US20090236095A1

US20090236095A1 - Method of cementing gas or oil pipeline and hydraulic cement slurry

Info

Publication number: US20090236095A1
Application number: US12/441,249
Authority: US
Inventors: Philippe Revil; Frank Vidar Rostol
Original assignee: Elkem ASA
Current assignee: Elkem ASA
Priority date: 2006-09-15
Filing date: 2007-08-29
Publication date: 2009-09-24
Also published as: CA2662941C; AU2007295181A1; AU2007295181B2; NO327763B1; BRPI0716721A2; CN101522854A; CA2662941A1; CN104405335A; NO20064174L; WO2008033027A1; DK2061857T3; MX2009002400A; EA013320B1; EP2061857A4; BRPI0716721B1; US20160340246A1; ES2369107T3; EG25452A; EP2061857B1; ATE526380T1

Abstract

The present invention relates to a method of cementing a casing of an oil or gas pipeline to a surrounding well wall, where an hydraulic cement slurry is formed and the slurry is deployed in the annulus between the pipeline casing and the surrounding well wall. The cement slurry is formed by mixing together an hydraulic cement 12 to 24% of silica based on the weight of cement, and water; wherein the silica comprises ⅓ to ⅔ microfine silica and ⅔ to ⅓ silica flour. The invention further relates to a cement slurry for use in the method.

Description

FIELD OF INVENTION

The present invention is concerned with the cementation of steel pipes or other structures in oil and gas well such as casings and liners.

BACKGROUND

In the cementation of oil wells, a cement slurry is usually pumped down into a casing and placed into the annular space between the outside of the casing and wall of the well. The two most important purposes of the cementation process are to prevent the transport of gas and liquid between subterranean formations and to tie up and support the casing pipe. In addition to sealing oil, gas and water producing formations, the cement also protects the casing against corrosion, and prevents gas- or oil-blow-outs as the cement slurry seals the well very quickly and impermeably.
At temperatures above 110° C., the hydration phases of set Portland cement undergo changes. This phenomenon is known as strength-retrogression (SR). This results in poorer isolation properties such as lower compressive-strength and higher set-cement permeability, and leads to a loss of zonal isolation as described in the oilfield cementing industry with possibility of liquid or gas influx from the formation into the well and across the different formations.
Strength-retrogression is easily identified through a quick and early compressive-strength decrease and set-cement permeability increase over time at temperature above 110 deg C. When no decrease of compressive strength and no increase in set-cement permeability can be observed, it is then concluded that no strength-retrogression is taking place.
For 50 years, companies have routinely added 35% by weight of cement (BWOC) of silica flour, with an average particle diameter of about 20-60 microns, to the cement to prevent SR from occurring (Journal of American concrete institute V27, No. 6, 678, February 1956).
However, there are handling and storage difficulties associated with the use of dry-blends prepared with cement and dry silica flour, such as lack of spaces on the rigs or offshore platforms to accommodate several different dry-blends, contamination misuse, and the general difficulties associated with the preparation and handling of fine powders.
More recently, liquid suspension of silica have been commercialised as an alternative to completely dry-blending operations. These liquid additives have proven effective in preventing SR when used at an equivalent 35% BWOC total silica. They have shown some advantages over dry-blending operations, especially in offshore or remote operations when only the deepest casings/liners require the use of silica to stabilise the Portland cement or other.
Unfortunately, a limitation that was identified early in its use was the relatively high concentration of liquid product that was required to equate to the 35% BWOC total silica. This meant that a large volume of liquid additives had to be transported and mixed during the cementing operation. This is particularly significant in the case of offshore drilling rigs, where deck and storage space can be extremely limited.
There is thus storage problems both with different dry materials and with liquid additives.

