in any order.
Optionally a solvent may be added to the mix via batch mixing or continuous mixing.
One preferred method of using the insulating fluid is for insulation of concentric piping, downhole tubulars, or similar situations where it is desirable to insulate the outside of a pipe. The insulating fluid may be injected into the annulus between two or more concentric pipes or between a pipe and a wellbore or the like. Applications in which the present insulating fluids may be used include, but are not limited to, outside of production tubing casing, between casing and tubing, and around surface pipelines, subsea pipelines, or risers.
Advantages of some embodiments of the invention include one or more of the following:
= Low thermal conductivity = Non-convection = High thermal stability = Synergistic effect between cross-linking agent and insulating particulates = High pumpability (can be continuously mixed) = Easily broken to remove from the concentric piping with acids, peroxides, or other breakers = Environmentally safe EXAMPLES
Example 1 In Example 1, the thermal conductivity of various formulations of the insulating fluid were measured using a guarded heat flow meter. The guarded heat flow meter method is appropriate for measuring thermal conductivities in the range of 0.1 to 8 Wm 1=K 1 in the temperature range from -120 to 300 C with an accuracy of approximately 6 %. This method is described in ASTM (American Society for Testing and Materials) Practice F 433, Standard Practice for Evaluating Thermal Conductivity of Gasket Materials and in ASTM E 1530, Standard Test Method for Evaluating the Resistance to Thermal Transmission of Thin Specimens of Materials by the Guarded Heat Flow Meter Technique.
A schematic diagram of the guarded heat flow meter is shown in Figure 1.
The sample (a 2.0 inch diameter disk) was placed between two plates at different temperatures, thus producing a heat flow through the sample. The hot-side heater temperature, Th, was controlled with a set-point controller; this parameter is used to set the mean temperature of the sample. The cold-side temperature and the guard temperature were controlled relative to the heater with differential controllers. The heat flow was measured with a heat flux transducer (a multi-junction thermopile across a thin sheet of insulation) contained in the lower plate.
The sample was surrounded by a cylindrical guard which was maintained at a temperature close to the mean sample temperature to reduce lateral heat flow.
Upper plate, lower plate, and guard temperatures were measured with type K
(chromel/alumel) thermocouples. The sample was held between the plates of the instrument with a piston pressure on the order of 20 psi.
Four samples containing a base fluid, Zr as a cross-linking agent, hydroxyl propryl guar (HPG) as a non-particulate viscosifying polymer, and varying amounts of glass beads as insulating particulates were tested. Two of the four samples also included a solvent (propylene glycol). Comparative sample (0419-1) contained no insulating particulates. Table 1 shows the compositions of the tested formulations:
Table 1 Glass Glass Beads beads cross-Polymer (g/100 linker Base Zr Sample wt% wt% mL) wt% HPG fluid cross-linker A 0.94 3.30 4.2 0.20 100# 10.5 ppg NaBr 2 gpt B 0.88 9.56 13 0.20 100# 10.5 ppg NaBr 2 gpt 50/50 2% KCI
and propylene C 1.05 11.30 13 0.20 100# glycol 2 gpt 50/50 2% KCI
and propylene D 1.20 0 0.0 0.20 100# glycol 2 gpt Each sample was tested at two temperatures and the thermal conductivity data was recorded. The results of the tests are displayed in Table 2 below:
Table 2 Thickness Temperature Conductivity Conductivity @ 25 c (W/m-K) BTU/(ft.h. F) Sample (mm) C F
A 10.4 4 39 0.433 0.250 23 73 0.457 0.264 B 9.84 5 41 0.341 0.197 23 73 0.342 0.198 C 11.0 5 41 0.304 0.176 23 74 0.299 0.173 D 10.3 5 41 0.393 0.227 23 74 0.389 0.225 Example 2 In Example 2, a sample was tested using a rheometer to determine thermal convection from yield strength (or gel strength) data. The standard paper used for natural convection of a viscous fluid in an annulus is G. Paul Willhite, "Over-all Heat Transfer Coefficients in Steam and Hot Water Injection Wells," Journal of Petroleum Technology, May, 1967, which is hereby incorporated by reference.
CONCENTRIC PIPING
Field of Invention The present inventions relate to an insulating fluid, a method for preparing the insulating fluid, and a method for insulating concentric piping using the insulating fluid.
Background Annular fluids or packer fluids are liquids that are pumped into an annular opening between a casing and a wellbore wall or between adjacent, concentric strings of pipe extending into a wellbore. The main functions of a packer fluid are to provide hydrostatic pressure in order to lower differential pressure across a sealing element, to lower differential pressure on the wellbore and casing to prevent collapse, and to protect metals in the completion from corrosion.
