Clay-free drilling fluid for completion of formations of controlled directional and horizontal wells in conditions of abnormally high formation pressures

FIELD: oil and gas industry.

SUBSTANCE: clay-free drilling fluid for completion of formations of controlled directional and horizontal wells in conditions of abnormally high formation pressures involves the following, wt %: potash or sodium formiate 10.0-50.0; Robus KK biopolymer 0.40-0.45; modified KREM amylase 1.0-1.1; water-repellent fluid "Osnova-GS" 0.25-0.30, complex lubricant KSD 1.0-1.5; water 46.65-87.35; marble powder 30-65 plus 100; barite weighting material - up to 65 plus 100.

EFFECT: providing high density of drilling fluid, required carrying-over and retaining capacity, reducing hydraulic resistances at movement, high lubricating and water-repellent properties of drilling fluid for improvement of the operating conditions of rock-destructing tool on working face; simplifying the passage of drilling string and preventing seizures in horizontal well shaft, high inhibiting and colmatation properties, low filtration rate for maintaining the stability of clay rocks forming the walls of the well at maintaining collecting properties of productive formation.

1 tbl, 7 dwg

 

The invention relates to the drilling of oil and gas wells, and in particular to compositions of non-clay biopolymer solutions for the opening of the reservoir by drilling directional and horizontal wells under conditions of abnormally high formation pressures (AHP).

Drilling fluid for drilling directional and horizontal wells should have the following properties:

- pseudo-plastic rheological characteristics to provide the necessary extension and the holding capacity of the drilling fluid and reduction of hydraulic resistance in the movement of drilling mud;

- high lubricating and gidrofobiziruyuschimi properties to improve working conditions in rock cutting tool on the bottom, facilitate the passage of the drill string and prevent sticking in highly deviated and horizontal sections of the wellbore;

- high any abscopal and clogging properties, low infiltration rate of the drilling fluid into the formation, the low surface tension of the filtrate on the border with hydrocarbon liquid to preserve the stability of clay rocks composing the walls of the well, preventing changes porosity and permeability of reservoir properties at the penetration of mud filtrate into the reservoir.

At the same time to prevent or is substantial to reduce the impact of contaminants on the reservoir allows the following actions for modification of drilling muds / Yeolekar. The choice of drilling fluids for drilling wells in the Jurassic deposits Uregolskogo deposits of OAO SN-MNG // Construction wells on land and at sea. - 2007, №3. - C-37/:

the exception in the composition of the solution of penomaterialov and a solid phase;

limit the penetration of the filtrate into the formation by treatment of a solution of polymer materials that increase the viscosity of the filtrate and destructively later without the formation of insoluble deposits;

treatment of aqueous drilling mud surfactants, regulatory neftemashremont and emulsifying ability of the liquid;

- the use of inhibitory effects on clay mineral collector, protection from hydrodynamic destruction;

- giving low values of standard filtration properties;

optimal selection of the particle size distribution of the solid phase to accelerate the formation of a dense low-permeability mud cake on the surface of the collector;

- giving the solution rheological properties of the solution, which should ensure the efficient transport of drilled cuttings to the surface, preventing delay in the trunk and therefore, further increase in repression, as well as preventing effect paravane and pulsation downhole pressure during sve and nails.

Thus, the presence of some common the requirements solutions may allow you to use one type of non-clay solution with variable density drilling directional and horizontal wells and further drilling with AHP.

Currently, the main volume of drilling inclined and horizontal wells is flushing the fluid, in which the regulator pseudo-plastic properties are biopolymer reagents.

Known non-clay drilling mud (SU 1774946 SC 7/02, 1990)containing the following components, wt%:

biopolymer0,5-0,6;
inorganic salt (calcium chloride)14-18;
waterthe rest of it.

A known solution has a high rheological and structural-mechanical properties, low coefficient of pseudoplasticity "n", which provides the solution needed remote and holding capacity while drilling the horizontal section of the wellbore. At the same time, this known solution has low lubricating properties, and also because of the low density does not allow you to open a layer with AHP.

Known process fluid for drilling, completion and repair of oil and gas wells under conditions of abnormally high pressure and elevated temperatures (EN 2215016), including, wt.%:

polysaccharide reagent 0,1-7,0;
salt of formic acid alkali metal (as
the weighting)45,0-83,0;
marble chips2-50;
waterthe rest of it.

Known process fluid is not effective for use as a drilling mud during drilling horizontal sections of boreholes.

Closest to the claimed solution in purpose and technical nature of a salt-tolerant drilling fluid for drilling in productive layers (EN 2277570), including as a weighting agent formate, sodium, polymer, filler - marble powder and water, containing as polymer Fito PK in the following ratio, wt.%:

formate sodium9-44;
the polymer Fito PK3-5;
marble powder0-10;
waterthe rest of it.

A known solution has a high heat resistance, low chemical AGR what Russia to the environment, proof.

Significant disadvantages of the known solution is low pseudoplasticity and low lubricating properties, which makes it efficient to use when drilling directional and horizontal wells. At the same time, the solution has a maximum density of 1420 kg/m3(see table description of the invention), and may not be used at the opening of the reservoir pore pressure prediction, for example in the Jurassic sediments, where necessary density of drilling fluids to 1780 kg/m3.

