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Method of Using Water-in-Oil Emulsion to Remove Oil Base or Synthetic Oil Base Filter Cake

a technology of oil base and emulsion, applied in the field of waterinoil emulsion composition, to achieve the effect of excellent particle suspension capacity

Inactive Publication Date: 2009-05-07
BAKER HUGHES HLDG LLC
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Benefits of technology

[0021]Such emulsions are capable of removing or inhibiting the formation of unwanted solids and particulates, including pipe dope, asphaltenes and paraffins, within the well and further serve to improve the permeability of the formation.
[0023]The present invention relates therefore to a process for increasing the effectiveness of production chemicals by reducing the number and duration of shut-in operations needed to increase the production rate from or into a well.
[0027]The water-in-oil emulsion used in the invention typically provides excellent particle suspension capacity. Such capacity prevents particulates from redepositing within the well, e.g., on tubings, casings or the formation surface.

Problems solved by technology

Further, the emulsions are highly efficacious in the removal of oil based mud (OBM) and synthetic oil based mud (SBM) filter cakes from the well and / or formation face.

Method used

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Examples

Experimental program
Comparison scheme
Effect test

example 1

[0076]This Example illustrates the displacement process for eliminating drilling mud components, especially solids and oil, from a well system prior to introduction of solids-free completion and / or packer brine. All percentages expressed in this Example are in weight percentages. The drilling mud is displaced from the well system by circulating therein. Two compositions were tested as designated below:

Composition 1:Composition 2:40% Paravan94% Paravan 1% Viscoflex - X 1% Viscoflex - X 5% SP-78 5% SP-7854% water

The compositions were used with sludge produced from a well of Venezuelan crude oil.

Mud displacement: 100 ml of mud sample was poured into a glass jar (4 oz) to coat the wall completely and excess mud was poured out. 100 ml of Composition 1 and 2 were poured into separate sludge treated jars, respectively, and stirred under constant RPM. After a pre-defined time, the liquids were poured out and the jars were examined for mud removal efficiency. Composition 1 effectively remove...

example 2

[0078]An emulsion was prepared consisting of 65% Bio-Base 637, 28% water, 3 pounds per barrel (ppb) soda ash and 7% Tween 81. (All percentages expressed in this Example are volume percentages.) The emulsion was prepared by introducing the oil and surfactant into a vessel and mixing the components at room temperature until uniformly mixed, about 10 minutes. To the resultant was added an aqueous system containing the soda ash. The components were then mixed at room temperature until uniformly mixed, about ten minutes. The resulting product, Treatment Emulsion, contained linear paraffins and surfactant as the external phase and an aqueous internal phase. The pH of the emulsion was approximately 9.5.

examples 3-12

[0079]Ten field drilling mud systems from actual drilling operations with varying compositions were used to evaluate the effectiveness of the Treatment Emulsion to break down the interfacial and / or rheological properties of the mud cakes and adherence of the cakes to the formation. Table I outlines the ten drilling mud systems as well as their mud density and rheological properties at 70° F.

TABLE IFann DialFann DialFann DialFann DialExampleReadingsReadingsReadingsReadings10 sec Gel / No.Density600 / 300200 / 10060 / 306 / 310 min Gel314.0 ppg200 / 11075 / 4227 / 176 / 5 5 / 254 9.0 ppg67 / 4740 / 3022 / 179 / 7 2 / 105 9.2 ppg105 / 62 45 / 2515 / 6 1 / 11 / 2614.0 ppg48 / 2819 / 128 / 73 / 23 / 5712.5 ppg64 / 3424 / 1212 / 7 2 / 11 / 1813.3 ppg186 / 10070 / 4126 / 166 / 5 9 / 12915.5 ppg>320 / 220 172 / 92 57 / 328 / 5 7 / 221015.9 ppg133 / 75 55 / 3321 / 146 / 55 / 81118.5 ppg292 / 160112 / 62 42 / 2712 / 9 10 / 141218.8 ppg>320 / 192 137 / 77 53 / 3516 / 14 4 / 22

[0080]A dynamic (stirred) high-temperature high-pressure (HTHP) fluid loss cell was used to evaluate the effectiveness of the T...

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Abstract

Fluid producing or injecting wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted particulates, including pipe dope, asphaltenes and paraffins. In addition, such emulsions are effective in the displacement of oil base drilling muds and / or residues from such muds from wells. The emulsion may also be used to break the interfacial and / or rheological properties of oil base mud and synthetic oil base mud filter cakes, and act as a demulsifier to break the water-in-oil emulsion present in such oil base and synthetic oil base muds. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Description

[0001]This application is a continuation application of U.S. patent application Ser. No. 11 / 820,085, filed on Jun. 18, 2007, which is a continuation-in-part application of U.S. patent application Ser. No. 11 / 701,685, filed on Feb. 20, 2007, now U.S. Pat. No. 7,455,111, which is a divisional application of U.S. patent application Ser. No. 10 / 932,965, filed on Sep. 2, 2004, now U.S. Pat. No. 7,188,676. U.S. patent application Ser. No. 11 / 820,085 is also a continuation-in-part application of U.S. patent application Ser. No. 11 / 388,103, filed on Mar. 23, 2006, which is now U.S. Pat. No. 7,392,845.FIELD OF THE INVENTION[0002]The invention relates to the use of water-in-oil emulsion compositions for use in oil field production and injection operations. Such compositions have particular applicability in the removal of drilling muds, scale, heavy crude, paraffins and / or asphaltenes from subterranean formations. In addition, the compositions have particular applicability in breaking oil base...

Claims

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Application Information

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Patent Type & Authority Applications(United States)
IPC IPC(8): E21B37/08C09K8/52
CPCC09K8/524C09K8/52Y10S507/929Y10S507/905
Inventor JAVORA, PAUL H.BEALL, BRIAN B.VORDERBURGGEN, MARK A.QU, QIBERRY, SANDRA L.
Owner BAKER HUGHES HLDG LLC
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