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(11) | EP 0 260 727 A2 |
| (12) | EUROPEAN PATENT APPLICATION |
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| (54) | Matched particle/liquid density well packing technique |
| (57) A method of packing a well, particularly an oil, gas or water well. A particle/liquid
slurry is injected into the wellbore, the particle density to liquid density ratio
of which is no greater than about 2 to 1. The particles are substantially free of
surface adhesive. The particles are strained out of the slurry in the wellbore, so
as to produce a packed mass of the particles adjacent the formation. The packed mass
is such as to allow flow of fluids therethrough between the formation and the wellbore,
while substantially preventing particulate material from the formation passing therethrough
and into the wellbore. The well may be deviated. The fluid density is preferably about
0.8 to about 1.2 g/cm³. |
Field of the Invention
[0001] This invention relates to a method for packing wells, particularly oil, gas or water wells, in which the density of the packing particles and the carrier liquid is matched within certain defined ranges. The invention is applicable to both production and injection wells.
Technology Review
[0002] The technique of packing a well, such as an oil, gas, or water well, has been well known for many years. In such a technique, a particulate material is produced between the earth formation and a point in the wellbore. The particle size range of the particulate material is preselected, and it is produced in such a manner, so that the packed material will allow flow of the desired fluid (the term being used to include liquids and/or gases) between the formation and the wellbore, while preventing particulate materials from the earth formation from entering the wellbore.
[0003] In the particular application of this technique to pack a well, typically a screen is first placed at a position in the wellbore which is within the formation. In completed wells, a perforated steel casing is usually present between the so placed screen and formation. A slurry of the particulate material in a carrier liquid is then pumped into the wellbore so as to place the particulate material between the screen and casing (or formation if no casing is present), as well as into the perforations of any such casing, and also into any open area which may extend beyond the perforated casing into the formation. Thus, the aim in packing in most cases, is to completely fill up the area between the screen assembly and the formation with the particulate material. In some cases this open area is packed with particulate material before placing the screen in the well. Such a technique, which is a particular type of packing, often referred to as "prepacking", is described in USP 3,327,783. The particulate material is typically gravel having a density (D) of about 2.65 grams per cubic centimeter (g/cm³). The carrier liquid is generally water with a density of 1 g/cm³. The gravel particle size range is generally 20 mesh (all mesh sizes, U.S.mesh unless otherwise specified) to 40 mesh (841 microns to 420 microns) or 40 mesh to 60 mesh (420 microns to 250 microns). The resulting density ratio of particulate material to carrier liquid (Dp/Dc), is about 2.65/l.
[0004] In many cases the overall packing efficiency (the percentage of the total volume of the area between the screen and the formation that is filled with gravel) is less than 100 percent (%). This is particularly true for deviated wells, and especially for highly deviated wells (those deviating from the vertical at an angle of more than about 45°). Of course, the lower the packing efficiency, the greater the likelihood of low production or injection rates and/or sand movement into the wellbore and production string.
[0005] Apparently, there has been no prior disclosure in well packing, of the use of packing materials and carrying liquids with closely matched densities, particularly in deviated wellbores. This is further particularly the case where both the carrier liquid and particulate packing material have low densities (for example both close to 1 g/cm³). It has been discovered that where the foregoing densities are matched within defined ranges, greater packing efficiencies can be obtained. Further, where low density particulate packing materials are used, water can be used as the carrier liquid and the greater packing efficiencies still obtained. Thus, the addition of viscosifiers to the carrier liquid can be reduced or eliminated while still obtaining high packing efficiencies.
Summary of the Invention
[0006] The present invention provides a method of packing a well which penetrates an earth formation. The method comprises injecting into the wellbore, a slurry of particles in a liquid. This slurry has a particle density to liquid density ratio of no greater than about 2 to 1. In addition, the particles are substantially free of surface adhesive (i.e., adhesive on their surface). The particles are then strained out of the slurry, typically by a screen and/or the formation, so as to produce a packed mass of the particles adjacent the formation. The packed mass is such as to allow flow of fluids between the formation and the wellbore while substantially preventing particulate material from the formation passing therethrough and into the wellbore.
[0007] The density of the particles is preferably less than about 2 g/cm³. Further preferably, the density of the particles is between about 0.7 to about 2g/cm³ . The liquid may preferably have a density of about 0.8 to about 1.2g/cm³.
[0008] Of the many liquids which can be used, water is preferred, either viscosified or unviscosified, but usually the former. The liquid may contain additives for friction reduction which may also act as viscosifiers. The particulate material used desirably has a Krumbein roundness and sphericity, each of at least about 0.5, and preferably at least about 0.6. That is, the particles of the material have a roundness and sphericity as determined using the chart for estimating sphericity and roundness provided in the text Stratigraphy And Sedimentation, Second Edition, 1963, W.C. Krumbein and L.L. Sloss, published by W.H. Freeman & Co., San Francisco, CA, USA.
