WO2009005503A1 - Fluides de forage à émulsion inversée à base de carburant diesel et procédé de forage de puits de forage - Google Patents

Fluides de forage à émulsion inversée à base de carburant diesel et procédé de forage de puits de forage Download PDF

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Publication number
WO2009005503A1
WO2009005503A1 PCT/US2007/015490 US2007015490W WO2009005503A1 WO 2009005503 A1 WO2009005503 A1 WO 2009005503A1 US 2007015490 W US2007015490 W US 2007015490W WO 2009005503 A1 WO2009005503 A1 WO 2009005503A1
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Prior art keywords
drilling
fluids
fluid
diesel
present
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PCT/US2007/015490
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English (en)
Inventor
Kenneth W. Oyler
Kimberly J. Burrows
Gary C. West
Don Siems
Jeff Kirsner
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Halliburton Energy Services, Inc.
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Priority to PCT/US2007/015490 priority Critical patent/WO2009005503A1/fr
Publication of WO2009005503A1 publication Critical patent/WO2009005503A1/fr

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    • 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
    • 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

Definitions

  • the present invention relates to compositions and methods for drilling, cementing and casing boreholes in subterranean formations, particularly hydrocarbon bearing formations. More particularly, the present invention relates to diesel oil based drilling fluids and most particularly to diesel oil-based invert emulsion drilling fluids that provide good stability and performance properties.
  • a drilling fluid or mud is a specially designed fluid that is circulated through a wellbore as the wellbore is being drilled to facilitate the drilling operation.
  • the various functions of a drilling fluid include removing drill cuttings from the wellbore, cooling and lubricating the drill bit, aiding in support of the drill pipe and drill bit, and providing a hydrostatic head to maintain the integrity of the wellbore walls and prevent well blowouts.
  • Specific drilling fluid systems are selected to optimize a drilling operation in accordance with the characteristics of a particular geological formation.
  • Oil or synthetic fluid-based muds are normally used to drill swelling or sloughing shales, salt, gypsum, anhydrite or other evaporate formations, hydrogen sulf ⁇ de- containing formations, and hot (greater than about 300 degrees Fahrenheit (“° F") holes, but may be used in other holes penetrating a subterranean formation as well.
  • the terms "oil mud” or “oil-based mud or drilling fluid” shall be understood to include synthetic oils or other synthetic fluids as well as natural or traditional oils, and such oils shall be understood to comprise invert emulsions.
  • “higher temperatures” means temperatures over about 120° F and “lower temperatures” means temperatures at about 40° F to about 60° F.
  • Rheology of a drilling fluid is typically measured at about 120° F or about 150° F.
  • Oil-based muds used in drilling typically comprise: a base oil (or synthetic fluid) comprising the external phase of an invert emulsion;' a saline, aqueous solution (typically a solution comprising about 30% calcium chloride) comprising the internal phase of the invert emulsion; emulsif ⁇ ers at the interface of the internal and external phases; and other agents or additives for suspension, weight or density, oil-wetting, fluid loss or filtration control, and rheology control.
  • Such additives commonly include organophilic clays and organophilic lignites. See H.C.H. Darley and George R.
  • An oil-based or invert emulsion-based drilling fluid may commonly comprise between about 50:50 to about 95:5 by volume oil phase to water phase.
  • An all oil mud simply comprises 100% liquid phase oil by volume; that is, there is no aqueous internal phase.
  • Invert emulsion-based muds or drilling fluids (also called invert drilling muds or invert muds or fluids) comprise a key segment of the drilling fluids industry.
  • Diesel oil-based drilling fluids and particularly diesel oil-based invert emulsion drilling fluids, have been a staple in onshore and zero-discharge drilling operations for decades, because of their stability, lubricity, temperature tolerance, and ability to inhibit reactive clays.
  • diesel oil-based fluids have been known to respond relatively slowly to treatments such as additives for thinning, rheology control, and/or fluid loss, resulting in overtreatment and the need for dilution with more diesel, with consequences of the fluid becoming laden with colloidal solids that can impair drilling performance.
  • drilling fluids have been subjected to greater environmental restrictions and performance and cost demands. There is consequently an increasing need and industry-wide interest in new drilling fluids that provide improved performance while still affording environmental and economical acceptance.
  • the present invention provides improved methods of drilling wellbores in subterranean formations employing diesel oil-based muds, or more particularly, invert emulsion-based muds or drilling fluids comprising diesel oil.
  • diesel oil-based muds or more particularly, invert emulsion-based muds or drilling fluids comprising diesel oil.
  • invert emulsion-based muds or drilling fluids comprising diesel oil.
