Polymer-clay drilling fluid in permafrost and highly colloidal clay rocks

FIELD: oil and gas industry.

SUBSTANCE: polymer-clay drilling fluid in permafrost and highly colloidal clay rocks includes the following, wt %: clay powder - 1.000-3.000, Robus KK biopolymer - 0.300-0.100, Na CMC (carboxymethyl cellulose) - 0.200-0.300, Praestol 2530 - 0.010-0.015, water-repellent fluid "Osnova-GS" - 0.200-0.300, lubricant KSD - 1.000-1.500, water - 97.290-94.785, carbonate weighting material - 37.000-0.000 plus 100, barite weighting material - 14.000-62.000 plus 100.

EFFECT: providing pseudoplastic properties and controlled density of polymer-clay fluid.

1 tbl


The invention relates to the drilling of oil and gas wells, in particular, compositions polymerphysik solutions used in the conditions of permafrost (MMP) and vysokokalorijnyh clay rocks.

The practice of drilling in terms of MSE shows that in these conditions the most widely used polimergranita solutions with a low solids content, as the most cost-effective, their improvement is relevant. Polimergranita solutions with pseudo-plastic properties that can reduce restasurant MMP even if they have a positive temperature.

Known drilling fluid (patent RU 2184756) with pseudo-plastic properties that can reduce restasurant MMP even at positive temperature and containing bentonite bentonite water-soluble polymer Praestol (grades 2510 2515 or, or 2530 or 2540) and water in the following ratio, wt.%:

bentonite bentonite5,000;
Praestol brand 2510, 25150,010-0,050;
brand 2530, 25400,005-0,010;
waterthe rest of it.

The lack of a f the th mud is its mechanical destruction. This effect was observed in the practical use, the drilling fluid is greatly changes its rheological characteristics through several cycles of circulation in the well. In addition, the drilling fluid is not proof, and for some fields in the North of Western Siberia (for example, the Yamal Peninsula) is characterized by the presence of salt MMP.

Also known pseudo-plastic solution (patent RU 2254353) for drilling, MMP, salt-tolerant and resistant to mechanochemically reducing restasurant MMP at positive temperature in the process of drilling wells, including bentonite bentonite water-soluble polymer Praestol brand 2530, polyanionic cellulose high viscosity in the following ratio, wt.%:

bentonite bentonite2,000-4,000;
Praestol brand 25300,020-to 0.060;

This solution does not have any abscopal good, in relation to clay deposits, as well as lubricating properties.

Closest to the claimed solution is primarlily solution (patent RU 2274651) to storm the Oia wells in MMP, consisting of a clay stabilizer in the form of a mixture of polysaccharide reagent and amendment, hydrocarbon antifreeze and water, as polysaccharide reagent it contains biopolymer Acinetobacter Sp., and as the amendment is condensed sulfite-alcohol bard kssb in the following ratio of ingredients, wt.%:

biopolymer Acinetobacter Sp.2,000-4,000;
hydrocarbon antifreeze (urea or glycerol)7,000-19,000;
waterthe rest of it.

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

Although this solution has an improved pseudo-plastic properties, low filter, low speed heat MMP, but the maximum density is 1090 kg/m3(examples 3, 6), and high rheological parameters of a solution does not allow its further increase. It is known that the geotechnical conditions of the Yamal Peninsula (Bovanenkovo, Kharasavey) in the interval MMP complicated gasag dratini deposits, creating in the process hydrocoritsone anomaly ratio to 1.35 /Wellordered and other Chemical characteristics adenomas deposits of the Yamal Peninsula (on the example of the Bovanenkovo oil and gas condensate mestorozhdeniya). - Geology, Geophysics and development of oil and gas fields, No. 5, 2008. - C-33/. To prevent gas shows were observed in these conditions it is necessary that the drilling fluid had a high density (up to 1420 kg/m3).

