US20040138069A1 - Drilling fluid with circulation loss reducing additive package - Google Patents

Drilling fluid with circulation loss reducing additive package Download PDF

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Publication number
US20040138069A1
US20040138069A1 US10/342,852 US34285203A US2004138069A1 US 20040138069 A1 US20040138069 A1 US 20040138069A1 US 34285203 A US34285203 A US 34285203A US 2004138069 A1 US2004138069 A1 US 2004138069A1
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United States
Prior art keywords
fluid
component
combinations
additive package
starch
Prior art date
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Abandoned
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US10/342,852
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English (en)
Inventor
Sarkis Kakadjian
Jacques Gabay
Gerardo Sanchez
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Intevep SA
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Intevep SA
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Intevep SA filed Critical Intevep SA
Priority to US10/342,852 priority Critical patent/US20040138069A1/en
Assigned to INTEVEP, SA reassignment INTEVEP, SA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GABAY, JACQUES REINALDO, KAKADJIAN, SARKIS, SANCHEZ, GERARDO ALONSO
Priority to CO04001055A priority patent/CO5540063A1/es
Priority to EC2004004942A priority patent/ECSP044942A/es
Priority to ARP040100086A priority patent/AR042852A1/es
Priority to BRPI0400020-0A priority patent/BRPI0400020B1/pt
Publication of US20040138069A1 publication Critical patent/US20040138069A1/en
Priority to US12/535,854 priority patent/US8138124B2/en
Abandoned legal-status Critical Current

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    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/50Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504Compositions based on water or polar solvents
    • C09K8/506Compositions based on water or polar solvents containing organic compounds
    • C09K8/508Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/514Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02Well-drilling compositions
    • C09K8/04Aqueous well-drilling compositions
    • C09K8/06Clay-free compositions
    • C09K8/08Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02Well-drilling compositions
    • C09K8/04Aqueous well-drilling compositions
    • C09K8/06Clay-free compositions
    • C09K8/08Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
    • C09K8/10Cellulose or derivatives thereof
    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/18Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts

Definitions

  • the invention relates to drilling fluid and, more particularly, to drilling fluids including a circulation loss reducing additive package which is particularly useful in high permeability reservoirs and the like.
  • a drilling fluid which comprises a base fluid and a circulation loss reducing additive package comprising a polysaccharide, a cellulose derivative and a pH controlling component.
  • the additive package preferably also includes starches, bridging agents, anti-oxidants and biocides, as well as other additives which may be desirable for particular applications.
  • a circulation loss reducing additive package comprising a polysaccharide, a cellulose derivative and a pH controlling component.
  • FIG. 1 schematically illustrates shear rate verses shear stress for fluids in accordance with the present invention after aging for sixteen hours at a temperature of 250° F.;
  • FIG. 2 graphically illustrates filtrate volume over time for drilling fluids in accordance with the present invention
  • FIGS. 3 and 4 illustrate plastic viscosity and yield point for conventional drilling fluids and a drilling fluid in accordance with the present invention
  • FIG. 5 graphically illustrates filtration loss over time for a fluid in accordance with the present invention and for conventional fluids
  • FIG. 6 graphically illustrates shear stress verses shear rate for a fluid in accordance with the present invention as compared to conventional fluids
  • FIGS. 7 and 8 illustrate shear stress verses shear rate for a further fluid in accordance with the present invention, before and after aging for sixteen hours at a temperature of 200° F.;
  • FIGS. 9 and 10 graphically illustrate apparent viscosity verses shear rate in accordance with the present invention, before aging and after aging for sixteen hours at a temperature of 200° F.;
  • FIG. 11 graphically illustrates filtrate volume over time for a further fluid in accordance with the present invention.
  • FIG. 12 illustrates storage modulus/loss ratio over a range of frequencies.
  • the invention relates to a drilling fluid and, more particularly to a drilling fluid including an additive package for controlling circulation loss which is well suited for use in drilling through highly permeable, unconsolidated or micro-fractured formations and the like.
  • a drilling fluid preferably a water based drilling fluid
  • a circulation loss reducing additive package which includes a polysaccharide component which helps to improve rheology and reduce filtration losses, a cellulose derivative component which also serves to improve rheology and reduce filtration losses, and a pH controlling component.
  • the polysaccharide component and cellulose derivative component combine to provide the fluid with excellent elastic properties.
  • drilling fluids containing the additive package in accordance with the present invention advantageously demonstrate much lower circulation losses when used in drilling through highly permeable, unconsolidated, micro-fractured and similar formations.
  • Such drilling fluid formulations containing the additive package of the present invention further demonstrate desirable shear properties, filtrate loss, plastic viscosity and yield point, and apparent viscosity.
  • the polysaccharide component is preferably a non or low ionic charge polysaccharide.
  • a preferred non-ionic polysaccharide is a non-ionic polysaccharide having double helix or triple helix configuration, or combinations thereof, in aqueous solutions.
  • a particularly preferable non-ionic polysaccharide is scleroglucan which can be purified (CS11-Degussa) or not (Biovis or Actigum CS-Degussa), which, in combination with the cellulose derivative and bridging agent components, provide the fluid with improved viscoelastic, Theological and sealing properties
  • Suitable low ionic charge polysaccharides include xanthan gum, which can be clarified or not, and further which can be acetylated or not.
  • Commercial examples of suitable non and low ionic polysaccharides include Actigum CS, from Degussa, Xanvis, Diutam and NAX, all from CP Kelco.
  • Other non or low ionic charge polysaccharides can also be used in accordance with the broad scope of the present invention.
  • the additive in accordance with the present invention also preferably includes a cellulose derivative component which can preferably be provided in the form of hydroxypropyl cellulose, carboxymethyl hydroxyethyl cellulose, hydroxyethyl cellulose, hydrophobically modified cellulose and the like, preferably hydroxyethyl cellulose.
  • This component of the additive package combined with the polysaccharide component, advantageously serves to improve Theological and viscoelastic properties of the drilling fluid, and also serves to reduce filtration losses or losses of fluid into a high permeability, unconsolidated or micro-fractured formation.
  • the additive further preferably includes a pH controlling component or additive, and this pH controlling component can advantageously be selected from the group consisting of monoethanolamine, ethanolamine, magnesium oxide, triethanolamine, sodium hydroxide, sodium carbonate, potassium carbonate and combinations thereof.
  • the pH controlling additive is preferably added so as to pH at desired levels, preferably up to about 12.
  • a further component of the additive package in accordance with the present invention may preferably be a starch or starch derivative, which advantageously serves to provide further filtrate volume control.
  • suitable starch or starch derivative components include carboxymethyl starch, hydroxyethyl starch, hydroxypropyl starch, starches cross-linked with etherifying and/or esterifying agents and the like, preferably slightly cross-linked starches such as FL-7 Plus, M-I Drilling Fluids. These starches, starch derivatives and modified starches are collectively referred to herein as a starch component.
  • a bridging agent is preferable to include to achieve good filtration control and low fluid loss, and a particularly preferred bridging agent is calcium carbonate.
  • Sized calcium carbonate such as Milcarb from Baker Hughes Inteq, is particularly suitable for use in the package of the present invention. The size of the calcium carbonate particle is selected to avoid formation damage and also to control fluid loss.
  • calcium carbonate serves mainly as a bridging agent, to control fluid loss into the reservoir, calcium carbonate also serves to increase density of the fluid as desired so as to provide a final fluid having the desired density.
  • a still further component which may be included in the additive package of the present invention is an antioxidant component, and suitable antioxidants include sodium bisulfite, sodium sulfite and the like, preferably sodium bisulfite. These components serve to protect the biopolymers used in the additive package and drilling fluid formulation from oxidation, and thereby help to maintain the molecular weight of the polymers relatively constant as desired.
  • a biocide component is also preferably incorporated into the additive package of the present invention.
  • Suitable biocide components include isothiazolones, glutaraldehyde, quaternary amines and the like.
  • the biocide component advantageously serves to avoid undesirable hydrolysis of biopolymers in the formulation by reducing oxidative and enzymatic degradation of same.
  • the fluid itself can advantageously be water-based, and thus the base fluid may be water.
  • the base fluid may be water.
  • other base fluids can be used as well.
  • water based fluids are preferable in that the cost of the base fluid is desirably low, and the additives perform as desired in a water base.
  • a drilling fluid containing a circulation reducing additive package according to the invention preferably includes at least about 0.05 ppb of polysaccharide component, at least about 0.05 ppb of cellulose derivative component, at least about 1.0 ppb of pH controlling component, at least about 0.05 ppb of starch component, at least about 20 ppb of bridging agent, at least about 1.0 ppb of antioxidant and at least about 0.05 ppb of biocide, all taken with respect to weight of the component per barrel of drilling fluid.
  • the drilling fluid can advantageously be prepared by sequentially mixing in the various additive components into the base fluid.
  • a starting volume of water may advantageously first be mixed with potassium chloride, then fumaric acid and then the hydroxyethylcellulose. After these components, then biocide materials can be added, followed by sodium bisulfides, scleroglucan, starch and finally calcium carbonate, each with a mixing time of between about 5 and about 20 minutes before addition of the next component.
  • fluids prepared in accordance with the present invention have excellent high pressure, high temperature Theological and viscoelastic properties.
  • a fluid prepared in accordance with the present invention was aged for sixteen hours at a temperature of about 250° F., and then subjected to HPHT Theological property testing, and the results are shown in FIG. 1.
  • formulas A, B and C from Table 2 each provided excellent shear stress over shear rate, as desired.
  • Table 7 shows that the fluid of the present invention has excellent properties in connection with Cw coefficients and spurt loss.
  • a further fluid was prepared in accordance with the present invention, and this formulation, designated Formulation E, was prepared as shown in Table 8 below.
  • Table 8 Additives Concentrations Hydroxyethylcellulose 3.0 (lb/bbl) Scleroglucan 2.0 (lb/bbl) Starch 2.5 (lb/bbl) Biocide 0.15 (lb/bbl) Magnesium oxide 0.5 (lb/bbl) KCl 2.0 (%) CaCO 3 20.0 (lb/bbl) Mineral oil 10.0 (%) Clay swelling inhibitor 2.0 (%)
  • Formulation E was evaluated in a series of tests so as to determine shear stress verses shear rate for various temperatures after no aging, and after aging for sixteen hours at a temperature of 200° F.
  • FIGS. 7 and 8 show the results of this testing, and show excellent results for the fluid of the present invention, both prior to and after aging.
  • formulation E was further evaluated so as to determine apparent viscosity as a function of shear rate, and the results of this testing are shown in FIGS. 9 and 10.
  • FIGS. 9 and 10 demonstrate that apparent viscosity is maintained as desired even after aging at 200° F., and that the apparent viscosity is not affected by increases in temperature in the range of 150° F.-250° F.
  • the core conditions for carrying out this evaluation include a Berea core type, permeability of 500 mD, formation water containing approximately 2% wt. KC1, crude oil from a field in Western Venezuela, and the additive package of Formulation E.
  • FIG. 11 shows the filtrate volume obtained With this formulation, and the test further shows an initial Mobility of 1.04 mD/cP, a final mobility of 0.84 mD/cP, and a delta P of 1000 psi, and a formation damage of 18.87% had occurred.
  • Formulation E in accordance with the present invention was also evaluated to determine storage and loss moduli as a function of frequency at a deformation located in the linear viscoelastic range, by using an oscillatory rheometer. Moduli of a high commercial viscoelastic fluid were also evaluated and compared to results obtained using Formulation E. Both formulations had been aged for 16 hours at 120° F. before taking of these measurements, and FIG. 12 shows the results in terms of the storage modulus/loss modulus (G′/G′′), vs. frequency.
  • FIG. 12 shows the results in terms of the storage modulus/loss modulus (G′/G′′), vs. frequency.
  • Formulation E has G′/G′′ values that are comparable to those of the high performance commercial viscoelastic fluid, and both fluids have a high elastic component over a wide range of frequencies, since the G′/G′′ ratio is greater than unity. Such fluids are reported to provide better cuttings suspension and hole cleaning functions when used as drilling fluids. Thus, Formulation E provides a drilling fluid having desirable cutting suspension properties and sealing properties, and elasticity is comparable to high performance commercial viscoelastic fluids.
  • Formulation E was also subjected to this testing after having been aged at a temperature 150° F. for 16 hours, and even after such aging Formulation E holds elasticity over a wide range of frequencies as demonstrated by the ratio G′/G′′ which is still greater than unity.
  • a displacement test was conducted for a fluid similar to Formulation E, but not having the CaCO 3 additive. The test was conducted under severe conditions to maximize formation damage and to simulate fluid invasion.
  • the core type was Berea, with a 500 mD permeability, and fluid conditions included 2% KCl, West Venezuela crude, and Formulation E in the form of an additive package according to the invention. The test was conducted under these conditions to maximize potential damage and simulate fluid invasion of the well.
  • results obtained include an initial mobility of 0.78 mD/cP, a final mobility of 0.59 mD/cP, a percent damage of 24.44, and a final delta P which was higher than an initial delta P.
  • the drilling fluid of the present invention was also field tested during the drilling of a horizontal reservoir in Western Venezuela.
  • the fluid weight was 8.8 ppg, and estimated production was 800 bpd. Real production reached 1500 bpd, and no operational problems were observed during the entire course of the operation. Thus, field testing confirmed the excellent performance of the fluid of the present invention.