Packer fluids are prepared according to the requirements of the given completion.
Generally, they should be of sufficient density to control the producing formation, solids-free and resistant to viscosity changes over long periods of time, and non-corrosive to the wellbore and completion components.
Special well conditions may require a packer fluid to also serve an insulating function. In high temperature wells, hot fluid flowing inside the production tubing can cause the packer fluid to expand, rapidly building up pressure in the sealed annulus. In extreme circumstances, this build-up could potentially collapse the tubing or burst the casing, a result that would be catastrophic to the well. In addition, heat loss from the production tubing may cause a variety of low-temperature problems including hydrate build-up, paraffin deposition, and precipitation of salts.
Deepwater wells face a similar problem related to flow assurance.
Undesired heat loss from production tubing to outer annuli can lead to the deposition of sludge, paraffin and asphaltene materials, the formation of gas hydrates, and cause severe flow assurance problems and loss of productivity.
In recent years, thermal insulation fluids have been successfully applied in wellbore and deepwater risers to prevent undesired heat loss. Other alternatives include external insulation or injection of nitrogen gas for risers. Thus, many wells could benefit from the use of an insulating fluid capable of use in completions and risers.
US Published Application 2004/0011990 Al (hereafter Dunaway) discloses a thermally insulating fluid comprising a glycol solvent for a viscosifier, a viscosifier, and optionally an aqueous brine. The glycol may be selected from a propelyne glycol, or under excessive heat temperatures, a butylenes glycol, which can be used with or without a viscosifier. Viscosifiers can be selected from hydroxyl propyl methyl cellulose, xanthan and hydroxyl propyl guar and combinations thereof. The Dunaway fluid is not as insulating as is often desired.
US Published Application 2005/0038199 Al (hereafter Wang) discloses a thermal insulating fluid containing water and/or brine, a crosslinkable viscosifying polymer, a crosslinking agent and an optional set retarder. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is such as to reduce the convection flow velocity within the annulus. Although the insulating fluid in Wang exhibits low convection, the Wang fluid is not as insulating as is often desired.
US Published Application 2004/0059054 (hereafter Lopez) discloses a thermal insulating fluid containing at least one water superabsorbent polymer and optionally water and/or brine, and a viscosifying polymer. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is sufficient to reduce the convection flow velocity within the annulus. One of the potential drawbacks of using the fluid in Lopez is that when a workover is necessary, The Lopez fluid is not as insulating as is often desired.
There is a need in the industry for the development of a insulating fluid that exhibits low thermoconductivity, low convection, and thermal stability.
Summary of the Invention The present inventions include an insulating fluid comprising a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates.
In some embodiments, the present inventions include a method for insulating concentric pipes having an annulus, comprising injecting an insulating fluid in the annulus; wherein the insulating fluid comprises a non-particulate viscosifying polymer, a water or a brine, a cross-linking agent, and insulating particulates.
In other embodiments, the present inventions include a method for producing an insulating fluid comprising the following steps: adding a non-particulate viscosifying polymer to a brine, adding a cross-linking agent, and adding insulating particulates. The adding may be performed by continuous mixing or batch mixing; and steps (a) through (c) may be performed in any order.
Brief Description of the Drawings The present invention is better understood by reading the following description of non-limitative embodiments with reference to the attached drawings, which are briefly described as follows:
Figure 1 illustrates the test setup used for measuring the thermal conductivity of the insulating fluid.
Figure 2 is a plot of the yield strength of the insulating fluid.
Detailed Description The invention relates to the application of a polymer-based fluid as an annular fluid (insulating fluid or packer fluid) for insulating production tubing or casing, insulating fluid during well treatment, or insulating fluid for risers for deepwater wells.
This fluid is non-convective and exhibits low thermal conductivity and high thermal stability. The insulating fluid comprises a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates.
Optionally, the insulating fluid may further comprise a solvent. The density of the fluid is adjustable to fit the downhole pressure requirement for the wells.
Preferred non-particulate viscosifying polymers are those having a high degree of molar substitution (MS) and are salt-tolerant. The hydroxyl groups enable better hydration in high concentration brines. Suitable non-particulate viscosifying polymers include cellulose, xanthan, starch, guar gum and a derivatives thereof.
Particularly suitable viscosifying polymer fluids include hydroxyl propryl guar, carboxymethyl hydroxypropyl, and carboxymethyl-cellulose. The non-particulate viscosifying polymer is preferably present in a quantity of 0.1 % to 5 % by weight.
The fluid can be crosslinked by metal ions such as Zr or Ti crosslinkers.
