Polymer-clay fluid for drilling well in permafrost rock

FIELD: petroleum and gaseous industry.

SUBSTANCE: invention relates to drilling oil and gaseous wells, in particular, to polymer-clay fluids for drilling used under conditions of permafrost rocks. Proposed polymer-clay fluid shows the improved pseudoplastic properties providing enhancing retaining and transporting capacity and treatment degree of the well walls, diminished filtration due to high rate in formation of low-penetrable filtration crust preventing the well pollution and promoting to retention of its collector properties, reduced rate of warming up of permafrost rocks that prevents formation of caverns and destruction of the well walls and as result provides prolonged retention of the well trunk in the stable state. Polymer-clay fluid for wells drilling in permafrost rocks doesn't freeze at negative temperatures and comprises clay, stabilizing agent as a mixture of polysaccharide reagent and structure-forming agent, hydrocarbon antifreeze and water. As a polysaccharide reagent the polymer-clay fluid comprises Acinetobacter sp. biopolymer, and as a structure-forming agent it comprises condensed sulfite-alcohol distillery grains in the following ratio of components, wt.-%: clay, 6-8; condensed sulfite-alcohol distillery grains, 4-6; Acinetobacter sp. biopolymer, 2-4; hydrocarbon antifreeze, 7-19, and water, the balance, wherein the ratio of Acinetobacter sp. biopolymer and condensed sulfite-alcohol distillery grain = 1:(1-3) mas. p., respectively. As hydrocarbon antifreeze, polymer-clay fluid comprises carbamide or glycerol. Invention provides enhancing effectiveness in drilling of wells in permafrost rocks.

EFFECT: improved properties of polymer-clay fluid.

2 cl, 15 ex

 

The invention relates to the drilling of oil and gas wells, in particular to polymerphysik solutions (PHS) for drilling, used in conditions of permafrost.

Analysis of the existing state of the art showed the following:

known drilling fluid for drilling wells in the North, containing the following components, wt%:

The bentonite clay5-6
Carboxymethycellulose-6001-1,2
Sodium acetate16-17
WaterRest

(see A.S. USSR №812823 from 09.04.1979,, CL 09 To 7/02, publ. in ABOUT No. 10, 1981). Sodium acetate is antifreeze.

The disadvantage of this mud is the low efficiency of drilling in permafrost. This is due to the following reasons: drilling fluid characterized by degraded pseudoplastic-type properties, causing reduced holding and carrying capacity, the degree of purification and removal of drilling cuttings from the borehole. This is due to the low structural and rheological properties (static and dynamic shear stress). Drilling mud is characterized by increased filtering the slow formation of filtration the cover, in addition to being a highly permeable. This is due to the lack of content carboxymethycellulose-600 in a solution with a high content of sodium acetate. Is the penetration of the liquid phase and the solid particles of the mud into the formation and, consequently, pollution and the reduction of reservoir properties. The high speed of thawing permafrost in the stalk zone due to component composition, in particular the presence of the higher content of antifreeze, sodium acetate, sufficient to reduce the freezing point of the solution and interacting with ice with the destruction of the latter, and a low content of carboxymethycellulose-600, which can lead to the formation of cavities and integrity of the borehole walls. In turn, the latter does not provide long-term preservation of the wellbore at steady state;

known drilling mud containing the following components, wt%:

Clay28-49
Reagent stabilizer0,3-2,0
The waste product of glycerol in the final stage0,25-3,00
WaterRest

(see A.S. USSR №1640137 from 01.06.1988,, CL 09 To 7/02, publ. ON No. 13, 1991). Use reagent stabilizer in the form with the art of polycyclic sulfite - spirit bards kssb-2 and carboxymethylcellulose.

The disadvantage of this mud is the low efficiency of drilling in permafrost. This is due to the following reasons: the disadvantages of the drilling fluid are its advanced filtering (up to 20 cm3and high-speed thawing permafrost. Despite the high rheological parameters (viscosity and static shear stress), sufficient pseudoplastic-type properties, contributing to holding and carrying capacity, its use is impractical for drilling in permafrost. High values of the filter are associated with a low rate of formation of mud cake and result in the loss of some volume of the solution through the filter into the reservoir, which, in addition to pollution and reduction of reservoir properties, saguday drilling fluid and causes complications when it is pumping. At high initial density of solution (up to 1450 kg/m3in connection with the loss of the liquid phase by filtering its density is further increased, contributing to the growth of dynamic resistance when pumping and difficulties in the operation of the equipment. High density solution activates the process of penetration of leachate pore protrans is in permafrost, increases the area and the depth of its physico-chemical effects on the ice, thus contributing to the weakening of the breed, buckling and fracture of the walls of the borehole. High speed thawing permafrost is also due to the insufficient amount of stabilizer in the composition of the drilling fluid, which reduces the heat transfer coefficient. In addition, the low content of antifreeze, waste production of glycerol in the composition of the drilling fluid does not provide the necessary temperature freezing. The latter leads to cavernosometry and destruction of the walls of the borehole and, consequently, does not provide long-term preservation of the wellbore in the steady state, which indicates the difficulty in the application of this drilling mud for well drilling in permafrost;

there is a method of drilling wells in permafrost using drilling mud containing the following ingredients, wt.%:

The bentonite clay5,5
Reagent-dispersant
(ethylene glycol)5,6
Biopolymer Xanthomonas campestris,
custom made chrome-aluminum-agent0,5
WaterThe OS is real

(see U.S. patent No. 3633689 from 27.05.1970,, CL E 21 In 21/04, publ. 11.01.1972 g).

