WO1983002951A1 - Fluides de forage et leur procede d'utilisation - Google Patents

Fluides de forage et leur procede d'utilisation Download PDF

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Publication number
WO1983002951A1
WO1983002951A1 PCT/GB1983/000051 GB8300051W WO8302951A1 WO 1983002951 A1 WO1983002951 A1 WO 1983002951A1 GB 8300051 W GB8300051 W GB 8300051W WO 8302951 A1 WO8302951 A1 WO 8302951A1
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WO
WIPO (PCT)
Prior art keywords
oil
naphthenic
drilling fluid
oils
cst
Prior art date
Application number
PCT/GB1983/000051
Other languages
English (en)
Inventor
Richard Pawel Jachnik
Original Assignee
Richard Pawel Jachnik
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
Priority claimed from FR8302603A external-priority patent/FR2521584A1/fr
Application filed by Richard Pawel Jachnik filed Critical Richard Pawel Jachnik
Publication of WO1983002951A1 publication Critical patent/WO1983002951A1/fr

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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

Definitions

  • Drilling fluids are used to carry debris, such as drill cuttings, out of a bore hole during the drilling of the hole or during other operations within the hole. Thus the fluids are circulated down the hole and carry the debris up the hole.
  • drilling fluids in the generic sense ' to mean the fluids (sometimes called muds) that are intended to be used during the actual drilling of an oil well or other bore hole as well as the fluids that are intended to be used at other stages, for instance the work over or completion of a well, such other fluids sometimes being known as work over fluids or packer fluids.
  • the debris that is carried from the bore hole by the drilling fluids is separated from the fluid at the head of the hole and the fluid is recycled.
  • the debris may be dumped.
  • the drilling fluids consist of a liquid phase and often contain also a solid phase dispersed in it, for instance a weighting agent such as barytes.
  • the liquid phase may consist of water in which various ' minor additions may be dissolved or dispersed, e.g. various gelling agents and dispersing agents.
  • various gelling agents and dispersing agents e.g. various gelling agents and dispersing agents.
  • the liquid phase may consist of oil or it may be a mixture of oil and water, for instan ⁇ ce an oil-in-water emulsion or a water-in-oil emulsion.
  • Numerous oils have been proposed for use as the oil in the liquid phase of drilling muds. There have been some proposals to use vegetable or other edible oils but mineral oils have generally been consi ⁇ dered as more satisfactory and cost effective. Various mineral oils have been proposed. A typical disclosure is in British Patent Specification No. 1,467,841 in which it is stated that the oil may be diesel oil, crude oil, kerosene or other aliphatic hydrocarbons or mixtures. Another appears in US Patent Specification No.
  • naphthenic oils are, as a class, especially suitable for use as the oil of oil based drill ing fluids intended for carrying debris out of a subsea bore hole, prior to dumping of the debris in the sea whil still contaminated with the oil.
  • Naphthenic oils may be derived rom naphthenic crude and it seems that they can be muc ⁇ less toxic to marine life than diesel oil and US Mentor 28.
  • the naphthenic oil may be obtained by blending two or more oils of which at least one generally is derived from naphthenic crude.
  • a blend may be formed of an oil derived from naphthenic crude and a paraffin oil, provided that the final blended oil can still be classified as a naphth enic oil.
  • the blending oil must not be such as to introduce toxic components, and this is discussed in more detail below.
  • Suitable naphthenic crude for use as the source of some or all of the naphthenic oil is.
  • Kunststoffan crude is a blend of derived from naphthenic crude and a paraffin oil
  • the oil may have been hydrogenated during its production from naphthenic or other crude to convert aromatic compou ds to naphthenes.
  • Naphthenic oils are a well recognised class of oils clearly distinguished from paraffinic oils. They are characterised by the fact that they contain less than about 70% paraffinic (aliphatic) compounds and a substantial amoutit of naphthenic (cycloaliphatic) co - pounds. For instance at least 25% and preferably at least " 35 or 40% of the oil is provided by naphthenic compounds. Best results appear to be provided when the oil contains 30 to 60%, preferably 45 to 60%, naphthenic compounds, but higher amounts (for instance up to 70% or 80%) or lower amounts (for instance 25 to 30 up to 45%) are sometimes suitable.
  • the paraffinic content is preferably not more than 65%, or 70% at the most.
  • the naphthenic oil preferably has a characteri ⁇ sation factor of less than 12.0 and preferably from 11.8 to 11.0 or even down to 10.0.
  • the oil has an aromatic content of less than 5%, preferably less than 4% and most preferably 0.2 to 3.5%.
  • the aromatic content of an oil may be recorded by. various test methods. . Typically it may be determined as the percentage by volume of the oil that is provided by aromatic compounds. It can be mea ⁇ sured by calculating the proportion of carbon atoms in the oil that are present in aromatic compounds, based on the total proportion of carbon atoms in the hydrocar ⁇ bon content of the oil.
  • the contents of naphthenic and paraffinic compounds may be determined in the same manner. Suitable--methods, are ASTM D2140-66 and ASTM D2007.