Crosslinking generally increases viscosity, which in turn reduces eliminates convection. If desired, the crosslinking can be delayed to ensure pumpability of the fluid during mixing and for an amount of time thereafter. Suitable cross-linking agents include borate, zirconium, and organic complexed metals. The cross-linking agent is present in a quantity of 0.01 % to 5% by weight.
To lower the thermal conductivity and increase viscosity, particulates such as hollow glass bubbles, beads, or fibers are added to the mixture. The insulating particulates can be suspended in the mixture because of its high viscosity.
Void spaces in the insulating particulates, if present, help reduce thermal conductivity of the mixture. The insulating particulates are preferably present in a quantity of 0.1 %
to 30% by weight.
Optionally, a solvent may be added to the insulating fluid to enhance the properties. Particularly suitable solvents include ethylene glycol ethers, propylene glycol ethers, and polyols.ethylene glycol ethers, propylene glycol ethers, and polyols. The solvent is preferably present in a quantity of 0.1 % to 99.9% by weight.
Preferred methods for producing the present insulating fluids generally include: adding a non-particulate viscosifying polymer to a water or brine, adding a cross-linking agent; and adding insulating particulates. The insulating fluid may be mixed in the lab or in the field using a batch mixing method or continuous mixing method. The components of the insulating fluid may be mixed in any order.
Optionally a solvent may be added to the mix via batch mixing or continuous mixing.
One preferred method of using the insulating fluid is for insulation of concentric piping, downhole tubulars, or similar situations where it is desirable to insulate the outside of a pipe. The insulating fluid may be injected into the annulus between two or more concentric pipes or between a pipe and a wellbore or the like. Applications in which the present insulating fluids may be used include, but are not limited to, outside of production tubing casing, between casing and tubing, and around surface pipelines, subsea pipelines, or risers.
Advantages of some embodiments of the invention include one or more of the following:
= Low thermal conductivity = Non-convection = High thermal stability = Synergistic effect between cross-linking agent and insulating particulates = High pumpability (can be continuously mixed) = Easily broken to remove from the concentric piping with acids, peroxides, or other breakers = Environmentally safe EXAMPLES
Example 1 In Example 1, the thermal conductivity of various formulations of the insulating fluid were measured using a guarded heat flow meter. The guarded heat flow meter method is appropriate for measuring thermal conductivities in the range of 0.1 to 8 Wm 1=K 1 in the temperature range from -120 to 300 C with an accuracy of approximately 6 %. This method is described in ASTM (American Society for Testing and Materials) Practice F 433, Standard Practice for Evaluating Thermal Conductivity of Gasket Materials and in ASTM E 1530, Standard Test Method for Evaluating the Resistance to Thermal Transmission of Thin Specimens of Materials by the Guarded Heat Flow Meter Technique.
A schematic diagram of the guarded heat flow meter is shown in Figure 1.
The sample (a 2.0 inch diameter disk) was placed between two plates at different temperatures, thus producing a heat flow through the sample. The hot-side heater temperature, Th, was controlled with a set-point controller; this parameter is used to set the mean temperature of the sample. The cold-side temperature and the guard temperature were controlled relative to the heater with differential controllers. The heat flow was measured with a heat flux transducer (a multi-junction thermopile across a thin sheet of insulation) contained in the lower plate.
The sample was surrounded by a cylindrical guard which was maintained at a temperature close to the mean sample temperature to reduce lateral heat flow.
Upper plate, lower plate, and guard temperatures were measured with type K
(chromel/alumel) thermocouples. The sample was held between the plates of the instrument with a piston pressure on the order of 20 psi.
Four samples containing a base fluid, Zr as a cross-linking agent, hydroxyl propryl guar (HPG) as a non-particulate viscosifying polymer, and varying amounts of glass beads as insulating particulates were tested. Two of the four samples also included a solvent (propylene glycol). Comparative sample (0419-1) contained no insulating particulates. Table 1 shows the compositions of the tested formulations:
Table 1 Glass Glass Beads beads cross-Polymer (g/100 linker Base Zr Sample wt% wt% mL) wt% HPG fluid cross-linker A 0.94 3.30 4.2 0.20 100# 10.5 ppg NaBr 2 gpt B 0.88 9.56 13 0.20 100# 10.5 ppg NaBr 2 gpt 50/50 2% KCI
and propylene C 1.05 11.30 13 0.20 100# glycol 2 gpt 50/50 2% KCI
and propylene D 1.20 0 0.0 0.20 100# glycol 2 gpt Each sample was tested at two temperatures and the thermal conductivity data was recorded. The results of the tests are displayed in Table 2 below:
Table 2 Thickness Temperature Conductivity Conductivity @ 25 c (W/m-K) BTU/(ft.h. F) Sample (mm) C F
A 10.4 4 39 0.433 0.250 23 73 0.457 0.264 B 9.84 5 41 0.341 0.197 23 73 0.342 0.198 C 11.0 5 41 0.304 0.176 23 74 0.299 0.173 D 10.3 5 41 0.393 0.227 23 74 0.389 0.225 Example 2 In Example 2, a sample was tested using a rheometer to determine thermal convection from yield strength (or gel strength) data. The standard paper used for natural convection of a viscous fluid in an annulus is G. Paul Willhite, "Over-all Heat Transfer Coefficients in Steam and Hot Water Injection Wells," Journal of Petroleum Technology, May, 1967, which is hereby incorporated by reference.