The disadvantage of this mud is the low efficiency of drilling in permafrost. This is due to the following reasons: despite the low freezing temperature of the drilling fluid is reduced pseudoplastic-type properties. Not high enough pseudoplastic-type properties of the solution due to the low clay content and biopolymer in the composition, which does not allow for the necessary rheological indicators for the implementation of holding and transporting ability of the drilling fluid and a high degree of purification of the well drilling due to the alignment of the velocity profile of fluid flow in the annular space. Increased filtration of the drilling fluid is associated with a low rate of formation of mud cake, which is highly permeable due to insufficient content of the biopolymer, and because of its application in custom made chrome-aluminum cations form, which hinders the diffusion of this component and its adsorption on the walls of the borehole. The high speed of thawing permafrost due to physico-chemical interaction of the applied ethylene glycol with ice, causing the destruction of the latter even when negative temperatureare this results in thawing of the ice, composing the walls of the well, is their destruction with the formation of cavities, which does not ensure the preservation of the wellbore in the steady state. In addition to the disadvantage of the drilling fluid is high cost and enzymatic instability of biopolymer Xanthomonas campestris, requiring the introduction of additional bactericides, which leads to an increase in the cost of preparation of the solution.

This PHS is not listed as the closest analogue of the prototype due to the fact that the patent does not address the parameters of static shear stress and filtering PHS, speed, ice breaking when exposed to ingredients PHS. The test formulation of the analogue in the laboratory of the applicant for comparison with the proposed technical solution without knowledge of the details of the "know-how" is not possible. In this regard, the following assessment of the technological properties of the analogue was carried out according to the description of patent data and expected performance, theoretically sound of the description information about PHS.

as the prototype was taken PHS for drilling in permafrost containing the bentonite stabilizer in the form of a mixture of polysaccharide reagent - carboxymethylcellulose CMC-600 and amendment of sodium carbonate, uglevodorov the hydrated antifreeze and water in the following ratio of ingredients, wt.%:

The bentonite3,0
Carboxymethycellulose-6000,2-0,5
Sodium carbonate0,2
Urea5,0-26,4
WaterRest

(see Wash environment for drilling in frozen rocks and ice. / Vchistyakov, P.g.talalay, Joe, Amicable. General. inform. Ser. Technique, technology and organization of exploration. - M.: ZAO "Geoinformmark", 1999. - V.2. - P.28-29).

The disadvantage of this PHS is the low efficiency of drilling in permafrost. This is due to the following reasons: despite the low temperature freezing the solution is reduced pseudoplastic-type properties. Low pseudoplastic-type properties due to its rheological indicators: low values of plastic viscosity and the dynamic and static shear stress, which does not provide implementations of holding and transporting abilities of the specified solution, cleaning of wells drilling. The quantitative composition and the ratio of ingredients of the solution allows to obtain not somersalo at low temperatures the system, which nevertheless has a high fil the radio (up to 10 cm 3/30 min). Forming a permeable filter crust formed from particles of the dispersed phase, is quite slow because of the low content of bentonite and stabilizer, especially included in its membership policy harinowo reagent - carboxymethycellulose-600, which prevents the infiltration process of the filtrate into the frozen rock and erosion thawed particles with hydrodynamic effects of the circulation flow in the borehole wall. The result is contamination of the reservoir with the filtrate and the solid particles of the dispersed phase is the reduction of reservoir properties and well productivity. High speed thawing of permafrost during circulation PHS used due to the combination of ingredients: urea and sodium carbonate, each of which is antifreeze. The intensity of breaking ice, determining the speed of thawing permafrost, increases significantly in the presence of salt is sodium carbonate, which leads to the weakening of polydisperse permafrost, loss of their stability and cohesion. Experiencing the phenomenon of subsidence, sufoziya, leading to the formation of cavities, the destruction of the walls of the borehole, which does not ensure the preservation of the wellbore in the steady state. In addition, there are tacks tool and casing, with yaetsya yield and quality of the core.

The technical result that can be obtained when implementing the present invention is to improve the efficiency of drilling in permafrost due to the use of not freezing at subzero temperatures, PHS, with:

- improved pseudoplastic-type properties, providing increased holding and transporting abilities and degree of cleaning of the walls of the borehole;

- reduced filtering in the high-speed formation of low-permeability mud cake, preventing pollution of the reservoir and contributing to the preservation of reservoir properties;

- reduced the rate of thawing of the permafrost, which prevents cavernosometry and the destruction of the walls of the borehole and, consequently, ensures lasting wellbore in a stable state.

The technical result is achieved by using known polimergranita solution for drilling in permafrost soils consisting of clay stabilizer in the form of a mixture of polysaccharide reagent and amendment, hydrocarbon antifreeze and water, which as a polysaccharide reagent contains a biopolymer Acinetobacter Sp., and as an amendment - kssb in the following ratio of ingredients, wt.%:

Clay6-8
Kssb4-6
Biopolymer Acinetobacter Sp.2-4
Hydrocarbon antifreeze7-19
WaterRest

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:1-3, respectively. As hydrocarbon antifreeze it contains urea or glycerin.

The inventive composition meets the condition of "novelty."

Clay use first class or second class with consumption 57-97 kg/m3and the output solution of 17.5-10,8 m3/t, kssb - THE 39-094-75, urea - according to GOST 2081-92, glycerin - according to GOST 6259-75.

Use the biopolymer Acinetobacter Sp. in the culture fluid of the microorganism Acinetobacter Sp. called "Simpan" beyond 64-13-127-88 called "Artisan" beyond 9291-001-58114197-2003. Action in their PHS are equivalent.