  • Naphthenic oil derived from suitable naphthenic crude can have a satisfactorily low aromatic content but if the oil is obtained by blending then the oils blended into the naphthenic oil must not be such as to introduce toxic components. In general they should not be such as to increase the aromatic content above the values quoted since it seems that high aromatic contents are often associated with toxicity.
  • Mentor 28 in USA seems to have an aromatic content of above 10%.
  • some low molecular weight aromatic compounds are non-toxic and that the toxicity probably arises from the presence of some or all of the polynuclear aromatic compounds, where poly represents at least 4 ben ⁇ zene rings and generally 5 or more, (especially benzo- pyrene and 1,2,5,6 dibenzanthracene) and some lower molecular weight compounds such as toluene, xylenes, phenanthrenes and possibly also naphthalenes. If these are absent then the total aromatic content can be higher than the 5% mentioned above and may be as high as 10 or even 12%. It is however safest, from the toxicity point of view, to have the aromatic content as low as possible, preferably below 2.5%.
  • the naphthenic oil is preferably substantially colourless and substantially odourless. It must of course comply with safety regulations and in practice this means that it must have a flash point of at least 60°C, preferabl 66°C or more.
  • the oil of the oil base should at 5°C, and generally also at 20°C, have a viscosity less than the viscosity of diesel oil. This is particularly important because of the low ambient temperatures encountered in many offshore drilling operations and the difficulties that follow from funnel and plastic mud. viscosities that may be too high at ambient temperatures unless oils of very low viscosity are used.
  • the viscosity at 5°C is below 15, preferably below 10, for instance 1 to 7 cSt.
  • The. viscosity at 20 C C should be low, generally below 15 and preferably below 10, most preferably below 8. It is normally at least 1 , typically from 3 to 8 and often 4 to 7 cSt.
  • the oil of the oil base generally ha a viscosity at 40°C of below 6 cSt and preferably below 5.5 cSt. This viscosity is often in the range 1 to 5.5, for instance 3 to 5. However there are indica ⁇ tions that best results are obtained with very low value preferably 1.2 to ' 3.8 cSt.
  • the oil preferably has a viscosity at 100°C of from 0.6 - 2:5, generall .0.7 to 1.4 cSt. All
  • viscosity measurements herein are kinematic viscosity values obtained by ASTM 445.1P71.
  • the initial boiling point of the distillation range of the oil used as the oil base is preferably belo 250°C.
  • the A.P.I, gravity value of the oil is generally at least 15 and is normally below 35.
  • naphthenic oils suitable for use in the invention are 60 Solvent Pale and KL55 (also sold as Prospect 5) from J.O. Buchanan of Renfrew, Scotland, POLY-X-HP35 supplied by Burmah-Castrol Company and Clairsol 350 supplied by Carless Solvents of Winney Wick London. Typically analyses of these oils are as follows.
  • Naphthenic content 40% v/v isoparaffin content 20% v/v n-paraffin content 40% v/v
  • oils having similar analys ' is may be used especially other naphthenic solvents , for instance having characteristics similar to Clairsol 350.
  • any of these oils can be used individually or blends can be formed of ws or more of these oils or of one or more of these oils with another oil, for instance a paraffinic oil.
  • a suitable blend is formed of 40 to 90, preferably 60 to 80, parts by volume of a naphthenic oil with a paraffinic oil, provided the blend still has a sufficiently high naphthenic content to be classed as a naphthenic oil.
  • a suitable oil for use in the invention is formulated by blending 70 parts by volume of 60 Solvent Pale oil and 30 parts by volume of Clairsol 350.
  • The.resultant blended naphthenic oil has the following properties. ' Typical Properties
  • a characteristic of the defined oils is that, compared to the toxicity of diesel oil, they are substantially non-toxic if they are dumped in the sea in relatively small quantities, e.g. as contamina ⁇ tion on cuttings that have been separated from drilling fluid. Toxicity can be observed by determining the effect of a selected amount of the oil in sea water on brown shrimps (Grangon crangonQ . Healthy shrimps are maintained in aerated sea water at 15°C in the presence of a selected concentration of the oil and the mortality of the shrimps after varying periods is observed. On this test diesel oil gives high mortality, e.g. above 50% and often 90 to 100% at a concentration of 100 ⁇ l/1 after 24 hours.
  • the oils used in the invention preferably give substantially no mortality (for instance below 10% and preferably below 1%) at 24 hours when present in amounts of 100 ⁇ l/1 and preferably also substantially no mortality when used in amounts of ' 333 ⁇ l/1 for ' 24 hours.
  • the mortality at 96 hours at 100 ⁇ l/1 is also low, generally, being below ' 30% and preferably below 15% and preferably also the mortality at " 333 ⁇ l/1 at 96 hours is in the same range, most preferably below 15%.
  • the toxicity is such that at least 50% of the brown shrimps survive for at least 5 days at oil concentrations of at least ' 333 ⁇ l/1 and-often of at least 1000 ⁇ l/1.
  • the oil base of the drilling fluid may consist of the described mineral oil or it may be a blend of the described mineral oil and water. At least 1% by volume of this blend must be the mineral oil and generally the amount of oil is at least 30% by volume based on water plus oil, with the amount preferably being from 51 to 99%, most preferably 60 to 95% by volume oil, with the balance to 100% by volume being water.