There is an inverse correlation between gel strength and convection because insulating fluids can be modeled as Bingham materials. When a layer of Bingham material is subjected to a shear stress, it will not flow unless the shear stress exceeds the yield strength strength, -co. Therefore a fluid with high yield strength will exhibit low convection.
In this example, the formulation of the sample was the same as that of sample A in Example 1. The experiments were performed at 1 Hz of frequency with an oscillation rheometer at a temperature of 44 C. A 1 mm sample was placed in between two plates. The bottom plate was fixed and the upper plate was oscillated. The torque required to oscillate the plate was measured and the yield strength of the sample. The results are shown Figure 2. The same test was performed for a non-convective oil-based packer fluid. Sample A exhibits much higher yield point than the packer fluid, which suggests that the sample A is non-convective.
Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments, configurations, materials, and methods without departing from the scope of the invention.
Accordingly, the scope of the claims appended hereafter and their functional equivalents should not be limited by particular embodiments described and illustrated herein, as the latter are merely exemplary in nature.
In this example, the formulation of the sample was the same as that of sample A in Example 1. The experiments were performed at 1 Hz of frequency with an oscillation rheometer at a temperature of 44 C. A 1 mm sample was placed in between two plates. The bottom plate was fixed and the upper plate was oscillated. The torque required to oscillate the plate was measured and the yield strength of the sample. The results are shown Figure 2. The same test was performed for a non-convective oil-based packer fluid. Sample A exhibits much higher yield point than the packer fluid, which suggests that the sample A is non-convective.
Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments, configurations, materials, and methods without departing from the scope of the invention.
Accordingly, the scope of the claims appended hereafter and their functional equivalents should not be limited by particular embodiments described and illustrated herein, as the latter are merely exemplary in nature.
Claims (12)
1. A method for insulating a length of pipe within an annulus, comprising injecting into the annulus an insulating fluid, characterized in that the insulating fluid comprises a non-particulate viscosifying polymer, a water or brine, a cross-linking agent, and insulating particulates.
2. The insulating fluid of claim 1 wherein the insulating particulates are selected from the group consisting of microspheres, glass beads, and fibers.
3. The method of claim 1 or 2 wherein the pipe is production tubing, casing, surface pipelines, subsea pipelines, or risers.
4. The insulating fluid of any of claims 1-3 wherein the cross-linking agent is selected from the group of consisting of borate, zirconium, titanium and organic complexed metals.
5. The method of any of claims 1-4 wherein the insulating fluid further comprises a solvent.
6. The insulating fluid of any of claim 5 wherein the solvent is an ether.
7. The insulating fluid of claim 6 wherein the ether is selected from the group consisting of ethylene glycol ethers, propylene glycol ethers, and polyols.
8. The insulating fluid of any of claims 1-7 wherein the non-particulate viscosifying polymer is selected from the group consisting of cellulose, xanthan, starch, guar gum and a derivatives thereof.
9. The insulating fluid of claim 8 wherein the a non-particulate viscosifying polymer is selected from the group consisting of hydroxyl propryl guar, carboxymethyl hydroxypropyl, and carboxymethyl-cellulose.
10. The insulating fluid of any of claims 1-9 wherein the cross-linking agent is present in a quantity of 0.01 % to 5% by weight.
11. The insulating fluid of any of claims 1-10 wherein the non-particulate viscosifying polymer is present in a quantity of 0.1 % to 5 % by weight.
12. The insulating fluid of any of claims 1-11 wherein the insulating particulates are present in a quantity of 0.1 % to 30% by weight.