In addition, the claimed solution is intended only for drilling in the range 0-550 m (conductor), further drilling to the target depth is replacing drilling mud (p.6 description of the patent RU 2274651). A significant disadvantage of this solution is that used in the composition of the biopolymer is a liquid, which creates difficulties during its transportation in remote Northern areas of the drilling operations, which are characterized by the presence of MMP. To reduce the freezing temperature in the composition of the reagent is injected hydrocarbon antifreeze in number from 7 to 19 wt.%, it is very considerably increases the cost of the solution, and the temperature of freezing is reduced up to a maximum of -12°C (examples 1-10 description of the patent RU 2274651), which is clearly insufficient for the conditions of the Far North.

The task consisting in the claimed invention, the retaining abutment is ivoti the borehole walls during drilling MMP, complicated gas hydrate deposits, and rocks, folded vysokokulturnye clayey sediments.

The technical result provided by this invention is the creation polimergranita solution with pseudo-plastic properties and variable density to preserve the stability of the borehole walls in terms of MSE, complicated gas hydrate deposits, and the expansion of its application for drilling hydrate accumulations intervals, folded vysokokulturnye clayey sediments due to the additional provision of a high inhibiting, lubricants and blocking properties, is easy to apply.

The task and the technical result is achieved by the fact that polymerclay solution for drilling in permafrost and vysokokalorijnyh clay rocks, consisting of bentonite, biopolymer and water, as biopolymer includes QC Robes and additionally contains sodium carboxymethyl cellulose, acrylic polymer Praestol 2530, liquid gidrofobiziruyuschey "Basis-TOS", lubricant additive CFC and carbonate and barite in the following ratio, wt.%:

the bentonite1,000-3,000;
biopolymer QC RobusNa CMC0,200-0,300;
Praestol 25300,010-0,015;
liquid waterproofing admixture "basis-GS"0,200-0,300;
lubricant additive CFC1,000-1,500;
carbonate weighting agent37,000-over 0,000 100;
barite14,000-62,000 over 100.

The inventive composition of the drilling fluid is different from the known use of other components in the claimed ratio, i.e. meets the criterion of "novelty".

In the inventive composition polimergranita solution with a low content of solid phase used the synergies reagents polysaccharide nature (QC Robus, Na CMC), which controls the rheological properties, fluid filter, fluid swelling clay phases, as well as stabilizing and redispersible effect acrylic polymer (Praestol 2530), hydrophobic liquid (Base-GS) and lubricant additives CFC. Regulation of the density of the solution is carbonate Ooty is elitesem, which performs the additional function of clogging of the filler with the purpose of prevention of possible acquisitions and doutreligne its the barite weighting agent to obtain a density of more than 1300 kg/m3.

Laboratory experiments on the development of the proposed composition of the drilling fluid is produced using the following materials and reagents: bentonite "PENTACON-basis" with access to 18.7 m3/t on THE 5751-006-70896713-2005 LLC bencoprim" (Stary Oskol), powder biopolymer QC Robes on THE 2458-011-35944370-2007 ZAO NPO "Promservis" (Chuvashia), sodium carboxymethylcellulose, polycell CMC on THE 2231-017-32957739-02 CJSC polycell" (Vladimir), copolymer of acrylamide Praestol 2530 LLC Stockhausen Eurasia "Technology and environment" on THE other 2216-001-40910172-98, hydrophobic liquid Foundation-TOS THAT 2229-002-70896713-2004 (30-60% solution of methylsilicon potassium or sodium) LLC HCG Basis" (commercial structures), complex powder lubricant additives CFC on THE 2458-013-35944370-2008 CJSC NGOs Promservis" (Chuvashia), carbonate weighting agent on the basis of the marble on THE 5716-003-52817785-03 ZAO Specrometry" (Lyubertsy) and barite weighting agent according to GOST 4682-84 CJSC "Barite" (Khakassia).