  • the fluid may be a water- in-oil emulsion or an oil-in-water emulsion.
  • the water used for forming the fluid may be fresh water or sea water and may contain dissolved salts such as sodium chloride or calcium chloride, up to saturation concentrations.
  • the fluid may be an oil-in-water emulsion in which the water is a sodium chloride brine.
  • the drilling fluids may contain other additives as is conventional in oil based drilling fluid and these additives may be dissolved or dispersed in the oil. base.
  • these additives may contain one or more emulsifi ers, for instance, polymerised organic acids such as the product sold by the Applicant under the Trade Name Carbo tec L and oil soluble amide polymers that are wetting ag and supplementary emulfieirs, such as the product sold by the applicant under the Trade Name Carbo-Mul.
  • the amount of any emulsifiers is generally from 0.1 to 10% (of the commercial emulsifier) by volume, most preferably 1 to 5% by volume, based on the total, volume of oil and - water, or 1 to 20%, preferably 2 to 5% based on the water.
  • the mud may contain high molecular weight organ ⁇ ic polymers and inorganic bridging agents, such as the mixtures sold by the Applicants under the Trade Name Carbo-Trol. Lime hydrate may be dissolved in the water.
  • the drilling fluids will, in particular, generally contain a large amount of weighting material, such as barite, iron oxide, siderite or calcite.
  • the amount of weighting aid is generally from 100 to 400 grams per 100 cc drilling fluids, for instance 200 to 500 pounds per barrel.
  • gelling agents It is standard practice to adjust the rheologi- cal properties of oil based and other drilling fluids by including gelling agents in them.
  • gelling agents A variety of materials have been proposed as gelling agents.
  • the most widely used gelling agents are bentonites, for instance the material commercially available as DMB (drilling mud bentonite) and the products available as Sedapol 155 or Sedapol 44, or Claytone ' 34 or Claytone 40. They can be used in the invention but better results are obtained by use of an organophilic hectorite.
  • This may be a naturally occurring hectorite or synthetic hectorite, for instance as described in British Patent Specification No. 1054111. If it is a synthetic hectorite it preferably includes exchangeable organic ammonium cations as described in British Patent Specification No * 1121501.
  • the preferred materials may be described as tetraalkylammonium hectorites, as described in British Patent Specification No. 1121501.
  • One to three of the alkyl groups are preferably short chain alkyl groups (e.g. C., o most preferably C-_ 3 , typically methyl) and
  • O PI one to three of the alkyl groups are preferably long chain alkyl groups (e.g. c - j ⁇ _25' typically C, 4-22 , most preferably C 1g ).
  • a preferred material is dimethyldioctadecyl ammonium hectorite, preferably Bentone 38 or Imvitone 1 or Imvitone 2, which are derivatives of naturally occurr ⁇ ing hectorite.
  • the amount of gelling aid is typically from 1 to 10, most preferably 1.25 to 4, grams gelling aid per 100 cc fluid.
  • An alternative way of expressing the amount is as ' 3 to 15, most preferably 5 to 9, pounds gelling aid per barrel drilling fluid.
  • the amount of gelling aid required in the fluids of the invention is greater than the amount required in conventional drilling fluids, for instance being from
  • Example 1 A drilling fluid is prepared containing 212 cc Pale Oil 60 as defined above, 7 cc blown tall oil emulsifier, 5 cc oil soluble amide polymer as secondary emulsifier, 53 cc water containing 25% calcium chloride, 6 g lime hydrate, 7g of a blend of high molecular weight organic polymers and inorganic bridging agents, 358 g barite and 6 g dimethyldioctadecyl ammonium hectorite. Its properties are measured before and after hot rolling at 122°C for 17 hours (H/R) . The results are set out in the following table. ES is electrical stability.
  • a drilling fluid is prepared having the same composition as- above except that the amount of Pale Oil 60 is 149 cc and this is blended with 63 cc Clairsol 350. Very satisfactory downhole and toxicity properties ⁇ are obtained when used in a subsea bore hole followed by filtration of the debris from the fluid and dumping of the debris in sea.
  • Example " 3 A drilling fluid is prepared as in Example 1 except that POLY-X-HP-35 is used in place of the Pale Oil 60. The resultant fluid had particularly good proper ⁇ ties under high downhole temperature conditions.
  • Example 4 A drilling fluid was prepared by blending 235 cc Clairsol 350, 5 cc primary emulsifier, 5cc secondary emulsifier, 9 grams gelling aid, 42 cc calcium chloride brine, 5 grams lime, 15 grams bridging aid and 309 grams barytes.
  • This drilling fluid is a 13 pound per gallon mud having an 85:15 oil:water ratio and an internal phase activity of " 0.75.
  • a drilling fluid is prepared as in Example 2 using a bentonite gelling aid in place of the hectorite.
  • the resultant fluid is less satisfactory when it is allowed to cool to, say, 5°C but still gives useful downhole properties.
  • the oil has an aromatic content of below 15, and preferably below 5 and most preferably below 1% by volume when measured by ASTM 2007 (especially when the oil is a naphthenic solventjor, if it is an insulating oil, when its aromatic content is below 5% when measured by ASTM 2041.
  • the aromatic content may be below 10, preferably belo 6, for instance 0.1 to 5% (compared to about 12% for US Mentor 28 and 18-20% for Diesel).