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|---|---|---|---|
| US86627706P | 2006-11-17 | 2006-11-17 | |
| US60/866,277 | 2006-11-17 | ||
| PCT/US2007/084814 WO2008064074A1 (en) | 2006-11-17 | 2007-11-15 | Insulating fluid and methods for preparing and insulating concentric piping |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2669400A1 true CA2669400A1 (en) | 2008-05-29 |
| CA2669400C CA2669400C (en) | 2015-06-23 |
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| CA2669400A Expired - Fee Related CA2669400C (en) | 2006-11-17 | 2007-11-15 | Insulating fluid and methods for preparing and insulating concentric piping |
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| US (1) | US20100025615A1 (en) |
| AU (1) | AU2007323801B2 (en) |
| CA (1) | CA2669400C (en) |
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| WO2009135073A2 (en) | 2008-04-30 | 2009-11-05 | Altarock Energy, Inc. | System and method for aquifer geo-cooling |
| US9874077B2 (en) | 2008-04-30 | 2018-01-23 | Altarock Energy Inc. | Method and cooling system for electric submersible pumps/motors for use in geothermal wells |
| US8272437B2 (en) | 2008-07-07 | 2012-09-25 | Altarock Energy, Inc. | Enhanced geothermal systems and reservoir optimization |
| WO2010022283A1 (en) | 2008-08-20 | 2010-02-25 | Altarock Energy, Inc. | A well diversion agent formed from in situ decomposition of carbonyls at high temperature |
| US9074465B2 (en) | 2009-06-03 | 2015-07-07 | Schlumberger Technology Corporation | Methods for allocating commingled oil production |
| WO2010144872A1 (en) | 2009-06-12 | 2010-12-16 | Altarock Energy, Inc. | An injection-backflow technique for measuring fracture surface area adjacent to a wellbore |
| US9151125B2 (en) | 2009-07-16 | 2015-10-06 | Altarock Energy, Inc. | Temporary fluid diversion agents for use in geothermal well applications |
| WO2011047096A1 (en) | 2009-10-14 | 2011-04-21 | Altarock Energy, Inc. | In situ decomposition of carbonyls at high temperature for fixing incomplete and failed well seals |
| US8322423B2 (en) | 2010-06-14 | 2012-12-04 | Halliburton Energy Services, Inc. | Oil-based grouting composition with an insulating material |
| US9062240B2 (en) | 2010-06-14 | 2015-06-23 | Halliburton Energy Services, Inc. | Water-based grouting composition with an insulating material |
| US8895476B2 (en) | 2011-03-08 | 2014-11-25 | Tetra Technologies, Inc. | Thermal insulating fluids |
| US10870795B2 (en) | 2015-10-15 | 2020-12-22 | Halliburton Energy Services, Inc. | Rheology modifier |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5607901A (en) * | 1995-02-17 | 1997-03-04 | Bp Exploration & Oil, Inc. | Environmentally safe annular fluid |
| US20040011990A1 (en) * | 2002-07-19 | 2004-01-22 | Tetra Technologies, Inc. | Thermally insulating fluid |
| WO2004025076A1 (en) * | 2002-09-12 | 2004-03-25 | Bj Services Company | Compositions for thermal insulation and methods of using the same |
| US6908886B2 (en) * | 2003-01-09 | 2005-06-21 | M-I L.L.C. | Annular fluids and method of emplacing the same |
| US7306039B2 (en) * | 2003-08-13 | 2007-12-11 | Bj Services Company | Methods of using crosslinkable compositions |
| US7316275B2 (en) * | 2005-03-17 | 2008-01-08 | Bj Services Company | Well treating compositions containing water superabsorbent material and method of using the same |
| US7713917B2 (en) * | 2006-05-08 | 2010-05-11 | Bj Services Company | Thermal insulation compositions containing organic solvent and gelling agent and methods of using the same |
| US7625845B2 (en) * | 2006-11-09 | 2009-12-01 | Bj Services Company | Method of using thermal insulation fluid containing hollow microspheres |
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2007
- 2007-11-15 US US12/514,967 patent/US20100025615A1/en not_active Abandoned
- 2007-11-15 WO PCT/US2007/084814 patent/WO2008064074A1/en active Application Filing
- 2007-11-15 CA CA2669400A patent/CA2669400C/en not_active Expired - Fee Related
- 2007-11-15 AU AU2007323801A patent/AU2007323801B2/en not_active Ceased
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| GB2456272B (en) | 2011-04-20 |
| CA2669400C (en) | 2015-06-23 |
| US20100025615A1 (en) | 2010-02-04 |
| GB0908297D0 (en) | 2009-06-24 |
| GB2456272A (en) | 2009-07-15 |
| AU2007323801A1 (en) | 2008-05-29 |
| WO2008064074A1 (en) | 2008-05-29 |
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