[0009] The method may be used in wells which pass vertically through the formation. However it is particularly advantageous to apply it to a wells which pass through the formation at an angle to the vertical. This is especially true where the angle is greater than about 45°, for example about 75°.
Drawing
[0010] The Figure is a schematic cross-section of a model used to simulate a portion of a well in which packing may be placed in accordance with the present inventive technique.
Detailed Description of Embodiments of the Invention
[0011] In order to ascertain the effects of varying the density ratio of packing particles and carrier liquid, in a wellbore, a transparent plastic test model was used. The model basically emulated, in plastic, many components of a cased well prepared for packing. The model included an elongated hollow tube serving as a casing 2, with a number of tubes extending radially therefrom, acting as perforations 4. Perforation chambers 6 communicate with each perforation 4. For simplicity, only one perforation 4 and its corresponding chamber 6 is shown in the Figure. However, the model had a total of 20 perforations, arranged in 5 sets. Each set consists of 4 coplanar perforations spaced 90° apart from one another, the sets being spaced one foot apart along a 5 foot section of the hollow tube serving as the casing 2, starting one foot from the bottom of the model. Each perforation has a perforation chamber 6 in communication therewith. The model further had a wire screen 8 extending from a blank pipe 10, and washpipe 12 extending into screen 8. The annular space between the screen 8 and casing 2, defines a screen-casing annulus. The entire model was arranged so that it could be disposed at various angles to the vertical.
[0012] The model was operated in a number of tests, using US Mesh 20-40 gravel, or US Mesh 18-50 styrene-divinylbenzene copolymer (SDVB) beads obtained from The Dow Chemical Company (Product Number 81412), in place of the gravel. Four tests were performed, three with the model at an angle of 75° to the vertical, and one at an angle of 90° thereto. In the first test, gravel with a density of 2.65 g/cm³ was used in combination with a carrier liquid of viscosified water (density 1.0 g/cm³). The foregoing (Test 1) typifies a current field operation. Tests 2 and 3 used SDVB beads with viscosified and unviscosified water, respectively. The model was disposed at angles of 75° and 90°, respectively to the vertical. Test 4 used gravel of the type used in Test 1, with the wellbore being disposed at the same angle to the vertical as in Test 1. Also, Test 4 used an aqueous calcium chloride brine instead of water, such that the particle density to carrier liquid density (Dp/Dc) ratio was about 1.97. The test conditions of Tests 1-4 are summarized below in Table 1. Tables 2 and 3 below, respectively provide the perforation chamber packing efficiency and liquid leakoff, for each perforation. The data from Tables 2 and 3 are consolidated and summarized in Table 4 below. The reference in Table 4 to various "rows" of perforations, is to a colinear group of five perforations.
[0013] It is apparent first from comparing the results of Tests 2 and 3 (Dp/Dc=1.05) with those of Test 1 (Dp/Dc=2.65), that using the lower density SDVB beads in place of the gravel used in Test 1, resulted in far better packing efficiency in Tests 2 and 3. This is true even though Test 3 was performed with the model disposed at a 90° angle to the vertical, versus the 75° to the vertical angle of the model in Test 1. Furthermore, it will be seen from Test 4, which used the same gravel as in Test 1 but with a densified carrier liquid (brine solution), that the Dp/Dc ratio can be effectively lowered by increasing the density of the carrier liquid, thereby also producing better packing results. Thus, as is apparent from the Test results, lowering the Dp/Dc ratio to a figure which approaches 1, produces better packing results than if the standard Dp/Dc ratio of about 2.65 is used. It might be noted that this is true even if no viscosifier is used, as was the case in Test 3 versus Test 1 (the former Test also being at a greater angle to the vertical). Furthermore, as is apparent from reviewing Test 4 versus Test 2, a gravel/densified carrier liquid with a Dp/Dc=2.0, still functions better than the usual gravel/water slurry(Dp/Dc=2.65), although certainly nowhere near as well as a slurry in which the Dp/Dc=1. See Response A.
[0014] The SDVB beads, disclosed above, have chemical and physical properties (e.g., glass transition temperatures, softening points, oil solubility, etc.) that make such beads useful in packing shallow, low-pressure, low-temperature wells. Other materials which can be used, include nut shells, endocarp seeds, and particulate materials formed from known synthetic polymers. The packing material selected should obviously be able to withstand the temperature, pressure and chemical conditions which will be encountered in a well to be packed.
[0015] In order to ensure that the particles of the packed mass produced by the above method remain in place, it may be desirable to place over that packed mass, a second packed mass of particulate material which is consolidated. This can be accomplished by repeating the same packing procedure, except using a particulate material which has a coating of adhesive on the particles. The second packed mass of such adhesive coated material, can be consolidated by a means appropriate to the type of adhesive on the particles. For example, if required a catalyst can be pumped down the wellbore and into contact with the packed materials to accelerate the cure of the polymeric adhesive. Alternatively, a thermosetting adhesive can be used to consolidate the second packed mass.