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  • Chemical & Material Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Agricultural Chemicals And Associated Chemicals (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
  • Drilling And Boring (AREA)
  • Earth Drilling (AREA)
  • Detergent Compositions (AREA)
  • Adhesives Or Adhesive Processes (AREA)
  • Anti-Oxidant Or Stabilizer Compositions (AREA)
US10/342,852 2003-01-15 2003-01-15 Drilling fluid with circulation loss reducing additive package Abandoned US20040138069A1 (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
US10/342,852 US20040138069A1 (en) 2003-01-15 2003-01-15 Drilling fluid with circulation loss reducing additive package
CO04001055A CO5540063A1 (es) 2003-01-15 2004-01-08 Fluido de perforaion con aditivos que reducen la perdida de circulacion
EC2004004942A ECSP044942A (es) 2003-01-15 2004-01-14 Fluido de perforación con aditivos que reducen la perdida de circulacion
ARP040100086A AR042852A1 (es) 2003-01-15 2004-01-14 Fluido de perforacion con aditivos que reducen la perdida de circulacion
BRPI0400020-0A BRPI0400020B1 (pt) 2003-01-15 2004-01-14 Fluido de perfuração e pacote de aditivo de redução de perda de circulação
US12/535,854 US8138124B2 (en) 2003-01-15 2009-08-05 Drilling fluid with circulation loss reducing additive package

