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WO2019069280A1 - Formulations de fluide de forage et procédés associés - Google Patents

Formulations de fluide de forage et procédés associés Download PDF

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Publication number
WO2019069280A1
WO2019069280A1 PCT/IB2018/057749 IB2018057749W WO2019069280A1 WO 2019069280 A1 WO2019069280 A1 WO 2019069280A1 IB 2018057749 W IB2018057749 W IB 2018057749W WO 2019069280 A1 WO2019069280 A1 WO 2019069280A1
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WO
WIPO (PCT)
Prior art keywords
drilling fluid
formulation
fluid formulation
barite
ppg
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/IB2018/057749
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English (en)
Inventor
Mahaboob Subhahani MOHAMED ALI
Faizan Ahmad
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Oren Hydrocarbons Private Ltd
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Oren Hydrocarbons Private Ltd
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 Oren Hydrocarbons Private Ltd filed Critical Oren Hydrocarbons Private Ltd
Priority to CA3078569A priority Critical patent/CA3078569A1/fr
Publication of WO2019069280A1 publication Critical patent/WO2019069280A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C09K8/36—Water-in-oil emulsions
    • 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
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions

Definitions

  • the present invention relates to drilling fluid formulations and associated methods. More particularly, the present invention relates to drilling fluid formulations containing weighting agents and methods for formulating such fluids.
  • Natural resources such as oil and gas present in the subterranean formation are recovered by drilling a wellbore that penetrates the formation.
  • a drilling fluid is generally used for cooling and lubricating the drill bit as it grinds through the earth's crust. Further, as the drill bit descends, it generates "cuttings", or small bits of stone, clay, shale or sand.
  • An important function of the drilling fluid is to transport these cuttings back up to the earth's surface, and provide a hydrostatic pressure to prevent formation fluids from entering into the wellbore.
  • the hydrostatic pressure of the drilling fluid in the wellbore should be greater than the pressure of the formation fluids.
  • the hydrostatic pressure of the drilling fluid is a function of its density, and depth of the wellbore. Accordingly, density is an important property of the drilling fluid for preventing undesirable flow of formation fluids into the wellbore.
  • weighting agents are commonly added to the drilling fluids. These weighting agents are typically inert, high specific gravity, finely ground solid materials. Preferred weighting agents include powdered minerals of barite, calcite, hematite, ilmentite, manganese tetraoxide and galena.
  • Barite is a mineral composed of barium sulfate (BaS0 4 ), which is a high-density mineral used as a weighting agent in drilling fluids. Barite is chemically inert and insoluble.
  • the low hardness barite is l preferred as it prevents abrasion and erosion of the drilling equipment. Due to the high density of barite it is used to formulate drilling fluids of the desired weights required to control the range of subsurface pressures normally encountered in oil and gas drilling. US Pat. No.
  • Yet another US Pat. No. 9676988 teaches manufacturing a solid phase barite containing material for use in wellbore fluids in which at least 50 vol% barite particles having a diameter in the range of 1 um to 10 um and at least 90 vol % barite particles having a diameter in the range of 4 um to 20 um are contacted with a liquid to form relatively large particles with at least 90 vol % of the barite particles having a diameter of at least 30 um.
  • the barite used in the drilling fluids taught by the prior arts has a specific gravity of at least 4.2.
  • the high specific gravity of barite can produce mud weights in excess of 19 lb/gal. Further, it is easily millable to a particle size that reduces settling and minimizes losses on shaker screens.
  • barite filter-cake removal after the drilling operation is a huge problem due to low solubility of barite in the available fluids.
  • a further drawback of using barite is that the lower grade barite has a required density, however, impure barium sulfate can contain significant quantities of contaminants. These non-barite contaminants not only affect the fluid quality but also significantly increase the required quantity of drilling fluid. Therefore, excess addition of barite to drilling fluid formulation may lead to increase in the waste generation.