Biopolymer Acinetobacter Sp. it is a viscous gel-like dispersion system light cream color with low specific smell and pH in the range 5-7, contains on average 1% (but not less than 0.5%) of exogenous macromolecular (5-8 million units) polysaccharide, about 0.25% of the biomass (cell substance producer), as well as monosaccharides, fatty acids, salt grape acid (pyruvate), the balance of salts, the autolysate, formaldehyde and water. The dry weight of the residue is 2%.

Joint prima is giving ingredients helps to ensure a PHS, with the complex physico-chemical and technological properties that enhance the efficiency of drilling in permafrost. This is due to the following processes.

Rheological characteristics of most drilling fluids are significantly different from Bigamously liquids, especially in the lower range of relative velocities of the shift. For performance characteristics of the mud are the most suitable constant power-law flow, for example the index of nonlinearity (pseudoplasticity) n, which characterizes the degree of deviation of the rheological properties of the fluid from Newtonian fluid. For Antonovsky liquids, such as water, oil, glycerin and other, n=1. For pseudoplastic-type liquids 0<n<1 and less than n, the more liquid exhibits a pseudoplastic-type properties. This means that the viscosity of a liquid decreases with increase of relative shear rates and, conversely, the viscosity increases with decreasing relative velocity shift. Reducing the constant n can improve the removal of the rock and cleanout due to alignment (flattening) of the velocity profile of fluid flow in the annular space.

The parabolic velocity distribution in the flow characteristic of Newtonian fluids (n=1), contributes to the education torquing effect of suspended particles drilling and pushes them into areas with lower velocities. The result of this is the recycling of solid particles along the entire liquid flow and, consequently, low cleaning efficiency of the well. Pseudoplastic-type liquid with a value of 0<n<1 has a flatter velocity profile, which reduces the twisting effect, and thus the recycling of the solid phase, and displaces it evenly up the wellbore. Lower values of n provide a flatter velocity profile and contribute to laminarinase flow and stability of the well.

The values of n calculated on the basis of any two of the viscometer readings for two different speeds of revolutions of the rotor by the formula

where R1- reading viscometer with N1rpm;

R2- reading viscometer with N2rpm

(see gray Jr, Darley GSG Composition and properties of drilling agents (drilling fluids): Per. s angl. - M.: Nedra, 1985. - S-193).

The composition of the proposed PHS has low values of the index of nonlinearity n (0<n≤0,5)that, subject to the foregoing demonstrates its high pseudoplastic-type properties. Pseudoplasticity PHS due to the used drilling fluid stabilizer in the form of a mixture of biopolymer Acinetobacter Sp. and kssb.

Microorganisms Acinetobacter Sp. can accumulate in the culture liquid of olished, possessing significant advantages compared with the known biopolymers (xanthan gum, scleroglucan and others). The source of carbohydrate nutrition of microorganisms Acinetobacter Sp. is glucose-ethanol medium, which in contrast to carbohydrate raw materials of plant origin used in the production of xanthan gum, characterized by a stable structure, the absence of impurities, asepsis, low cost, ease of transportation, storage and dosing. Biopolymer synthesized by Acinetobacter Sp., combines structural elements, chemical and rheological properties of xanthan gum and emulsan. On the one hand, this sour branched polysaccharide having the main chain as xanthan gum, on the other hand, in its composition, like emulsan, are the remains of higher fatty acids, resulting from the esterification of which he has a remarkable surface activity. This improves the structural and rheological properties of the claimed PHS, the dispersed phase of which contains hydrated particles of clay minerals with a developed surface.

The large number of reactive functional groups (hydroxyl, carboxyl, acetylenic and others) leads to the possibility of obtaining various modifications of the biopolymer and education based compositions with other chemical compounds.

In FL the th joint application of biopolymer Acinetobacter Sp. with kssb as stabilizer is a major factor contributing to the increase in structural-rheological indicators PHS (plastic viscosity, dynamic shear stress), which has a positive impact on its pseudoplastic-type properties, contributing to retaining and transporting abilities and degree of cleaning of the borehole walls.

The manifestation of these properties is associated with the formation of complex high-molecular compounds - polymer three-dimensional structure of the polysaccharides of the biomass of the culture fluid and low molecular weight fractions of lignosulfonates by the condensing action of polyvalent ions of mineral background residue nutrient medium containing CaCl2KH2PO4, MgSO4, Fe2(SO4)3. At rest the long chain formed of high-molecular compounds randomly oriented (tangled)as between molecules are predominantly repulsive forces of electrostatics. Under stirring PHS chains tend to align parallel to the direction of flow, and this tendency increases with increasing shear rate, resulting in laminar flow regime circulating flow and a stable job well.

The formation of high-molecular compounds branched structure of biopolis the RA Acinetobacter Sp. and kssb promotes better retention of water in suspension PHS and reduce its filtering both by increasing the viscosity of the liquid phase in the resulting gel-like reaction products, and by increasing the speed of formation of low-permeability mud cake from PHS with the participation of urea or glycerol. So, for example, contained in kssb formaldehyde can react condensation with urea with the formation of urea resins, and glycerin as a trivalent alcohol resulting from the esterification reaction with lignosulphonic acids kssb forms polyesters patterns. The content of free water in the PHS decreases and its filtration ability is significantly reduced, which in turn, prevents the pollution of the reservoir and contributes to the preservation of reservoir properties.