The challenge in the claimed invention, the effective opening of productive layers with AHP in directional and horizontal drilling.

The technical result provided by this invention is the creation of the drilling fluid high density (up to 1780 kg/m3)that meet the conditions of opening the seams with AHP inclined and horizontal holes with improved pseudoplastic-type rheological characteristics to provide the necessary extension and retention, and reduction of hydraulic resistance at movement, high lubricating and gidrofobiziruyuschimi properties to improve working conditions in rock cutting tool on the bottom, facilitate the passage of the drill string and prevent sticking in the horizontal section SK is Ainy, high any abscopal and clogging properties, low velocity filtering to preserve the stability of clay rocks composing the walls of the well while maintaining the reservoir properties of productive formation by the absence in the composition of penomaterialov.

The task and the technical result is achieved by the fact that non-clay drilling mud for the opening of the reservoir by drilling directional and horizontal wells in abnormal conditions includes a modified starch CREAM, salt of an alkali metal organic acid potash or sodium formate, biopolymer QC Robus, gidrofobiziruyuschey additive Base-GS, integrated lubricant additive CFCs, water, marble powder and barite in the following ratio, wt.%:

salt of an alkali metal organic acid potash or
formate sodiumof 10.0 to 50.0;
Biopolymer QC Robus0,40-0,45;
modified starch KREM1,0-1,1;
water-repelling liquid Foundation-GS0,25-0,30;
to Mleczna lubricant additive CFC 1,0-1,5;
water87,35-46,65;
marble powder30-65 over 100;
bariteup to 65 over 100.

The inventive composition differs from the well-known application of CRAM as modified starch, as well as additional content in the claimed ratio of biopolymer QC Robus, hydrophobic liquid Foundation-GS and integrated lubricant additives CFC, that is, meets the criterion of novelty.

Non-clay drilling mud when the claimed ratio of components is synergistically active composition of reagents, allowing you to have optimal properties for drilling inclined and horizontal trunks. This fact speaks of inventive step of the claimed composition.

In the inventive structure of complex polysaccharides (biopolymer QC Robes and modified starch CRAM) provides increased structural-rheological, pseudoplastic-type properties, low filtering. The high density of the solution and its inhibiting properties are achieved by the presence of salt solution (potassium or sodium formate), integrated lubricant additive COP and silicone fluid Base-GS are additional stabilizers solution (fluid filtering), giving improved lubrication, water and inhibiting properties, marble powder acts as a weight and clogging additives, barite performs the function of doutreligne composition to the density 1780-1800 kg/m3.

For experimental verification of the proposed solution and part of the prototype in the laboratory prepared 11 compositions (see table). The technology of their preparation is as follows: into a glass mixing plant Voronezh poured into 800 ml of water and added to the estimated number of polysaccharides (Kay, CRAM), the solution is stirred until complete dissolution, then enter the estimated amount of salt (potash or sodium formate), the solution is again stirred until dissolution of the latter (15-30 minutes), then the solution is treated the estimated amount of the CFC and "Base-TOS" and mix for 30 minutes. The last step is introduced into a solution of marble powder and barite with a subsequent 30-minute stirring.

Laboratory experiments on the development of the proposed solution composition produced using the following materials and reagents: biopolymer Cap on THE 2458-011-3594-2007, modified starch CRAM on THE 9187-001-35944370-99 (ZAO NPO "Promservis", Chuvashia), integrated lubricating protivopravnoy supplements CFC on THE 2458-03-35944370-2008, potash (K2CO3) according to GOST 1069-73, sodium formate on THE 2432-011-00203803-93 (JSC "Metafrax", Gubakha, Perm region), liquid water-repelling "Basis-TOS" on THE other 2229-002-70896713-2004 (OOO XT "Basis, commercial structures), marble ground on THE other 5716-003-52817785-03 (CJSC "Specrometry", Lyubertsy) and barite weighting agent according to GOST 4682-84 (CJSC "Barite", Khakassia). To prepare the solution of the prototype used sodium formate, marble ground of the above manufacturers, and starch reagent Fito PK TU 10 RF 1039092 (NGOs MP "Saussureae", Moscow). Technological parameters of the solutions were measured on standard devices metrologically certified measurement procedures. The coefficient of friction of steel on steel was evaluated by the tester OFITE lubricity, inhibiting the ability of the solutions was determined by the tester longitudinal swelling OFITE in dynamic mode at a sample of clay with the release of 2.4 m3/t at 80°C. the test Results are presented in figures 1, 2.

Analysis of the obtained results (see table) shows that the optimum ratio of components (solutions 3, 4, 5, 6, 7, 8) the inventive composition of the drilling fluid in contrast to the solution of the prototype has a higher density (up to 1800 kg/m3), high pseudoplasticity (n=0,42-0,55), low stickiness of the mud cake (φFGC=0,1-0,16) and the izkuyu coefficient of friction steel on steel (φ OFI=0,149-0,165).