  • the term "drilling” or “drilling wellbores” shall be understood in the broader sense of drilling operations, which include running casing and cementing as well as drilling, unless specifically indicated otherwise.
  • the present invention also provides diesel oil-based invert emulsion drilling fluids for use in the methods of the invention to effect the advantages of the invention.
  • the methods of the invention comprise using a diesel oil-based drilling fluid that is not dependent on organophilic clays (also called “organo-clays") or lignites to obtain suspension of drill cuttings or other solids.
  • the drilling fluid comprises a synergistic combination of an invert emulsion diesel base, one or more rheology and fluid loss control additives, one or more emulsifiers, and/or optionally other additives, that form a "fragile gel” or show “fragile gel” behavior when used in drilling.
  • the fragile gel structure of the drilling fluid, with relatively low colloidal content for a diesel based fluid is believed to provide or enable suspension of drill cuttings and other solids and to afford the fluid excellent suspension and hole cleaning characteristics.
  • the fragile gel drilling fluids of the invention for use in the methods of the invention, are characterized by their performance.
  • the drilling fluid acts as a gel, suspending/continuing to suspend drill cuttings and other solids (such as for example weighting materials) for delivery to the well surface.
  • the fluid is flowable, acting like a liquid, with reduced or no substantial pressure spike (or no appreciable or noticeable pressure spike), as observed by pressure-while-drilling (PWD) equipment or instruments.
  • the fluids of the invention generally maintain consistently low values for the difference in their surface density and their equivalent density downhole (ECDs) and show significantly reduced loss when compared to other drilling fluids used in that formation or under comparable conditions.
  • ECDs equivalent density downhole
  • Diesel oil-based drilling fluids of the invention are particularly advantageous for use in onshore wells, and provide rheology and fluid loss control as well as desired suspension properties and enhanced temperature tolerance (i.e., retains desired characteristics) to at least about 450° F or even as high as about 500° F or higher.
  • the fluids of the invention yield flatter rheological profiles than other diesel based systems (e.g., see Tables 4, 5, and 6).
  • the fluids of the invention respond quickly to the addition of thinners or other treatments, with thinning or other treatment response of the fluids occurring soon after the thinners or other treatments are added, at least within one-half trip in the wellbore, and without need for multiple circulations of the fluids with the thinners or other treatment additive or additives in the wellbore to show the effect of the addition of the thinners or other treatments.
  • treatment additives other than thinners are emulsifiers and lost circulation control additives, although the fluids of this invention already show minimal downhole fluid losses when compared to other diesel based fluids.
  • the fluids of the invention also provide an enhanced rate of penetration during drilling, an important indicator of drilling performance, when compared to other diesel fluid systems.
  • Examples of preferred diesel oil-based invert emulsion drilling fluids of the invention have added to or mixed with the diesel base, other fluids or materials needed to comprise a complete drilling fluid that are environmentally acceptable and regulatory compliant.
  • Such materials may include, for example: additives for enhancing viscosity, for example, an additive having the tradename RHEMOD LTM suspension agent/viscosifier (modified fatty acid comprising dimeric and trimeric fatty acids) and an additive having the tradename POLYBOOSTTM (non-organophilic clay/crystalline silica material) used to impart viscosity and suspension properties; additives for filtration control, for example, additives having the tradename ADAPTA® or ADAPTA® HP filtration control agent (methylstyrene/acrylate copolymer particularly suited for providing HPHT filtration control in non-aqueous fluid systems); additives for emulsif ⁇ cation, for example, additives having the tradename LE SUPERMULTM (polyaminated fatty acid) and the tradename FORTI
  • organophilic clays or lignites are added to the drilling fluid for use in the invention.
  • Any characterization of the drilling fluid herein as "clayless” shall be understood to mean lacking organophilic clays.
  • Omission of organophilic clays and lignites is a radical departure from traditional teachings respecting preparation of drilling fluids, and particularly diesel based drilling fluids.
  • this omission of organophilic clays and lignites in preferred embodiments of the present invention allows the drilling fluid to have low, reduced, or even substantially little or no colloidal solids and greater tolerance to drill solids (i.e., the properties of the fluid are not believed to be readily altered by the drill solids or cuttings).
  • this omission of organophilic clays and lignites in preferred embodiments of the present invention is believed (without limiting the invention by theory) to contribute to the fluid's superior properties in use as a drilling fluid.
  • Figure l(a) provides a graph showing field data indicating typical pressure spikes after connections and trips with a commercial diesel oil-based invert emulsion drilling fluid formulated with an organophilic clay viscosifier, for comparison with Figure l(b) which provides a graph showing field data with a diesel oil-based invert emulsion drilling fluid of the present invention having substantially no pressure spikes after connections and trips.