During the drilling of permafrost, in which at least part of the moisture is in the solid state, should take measures to prevent their thawing, since the thawing of the ice contained in the breed as a separate turn, can disrupt the stability of the borehole in the form of washouts and landslides with the formation of cavities. To prevent cavernosometry and destruction of the walls of the borehole during drilling and reducing the rate of thawing permafrost MARPs who will win the ingredients, which hydrocarbon antifreeze - antifreeze agents, but different different physico-chemical effects on ice and frozen breed as a whole.

The rate of thawing of the permafrost, which is characterized by the rate of destruction of ice is declining as a result of waterproofing the surface of the biopolymer Acinetobacter Sp. and kssb, at which there is a decrease in the intensity of surface interaction of ice and hydrocarbon antifreeze - urea or glycerol, causing the destruction of ice even at low temperatures. In addition, the decrease in the rate of destruction of ice contributes to higher clay content in the PRTs. Thus there is a decrease in the intensity of heat exchange processes, and hence the speed of melting ice.

For drilling and well wash PHS with high structural and rheological properties (higher values of the static shear stress) stream is only part of the cross section of the annular space, forming the walls of the borehole sedentary zone. This zone protects frozen rocks from mechanical abrasion destruction and prevents the development of erosion processes (destruction) of ice and thawing permafrost.

The achievement of the technical result from the application of the proposed PHS for drilling in megalyn the frozen sediments is determined by its physico-chemical, structural and rheological characteristics, realized thanks ingredient composition and their quantitative ratio, providing high pseudoplastic-type properties PHS, reduced infiltration and the rate of thawing of the permafrost, which together contributes to the efficiency of drilling in permafrost.

Thus, according to the above, the proposed set of essential features and achieve the claimed technical result.

The content in PHS clay in amounts of less than 6 wt.%, Kssb - less than 4 wt.%, biopolymer Acinetobacter Sp. - less than 2 wt.%, and hydrocarbon antifreeze is less than 7 wt.% affects pseudoplastic-type properties (pseudoplasticity n increases), increases the filtering PHS and the rate of thawing, which does not ensure efficient drilling in permafrost.

The content in PHS clay more than 8 wt.%, Kssb - more than 6 wt.%, biopolymer Acinetobacter Sp. - more than 4 wt.%, and hydrocarbon antifreeze - more than 19 wt.% impractical because of the significant improvement of technological properties of PHS does not occur.

The content in the PHS of the stabilizer in the form of a mixture of biopolymer Acinetobacter Sp. and kssb ratio, parts by weight: biopolymer Acinetobacter Sp. and kssb less than 1:1, respectively, increases infiltration and reduces pseudoplastic-type properties PHS (show the eh of pseudoplasticity n increases), which leads to formation damage, deterioration remote ability PHS and cleaning wells drilling.

The content in the PHS of the stabilizer in the form of a mixture of biopolymer Acinetobacter Sp. and kssb with a ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb more than 1:3, respectively impractical because of the significant improvement of technological properties of PHS does not occur.

Analysis of inventive step were as follows:

it is known that powdered biopolymer product "Artisan" is a thickener drilling fluids (see Biostability biopolymer solutions in the presence of bactericides / Omirbaev, UNISA, Ejoymulauw, Washitaw // Restore the productivity of oil and gas wells: scientific transactions. - VIP. - Krasnodar, NPO Burenie, p.72);

know the use of biopolymer Acinetobacter Sp. - "Simpan":

in the composition for enhanced oil recovery reservoir to increase the effectiveness of the composition in the facilitation of the preparation and reduce toxicity (see RF patent №2055982 from 20.08.1990,, CL E 21 In 43/22, publ. in ABOUT No. 7, 1996);

in the composition for oil recovery to increase the efficiency of extraction of oil from water layers at the late stage of development (see RF patent №2122631 from 03.10.1996,, CL E 21 In 43/22, publ. in No. 33, 1998);

in the way of the oil field development with the aim above the Oia, the efficiency of the method by reducing permeability flushed zones of the reservoir, improved detergent properties and enhanced oil recovery (see RF patent №2136869 from 21.07.1998,, CL E 21 In 43/22, With 12 N 1/26, publ. in No. 25, 1999);

in the composition for water flooding of the oil reservoir to increase the effectiveness of the composition for oil displacement by improving its viscosity properties (see RF patent №2140530 from 05.05.1998,, CL E 21 In 43/22, 12 P 19/04, publ. in No. 30, 1999);

in the way of development of an oil field to increase the efficiency of the method for improving the rheological properties of the polymer in saline water and the formation of the microemulsion on the border of the oil - solution (see RF patent №2132941 from 02.09.1997,, CL E 21 In 43/22, publ. in ABOUT No. 19,1999,);

in the way that the displacement of residual oil from flooded oil reservoir to increase the efficiency of the method of the oil field development under conditions of nonuniform permeability layers at the late stage of their development through redistribution of filtration flows, optimization of the process of gelation, process improvement flooding through the use of products of microbial synthesis (see RF patent №2156354 from 02.03.2000,, CL E 21 In 43/22, 12 P 19/04, publ. in No. 26, 2000);

in the way of development of oil-water deposits with the aim of increasing the efficiency of oil recovery of layers, reduce the water content and reduce the cost of oil production at the expense of saving Energostroy reduction of metal equipment of oil production (see RF patent №2190092 from the 27.03.2001,, CL E 21 In 43/22, publ. in No. 27, 2002);

in the method of isolating the flow of formation waters in order to improve the efficiency of the method by increasing the size of the insulating screen (see A.S. SSSS No. 1726732 from 08.08.1989,, CL E 21 In 33/138, publ. in ABOUT No. 14, 1992).

Not detected for existing sources known technical solutions, which have characteristics that match with the distinctive features of the present invention according to the claimed technical result.