For experimental verification of the claimed drilling mud in the laboratory were prepared 15 compounds (see table). The technology of their preparation is limited to following the existing. In a glass mixing plant Voronezh poured into 800 ml of water and placed in it the estimated amount of the bentonite. The solution is left for 24 hours at room temperature for hydration and swelling of clay particles, and then stirred for one hour at a speed of 3000 Rev/min the Obtained clay suspension handled the estimated number of polymers with additives and mixed in the mixer at the same speed for 30 minutes, and then processed by weighting and measured its technological parameters of standard devices (at 20°C and after cooling (at +5°C). The parameters of the solution prototype taken from the description of the invention (table, solution 3). Analysis of the results shows that the optimum ratio of components (solutions 1, 2, 3) of the claimed composition of the drilling fluid is pseudo-plastic fluid (n=0,49-0.5), and high values of the rheological parameters (η=22-32; τ0=158-229), which increase when cooled to 1.7 times. This circumstance leads to the reduction of erosive destruction of the walls of the well and reduces the heat transfer between the borehole wall and mud. In the absence of circulation in this solution forms the structure strong enough to hold the suspended sludge, creating minimal destruction of the walls of the borehole. When is oznacevanje flow structure is quickly destroyed and the solution again becomes a low viscosity. Due to the laminar flow regime flow, the solution u of the walls moves with less speed and remains at rest (George Rgra, Gstar. The composition and properties of drilling agents (drilling fluids): Per. s angl. - M.: 1985. - p.á192-193), forming a gel-like wall screen, reducing the heat transfer. This effect is enhanced by cooling the near-wall layer of mud at its contact with the MMP, which has a negative temperature. The inventive solution also has a high lubricating properties (coefficient of stickiness of the mud cake (φTr=0,1-0,17), low filtering (f=5,4-5,0), high any abscopal effect against visokokvalitetnim clay deposits. Tests of inhibitory capacity of the developed solution composition were produced by the tester longitudinal swelling FIT in dynamic mode at a temperature of 80°C on a sample of clay with the release of 2.4 m3/t, mineralogical composition similar to clay hydrate accumulations of deposits of the Northern fields in Western Siberia. The results of the experiment are presented graphically (figure). There is a decrease in the degree of swelling clay in the solution of the proposed structure in comparison with water 4.0-3.5 times in 60-420 minute process that allows us to talk about his good inhibitory and redispersible properties.

Developed compositions of the drilling fluid shall have a density 1310-1420 kg/m 3that allows them to be used for drilling MMP complicated gas hydrate deposits.

The table also presents the experimental data, illustrating the fact of impossibility of achieving technological parameters inherent in the claimed composition, the use of certain ingredients of the formulations (solutions 10-15). This allows you to make a statement about the mutual influence of the individual components in the mixture and their synergistic effect on the clay suspension.

Comparison of the proposed structure with protophyta shows that he is not inferior to the well-known solution in pseudoplasticity has a higher rheological and structural indicators, more easy to apply (biopolymer QC Robus powdered product), more economical, as it has less total consumption of reagents, and can be applied when drilling hydrate accumulations intervals due to the inherent additional lubricating and inhibiting properties. Due to the high density of this solution can also be applied when drilling MMP on the Yamal Peninsula, complicated gas hydrate deposits, which is of particular relevance in connection with the beginning of mass drilling of these deposits.