  • Figure 2 is a graph comparing fragile gel strength of a diesel oil-based invert emulsion fluid of the present invention with the gel strength of a commercial diesel oil-based invert emulsion drilling fluid formulated with an organophilic clay viscosifier.
  • Figure 3 is a bar graph showing the average diesel use (in drilling fluid formulation) per well in a 32-well comparison where 16 wells were drilled using commercial diesel based drilling fluids formulated with an organophilic clay viscosifier and 16 wells were drilled using an example diesel based drilling fluid of the present invention, indicating that less diesel is employed in the drilling fluids of the invention than in other diesel based drilling fluids.
  • Figure 4 is a graph comparing the rates of penetration in drilling a well using a diesel based drilling fluid of the present invention with the rates of penetration in drilling three comparable wells using commercial diesel based drilling fluids formulated with an organophilic clay viscosifier.
  • Figure 5 is a bar graph showing the average rate of penetration in ft/hr during drilling with a diesel based drilling fluid of the present invention compared to drilling with a commercial diesel based-drilling fluid formulated with an organophilic clay viscosifier.
  • Figure 6 is a bar graph showing the average rate of penetration in ft/hr of the wells plotted in the graph in Figure 4, and particularly comparing the rates of drilling a well with an example diesel-based drilling fluid of the invention with the rates of drilling three comparable wells using a commercial diesel-based drilling fluid formulated with an organophilic clay viscosifier.
  • Figure 7(a) and Figure 7(b) are graphs comparing Brookf ⁇ eld stress test data for a commercial diesel-based drilling fluid formulated with a clay viscosifier (Fig. 7(a)) and a diesel- based fluid of the present invention (Fig. 7(b)).
  • the present invention provides a diesel oil-based invert emulsion drilling fluid
  • diesel based invert drilling fluid also referred to herein as a “diesel based invert drilling fluid” and as a “diesel based fluid of the present invention”
  • the fluid does not rely on organophilic clays or lignites to obtain suspension of barite or drill cuttings, in contrast to other diesel based drilling fluids used commercially today.
  • Some of the other characteristics that further distinguish the drilling fluid of the present invention from other diesel and diesel invert fluids are: (1) no or substantially no pressure spikes (as detected for example with pressure-while-drilling or PWD equipment or instruments) when resuming pumping after a period of rest during drilling; (2) rapid incorporation of additives while pumping; (3) no or substantially no sag of barite or other solids, including drill cuttings; (4) reduction in fluid losses during drilling; (5) faster rates of penetration when drilling; and (6) low ECDs.
  • a “gel” may be defined a number of ways. One definition indicates that a “gel” is a generally colloidal suspension or a mixture of microscopic water particles (and any hydrophilic additives) approximately uniformly dispersed through the oil (and any hydrophobic additives), such that the fluid or gel has a generally homogeneous gelatinous consistency.
  • a "gel” is a colloid in a more solid form than a "sol” and defines a “sol” as a fluid colloidal system, especially one in which the continuous phase is a liquid. Still another definition provides that a "gel” is a colloid in which the disperse phase has combined with the continuous phase to produce a viscous jelly-like product.
  • a gel has a structure that is continually building. If the yield stress of a fluid increases over time, the fluid has gelled. "Yield stress” is the stress required to be exerted to initiate deformation.
  • a "fragile gel” as used herein is a “gel” that is easily disrupted or thinned, and that liquifies or becomes less gel-like and more liquid-like under stress, such as caused by moving the fluid, but which quickly returns to a gel or gel-like state when the movement or other stress is alleviated or removed, such as when circulation of the fluid is stopped, as for example when drilling is stopped.
  • the "fragileness” of the "fragile gels" of the present invention contributes to the unique and surprising behavior and advantages of the present invention.
  • the gels are so “fragile” that it is believed that they may be disrupted by a mere pressure wave or a compression wave during drilling.
  • Figure l(a) shows typical pressure spikes with a commercial diesel based drilling fluid formulated with an organophilic clay viscosifier and Figure l(b) shows substantial lack of pressure spikes as typical with a diesel based drilling fluid of the present invention.
  • the figure shows that the example fluid of the present invention has a gel strength or a peak value of about 40 lb/100ft 2 and then when shear is resumed returns to about 10 Ib/ 100ft 2 at 120° F whereas the gel strength or peak value of the diesel fluid with the organophilic clay viscosifier peaks at 15 lb/lOOfP and then when shear is resumed returns to about l0 1b/100ft 2 at l20° F.