DESCRIPTION OF INVENTION

It is therefore an object of the present invention to provide a means for reducing SR in the cement used for oil and gas pipelines, in particular, for offshore wells.
It is a further object to avoid the need to store and mix dry powders to form cement slurries, and also to minimise the volume of any cement slurry additives brought to the rig.
Often, in the case of offshore wells, the well temperatures lie in the range 100° C. to 150° C. It has been observed by the present inventors that at these well temperatures, a different approach to the use of silica as a cement slurry additive can be adopted.
According to the invention, therefore, there is provided a method of cementing a casing of an oil or gas pipeline to a surrounding well wall, which comprises forming an hydraulic cement slurry, deploying the slurry in the annulus between the pipeline casing and the surrounding well wall, and allowing the cement to set; in which the cement slurry is formed by mixing together an hydraulic cement, 12 to 24% of silica based on the weight of cement, and water; the silica comprising of ⅓ to ⅔ microfine silica and ⅔ to ⅓ silica flour.
According to a preferred embodiment of the invention the silica is in the form of an aqueous suspension of microfine silica and silica flour.
The preferred microfine silica particles used in this invention are of amorphous nature such as microsilica, but could also be crystalline.
It has been found by the inventors that by adopting a combination of microfine silica particles and silica flour, preferably in the form of an aqueous suspension, in a cement slurry for use in wells with temperatures in the range 110° C. to 150° C., the amount of silica can be significantly reduced, while still preventing SR from occurring in the cement.
Particularly with the use of silica in the form of a liquid suspension, the use of dry silica flour is avoided, mixing dry ingredients is avoided, a single component (namely the aqueous silica suspension) only need be transported and stored, and the volume that needs to be transported and stored is minimised in circumstances where storage availability is at a premium.
Preferably, the total silica represents 15 to 20% by weight of cement.
At levels of silica of 10% BWOC and less, the suppression of SR is not effective, particularly at higher temperatures, while at temperatures above 150° C. it becomes necessary to use silica levels above 25% of BWOC.
The term “microsilica” used in the specification and claims of this application is particulate, amorphous SiO₂obtained from a process in which silica (quartz) is reduced to SiO-gas and the reduction product is oxidised in vapour phase to form amorphous silica. Microsilica may contain at least 70% by weight silica (SiO₂) and has a specific density of 2.1-2.3 g/cm³and a surface area of 15-40 m²/g. The primary particles are substantially spherical and have an average size of about 0.15 μm. Microsilica is preferably obtained as a co-product in the production of silicon or silicon alloys in electric reduction furnaces. In these processes large quantities of microsilica are formed. The microsilica is recovered in conventional manner using baghouse filters or other collection apparatus.
The term “microfine crystalline silica” used in the specification and claims of this application is particulate crystalline silica having a D50 of maximum 10 μm and preferably a D50 of about 3 μm.
Silica flour is simply ground crystalline silica with a mean particle size of about 25 μm.

DETAILED DESCRIPTION OF INVENTION

The invention will now be illustrated in more detail in the following non-limiting Examples.

Example 1

Prior Art

A standard cement slurry without silica was mixed, cast and cured at 150 deg C.
Compressive strength was measured and set-cement permeability were measured. The results are shown in Table 1 and in FIG. 1. As can be seen SR is rapidly occurring after 9 hrs as shown in FIG. 1.

TABLE 1

Set-cement permeability measurements of cement
without silica cured at 150 deg C.

		Temperature
Sample #	Composition	during cement set	Permeability

	Cement without	150 deg C.	High, typically of the
	silica		order of 10 mD

Example 2

Prior Art

Cement with 35% BWOC dry silica flour was mixed, cast and tested for compressive strength and permeability at 150 deg. C. The results are shown in Table 2. As expected no SR occurred with addition of 35% BWOC.

TABLE 2

Cubes (48 hr)		UCA Strength
At 150 deg C.	C.S. (psi)	psi @ 48 Hr

35% Silica Flour	8503	3633
35% Silica Flour	8946

Set-cement permeability measurements

		Temperature	Air
Sample #	Composition	during cement set	Permeability

5	35% BWOC silica flour	175 deg C.	0.000838 mD
From	35% BWOC silica flour	150 deg C.	0.004 mD
literature

Example 3

Prior Art

Cement+35% silica BWOC originating from a liquid suspension of ⅓ microsilica and ⅔ silica flour was mixed, cast and tested at 150 deg C.
The results are shown in Table 3 and in FIG. 2.

TABLE 3

Cubes (48 hr)		UCA Strength
At 150 deg C.	C.S. (psi)	psi @ 48 Hr

35% BWOC MBHT	8078	4069
35% BWOC MBHT	9197

From FIG. 2 it can be seen that CS increases to a value of more than 2000 psi and stays at this level. No strength retrogression can be observed. This was expected as the cement had conventional silica content of 35 BWOC.