  • a higher concentration of the weighting agents may be included in the drilling fluid.
  • increasing the concentration of the weighting agent may be problematic as particle sedimentation or "sag" may occur.
  • the sag phenomenon arises from the settling out of particles from the wellbore fluid. This settling out causes significant localized variations in mud density or "mud weight,” both higher and lower than the nominal or desired mud weight.
  • particle sedimentation may result in stuck pipe or a plugged annulus.
  • increasing the concentration of the weighting agent may also increase the viscosity of the drilling fluid. Excessive viscosity may have adverse effects on equivalent circulating density which may result in an increase in pumping requirements for circulation of the drilling fluid in the wellbore.
  • a drilling fluid formulation including a base fluid and an additive mixture, wherein the additive mixture comprises barite having specific gravity of about 4.25 in a concentration of about 422 Kg/m 3 , about 651 Kg/m 3 and about 1339 Kg/m 3 for about 10.5, 12 and 16.5 PPG of mud weight, respectively.
  • a drilling fluid formulation including a base fluid and an additive mixture, wherein the additive mixture comprises barite having specific gravity of about 4.1 in a concentration of about 426 Kg/m 3 , about 658 Kg/m 3 and about 1352 Kg/m 3 for about 10.5, 12 and 16.5 PPG of mud weight, respectively.
  • the additive mixture may further comprise an emulsifier, a viscosifier, a rheology modifier and a fluid loss control agent.
  • the drilling fluid formulation comprises said base fluid (olefin base oil) and water (Cack brine), said oil to water ratio being about 70:30 for about 10.5, 12 and 16.5 PPG mud weight.
  • barite used as weighting agent has a particle size between 50 - 100 microns.
  • the formulation according to preferred embodiment has a density in the range of about 10.5 lb/gal to about 22 lb/gal.
  • the base fluid is selected from diesel, paraffin, blended ester, internal olefin, and combinations thereof.
  • the emulsifier is a polyamide, more preferably, a dicarboxylic acid terminated polyamide.
  • the viscosifier is selected from a saturated fatty acid derivate.
  • the rheology modifier is selected from a dicarboxylic acid.
  • the fluid loss control agent is selected from a fatty acid is modified with a dicarboxylic acid.
  • the formulation is stable and effective at a temperature up to 300 °F, reduces the filter cake thickness by 10 to 25%, and is significantly free from organophilic clay and organophilic lignite.
  • FIG. 1 illustrates a graph showing the comparison of standpipe pressure (SPP) vs depth between traditional drilling fluid formulation and drilling fluid formulation of the present invention.
  • SPP standpipe pressure
  • the present invention relates to drilling fluid formulations and methods for obtaining the formulations. Accordingly, the present invention provides a drilling fluid formulation having a desired density without an undesirable increase in the viscosity. Also, the drilling fluid formulation of the present invention inhibits particle sedimentation, and enhances emulsion stability.
  • a drilling fluid formulation comprising a weighting agent.
  • the weighing agent should have the following characteristics: lower plastic viscosity value for high density mud; low settling nature and providing low sag, easily removable from the reservoir by mechanical or chemical method, hard enough not to create fines during drilling, contain minimum coarse particles to prevent abrasion, to be sustainable and readily obtainable in bulk quantities, environment friendly and cost effective.
  • weighting agent as well as drill cuttings can create sedimentation or sag that can lead to serious problems in the drilling well such as loss of well control, stuck pipe and lost circulation.
  • the sag formation is due to settling out of particles from wellbore drilling fluid. This settling out causes significant localized variations in mud density or "mud weight,” both higher and lower than the nominal or desired mud weight.
  • the phenomenon generally arises when the wellbore or drilling fluid is circulating bottoms-up after a trip, logging or casing run. In general, light mud is followed by heavy mud in a bottoms-up circulation. In order to avoid the low-grade barite sagging in drilling fluid, the drilling fluid is provided with superior barite having specific gravity between 4.1 to 4.25.