  • diesel based drilling fluids using clays and/or lignites to achieve suspension of solids are believed to have linked or interlinked clay and/or lignite particles providing structure. That is, organophilic clays or organo-clays, which are typically formed from montmorillonite treated with a di-alkyl cationic surfactant, swell in non-polar organic solvents, forming open aggregates. This structure, combined with the volume occupied by water droplets, is believed to be the main suspending mechanism for barite and other inorganic materials in conventional invert drilling fluids.
  • the unique "fragile" gel nature or structure of the fluid of the invention contributes to relatively low “ECDs” obtained with the fluid.
  • ECD downhole pressure- while-drilling
  • Low “ECDs” that is, a minimal difference in surface and downhole equivalent circulating densities, is critical in drilling wells where the differences in subterranean formation pore pressures and fracture gradients are small.
  • the unique "fragile" gel structure of the fluid of the invention contributes to an increased drilling rate or rate of penetration when using the fluid of the invention.
  • a high colloidal solids content can impair the rate of penetration and increase the demand for diesel and additives.
  • organophilic clays or other organophilic colloidal solids that are commonly used in diesel-based muds as viscosifiers and gelling agents.
  • the diesel based drilling fluids of the invention respond quickly to the addition of treatment additives such as fluid loss control agents, emulsifiers, thinners, viscosifiers, and other rheology control agents, with treatment response of the fluids occurring soon after the additives are added, at least within one-half trip in the wellbore, and without need for multiple circulations of the fluids with the additives in the wellbore to show the effect of the addition of the additives.
  • treatment additives such as fluid loss control agents, emulsifiers, thinners, viscosifiers, and other rheology control agents
  • Another distinctive and advantageous characteristic or feature of the diesel based drilling fluids of the invention is that sag does not occur or does not significantly occur when the fluids are used in drilling deviated wells. Suspensions of solids in non-vertical columns are known to settle faster than suspensions in vertical ones, due to the "Boycott effect.” This effect is driven by gravity and impeded by fluid rheology, particularly non- Newtonian and time dependent rheology.
  • Sag Manifestation of the Boycott effect in a drilling fluid is known as "sag.”
  • Sag may also be described as a "significant" variation in mud density (> 0.5 to 1 pound per gallon) along the mud column, which is the result of settling of the weighting agent or weight material and other solids in the drilling fluid.
  • Sag can result in formation of a bed of the weighting agent on the low side of the wellbore, and stuck pipe, among other things.
  • sag can be very problematic to the drilling operation and in extreme cases may cause hole abandonment.
  • Field-based fluids may yield varying results in the tests discussed herein because of the presence of other fluids, subterranean formation conditions, etc.
  • the fluids of the invention are tolerant of such clay to some extent.
  • the fluids of the invention behave more like conventional drilling fluids with organophilic clay viscosifiers as the amounts of organophilic clay increase.
  • the exact tolerance of the fluids of the invention to the organophilic clay that is, the exact amount of organophilic clay that can be added or be present in the fluids and still have the fluids of the invention achieve their distinctive, advantageous characteristics of the invention, varies with the density of the fluids and the operating conditions and wellbore characteristics.
  • organo-clay may be present in fluids of the invention in quantities that are not sufficient to destroy or nullify the distinctive, advantageous characteristics of the invention as described herein.
  • the fluids of the invention typically exhibit no adverse response to even substantial influx of water. Fluids of the present invention have been found to easily withstand unplanned water flows that have reduced the OWR (oil to water ratio) to as low as 52/48, without evidence of water-wet solids or water in the HPHT filtrate.
  • OWR oil to water ratio
  • an operator took a 196-bbl salt water kick while drilling with a 16.0 ppg INTEGRADETM drilling fluid system in an onshore Louisiana field.
  • the INTEGRADETM drilling fluid system is an example diesel based invert drilling fluid of the present invention, commercially available from Halliburton Energy Services, Inc. in Houston, Texas.
  • the oil/water ratio dropped from 77/23 to 52/48.
  • the electrical stability went from 640 to 272.
  • Fluids of the present invention typically have higher water content, and less diesel oil, by design than other diesel oil-based muds. See Figure 3, for example, which will be discussed further below.
  • the water phase has high-salinity and the fluids exhibit excellent inhibition, osmotic membrane effect and protection against water wetting.
  • the recorded gel strengths for the fluids of the invention may appear somewhat elevated when compared to other diesel muds, yet the "gels" of the drilling fluids of the present invention are easily “broken,” as shown in Figure l(b) when circulation commences so that ECD and surge pressures are minimized.