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US10/342,852 US20040138069A1 (en) 2003-01-15 2003-01-15 Drilling fluid with circulation loss reducing additive package

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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070281868A1 (en) * 2004-07-13 2007-12-06 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
DE102006029265A1 (de) * 2006-06-26 2008-01-03 Basf Construction Polymers Gmbh Verwendung von Dicarbonyl-Verbindungen zur Erhöhung der Temperaturstabilität von Biopolymeren bei der Erdöl- und Erdgasexploration
US20090042750A1 (en) * 2004-07-13 2009-02-12 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
US20100022421A1 (en) * 2008-07-25 2010-01-28 Intevep, S.A. Process for preparing thermally stable oil-in-water and water-in-oil emulsions
CN105435751A (zh) * 2016-01-06 2016-03-30 昆明理工大学 一种玉米秆芯再生多糖醚化物复合凝胶的制备方法
CN109652027A (zh) * 2018-12-18 2019-04-19 中国石油集团川庆钻探工程有限公司 一种提高聚合物钻井液高温稳定性的方法
CN109652034A (zh) * 2018-12-18 2019-04-19 中国石油集团川庆钻探工程有限公司 一种维持高温及高含盐条件下水基钻井液pH值的方法

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Publication number Priority date Publication date Assignee Title
US9611716B2 (en) 2012-09-28 2017-04-04 Schlumberger Technology Corporation Compositions and methods for reducing fluid loss
CA2990509C (en) 2015-07-23 2022-07-12 Uniquem Inc. Modified natural polymers as bitumen encapsulants
US20200131420A1 (en) * 2017-03-17 2020-04-30 Bastlab, Llc Method and composition of matter for reducing lost circulation
CN108774506B (zh) * 2018-04-17 2021-09-21 中原工学院 一种抗高温型醚化改性淀粉降滤失剂及其制备方法

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Publication number Priority date Publication date Assignee Title
US20070281868A1 (en) * 2004-07-13 2007-12-06 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
US20090042750A1 (en) * 2004-07-13 2009-02-12 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
US7727936B2 (en) * 2004-07-13 2010-06-01 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
US7727937B2 (en) * 2004-07-13 2010-06-01 Halliburton Energy Services, Inc. Acidic treatment fluids comprising xanthan and associated methods
DE102006029265A1 (de) * 2006-06-26 2008-01-03 Basf Construction Polymers Gmbh Verwendung von Dicarbonyl-Verbindungen zur Erhöhung der Temperaturstabilität von Biopolymeren bei der Erdöl- und Erdgasexploration
US20100022421A1 (en) * 2008-07-25 2010-01-28 Intevep, S.A. Process for preparing thermally stable oil-in-water and water-in-oil emulsions
US9109151B2 (en) * 2008-07-25 2015-08-18 Intevep, S.A. Process for preparing thermally stable oil-in-water and water-in-oil emulsions
CN105435751A (zh) * 2016-01-06 2016-03-30 昆明理工大学 一种玉米秆芯再生多糖醚化物复合凝胶的制备方法
CN109652027A (zh) * 2018-12-18 2019-04-19 中国石油集团川庆钻探工程有限公司 一种提高聚合物钻井液高温稳定性的方法
CN109652034A (zh) * 2018-12-18 2019-04-19 中国石油集团川庆钻探工程有限公司 一种维持高温及高含盐条件下水基钻井液pH值的方法

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US8138124B2 (en) 2012-03-20
CO5540063A1 (es) 2005-07-29
ECSP044942A (es) 2004-10-26
BRPI0400020A (pt) 2004-12-28
US20090291862A1 (en) 2009-11-26
AR042852A1 (es) 2005-07-06
BRPI0400020B1 (pt) 2015-03-17

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