Customer Manual.pdf

HALLIBURTON

Kuwait Cementing Manual

Section A Table of Contents

Kuwait Cementing Manual HALLIBURTON

Prepared for Kuwait Oil Company

Notices Sales of Halliburton products and services will be in accord solely with the terms and conditions continaed in the contract between Halliburton and the customer that is applicable to the sale.

©Copyright 2005, Halliburton Company, All Rights Reserved. ®Trademark registered in the United States and other foreign countries.

2005

A-i

Section A Table of Contents

Kuwait Cementing Manual

HALLIBURTON

Contents (Currently in stock in Kuwait) POZMIX® Cement Additive POZMIX A

Special Cement

THIX-SET

Cement Accelerators

Calcium Chloride (CaCl2) Sodium Chloride (NaCl) Cal-Seal ECONOLITE

Cement Retarders

HR-5 HR-12 SCR-100 HR-25 Diacel LWL

Fluid-Loss Additives

HALAD-344 Diacel LWL HALAD®-413 HALAD-9 HALAD-600 LE+

Friction Reducers

HALAD-9 HALAD-413 Salt CFR-3 (without defoamer)

Heavyweight Additives

HI-DENSE® No. 3 MICROMAX

Miscellaneous Additives D-AIR 3 SSA-1 (Silica Flour) SSA-2 (Coarse Silica)

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2005

HALLIBURTON

Kuwait Cementing Manual

Section A Table of Contents

Latex Additives LATEX 2000 Stabilizer 434B

Lost-Circulation Materials

Cal-Seal Flo-Chek® A SPHERELITE THIX-SET

Lightweight Additives

Halliburton Gel (Bentonite) ECONOLITE SPHERELITE Silicalite Microblock

Salt Cement Additive Sodium Chloride (NaCl)

Gas Migration Materials Cal-Seal THIX-SET LATEX 2000 Stabilizer 434B

Spacers

DUAL SPACER DUAL SPACER Mixing Aid (DSMA) DUAL SPACER Surfactant B SEM-7 Tuned Spacer Blending Additive EZ-FLO

Expansive Additives MicroBond M MicroBond HT

2005

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Section A Table of Contents

Kuwait Cementing Manual

HALLIBURTON

New Technologies���� Tuned light Systems (Have been used in Kuwait)�� Foam Cementing Tuned Light Cementing Halliburton's Software�� Well life OptiCEM RT��� Cementing Equipment�� High Wiping Efficiency (HWE®) Cement Plugs Super Seal II Floating Equipment Foam Wiperball Geothermal System (Have been used in Kuwait)�� Thermalock Multilateral Sealant System StrataLock M-Seal DrillAhead System�� FlexPlug FlexPlug®W� Deep Well System�� ChannelSeal

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2005

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H A L L I B U R T O N

Pozmix®A Cement Additive Pozmix® A pozzolanic cement additive (fly ash) is made from burned coal. It is a major component in Pozmix® cement.

BENEFITS

APPLICATIONS

• It helps reduce the permeability of set

Pozmix® A additive helps lighten the slurry and enhance its pumping properties. This additive can be used at bottomhole temperatures (BHTs) between 80° and 550°F (27° to 288°C). Typical Pozmix® slurries are a 50/50 blend of Pozmix® A additive and cement.

Pozmix® A additive is compatible with all classes of cement used to make Pozmix® cement slurries. It also reacts with lime to produce a cement-like material. At high BHTs, Pozmix® A additive should not be used with retarded cement.

Part No. (Bulk)

cement and helps improve the cement’s perforating properties.

• It helps cement resist attack from sulfate and acid, and it helps prevent corrosion from seawater.

• Pozmix® A additive requires minimal mixing water and can provide good expansion properties.

COMPATIBILITY

Part No. (50-lb bag)

Pozmix® A additive can provide the following benefits:

• This additive helps promote a good cement bond.

Pozmix A Additive—Product Specifications 890.51036 Form Gray or black powder 516.00286 (100003690 SAP)

Zonal Isolation Technology

Specific Gravity

2.300

Bulk Density

74 lb/ft3

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H A L L I B U R T O N

THIX-SET Cement THIX-SET cement is a thixotropic cement consisting of Class A, B, C, D, or H cement, THIX-SET A additive, THIX-SET B additive, and mixing water. THIX-SET cement builds static gel strength after remaining static for 5 minutes. However, the gel can be broken after the slurry has been static for up to 25 minutes. This operation can be repeated until the cement begins to hydrate.

APPLICATIONS THIX-SET cement can be used for primary or squeeze cementing jobs. Because it forms a solid, gelatinous mass, it also helps prevent lost circulation. THIX-SET cement can be used in wells with bottomhole circulating temperatures (BHCTs) between 60° and 250°F (16° to 121°C).

FEATURES Calcium chloride (CaCl2) can be used to accelerate THIX-SET cement at temperatures between 60° and 120°F (16° and 49°C). Common retarders can be used to retard THIX-SET cement at temperatures between 120° and 250°F (49° and 121°C).