  • Fluids of the present invention are suitable for a wide range of drilling applications and have been proven and tested to achieve superior high return permeabilities when used to drill the reservoir (or hydrocarbon producing) section of the well. Fluids of the present invention can be used to drill any well type conventionally drilled with oil-based muds, including without limitation HPHT, casing drilling, zero discharge (onshore, offshore), slim-hole drilling, high-angle or horizontal intervals, and coiled tubing applications.
  • drilling fluids of the present invention provide suspension of weighting agents and/or drill cuttings when stresses or forces associated with drilling are reduced or removed and produce substantially no pressure spike or pressure surge against the subterranean formation upon resumed drilling.
  • the invert emulsion drilling fluids of the present invention have a diesel invert emulsion base, this base is not limited to a single formulation.
  • Test data discussed herein is for example formulations of diesel oil-invert emulsion based drilling fluids of the invention.
  • a drilling fluid comprising a blend of diesel with one or more other natural or synthetic oils could also be used provided the fluid forms fragile gels or yields fragile gel behavior and provides low ECDs.
  • a polyalphaolefin (PAO) which may be branched or unbranched but is preferably linear and preferably ecologically acceptable (non-polluting oil) blended with diesel oil demonstrates some advantages of the invention.
  • isomerized or internal olefins could also be blended with the diesel.
  • Isomerized or internal olefins for blending with the diesel may be any such olefins, straight chain, branched, or cyclic, preferably having about 10 to about 30 carbon atoms. Isomerized, or internal, olefins having about 40 to about 70 weight percent and about 20 to about 50 weight percent C ⁇ $ are especially preferred.
  • An example of an isomerized olefin for use in the blend in the invention that is commercially available is SF BASETM fluid, available from Halliburton Energy Services, Inc. in Houston, Texas.
  • hydrocarbons such as paraffins, mineral oils, glyceride triesters, or combinations thereof may be substituted for or added to the olefins in the diesel blend.
  • Such other hydrocarbons may comprise from about 1 weight percent to about 99 weight percent of such blend.
  • the exact proportions of the components comprising a diesel base (or diesel blend base) for an invert emulsion for use in the present invention will vary depending on drilling requirements (and characteristics needed for the base to meet those requirements), supply and availability of the components, cost of the components, and characteristics of the base necessary to meet environmental regulations or environmental acceptance.
  • the manufacture of the various components of a diesel, or a diesel blend, invert emulsion base is understood by one skilled in the art.
  • the fluids of the invention will require less diesel than other diesel based drilling fluids and the fluids of the invention will show substantially less fluid loss during drilling.
  • the diesel invert emulsion based drilling fluids of the invention or for use in the present invention have added to them or mixed with their diesel invert emulsion base, other fluids or materials needed to comprise complete drilling fluids.
  • Such materials may include, for example: additives for enhancing viscosity, for example, an additive having the tradename RHEMOD LTM suspension agent/viscosif ⁇ er (modified fatty acid comprising dimeric and trimeric fatty acids); additives for filtration control, for example, an additive having the tradename ADAPTA® (methylstyrene/acrylate copolymer particularly suited for providing HPHT filtration control in non-aqueous fluid systems); additives for high temperature high pressure control (HTHP) and emulsion stability, for example, an additive having the tradename FACTANTTM (highly concentrated tall oil derivative); additives for emulsif ⁇ cation, for example, additive having the tradenames LE SUPERMULTM (polyaminated fatty acid) and FORTI-MULTM (
  • the fluids comprise an aqueous solution containing a water activity lowering compound, composition or material, comprising the internal phase of the invert emulsion.
  • a water activity lowering compound, composition or material comprising the internal phase of the invert emulsion.
  • Such solution is preferably a saline solution comprising calcium chloride (typically about 25% to about 30%, depending on the subterranean formation water salinity or activity), although other salts or water activity lowering materials known in the art may alternatively or additionally be used.
  • the fluids of the present invention comprise a minimal number of components.
  • a preferred example diesel invert emulsion based drilling fluid of the present invention comprises only about three products for rheology, filtration and emulsification, as opposed to the five or more additives typically used in most oil-based muds.
  • Such example preferred formulation comprises FORTI-MULTM emulsifier, RHEMODTM L viscosifier and ADAPTATM HPHT filtration control agent and/or FACTANTTM filtration control agent, all available form Halliburton Energy Services, Inc. in Houston, Texas.
  • the fewer materials needed on location the greater the savings in transportation expenses.
  • a system that uses fewer products helps decrease the usage of trucks onshore and the number of crane lifts required for zero-discharge offshore operations. In the case of multi-well applications, the cost savings can be significant.