The compositions of the solutions and their technological parameters
The composition of the solutionTechnological parameters
ρ, kg/m3T withCHC1/10, the AAAF, cm3/30 minK, mmφTrη, MPa·sτ0, the AAApHn
1. The composition of the prototype: clay - 8%; biopolymer - 3%; kssb - 6%; urea - 7%; water - 76% (description) at +4°C1090-16/253,5--22,3886,1-0,46
2. Solution 1 explicit in the act of composition: g/n - 1%; QC Robus - 0,3%; Na CMC - 0,2%; Praestol 2530 - 0,01%; base-GS - 0,2%; CFC - 1,0%; water - 97,29%; carbonate weighting agent is 37% (over 100); barite 14% (over 100) (at 20°C)13106065/755,51,00,1022,00158,09,900,49
3. Solution 2 at +5°C-10286/95---37,00249,0-0,50
4. Solution 2 the claimed composition: g/p - 2%; QC Robus - 0,2%; Na CMC - 0,25%; Praestol 2530 - 0,012%; base-GS - 0,25%; CFC - 1,2%; water - 96,088, carbonate weighting agent is 22% (over 100); barite weighting agent - 32% (over 100) (at 20°C)13506355/77of 5.41,10,1732,00168,08,760,50
5. A solution of 4 at +5°C-13484/90---46,00259,0--
6. A solution of 3 proposed structure: g/p - 3%; QC Robus - 0,1%; Na CMC - 0,3%; Praestol 2530 - 0,015%; base-GS - 0,3%; CFC - 1,5%; water - 94,785%; barite - 62% (above 100) (at 20°C)14208977/895,01,00,1032.50 to229,9being 9.610,49
7. A solution of 6 at +5°C-19395/115---47,00278,0--
8. A solution of 4 proposed structure: g/p - 0,5%; QC Robus - 0,4%; Na CMC - 0,1%; Praestol 2530 - 0,005%; base-GS - 0,1%; CFC - 0,5%; water - 98,395%; carbonate weighting agent - 42% (SVER is 100); barite - 12% (above 100) (at 20°C)137010281/10410,01,50,3016,00162,06,770,40
9. A solution of 8 at +5°C-n/tnot measurable---not measure concentration
not measure concentration
10. A solution of 5 proposed structure: g/p - 4%; QC Robus - 0,05%; Na CMC - 0,35%; Pres tol 2530 - 0,02%; base-GS - 0,35%; CFC - 2%; water - 93,23%; barite - 70% (over 100) (at 20°C)1470n/tnot measurable4,01,50,20not measure concentration
not measure concentration
11. G/p - 3%; water - 98%; barite - 62% (over 100)14203/5>40,05,0>1,06,50125,08,950,78
12. G/p - 3%; QC Robus - 0,1%; water - 96,9%; barite - 62% (over 100)14204048/5313,21,20,508,0053,09,800,50
13. T/p - 3%; Na CMC - 0,3%; water - 96,7%; barite - 62% (over 100)14202214/387,81,00,4523,0036,08,600,82
14. G/p - 3%; Praestol 2530 - 0,015%; water - 96,985%; barite - 62% (over 100)1420193/515,21,50,505,0034,0 9,490,50
15. G/p - 3%; base-GS - 0,3%; water - 96,7%; barite - 62% (over 100)1420160/2414,81,71,004,005,1-0,54
16. G/p - 3%; CFC - 1,5%; water - 95,5%; barite - 62% (over 100)14201934/4313,82,00,306,0033,59,940,55
Note - ρ is the density, T is the viscosity, SNA1/10- static shear stress, f - filter, K is the thickness of the crust, φTrthe friction coefficient, η is the plastic viscosity, τ0- maximum dynamic shear stress, pH - pH, n is the coefficient of nonlinearity.

Polymerclay solution for drilling in permafrost and vysokokalorijnyh clay rocks, including bentonite, biopolymer and water, featuring the the action scene, as the biopolymer contains QC Robus additionally contains sodium carboxymethyl cellulose, acrylic polymer Praestol 2530, liquid gidrofobiziruyuschey "Basis-TOS", lubricant additive CFC and carbonate and barite weighting materials in the following ratio, wt.%:

the bentonite1,000-3,000
biopolymer QC Robus0,300-0,100
Na CMC0,200-0,300
Praestol 25300,010-0,015
liquid waterproofing admixture "Basis-GS"0,200-0,300
lubricant additive CFC1,000-1,500
carbonate weighting agent37,000-over 0,000 100
barite14,000-over 62,000 100


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2 tbl

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1 tbl

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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