Declare PHS meets the condition of "inventive step".

In more detail the essence of the invention is described in the following examples.

Example (commercial).

Vertical well Yamburg oil and gas condensate field is constructed for the purpose of exploitation Cenomanian sediments. Used drilling rig Uralmash 3D-76 with typical cleaning system of the mud.

The source data

For drilling wells Yamburg oil and gas condensate field for conductors with a diameter of 324 mm, the descent to a depth of 550 m in terms of the MSE of the proposed PHS of 100 m3(65 m3+35 m3)defined by the formula

VPHS=VSLE+VCA,

where VSLE- volume wells minus the volume of the metal drill pipe, m3;

VCA- the volume of the circulating system, m3prepare to 10 m per cycle and is pumped in pump-accumulator block.

For preparation of 10 m3PRTs in the following ratio of ingredients, wt.%:

The conductor324 mm
The depth of the down conductor550 m
Production column219 mm
The bottom of the production string1400 m
Lifting height cement
for the conductor and the production columnTo mouth
The bentonite6
Kssb4
Biopolymer Acinetobacter Sp.2
Antifreeze-urea15
Water73

with a ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb 1:2, respectively, in the clay mixer G2-10, filled with water 7,87 m (73 wt.%) consistently give the estimated number of biopolymer Acinetobacter Sp. (204 l "Artisana" density 1060 kg/m3(2 wt.%) and 431 kg kssb (4 wt%), stirred for 1 h for the interaction between the ingredients and form a homogeneous solution. Then add 647 kg clay (6%), stirred for 2 h and left to swell for 1 day. After this time enter 1617 kg is glevodorodnogo antifreeze - urea (15 wt.%) and stirred suspension until smooth. PHS, ready to use, is pumped in pump-accumulator unit. Thus prepared, the entire amount of PHS for drilling below the conductor.

PHS has the following technological features: ρ=1078 kg/m3F30=5 cm3that η=14,22 MPa·, τ0=111,9 DPA, θ1/10=22/41 DPA, n=0,39,R.L.=5,12 g/h, TC=-9°C.

Drilling below the conductor in the area of MLM carry out rotary method using BHA: bit diameter 393,7 mm + UTL 203 length 50 m + drill pipe TBPC-h rest. Drilling lead with a mechanical speed of 18 m/h output capacity mud pump UNB - 600, equal 0,045 m3/with that given the structural and rheological parameters PHS provides laminar mode currents in the annular space of the well.

In the drilling process must be capable of cleaning PHS drilling. For these purposes, it is advisable to use shakers, and not hydrocyclones (sand and hydrocyclone GZ), which is formed by the interaction between the biopolymer and kssb structure of the Navy may break down, which inevitably will lead to lower pseudoplastic-type properties PHS (increasing values), and hence reduced its holding and transporting abilities, as well as the improving the filtering. When drilling parameters PHS supported at the level regulated by the introduction of additional quantities of cultural liquid biopolymer and kssb as necessary.

Upon completion of the drilling interval 0-550 m for the conductor using the PHS perform cementing of the conductor.

Further drilling below the production casing to the design depth is carried out on the mud with the recipe provided by the project for the construction of the well.

The use of PRTs in drilling wells in terms of MSE with a stable structural-rheological, pseudoplastic-type and filtration properties prevents complications associated with impaired stability of the wellbore.

Example 1 (lab)

To prepare 1000 g in 660 ml (66 wt.%) water under stirring enter 38 ml of biopolymer Acinetobacter Sp. mark Artisan" (ρ=1060 kg/m3), that is (4 wt.%) and 40 g (4 wt.%) Kssb. The ratio of parts by weight of the biopolymer Acinetobacter Sp. mark Artisan" and kssb 1:1, respectively. After stirring for 0.5 h add 70 g (7 wt.%) clay is stirred for further 0.5 h leave on such for swelling clay. After 1 day enter 190 g (19 wt.%) urea and mixed in a mixer until it is fully dissolved and a homogeneous PHS.

During the drilling of frozen soils with high ice is STU use PHS, chilled to the desired negative temperature. At this rate of destruction of ice is minimal, since there is almost complete termination of defrost.

When drilling malolactic permafrost at positive temperature circulation PHS (for example, at a temperature of 3-6° (C) is the physical-mechanical and thermal erosion of permafrost, accompanied by the melting of ice at a certain speed.

With this in mind, as the most hard for destruction ice is taken positive temperature exposure to PHS with an average temperature of 4°in which are defined the main technological properties PHS.

The determination of the rheological indicators PHS produced rebeccasommer "Fann". The rate of destruction of ice in the PHS was determined by loss of mass per unit time.

PHS has the following properties: density ρ=1112 kg/m3filtering for 30 min f30=6.0 cm3the plastic viscosity η=18,96 MPa·C dynamic shear stress τ0=126,3 DPA, static shear stress for 1 and 10 min θ1/10=22/35 DPA, the rate of pseudoplasticity n=0,19, the rate of destruction of ice WithR.L.=5,67 g/h, the freezing temperature TC=-12°C.

Example 2

Prepare 1000 g PHS, g/ wt.%:

Clay 60/6
Biopolymer Acinetobacter Sp.-20/ 2 (use 19 ml
"Artisan"ρ=1060 kg/m3)
Kssb40/4
Urea150/15
Water730/73

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1078 kg/m3F30=5.0 cm3that η=14,22 MPa·, τ0=111,9 DPA, θ1/10=22/41 DPA, n=0,39,R.L.=5,12 g/h, TC=-9°C.