  • EZ MUL® emulsifier polyaminated fatty acid
  • INVERMUL® emulsifier blend of tall oil and polyaminated fatty acid
  • LE SUPERMULTM emulsifier polyaminated fatty acid
  • DURATONE® HT filtration control agent organophilic leonardite
  • ADAPTA® filtration control agent methylstyrene/acrylate copolymer particularly suited for providing HPHT filtration control in non-aqueous fluid systems
  • RHEMOD LTM suspension agent/viscosif ⁇ er modified fatty acid comprising dimeric and trimeric fatty acids
  • GELTONE® II viscosifier organophilic clay
  • Table 3 (a) provides FANN 75 viscometer data for Sample C of the INVERMUL® diesel fluid from Table 2(a) and Table 3(b) provides FANN 75 rheometer data from Sample F of the example fluid of the present invention from Table 2(b).
  • Emulsif ⁇ er (blend of tall oil and polyaminated fatty acid).
  • Emulsifier polyaminated fatty acid
  • the diesel invert emulsion drilling fluids of the present invention preferably do not have any organophilic clays or organophilic lignites added to them.
  • the fluids of the invention do not need organophilic clays or organophilic lignites to provide their needed viscosity, suspension characteristics, or filtration control to carry drill cuttings to the well surface.
  • the lack of appreciable amounts of organophilic clays and organophilic lignites in the fluids is believed to enhance the tolerance of the fluids to the drill cuttings. That is, the lack of appreciable amounts of organophilic clays and organophilic lignites in the fluids of the invention is believed to enable the fluids to suspend and carry drill cuttings without significant change in the fluids' rheological properties.
  • the present invention provides a drilling fluid with a substantially flat rheological profile.
  • Tables 4, 5, and 6 provide example rheological data for three example drilling fluids of the invention comprising 16.0 pounds per gallon ("ppg" or "lb/gal"), 17.2 lb/gal and 16.0+ lb/gal respectively. These fluids are comprised of substantially the same composition (except for weight) as the example New Diesel Mud of the invention specified in Table 2(b) above.
  • the fluids were tested at their respective known bottom hole temperatures and calculated pressures as used in drilling their respective wells. A midpoint temperature and pressure was also included in the FANN 75 viscometer test sequences.
  • the tables include data for electrical stability (ES), FANN 35 viscometer rheology, and FANN 75 viscometer rheology. As used in Tables 4, 5 and 6, "n" and "K” are Power Law model rheology parameters.
  • Mud weight was measured at 16.0 lb/gal at room temperature and the ES was 639 volts at 150 0 F. TABLE 5
  • Mud weight was measured at 17.2 lb/gal at room temperature and the ES was 1025 volts at 150° F.
  • Mud weight was measured at 16.0+ lb/gal at room temperature and the ES was 762 volts at 150° F.
  • the preferred temperature range for use of a drilling fluid of the present invention extends from about 38° F to at least about 450° F, although the fluid is believed to be useful in drilling wells in subterranean formations having temperatures as hot as 500° F or more.
  • the preferred mud weight for a drilling fluid of the invention extends from about 7 ppg. to about 18.5 ppg.
  • the present invention has been tested in the field and the field data demonstrates the advantageous performance of the fluid compositions of the invention and the methods of using them.
  • the present invention provides a diesel invert emulsion drilling fluid that may be used in drilling boreholes or wellbores in subterranean formations, and in other drilling operations in such formations (such as in casing and cementing wells), requiring substantially less consumption of diesel, when compared to drilling operations using other diesel fluids.
  • an operator drilled a deep slim-hole (4-1/4") re-entry well (62° maximum angle) to 12,416 ft using an example 15.3 ppg fluid of the present invention with zero mud losses in an area where all the offset wells had experienced significant mud losses (average of 1,178 bbl on three offset wells) with diesel fluids having organophilic clay viscosif ⁇ ers. Reducing and controlling the equivalent circulating density (ECD) was considered a critical factor in minimizing or eliminating losses while drilling this deviated slim-hole.
  • ECD equivalent circulating density
  • the formation integrity test at the casing shoe had been 17.1 ppg, but the operator encountered depleted sands at 3,760-ft with formation pressures of 3.0 to 5.0 ppg equivalent mud weight (EMW).
  • drilling fluid loss may be reduced by employing a drilling fluid in drilling operations that is formulated to comprise fragile gels or to exhibit fragile gel behavior.
  • drilling operations shall mean drilling, running casing and/or cementing unless indicated otherwise.
  • Drilling fluids of the present invention may be used in drilling, running casing, cementing, and/or producing hydrocarbons from subterranean formations.