BENEFITS THIX-SET cement can provide the following benefits: • It helps provide adequate compressive strength for primary cementing operations and helps control gas migration. • THIX-SET cement can help provide static gel strength while allowing cement hydration. • All necessary additives can be dry-blended with THIX-SET cement.

THIX-SET A Cement Additive—Product Specifications Part No.

70.15347

Form

Solid, white crystals

Specific Gravity 2.310

Bulk Density 70.00 lb/ft3 1.0 (1-mol solution) pH Packaging

50-lb drum

THIX-SET B Cement Additive—Product Specifications Part No.

516.00541

Form

White to offwhite, solid crystals

Specific Gravity 0.600

Zonal Isolation Technology

Bulk Density 32.00 lb/ft3 6.5 to 8.5 (25% solution) pH Packaging

50-lb bag

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HALLIBURTON

Calcium Chloride (CaCl2) Additive

Calcium chloride (CaCl2) additive is the most widely used and accepted accelerator for all classes of cement. It is widely used in shallow, low-temperature formations to speed the setting of cement slurries.

COMPATIBILITIES

FEATURES

BENEFITS

CaCl2 additive decreases thickening time, increases early strength, and shortens time spent waiting on cement. It also decreases slurry viscosity at low concentrations and increases slurry viscosity at high concentrations.

CaCl2 additive can provide the following benefits:

CaCl2 additive is effective at temperatures between 40° and 120°F (4° and 49°C) in concentrations of 2 to 4% by weight of cement (bwoc), or equivalent liquid concentrations of 40 gal/100 sk (2%).

When cold mixing-water is used, CaCl2 additive should be added directly to the mixing water rather than to the dry cement.

• In low concentrations, it decreases viscosity and thickening times. • In high concentrations, it increases viscosity and early strength. • CaCl2 additive is available in liquid, flake, and powder form.

Calcium Chloride (CaCl2) Additive (Flake Form)—Product Specifications Part No. (50-lb bag)

516.01024

Part No. (100-lb bag)

890.50811 (100078105 SAP)

Form

Solid, white flakes

Specific Gravity

1.850

Bulk Density

56 lb/ft3 10

pH

Calcium Chloride (CaCl2) Additive (Liquid Form)—Product Specifications Clear, colorless 890.50844 Form Part No. liquid (100005054 SAP) (5-gal can) Part No. (Bulk)

516.00921 (100064159 SAP)

Specific Gravity

1.320

Bulk Density

11 lb/gal

Calcium Chloride (CaCl2) Additive (Powder Form)—Product Specifications 890.50810 Specific Gravity 0.835 (100078104 SAP) 51 lb/ft3 Bulk Density

Part No. (100-lb bag) Form

Solid, white powder

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HALLIBURTON

Sodium Chloride (NaCl) Accelerator 500°F (10° to 260°C). NaCl has the following effects on slurry properties:

Sodium chloride (NaCl), commonly known as salt, can be used in low concentrations to accelerate the setting of cement. In high concentrations, NaCl retards the setting of most cements, improves bonding of cement to shales, and minimizes damage in zones sensitive to fresh water. A defoamer should be added to dry blends or to mixing water to minimize foaming and air entrainment.

• It decreases viscosity and thickening times at low concentrations and increases final strength.

• It increases density and water loss.

BENEFITS When used for oilwell cementing, NaCl provides the following benefits:

FEATURES

• increased final strength

Sodium chloride is a crystalline solid additive used in oilwell cementing applications. NaCl will not accelerate as effectively as calcium chloride (CaCl2); however, NaCl may be more readily available. NaCl salt is applicable over a temperature range of 50° to

• accelerated setting • better cement bonding to shales • reduced damage to water-sensitive reservoirs

Sodium Chloride Accelerator (NaCl)—Product Specifications Part No.

516.00158

Form

White, solid, crystalline pH

71.00 lb/ft3 5.2

Specific Gravity

2.165

80-lb bag

Bulk Density Packaging

Zonal Isolation Technology

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H A L L I B U R T O N

Cal-Seal 60 Cement Accelerator Cal-Seal 60 accelerator is blended with Portland cements. It helps shorten the slurry’s setting time and can improve its expansive properties.

APPLICATIONS Cal-Seal 60 accelerator is used in shallow wells and for surface applications that require short setting times and rapid strength development. It is effective at temperatures between 40° and 170°F (4° and 66°C). Accelerator concentrations vary between 5 and 90% by weight of cement (bwoc).

BENEFITS Cal-Seal 60 accelerator can provide the following benefits: • Within 60 minutes, slurries containing Cal-Seal 60 accelerator can withstand pressures greater than 2,600 psi. • Cal-Seal 60 accelerator has a shelf-life of up to 24 months. • The Environmental Protection Agency does not classify Cal-Seal 60 accelerator as a hazardous waste.

FEATURES At low temperatures, mixing small amounts of sodium chloride (NaCl) to Cal-Seal 60 accelerator can help enhance cement acceleration.