  • the weighting agent is preferably barite having specific gravity greater than 4.1, more preferably the weighting agent is barite having specific gravity in the range of 4.1 to 4.25.
  • barite having specific gravity 4.25 leads to formation of easier to remove less thickness filter cake. From the results in a drilling fluid and cement slurry of enhanced stability, which assists in avoiding drilling problems such as sagging and cement channeling.
  • the main role of the weighting materials in the drilling fluid is to increase mud density and provide the borehole stability. It also creates sufficient hydrostatic pressure in the hole and minimizes fluid loss by formation of thick filter cake on the walls of the drill well. Further increase in density of mud also results in increasing the penetration rate; whereas if the density is excessive it can lead to differential sticking of the drill string. On the other hand, barite is prone to sag, and so requires adequate viscosifiers to keep it in suspension.
  • an oil-based drilling fluid formulation includes a base fluid and an additive mixture.
  • the base fluid (olefin base oil) and water (Cack brine) are typically used in a ratio of about 70:30 for 10.5, 12 and 16.5 PPG mud weight.
  • the additive mixture comprises barite having specific gravity of about 4.1 to 4.25.
  • the concentration of barite having specific gravity of about 4.1 is about 426 Kg/m 3 , about 658 Kg/m 3 and about 1352 Kg/m 3 for about 10.5, 12 and 16.5 PPG of mud weight, respectively.
  • the concentration of barite having specific gravity of about 4.25 is about 422 Kg/m 3 , about 651 Kg/m 3 and about 1339 Kg/m 3 for about 10.5, 12 and 16.5 PPG of mud weight, respectively.
  • concentration of barite in the additive mixture is in the range of about 422 - 426 Kg/m 3 , 651 - 658 Kg/m 3 , and 1339 - 1352 Kg/m 3 for about 10.5, 12 and 16.5 PPG of mud weight, respectively.
  • the particle size of barite is preferably between 50 - 100 microns, more preferably ⁇ 75microns.
  • the drilling fluid has a density of greater than about 10.5 lb/gal.
  • the drilling fluid has a density of about 10.5 lb/gal to about 22 lb/gal.
  • the base fluid may be selected from aqueous-based fluids (e.g., water, oil-in-water emulsions) and oleaginous-based fluids (e.g., invert emulsions).
  • aqueous-based fluids e.g., water, oil-in-water emulsions
  • oleaginous-based fluids e.g., invert emulsions
  • Suitable oleaginous fluids include, but are not limited to, a -olefins, internal olefins, alkanes, aromatic solvents, cycloalkanes, liquefied petroleum gas, kerosene, diesel oils, crude oils, gas oils, fuel oils, paraffin oils, mineral oils, low-toxicity mineral oils, olefins, esters, amides, synthetic oils (e.g., polyolefins), polydiorganosiloxanes, siloxanes, organosiloxanes, ethers, acetals, dialkylcarbonates, hydrocarbons, and combinations thereof.
  • the base fluid is selected from diesel, paraffin, blended ester, internal olefin or combinations thereof.
  • the base fluid may be present in an amount sufficient to form a pumpable drilling fluid formulation.
  • the drilling fluid formulation may comprise a viscosifier for increasing the viscosity of the drilling fluid and imparting a sufficient carrying capacity to the drilling fluid, enabling the drilling fluid to transport drill cuttings and/or weighting materials, and prevent the undesired settling of the drilling cuttings and/or weighting materials.
  • suitable viscosifiers include, but are not limited to, clays and clay derivatives, polymeric additives, diatomaceous earth, polysaccharides such as starches, and combinations thereof.
  • the drilling fluids may further comprise additional additives.
  • additives include, but are not limited to, emulsifiers, wetting agents, dispersing agents, shale inhibitors, pH-control agents, rheology modifiers, fluid loss control agents, filtration-control agents, lost-circulation materials, alkalinity sources such as lime and calcium hydroxide, salts, or combinations thereof.
  • the formulation is stable and effective at a temperature up to 300 °F.
  • the formulation is significantly free from organophilic clay and organophilic lignite.
  • the filter cake thickness can be reduced by 10 to 25 %.
  • the formulation showed good low shear rheology and facilitates better hole cleaning and sag control.