  • Rate of penetration another important indicator of drilling performance, is enhanced by the low colloidal content of the drilling fluids of the present invention, as demonstrated by a field test with four wells selected for comparison based on their similarity. As shown in Figure 4, three of the wells were drilled with a diesel-based fluid having an organophilic clay viscosifier (Wells 1, 2, 3). The fourth well was drilled with an example fluid of the present invention, INTEGRADETM fluid, available from Halliburton Energy Services, Inc. in Houston, Texas (Well 4). Four strings of casing were set on each well.
  • INTEGRADETM fluid available from Halliburton Energy Services, Inc. in Houston, Texas
  • the wells were displaced to oil-based fluid between 6,300 and 7,000 ft and drilled to approximately the same total depth (TD) of ⁇ 12,000 ft.
  • the bottomhole temperature on the four wells ranged from 325° F to 340° F.
  • the 8-3/4" intermediate sections were drilled with mud weights between 10.5 to 11.5 ppg.
  • the 6-1/4" production intervals were drilled with mud weights between 15.2 to 15.7 ppg.
  • the well drilled with the example fluid of the present invention reached TD at 12,225 feet in eight less days than the fastest well drilled with a diesel based fluid having an organophilic clay viscosifier (see Figure 4), while requiring fewer products and diesel additions on a daily basis.
  • the ernulsif ⁇ ers and polymers used with the system of the invention help eliminate the need to add colloidal size solids, such as organophilic clays, that are common in diesel-based muds.
  • colloidal size solids such as organophilic clays
  • a high colloidal solids content can impair rate of penetration and increase the demand for diesel and additives in a diesel-based mud.
  • Figures 7(a) and 7(b) represent in graphical form Brookfield test data indicating gel formation and gel strength in the samples listed in Tables 2(a) and 2(b) respectively.
  • Figure 2 discussed above also represents in graphical form the results of a Brookfield test with an example fluid of the present invention and a diesel fluid that has an organophilic clay viscosifier. When the fluids are at rest or static (as when drilling has stopped in the wellbore), the curves are flat or relatively flat (see area at about 25-55 minutes elapsed time for example).
  • the curves move up straight vertically or generally vertically (see area at about 55 elapsed minutes for example), with the height of the peak value being proportional to the amount of gel formed — the higher the peak the more gel built up.
  • the curves then fall down and level out or begin to level out, with the faster rate at which the horizontal line forms (and the closer the horizontal line approximates true horizontal) indicating the lesser resistance of the fluid to the stress and the lower the pressure required to move the fluid.
  • Figures 2 and 7(b) indicate superior response and performance by the drilling fluids of the present invention. Not only do the fluids of the present invention appear to build up more "gel" when at rest, which enables the fluids of the invention to better maintain weight materials and drill cuttings in suspension when at rest — a time other diesel based fluids are more likely to have difficulty suspending such solid materials — but the fluids of the present invention nevertheless surprisingly provide less resistance to the sheer, which will result in lower ECDs.
  • a Brookfield test as used herein also called a Brookfield viscometer gel strength test procedure, uses a BROOKFIELD DV-II+ Programmable (or nonprogrammable) viscometer to measure the gel strengths of a drilling fluid using a vane spindle.
  • the test allows for a more detailed description of the gel structure and uses lower revolution speeds than a FANN 35A viscometer.
  • the Brookfield viscometer should have an LV Spring with spindle guard off, and if the viscometer is programmable, the GELS-120.D2S test sequence should be installed. If the viscometer is not programmable, the same test sequence should be followed but the data will have to be recorded and graphed manually.
  • V-73 vane spindle modified in length (vane dimensions include a length of 0.468 inches and an outside diameter of 0.499 inches), a thermometer, a FANN Thermo cup, and preferably a computer with I/O port and DataWizard software.
  • the testing procedure is set forth in Table 7.
  • the GELS-120.D2S test sequence is set forth in Table 8. TABLE 7 Brookfield Gel Strength Test Procedure
  • a drilling fluid of the invention may be employed in drilling operations.
  • the drilling operations whether drilling a vertical or directional or horizontal borehole, conducting a sweep, or running casing and cementing — may be conducted as known to those skilled in the art with other drilling fluids. That is, a drilling fluid of the invention is prepared or obtained and circulated through a wellbore as the wellbore is being drilled (or swept or cemented and cased) to facilitate the drilling operation.
  • the drilling fluid removes drill cuttings from the wellbore, cools and lubricates the drill bit, aids in support of the drill pipe and drill bit, and provides a hydrostatic head to maintain the integrity of the wellbore walls and prevent well blowouts.
  • the specific formulation of the drilling fluid in accordance with the present invention is optimized for the particular drilling operation and for the particular subterranean formation characteristics and conditions (such as temperatures).
  • the fluid is weighted as appropriate for the formation pressures and thinned as appropriate for the formation temperatures.