Example 3

Prepare 1000 g PHS, g/ wt.%:

Clay

Biopolymer Acinetobacter Sp.-
80/8
"Simpan"30/3 (use 28 ml
ρ=1080 kg/m3)
Kssb60/6
Urea70/7
Water760/76

moreover, the ratio of wt. including biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1090 kg/m, f30=3.5 cm, η=22,38 MPa·, τ0=86,1 DPA, θ1/10=16/25 DPA, n=0,46,R.L.=4,27 g/h, TC=- 5°C.

Example 4

Prepare 1000 g PHS, g/ wt.%:

Clay60/6
Biopolymer Acinetobacter Sp.-
"Simpan"25/2,5 (using 23 ml
p=1080 kg/m3)
Kssb50/5
Urea100/10
Water765/76,5

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1072 kg/m, f30=4.5 cm3that η=14,22 MPa·, τ0=94,7 DPA, θ1/10=28/41 DPA, n=0,36,R.L.=4.83 g/h, TC=-7°C.

Example 5

Prepare 1000 g PHS, g/ wt.%:

Clay

Biopolymer Acinetobacter Sp.-
70/7
"Artisan"20/2 (use 19 ml
ρ=1060 kg/m3
Kssb60/6
Urea120/12
Water730/73,

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:3, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1084 to the/m 3F30=6.0 cm3that η=15,80 MPa·, τ0=77,5 DPA, θ1/10=22/32 DPA, n=0,41,R.L.=4,87 g/h, TC=-9°C.

Example 6

Prepare 1000 g PHS, wt.%:

Clay70/7
Biopolymer Acinetobacter Sp.-
"Artisan"40/4 (used 38 ml
ρ=1060 kg/m3)
Kssb40/4
Glycerin190/19 (use 148 ml
ρ=1280 kg/m3)
Water660/66

moreover, the ratio of wt. including biopolymer Acinetobacter Sp. and kssb is 1:1, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1090 kg/m3F30=3.5 cm3that η=14,70 MPa·, τ0=43,1 DPA, θ1/10=44/54 DPA, n=0,46,R.L.=6,64 g/h, TC=-7°C.

Example 7

Prepare 1000 g PHS, g/ wt.%:

Clay60/6
Biopolymer Acinetobacter Sp.-"Artisan"20/2(use 19 ml
ρ=1060 kg/m3)
Kssb
Glycerin150/15(use 117 ml
ρ=1280 kg/m3)
Water730/73

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1084 kg/m3F30=5.5 cm3that η=14,22 MPa·, τ0=66,0 DPA, θ1/10=28/44 DPA, n=0,36,R.L.=6,02 g/h, TC=5°C.

Example 8

Prepare 1000 g PHS, g/ wt.%:
Clay80/8
Biopolymer Acinetobacter Sp.-
"Simpan"30/3 (use 28 ml
ρ=1080 kg/m3)
Kssb60/6
Glycerin70/7 (using 55 ml
ρ=1280 kg/m3)
Water760/76

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1066 kg/m3F30=4.5 cm3that η=12,64 MPa· C τ0=31,6 DPA, θ1/10=19/28 DPA, n=0,38,R.L.=3,98 g/h, TC=-3°C.

Example 9

Prepare 1000 g PHS, g/ wt.%:

Clay60/6
Biopolymer Acinetobacter Sp.-25/2,5(using 23 ml
"Simpan"ρ=1080 kg/m3)
Kssb50/5
Glycerin100/10(use 78 ml
ρ=1280 kg/m3)
Water765/76,5,

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:2, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1076 kg/m, f30=3.5 cm3that η=14,22 MPa·, τ0=57.4 DPA, θ1/10=35/57 DPA, n=0,47,R.L.=5,11 g/h, TC=-4°C.

Example 10

Prepare 1000 g PHS, g/ wt.%:

Clay70/7
Biopolymer Acinetobacter Sp.-
"Artisan"20/2(use 19 ml
ρ=1060 kg/m3)
Kssb60/6
Glycerin120/12(use 94 ml
ρ=1280 kg/m3)
Water730/73

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:3, respectively. Conduct all operations as in example 1.

PHS has the following properties: ρ=1078 kg/m3F30=4.5 cm3that η=12,64 MPa·, τ0=54,3 DPA, θ1/10=32/47 DPA, n=0,37,R.L.=lower than the 5.37 g/h, TC=-5°C.

Thus the proposed solution meets the condition of "novelty, inventive step, industrial applicability", that is patentable.

1. Polymerclay solution for drilling in permafrost soils consisting of clay stabilizer in the form of a mixture of polysaccharide reagent and amendment, hydrocarbon antifreeze and water, characterized in that it as a polysaccharide reagent contains a biopolymer Acinetobacter Sp., and as the amendment is condensed sulfite-alcohol bard kssb in the following ratio of ingredients, wt.%:

Clay 6-8
Kssb4-6
Biopolymer Acinetobacter Sp.2-4
Hydrocarbon antifreeze7-19
WaterRest

moreover, the ratio of parts by weight of the biopolymer Acinetobacter Sp. and kssb is 1:1-3, respectively.

2. Polymerclay solution according to claim 1, characterized in that the hydrocarbon antifreeze it contains urea or glycerin.



 

Same patents:

FIELD: petroleum-gas-extracting industry.

SUBSTANCE: invention relates to materials used for cementing oil, gaseous, gas-condensate and geothermal holes under conditions of saline and hydrogen sulfide media. The salt-saturated plugging composition for high-temperature holes comprising a binding agent and sodium chloride includes additionally swollen vermiculite sand of fraction 0.3-2.5 mm in the following ratio of components, wt.-%: binding agent, 85-90; sodium chloride, 8-10; swollen vermiculite sand of fraction 0.3-2.5 mm, the balance. Invention provides preparing impermeable cement stone with enhanced coupling strength with a column in the range of temperatures 50-110°C.

