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• W4238056301 abstract "Sand Consolidation Using High-Temperature Alkaline Solution - Analysis of Reaction Parameters F.E. Moreno; F.E. Moreno Texas A & M University Search for other works by this author on: This Site Google Scholar D.D. Mamora D.D. Mamora Texas A & M University Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Western Regional Meeting, Bakersfield, California, March 2001. Paper Number: SPE-68847-MS https://doi.org/10.2118/68847-MS Published: March 26 2001 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Moreno, F.E., and D.D. Mamora. Sand Consolidation Using High-Temperature Alkaline Solution - Analysis of Reaction Parameters. Paper presented at the SPE Western Regional Meeting, Bakersfield, California, March 2001. doi: https://doi.org/10.2118/68847-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu nav search search input Search input auto suggest search filter All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Western Regional Meeting Search Advanced Search AbstractAs reported in SPE 62943, Wilmington Tar sand samples were successfully consolidated in the laboratory using high-temperature (250–260°C) solution of sodium carbonate (pH 11–12). The sample was placed in a vertical 18 in. long aluminum cylindrical cell with an ID of 1.5 in.. The top half of the cell was thermally insulated while the bottom half was cooled. Hot alkaline solution was injected at 20 ml/min for 3–4 hours at the top of the cell and liquid produced at the bottom of the cell. After each experiment, the cell contents were removed and analyzed to determine if sand consolidation occurred. Thin sections of the sample were analyzed using an electron microprobe to determine any change in shape, size, and composition of the sand pack.To better understand the process, experiments were subsequently conducted using samples of (a) pure quartz, (b) pure feldspar, and (c) a 50:50 (by weight) mixture of quartz and feldspar. In each case, the grain size was 20–40 mesh. For these cases, zeolites and amorphous silica were deposited on grain surfaces but were insufficient to cause overall sand consolidation. However, when a finer, poorly sorted (50–250 mesh) 50:50 mixture of feldspar and quartz was used, sand consolidation was obtained in 2.5 hours. At the top, hotter part of the cell, equant and acicular zeolite crystals (sodium aluminum silicates) weakly bound the sand grains. At the bottom and cooler part of the cell, the sand grains were strongly bound by amorphous silica. Results to-date indicate that both zeolite and silica may be cementing agents, the grain-bonding strength depending on the grain surface area. Further, the temperature, injection rate, and pH of the alkaline solution, and curing time are important process parameters that will be further investigated.IntroductionPremature well and downhole equipment failures often occur during oil production from unconsolidated sands under steam injection, as a result of early steam breakthrough and sand production. In addition, near-wellbore formation damage in heavy-oil reservoirs during steam flooding has been reported by several authors.1–3 To alleviate sand production problems, wells are typically completed with slotted liners, screens, or gravel packs. These sand control methods are expensive and may create skins that reduce well productivity.4,5 Sand consolidation using chemical methods gave limited success due to high temperatures encountered in thermal operations. The high cost of chemical injection including long downtimes to cure the resins have also limited the application.6The Wilmington oil field is the third largest oil field in the U.S. Over 2.5 billion barrels of oil have been produced to date. The field lies mainly beneath the City of Long Beach, California. It is an asymmetrical, highly faulted, doubly plunging anticline, 11 miles long and three miles wide. The main producing reservoir, the Tar Zone, contains heavy oil of 14°API gravity with a viscosity of 250 cp at the reservoir temperature of 123°F. The top of the Tar Zone lies at about 2200 ft. ss.. It consists of very permeable unconsolidated sands (average permeability of 1000 md).Primary production from the Wilmington field began in 1936. Waterflood was initiated on a large scale during the 1950's to enhance oil recovery and control surface subsidence. After pilot tests in 1981, steamflood was expanded since 1988. Sand exclusion methods were used, including the use of slotted liners, wire wrapped screens, gravel packs and in-situ consolidation methods.In 1991–1996, under a U.S. Department of Energy sponsored project, a new sand consolidation method was tested in 13 vertical and seven horizontal wells completed on the Tar Zone.7 The new method involved injecting 80% quality steam, the volume of steam per well being empirically set at 750 CWE bbls per 0.25 in. perforation. The well was then allowed to soak for several days. The wells were then produced, with no sand problems or reduction in productivity or injectivity. To-date, the new sand consolidation technique has been applied in a total of 12 horizontal and 22 vertical wells with over 90% of wells capable of production or injection after two years with no sand production problem.8 Keywords: cement, spe 68847, feldspar, experiment, enhanced recovery, consolidation, quartz, dissolution, pure feldspar, zeolite Subjects: Improved and Enhanced Recovery, Thermal methods This content is only available via PDF. 2001. Society of Petroleum Engineers You can access this article if you purchase or spend a download." @default.
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• W4238056301 title "Sand Consolidation Using High-Temperature Alkaline Solution - Analysis of Reaction Parameters" @default.
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