  • the fluids of the invention afford real-time monitoring and rapid adjustment of the fluid to accommodate changes in such subterranean formation conditions.
  • the fluids of the invention may be recycled during a drilling operation such that fluids circulated in a wellbore may be recirculated in the wellbore after returning to the surface for removal of drill cuttings for example.
  • the drilling fluid of the invention may even be selected for use in a drilling operation to reduce loss of drilling mud during the drilling operation and/or to comply with environmental regulations governing drilling operations in a particular subterranean formation.

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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)
  • Lubricants (AREA)

Abstract

L'invention concerne des fluides de forage à émulsion inversée à base de carburant diesel ayant des propriétés de gélification fragiles et des performances améliorées. L'invention concerne également des procédés de forage, de mise en place du tubage, de cimentage et/ou de production d'hydrocarbures dans une formation souterraine.
PCT/US2007/015490 2007-07-05 2007-07-05 Fluides de forage à émulsion inversée à base de carburant diesel et procédé de forage de puits de forage WO2009005503A1 (fr)

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WO2011121278A1 (fr) * 2010-03-27 2011-10-06 Halliburton Energy Services Inc Fluides de forage à émulsion inverse et procédés de forage de puits
WO2013048653A1 (fr) * 2011-09-29 2013-04-04 Chevron Phillips Chemical Company Lp Additifs anti-perte de fluide, leurs procédés de préparation et d'utilisation
WO2013162902A1 (fr) * 2012-04-25 2013-10-31 Isp Investments Inc Combinaison synergique d'un additif de perte de circulation et d'un modificateur de rhéologie
US8575072B2 (en) 2011-09-29 2013-11-05 Chevron Phillips Chemical Company Lp Fluid loss additives and methods of making and using same
CN110041902A (zh) * 2019-05-24 2019-07-23 西南石油大学 一种重晶石加重高密度水基钻井液性能调控方法
US11263691B2 (en) 2010-09-30 2022-03-01 The Western Union Company System and method for secure transactions at a mobile device

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EP1111024A1 (fr) * 1999-12-23 2001-06-27 Rheox, Inc. Fluides de forage du type huile ou émulsion inverse ayant des propriétés de mise en suspension améliorées
WO2002053675A1 (fr) * 2000-12-29 2002-07-11 Halliburton Energy Services, Inc. Diluants pour emulsions inverses
WO2002053676A1 (fr) * 2000-12-29 2002-07-11 Halliburton Energy Services, Inc. Diluants pour emulsions inverses

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Publication number Priority date Publication date Assignee Title
EP1111024A1 (fr) * 1999-12-23 2001-06-27 Rheox, Inc. Fluides de forage du type huile ou émulsion inverse ayant des propriétés de mise en suspension améliorées
WO2002053675A1 (fr) * 2000-12-29 2002-07-11 Halliburton Energy Services, Inc. Diluants pour emulsions inverses
WO2002053676A1 (fr) * 2000-12-29 2002-07-11 Halliburton Energy Services, Inc. Diluants pour emulsions inverses

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2011121278A1 (fr) * 2010-03-27 2011-10-06 Halliburton Energy Services Inc Fluides de forage à émulsion inverse et procédés de forage de puits
EA024120B1 (ru) * 2010-03-27 2016-08-31 Хэллибертон Энерджи Сервисиз Инк. Обратно-эмульсионные буровые растворы и способы бурения скважин
US11263691B2 (en) 2010-09-30 2022-03-01 The Western Union Company System and method for secure transactions at a mobile device
WO2013048653A1 (fr) * 2011-09-29 2013-04-04 Chevron Phillips Chemical Company Lp Additifs anti-perte de fluide, leurs procédés de préparation et d'utilisation
US8575072B2 (en) 2011-09-29 2013-11-05 Chevron Phillips Chemical Company Lp Fluid loss additives and methods of making and using same
US9034800B2 (en) 2011-09-29 2015-05-19 Chevron Phillips Chemical Company Lp Fluid loss additives and methods of making and using same
AU2012316673B2 (en) * 2011-09-29 2015-09-17 Chevron Phillips Chemical Company Lp Fluid loss additives and methods of making and using same
US9598627B2 (en) 2011-09-29 2017-03-21 Chevron Phillips Chemical Company Lp Fluid loss additives and methods of making and using same
WO2013162902A1 (fr) * 2012-04-25 2013-10-31 Isp Investments Inc Combinaison synergique d'un additif de perte de circulation et d'un modificateur de rhéologie
CN110041902A (zh) * 2019-05-24 2019-07-23 西南石油大学 一种重晶石加重高密度水基钻井液性能调控方法

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