[0016] The same SDVB particles, provided with a coating of adhesive, can be used in the foregoing additional step to provide the second packed mass. To illustrate this, a consolidated mass of particles (referred to below as a "core"), was prepared from the same SDVB particles provided with a coating of adhesive, using the following procedure:
Carrier Fluid Preparation
[0017]
1. Take a clean, dry 1-gallon vessel.
2. Add 3000 g. of cool tap water.
3. Add 60 g. of potassium chloride (KCl).
4. Position the vessel under a mixer equipped with an anchor stirrer.
5. Adjust the stirring rate (RPM) to permit maximum mixing without entraining air.
6. Add 25.9 g. of a viscosifier.
7. Allow solution to mix for five minutes in order to completely disperse the viscosifier.
8. Add 7.11 g. of Tetrasodium ethylenediaminetetraacetic acid (EDTA).
9. Reduce mixer speed to about 50 RPM and mix for 30 minutes.
12. Remove stirrer from vessel and seal.
Slurry Preparation
[0018] The slurry was prepared in 32 ounce wide mouth sample jars using an anchor stirrer blade and a mixer.
1. Add 297 g. of carrying liquid and 240 g. of SDVB beads U.S. Sieve No. 18-50 (i.e. material will pass through U.S. No. 18 Sieve but will be retained on U.S. No. 50 Sieve.
2. Adjust stirrer RPM to about 100 RPM and mix for five minutes.
3. Add 42.4 ml of 40 wt.% (based on solution) epoxy resin in diethylene glycol methyl ether solution.
4. Add 14.1 ml of a polyamine curing agent prepared by the method disclosed in United States Patent Number 4,247,430.
5. Add 1.4 ml of N,N-dimethylaminomethylphenol (primarily a mixture of the meta and para isomers).
6. Mix for thirty minutes.
Core Preparation
[0020] Consolidated resin coated gravel cores are prepared using 60 ml LEUR-LOCK syringes with the plungers notched to permit air escape. Eighty mesh wire cloth is inserted into the syringe prior to sample addition in order to retain the SDVB particles. Sixty ml of slurry is added to the syringe, the plunger is inserted, and the core is compacted. Compaction by hand is completed by maintaining about 90 lb. force on the plunger for 10 seconds. The syringe is then capped and placed in a hot water bath. The cores are then cured for the desired time interval, removed from the bath and washed by forcing hot tap water through the core several times. The cores are then removed from the syringe and either sawed into 2-1/4 inch lengths for compressive strength determination, and into 1 inch lengths for permeability determination. The measured compressive strength was 673 psi, while the permeability was 32 Darcies.
a) injecting into the wellbore a slurry of particles in a liquid, the slurry having a particle density to liquid density ratio of no greater than about 2 to 1, and the particles being substantially free of surface adhesive; and
b) straining the particles out of the slurry so as to produce a packed mass of the particles adjacent the formation, which packed mass will allow flow of fluids therethrough between the formation and wellbore, while substantially preventing particulate material from the formation passing therethrough and into the wellbore.
a) injecting into the wellbore a slurry of particles in a liquid, the slurry having a particle density to liquid density ratio of no greater than about 2 to 1, and the particles being substantially free of surface adhesive, having a density of between about 0.8 to about 1.2, and having a Krumbein roundness and sphericity of at least about 0.6;
b) straining the particles out of the slurry so as to produce a packed mass of the particles at that portion of the well, which packed mass will allow production of fluids therethrough from the formation into the wellbore, while substantially preventing particulate material from the formation passing therethrough and into the wellbore during such production.
a) injecting into the wellbore a slurry of particles in a liquid, the slurry having a particle density to liquid density ratio of no greater than about 2 to 1, and the particles being substantially free of surface adhesive, having a density of between about 0.8 to about 1.2, and having a Krumbein roundness and sphericity of at least about 0.6;
b) straining the particles out of the slurry so as to produce a packed mass of the particles at that portion of the well, which packed mass substantially completely fills a volume which includes the annular space between the screen and the casing, and the majority of perforations extending through the casing, and will allow production of fluids therethrough from the formation into the wellbore, while substantially preventing particulate material from the formation passing therethrough and into the wellbore during such production.
a) injecting into the wellbore a slurry of particles in a liquid, the slurry having a particle density to liquid density ratio of no greater than about 2 to 1, and the particles being substantially free of surface adhesive, having a density of between about 0.8 to about 1.2, and having a Krumbein roundness and sphericity of at least about 0.6;
b) straining the particles out of the slurry so as to produce a packed mass of the particles at that portion of the well, which packed mass substantially completely fills a volume which includes the annular space between the screen and the casing, and the majority of perforations extending through the casing, and will allow production of fluids therethrough from the formation into the wellbore, while substantially preventing particulate material from the formation passing therethrough and into the well bore during such production.
c) injecting into the wellbore a slurry of particles in a liquid, the particles having a coating of adhesive; and
d) straining the particles out of the slurry so as to produce a second packed mass of the particles over the packed mass produced by steps (a) and (b), which second packed mass can be consolidated so as to retain the particles of the first packed mass in position.