  • the formulation showed less Plastic Viscosity (PV) results implying lower equivalent circulating densities (ECD) at faster drilling rate.
  • the formulation showed a less PV value and enhanced the rate of penetration (ROP).
  • emulsifier trade name "EMSTABER” was provided with stable water-in-oil emulsion at the temperature of 300°F.
  • Viscosifier trade name “VISBUILDER” acted as gellent to the barite in more suspension and showed minimal changes in the rheological after dynamic ageing.
  • the rheology modifier trade name “ULTRAMOD” enhanced the yield point and gel strength of the mud system without affecting the plastic viscosity.
  • the fluid loss control agent trade name “FCPLUS” effectively controlled the HTHP fluid loss of drilling fluid formulation. Barite having specific gravity 4.1 and 4.25 were used as weighing agents in the drilling fluid formulation.
  • Mud formulation was prepared as follows. To the Poly Alpha Olefin PAO as a base fluid, the following components were added and mixed as follows: 1) EMSTABER from Oren Hydrocarbons act as a emulsifier, followed by mixing for 3 minutes; 2) lime (Ca(OH) 2 ), followed by mixing for 3 minutes; 3) water and calcium chloride, followed by mixing for 10 minutes; 4) VISBUILDER from Oren Hydrocarbons act as a Viscosifier, followed by mixing for 10 minutes; 5) ULTRAMOD from Oren Hydrocarbons act as a rheology modifier, followed by mixing for 3 minutes; 6) FC PLUS from Oren Hydrocarbons act as a fluid loss control additive, followed by mixing for 3 minutes; and 7) barite (4.1 & 4.25) weighing agent, followed by mixing for 10 minutes.
  • the evaluation of the drilling fluid formulation was performed through mud weights 10.5, 12 and 16.5 PPG and drilling mud samples prepared in which one sample contained barite having specific gravity 4.1 and second sample contained barite having specific gravity 4.25. Barites having specific gravity 4.25 showed significant results and reduced quantity of barite consumption in the drilling mud, which in turn decreased the quantity of waste generated.
  • the barite having specific gravity 4.25 was identified as a weighting agent suitable for use in drilling and completion fluids, which offered significant advantages in the control of formation damage.
  • the performance properties of drilling fluid system showed similar physical and rheological properties using barite having specific gravity 4.1 and 4.25 as weighting agents in drilling fluids.
  • FIG. 1 of the accompanying drawings illustrates a graph showing the comparison of standpipe pressure (SPP) vs depth between oil-based mud of test 1 and oil-based mud of test 2. It is observed that using the oil-based mud comprising barite having specific gravity 4.25, the drilling fluid can reach greater depth at reduced standpipe pressure.
  • SPP standpipe pressure
  • Embodiment of the present invention is applicable over a wide number of uses and other embodiments may be developed beyond the embodiment discussed heretofore. Only the most preferred embodiments and their uses have been described herein for purpose of example, illustrating the advantages over the prior art obtained through the present invention; the invention is not limited to these specific embodiments or their specified uses. Thus, the forms of the invention described herein are to be taken as illustrative only and other embodiments may be selected without departing from the scope of the present invention. It should also be understood that additional changes and modifications, within the scope of the invention, will be apparent to one skilled in the art and that various modifications to the construction described herein may fall within the scope of the invention.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne une formulation de fluide de forage. La formulation de fluide de forage comprend un fluide de base et un mélange d'additifs, le mélange d'additifs comprenant de la baryte ayant une gravité spécifique d'environ 4,1 à 4,25 en une concentration réduite dans la plage de 426 à 422 Kg/m3, de 658 à 651 Kg/m3 et 1 352 à 1 339 Kg/m3 pour 10,5, 12 et 16,5 % poids de boue en PPG, respectivement. La formulation de fluide de forage réduit la plage d'épaisseur de gâteau de filtration de 10 à 25 %, ne provoque pas de sédimentation ou d'affaissement des particules et n'a pas d'impact sur la rhéologie de fluide de forage. En outre, la formulation de fluide de forage est significativement exempte d'argile organophile et de lignite organophile.
PCT/IB2018/057749 2017-10-05 2018-10-05 Formulations de fluide de forage et procédés associés Ceased WO2019069280A1 (fr)