Example 4

Invention

A cement containing 17% BWOC total silica from the liquid suspension of silica containing ⅓ microsilica and ⅔ silica flour was mixed cast, cured and tested at 150 deg C. The air permeability and compressive strength was measured at intervals for a time period of one year. The results are shown in Table 4.

TABLE 4

Curing time at 150
deg C.	3 weeks	3 months	6 months	1 year

Klinkenberg air	0.092	0.00082	0.00028	0.00036
permeability mD
Compressive	—	4630	6230	—
Strength PSI

NOTE
Air permeability is of several orders higher than water permeability. ref. Paper: “Klinkenberg effect for gas permeability and its comparison to water permeability for porous sedimentary rocks” - W. Tanikawa and T. Shimamoto.

No sign of SR has occurred after 1 year at 150 deg C. Set-cement permeability remains low and CS remains high. Examination of the samples after one year showed a very low porosity and very fine pores making the cement very well suited for sealing well bores having a bottom temperature of up to 150 deg. C.
It was surprising that SR could be prevented by the use of about half of the amount of silica compared to conventional practice.

Example 5

Invention

A cement containing 17% BWOC total silica originating from a liquid suspension of silica prepared with ⅔^rdmicrosilica and ⅓^rdsilica flour was mixed, cast and tested at 150 deg. C.
As shown in FIG. 3 no sign of SR appears after 15 days curing at 150 deg C. showing that a liquid blend with this ratio of microsilica to silica flour is effectively preventing SR.

Example 6

Invention

A cement containing 17% BWOC originating from liquid suspension of silica prepared with ⅓ microfine crystalline silica with a D50 of 3 μm and ⅔ silica flour was mixed, cast and tested at 150 deg. C.
As can be seen from FIG. 4 no sign of SR occurs after 1 week curing at 150 deg C. The microfine silica particle in the liquid silica blend can be of amorphous or crystalline origins.

Example 7

Comparison

A cement containing 10% total silica BWOC originating from the liquid suspension of silica conatining ⅓ microsilica and ⅔ silica flour was mixed, cast and tested at 150 deg C.
As can be seen from FIG. 5, clear signs of SR occurs after 24 hrs at 150 deg. C. when only 10% BWOC total silica from the liquid suspension of silica is used. A minimum silica content is needed to effectively prevent SR.

Claims

1. A method of cementing a casing of an oil or gas pipeline to a surrounding well wall, which comprises forming an hydraulic cement slurry, deploying the slurry in the annulus between the pipeline casing and the surrounding well wall, and allowing the cement to set; in which the cement slurry is formed by mixing together an hydraulic cement, 12 to 24% of silica based on the weight of cement, and water; wherein the silica comprises ⅓ to ⅔ microfine silica and ⅔ to ⅓ silica flour.

2. A method as claimed in claim 1, in which the silica is in the form of an aqueous suspension of microfine silica and silica flour.

3. A method as claimed in claim 1, in which the microfine silica and silica flour are added separately.

4. A method as claimed in claim 1, in which the microfine silica is microsilica, microfine crystalline silica, colloidal silica or mixtures thereof.

5. A method as claimed in claim 4, in which the microfine crystalline silica has a D50 of maximum 10 μm.

6. A method as claimed in claim 1, in which the silica represents 15 to 20% by weight of cement.

7. An hydraulic cement slurry for use in the cementation of gas or oil wells having a bottom temperature of between 100 and 150° C., comprising: an hydraulic cement, 12 to 24 of silica based on the weight of cement and water wherein the silica comprises ⅓ to ⅔ microfine silica and ⅔ to ⅓ silica flour.

8. An hydraulic cement slurry as claimed in claim 7, in which the silica comprises an aqueous suspension of microfine silica and silica flour.

9. An hydraulic cement slurry as claimed in claim 7, in which the microfine silica is microsilica, microfine crystalline silica, colloidal silica or mixtures thereof.

10. An hydraulic cement slurry as claimed in claim 9, in which the microfine crystalline silica has a D50 of maximum 10 μm.