EFFECT: improved properties of composition.

1 tbl

FIELD: oil and gas production.

SUBSTANCE: invention provides water-based solid phase-free biocationic drilling fluid with density 10-70-1520 kg/m3. Drilling fluid contains 10-60% of a cation spectrum, namely calcium and sodium chlorides, and 0.1-2% of polymer additive, in particular xanthane series biopolymer.

EFFECT: improved wall-plastering and lubrication properties.

2 tbl

FIELD: lubricants and boring engineering.

SUBSTANCE: multiple-purpose reagent containing lubrication-and-stabilization component (70-80%) and solvent (20-30%) contains, as said lubrication-and-stabilization component, oxidized mixture of paraffins, naphthenic and aromatic hydrocarbons at ratio 2:3:4, and, as said solvent, diesel fuel or kerosene.

EFFECT: improved lubrication properties of viscous-plastic drilling fluids and stabilized inverted emulsions used in boring operation and in pullout of hole.

2 cl, 2 tbl, 6 ex

FIELD: lubricants and boring engineering.

SUBSTANCE: multiple-purpose reagent containing lubrication-and-stabilization component (70-80%) and solvent (20-30%) contains, as said lubrication-and-stabilization component, oxidized mixture of paraffins, naphthenic and aromatic hydrocarbons at ratio 2:3:4, and, as said solvent, diesel fuel or kerosene.

EFFECT: improved lubrication properties of viscous-plastic drilling fluids and stabilized inverted emulsions used in boring operation and in pullout of hole.

2 cl, 2 tbl, 6 ex

FIELD: oil and gas production.

SUBSTANCE: invention relates to oil production technology involving use of hydrochloric acid-based chemicals via complex hydrochloric acid effect on well bottom zone to intensify oil production and may be specifically used to increase oil recovery of viscous oil-saturated low-permeable carbonate reservoirs. Composition contains 22-28% of 20 vol % aqueous HCl solution, 7-8% of 98% aqueous acetic acid solution, and 65-70% of solvent based on light pyrolysis tar obtained as secondary product from petroleum processing enterprises.

EFFECT: increased well bottom zone treatment efficiency due to improved quality of treatment composition, in particular stability and dipping depth into formation.

4 tbl

FIELD: oil and gas production.

SUBSTANCE: invention relates to drilling fluids used when boring oil and gas wells. Lubricating additive contains 10-30% tall oil, 15-20% polyglycols, 40-50% oxal flotation reagent, and 15-20% beet molasses.

EFFECT: increased stabilizing, lubricating, and antiwear properties of drilling fluid.

2 tbl, 2 ex

Drilling mud // 2268909

FIELD: drilling wells; water-base drilling muds.

SUBSTANCE: drilling mud contains the following components, mass-%: clay, 1.5-3.0; carboxymethyl cellulose, 0.1-0.3;carboxymethyl starch, 0.75-1.5; mixture of ethers and amides of fatty acids and ethanol amides, 0.75-1.0; product of rectification of propylene oligomers of isoolefin type, fraction C13-C15, 0.75-1.5;lubricating additive, 0.5-3.0; the remainder being water.

EFFECT: enhanced inhibition ability of drilling mud at improved technological parameters.

2 tbl, 3 ex

FIELD: production and exploratory well drilling, particularly foaming drilling fluids used during penetration through incompetent rock intervals and during primary productive oil and gas deposit opening in the case of abnormally low formation pressure.

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EFFECT: reduced power inputs for well drilling, as well as reduced coefficient of friction between drilling tool and well wall.

1 tbl

FIELD: production and exploratory well drilling, particularly foaming drilling fluids used during penetration through incompetent rock intervals and during primary productive oil and gas deposit opening in the case of abnormally low formation pressure.

SUBSTANCE: foam composition comprises surfactant, foam stabilizer, water, water hardness control additive and lubricant. The water hardness control additive is sodium silicate. The lubricant is VNIINP-117 emulsion. The foam stabilizer is polyacrylamide, the surfactant is sulphonole. All above components are taken in the following amounts (% by weight): sulphonole - 0.8-1.5, sodium silicate - 0.2-0.5, polyacrylamide - 0.1-0.5, VNIINP-117 - 0.5-2, remainder is water.

EFFECT: reduced power inputs for well drilling, as well as reduced coefficient of friction between drilling tool and well wall.

1 tbl

Drilling mud // 2268909

FIELD: drilling wells; water-base drilling muds.

SUBSTANCE: drilling mud contains the following components, mass-%: clay, 1.5-3.0; carboxymethyl cellulose, 0.1-0.3;carboxymethyl starch, 0.75-1.5; mixture of ethers and amides of fatty acids and ethanol amides, 0.75-1.0; product of rectification of propylene oligomers of isoolefin type, fraction C13-C15, 0.75-1.5;lubricating additive, 0.5-3.0; the remainder being water.

EFFECT: enhanced inhibition ability of drilling mud at improved technological parameters.

2 tbl, 3 ex

FIELD: oil and gas production.

SUBSTANCE: invention relates to drilling fluids used when boring oil and gas wells. Lubricating additive contains 10-30% tall oil, 15-20% polyglycols, 40-50% oxal flotation reagent, and 15-20% beet molasses.

EFFECT: increased stabilizing, lubricating, and antiwear properties of drilling fluid.