It is established that the solutions of the proposed structure reduces the swelling properties of the investigated sample up to 6 times for 420 minutes process at 25°C and up to 3.5-4.0 times at 80°C. This confirms the assumption that its high inhibitory ability.

The drilling fluid of the inventive composition is tested at high temperature viscometer OFITE-1000. The dependences of the basic rheological parameters (plastic viscosity, maximum shear stress, the rate of non-linearity, static shear stress) when heated to 130°C, presented in figure 3, 4, 5, 6, 7. The dependences allow to conclude that, while at a temperature of 130°C and there is some reduction of rheological parameters, but they remain at an acceptable level, and the solution improves pseudoplasticity (a measure of nonlinearity is reduced to three or more times). This circumstance allows us to speak about thermal stability of the proposed structure.

14.4V/14,4
Table - Composition and technological parameters of solutions of the prototype and the proposed structure
Technological parameters
The composition of the solutionρ, kg/m3T CHC1/10, the AAAF, cm3/30 minK, mmφFGCη, MPa·sτ0, the AAApHnφTr, OFITE
123456789101112
1. The composition of the prototype: formate sodium - 41%; Fito PK - 3%; marble - 7%; water - 49% (solution 16 description prototype)1380-----52253---
2. The composition of the prototype (prepared in the laboratory): sodium formate - 40%; Fito PK - 4%; marble chips 9%; water - other13801091,00,50,238847,889,200,920,247
3. Solution 1 the claimed composition, wt.%: K2CO3- 10,00; Cap - 0,40; KRAM of 1.00; the Basis-GS - 0,25; CFC - 1,00; water - 87,35; marble - 30,00 (over 100)1220a 38.534/382,81,00,10171079,820,530,165
4. Solution 1 the claimed composition, wt.%: formate sodium - 10,00; Cap - 0,40; KRAM of 1.00; the Basis-GS - 0,25; CFC - 1,00; water - 87,35; marble - 30,00 (over 100)124040,041/502,91,00,1191149,50,53-
5. Solution 2 the claimed composition, wt.%: K2CO3- 50,00; K. the m - 0,45; KRAM - 1,10; Base-GS - 0,30; CFC - 1,50; water - 46,65; marble - 65,00; barite - 65 (over 100)17807738/691,90,50,141816710,040,420,139
6. Solution 2 the claimed composition, wt.%: formate sodium - 50,00; Cap - 0,45; KRAM - 1,10; Base-GS - 0,30; CFC - 1,50; water - 46,65; marble - 65,00; barite - 65 (over 100)18006543/482,01,00,1224129the 10.10,550,143
7. A solution of 3 of the claimed composition, wt.%: K2CO3- 40,00; Cap - 0,43; KRAM - 1,05; Base-GS - 0,37; CFC - 1,2; water - 57,05; marble - 47,00; barite - 46 (over 100)16005624/292,50,90,1622138 10,00,520,152
8. A solution of 3 of the claimed composition, wt.%: formate sodium - 40,00; Cap - 0,43; KRAM - 1,05; Base-GS - 0,37; CFC - 1,2; water - 57,05; marble - 47,00; barite - 46 (over 100)16206031/362,40,70,15211199,900,540,149

123456789101112
9. A solution of 4 of the claimed composition, wt.%: K2CO3- 5; Cap - 0,35; KRAM - 0,9; Base-GS - 0,2; CFC - 0,5; water - 93,05; marble - 26,00 (over 100)12202810/245,01,50,3 1047,9-0,580,310
10. A solution of 4 of the claimed composition, wt.%: formate sodium - 5; Cap - 0,35; KRAM - 0,9; Base-GS - 0,2; CFC - 0,5; water - 93,05; marble - 26,00 (over 100)12403828/385,01,00,351376-0,530,295
11. Solution 5 the claimed composition, wt.%: K2CO3- 60,00; K.K. Robus - 0,5; KRAM - 1,2; Base-GS - 0,4; CFC - 2,0; water - 35,90; marble - 70,00; barite - 70 (over 100)1820n/tnot measurable---not measurablenot measurable---
12. Solution 5 the claimed composition, wt.%: formate sodium - 60,00; Cap - 0,5; KRAM - 1,2; Base-GS - 0,4; CFC - 2,0; water - 35,90; marble - 70,00; barite - 70 (over 100)n/tnot measurable---not measurablenot measurable---

Non-clay drilling mud for the opening of the reservoir by drilling directional and horizontal wells under conditions of abnormally high formation pressures, including modified starch CREAM, salt of an alkali metal organic acid potash or sodium formate, biopolymer QC Robus, gidrofobiziruyuschey additive Base-GS, integrated lubricant additive CFCs, water, marble powder and barite in the following ratio, wt.%:

salt of an alkali metal organic
acid - potash or sodium formateof 10.0 to 50.0
biopolymer QC Robus0,40-0,45
modified starch KREM1,0-1,1
water-repelling liquid Foundation-GS0,25-0,30
integrated lubricant additive CFC1,0-1,5
water46,65-87,35
marble powder30-65 over 100
bariteup to 65 over 100



 

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