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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

Une huile naphténique est utilisée comme composante d'huile d'un fluide de forage à base d'huile servant à évacuer d'un trou de forage sous-marin des déblais qui pourront ensuite être déversés dans la mer encore contaminés avec l'huile.
PCT/GB1983/000051 1982-02-18 1983-02-18 Fluides de forage et leur procede d'utilisation WO1983002951A1 (fr)

Applications Claiming Priority (10)

Application Number Priority Date Filing Date Title
GB8204829 1982-02-18
GB8204829 1982-02-18
GB8206410 1982-03-04
GB8206410 1982-03-04
GB8207498 1982-03-15
GB8207498 1982-03-15
GB8216327 1982-06-04
GB8216327 1982-06-04
FR8302603A FR2521584A1 (fr) 1982-02-18 1983-02-17 Fluides de forage et leurs procedes d'utilisation
FR83/02603830217 1983-02-17

Publications (1)

Publication Number Publication Date
WO1983002951A1 true WO1983002951A1 (fr) 1983-09-01

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WO (1) WO1983002951A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5906966A (en) * 1991-06-24 1999-05-25 Exxon Research And Engineering Co. Drilling mud additives and in adding viscosification additives to oil-based drilling muds
EP1481039B1 (fr) 2002-03-06 2017-08-09 ExxonMobil Chemical Patents Inc. Procede de production de liquides hydrocarbones

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2637692A (en) * 1950-10-27 1953-05-05 Union Oil Co Oil-base drilling fluids
US2698833A (en) * 1952-08-25 1955-01-04 Oil Base Drilling fluid composition and method
US3712393A (en) * 1971-01-20 1973-01-23 Atlantic Richfield Co Method of drilling
FR2407252A1 (fr) * 1977-11-01 1979-05-25 Nl Industries Inc Composition a base d'huile et d'argiles organophiles presentant une aptitude amelioree a la dispersion
FR2507616A1 (fr) * 1981-06-10 1982-12-17 Larson Dana Composition de fluide concentre

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2637692A (en) * 1950-10-27 1953-05-05 Union Oil Co Oil-base drilling fluids
US2698833A (en) * 1952-08-25 1955-01-04 Oil Base Drilling fluid composition and method
US3712393A (en) * 1971-01-20 1973-01-23 Atlantic Richfield Co Method of drilling
FR2407252A1 (fr) * 1977-11-01 1979-05-25 Nl Industries Inc Composition a base d'huile et d'argiles organophiles presentant une aptitude amelioree a la dispersion
FR2507616A1 (fr) * 1981-06-10 1982-12-17 Larson Dana Composition de fluide concentre

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5906966A (en) * 1991-06-24 1999-05-25 Exxon Research And Engineering Co. Drilling mud additives and in adding viscosification additives to oil-based drilling muds
EP1481039B1 (fr) 2002-03-06 2017-08-09 ExxonMobil Chemical Patents Inc. Procede de production de liquides hydrocarbones

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