2 tbl, 2 ex

FIELD: oil and gas production.

SUBSTANCE: invention relates to oil production technology involving use of hydrochloric acid-based chemicals via complex hydrochloric acid effect on well bottom zone to intensify oil production and may be specifically used to increase oil recovery of viscous oil-saturated low-permeable carbonate reservoirs. Composition contains 22-28% of 20 vol % aqueous HCl solution, 7-8% of 98% aqueous acetic acid solution, and 65-70% of solvent based on light pyrolysis tar obtained as secondary product from petroleum processing enterprises.

EFFECT: increased well bottom zone treatment efficiency due to improved quality of treatment composition, in particular stability and dipping depth into formation.

4 tbl

FIELD: lubricants and boring engineering.

SUBSTANCE: multiple-purpose reagent containing lubrication-and-stabilization component (70-80%) and solvent (20-30%) contains, as said lubrication-and-stabilization component, oxidized mixture of paraffins, naphthenic and aromatic hydrocarbons at ratio 2:3:4, and, as said solvent, diesel fuel or kerosene.

EFFECT: improved lubrication properties of viscous-plastic drilling fluids and stabilized inverted emulsions used in boring operation and in pullout of hole.

2 cl, 2 tbl, 6 ex

FIELD: lubricants and boring engineering.

SUBSTANCE: multiple-purpose reagent containing lubrication-and-stabilization component (70-80%) and solvent (20-30%) contains, as said lubrication-and-stabilization component, oxidized mixture of paraffins, naphthenic and aromatic hydrocarbons at ratio 2:3:4, and, as said solvent, diesel fuel or kerosene.

EFFECT: improved lubrication properties of viscous-plastic drilling fluids and stabilized inverted emulsions used in boring operation and in pullout of hole.

2 cl, 2 tbl, 6 ex

FIELD: oil and gas production.

SUBSTANCE: invention provides water-based solid phase-free biocationic drilling fluid with density 10-70-1520 kg/m3. Drilling fluid contains 10-60% of a cation spectrum, namely calcium and sodium chlorides, and 0.1-2% of polymer additive, in particular xanthane series biopolymer.

EFFECT: improved wall-plastering and lubrication properties.

2 tbl

FIELD: petroleum-gas-extracting industry.

SUBSTANCE: invention relates to materials used for cementing oil, gaseous, gas-condensate and geothermal holes under conditions of saline and hydrogen sulfide media. The salt-saturated plugging composition for high-temperature holes comprising a binding agent and sodium chloride includes additionally swollen vermiculite sand of fraction 0.3-2.5 mm in the following ratio of components, wt.-%: binding agent, 85-90; sodium chloride, 8-10; swollen vermiculite sand of fraction 0.3-2.5 mm, the balance. Invention provides preparing impermeable cement stone with enhanced coupling strength with a column in the range of temperatures 50-110°C.

EFFECT: improved properties of composition.

1 tbl

FIELD: petroleum and gaseous industry.

SUBSTANCE: invention relates to drilling oil and gaseous wells, in particular, to polymer-clay fluids for drilling used under conditions of permafrost rocks. Proposed polymer-clay fluid shows the improved pseudoplastic properties providing enhancing retaining and transporting capacity and treatment degree of the well walls, diminished filtration due to high rate in formation of low-penetrable filtration crust preventing the well pollution and promoting to retention of its collector properties, reduced rate of warming up of permafrost rocks that prevents formation of caverns and destruction of the well walls and as result provides prolonged retention of the well trunk in the stable state. Polymer-clay fluid for wells drilling in permafrost rocks doesn't freeze at negative temperatures and comprises clay, stabilizing agent as a mixture of polysaccharide reagent and structure-forming agent, hydrocarbon antifreeze and water. As a polysaccharide reagent the polymer-clay fluid comprises Acinetobacter sp. biopolymer, and as a structure-forming agent it comprises condensed sulfite-alcohol distillery grains in the following ratio of components, wt.-%: clay, 6-8; condensed sulfite-alcohol distillery grains, 4-6; Acinetobacter sp. biopolymer, 2-4; hydrocarbon antifreeze, 7-19, and water, the balance, wherein the ratio of Acinetobacter sp. biopolymer and condensed sulfite-alcohol distillery grain = 1:(1-3) mas. p., respectively. As hydrocarbon antifreeze, polymer-clay fluid comprises carbamide or glycerol. Invention provides enhancing effectiveness in drilling of wells in permafrost rocks.

EFFECT: improved properties of polymer-clay fluid.

2 cl, 15 ex

FIELD: oil and gas industry, particularly flowing well killing for underground repair and overhaul performing.

SUBSTANCE: method involves blocking perforation interval and part of well bottom zone by replacing well fluid with blocking fluid and killing liquid arranged over the blocking one. Free gas is removed from well before blocking fluid delivery to well bottom. Necessary liquid level at well head is provided by well operation stoppage for a certain time, which provides termination of formation fluid degassing in well bore and free gas lifting to well head. Tube space and hole annuity is filled with liquid in several steps along with discharge of gas portions. Gas portion discharge may not result in formation fluid rise inside well bore to level of formation fluid degassing. Density of liquid to be added in tube space and hole annuity provides well filling to head thereof. Well killing liquid comprises industrial magnesium chloride, alkali or alkaline-earth metal hydrate, alkali metal carbonate and pore sealant, for instance cacao-bean pods and fresh water taken in predetermined ratio.

EFFECT: increased efficiency, possibility to kill wells characterized by abnormally high permeability of production bed and high gas factor.

2 cl, 1 ex

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