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Application Number Priority Date Filing Date Title
CA3078569A CA3078569A1 (fr) 2017-10-05 2018-10-05 Formulations de fluide de forage et procedes associes

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IN201741035396 2017-10-05
IN201741035396 2017-10-05

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Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN111748328A (zh) * 2020-06-15 2020-10-09 北京石大胡杨石油科技发展有限公司 超高温长效稳定型油基完井液及其制备方法
CN112111256A (zh) * 2020-09-24 2020-12-22 中国海洋石油集团有限公司 一种评价加重材料的实验浆
CN112538341A (zh) * 2019-09-20 2021-03-23 中国石油天然气股份有限公司 一种抗高温超高密度油基钻井液及其制备方法
CN114231262A (zh) * 2021-12-06 2022-03-25 沙克(天津)石油技术服务有限公司 一种适用于高温高压钻井环境的油基钻井液体系

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1996022342A1 (fr) * 1995-01-20 1996-07-25 Baroid Technology, Inc. Huiles de base pour fluides de forage
WO2005118742A2 (fr) * 2004-06-03 2005-12-15 M-I L.L.C. Utilisation de granules baryte calibres comme alourdissant pour les fluides de forage
WO2011110803A1 (fr) * 2010-03-06 2011-09-15 Halliburton Energy Services Inc Fluides de forage inversés à rhéologie améliorée et procédés de forage de puits de forage
WO2012085516A2 (fr) * 2010-12-23 2012-06-28 Halliburton Energy Services, Inc. Fluides de forage présentant un potentiel de sédimentation réduit, et procédés associés

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1996022342A1 (fr) * 1995-01-20 1996-07-25 Baroid Technology, Inc. Huiles de base pour fluides de forage
WO2005118742A2 (fr) * 2004-06-03 2005-12-15 M-I L.L.C. Utilisation de granules baryte calibres comme alourdissant pour les fluides de forage
WO2011110803A1 (fr) * 2010-03-06 2011-09-15 Halliburton Energy Services Inc Fluides de forage inversés à rhéologie améliorée et procédés de forage de puits de forage
WO2012085516A2 (fr) * 2010-12-23 2012-06-28 Halliburton Energy Services, Inc. Fluides de forage présentant un potentiel de sédimentation réduit, et procédés associés

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN112538341A (zh) * 2019-09-20 2021-03-23 中国石油天然气股份有限公司 一种抗高温超高密度油基钻井液及其制备方法
CN111748328A (zh) * 2020-06-15 2020-10-09 北京石大胡杨石油科技发展有限公司 超高温长效稳定型油基完井液及其制备方法
CN111748328B (zh) * 2020-06-15 2022-08-19 北京石大胡杨石油科技发展有限公司 超高温长效稳定型油基完井液及其制备方法
CN112111256A (zh) * 2020-09-24 2020-12-22 中国海洋石油集团有限公司 一种评价加重材料的实验浆
CN112111256B (zh) * 2020-09-24 2022-12-06 中国海洋石油集团有限公司 一种评价加重材料的实验浆
CN114231262A (zh) * 2021-12-06 2022-03-25 沙克(天津)石油技术服务有限公司 一种适用于高温高压钻井环境的油基钻井液体系

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