Cal-Seal 60 Cement Accelerator—Product Specifications Part No. (100-lb bag)

890.50131 (100005051 SAP)

Form

Solid, white powder

Specific Gravity

2.700

Part No. (bulk)

516.00335

Bulk Density

75 lb/ft3

Zonal Isolation Technology

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HALLIBURTON

Econolite Additive For Cement Slurries Halliburton’s Econolite additive is used in oilwell cementing to increase volume, decrease density, provide a detergent action, and reduce costs; the resulting slurries are widely used as filler cement. The additive is dry-blended, in finely ground powder form, with API cement Classes A, C, H, and Halliburton LIGHT cement at the rate of 1 to 3% by weight. Econolite additive cannot be used with calcium chloride (accelerator).

Halliburton LIGHT cement is 1%; for a slurry of 11.1 lb/gal, add 2% Econolite additive; free water in the resulting slurry will be about 1%.

BENEFITS Econolite additive helps provide the following benefits: • reduced slurry cost • extended slurry volume • decreased slurry density

FEATURES Econolite additive can be hydrated with fresh water, seawater (up to 5% salt), or salt water (up to 5% salt). High concentrations of salt can be detrimental to compressive strength; therefore, slurries hydrated with large amounts of salt water should be laboratorytested before use. The addition of 2% Econolite additive can produce an 11.4-lb/gal slurry with less than 2% free water in the API cement classes; increasing the concentration to 3% Econolite additive can reduce the free water content to less than 1%. The optimum addition to

Slurry Properties Cement

Econolite (%)

Water (gal/sk)

Slurry Density (lb/gal)

Class A

3.0

11.8

12.49

3.0

17.5

11.36

3.0

13.6

12.05

3.0

17.6

11.35

3.0

11.8

12.49

3.0

17.5

11.36

1.0

12.9

11.93

2.0

16.9

11.24

Class C Class H H-Lite

Econolite Additive—Product Specifications Part No.

70.15250

Bulk Density

Form

White, solid, crystalline

pH

75.00 lb/ft3 12.7 for 1% sol.

Packaging

50-lb bag

Specific Gravity

1.75

Zonal Isolation Technology

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HALLIBURTON

HR−5 Cement Additive HR-5 additive is a chemically modified lignosulfonate that retards the setting of

BENEFITS

cement. It is designed for use in wells with circulating temperatures between 125° and

HR-5 additive provides the following benefits:

206°F (290°F static).

• Increased concentrations of HR-5 additive enhance the predictability of

FEATURES

cement thickening times.

HR-5 additive is compatible with the following:

• fresh or saltwater slurries

• HR-5 additive decreases the danger of over-retarded slurries at the top of a long cement column.

• HR-5 additive provides early cement-

• most cement additives

strength development.

• all API cements

• Operators can use HR-5 additive to help

• bentonite cement

displace slurries at high rates while

• Pozmix A cement

maintaining formation pressure. HR-5 Additive—Product Specifications

SAP No.

100005050

Bulk Density

Form

Black, solid powder

Packaging

Specific Gravity

1.41

Zonal Isolation Technology

3

38 lb/ft 50-lb bag

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H A L L I B U R T O N

HRÒ-12 Cement Retarder BENEFITS

HR-12 retarder is a mixture of HR-4 retarder and an organic acid. It can be used to retard all API classes of cement as well as Pozmix cement.

HR-12 retarder can provide the following benefits:

APPLICATIONS

• It can allow cement retardation at high temperatures.

HR-12 retarder is effective in wells with bottomhole circulating temperatures (BHCTs) between 220° and 340°F (104° and 171°C). It can also withstand static temperatures up to 365°F (185°C).

• Low retarder concentrations are adequate for most jobs.

COMPATIBILITIES

• HR-12 retarder is available in liquid or powder form. Because the liquid form, HR-12L retarder, is a true aqueous solution, it will not cause settling problems.

HR-12 retarder is a strong cement dispersant. High concentrations of this product tend to decrease the effectiveness of cellulose-based fluid-loss additives, such as Diacel LWL, Halad-22A, and Halad-24. Slurries containing HR-12 retarder and any of these agents usually require the addition of a suspension aid, such as FWCA or Suspend HT.

• HR-12 retarder is effective in conditions that are too severe for other retarders, such as HR-4, HR-5, and HR-7.

• The Environmental Protection Agency does not list HR-12 retarder as a hazardous waste.

HR-12 Retarder (Powder Form)—Product Specifications Part No.

890.50914

Bulk Density

Form

Yellowish-brown powder

Packaging

Specific Gravity

1.22

Part No.

23.2 lb/ft3 (37.16 kg/m3) 50-lb sk

HR-12L Retarder (Liquid Form)—Product Specifications 516.00301 (5-gal) 10.10 lb/gal (1.21 kg/L) Bulk Density

Part No.

516.00507 (55-gal)

pH

5.9

Form

Dark-brown liquid

Pour Point

32°F (0°C)

Specific Gravity

1.21

Packaging

5- or 55-gal drum

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H A L L I B U R T O N

SCR-100 Cement Retarder SCR-100 retarder is a nonlignosulfonate cement retarder that helps simplify the design of thixotropic slurries.

APPLICATIONS SCR-100 retarder is effective in freshwater slurries at bottomhole circulating temperatures (BHCTs) up to 250°F (121°C). In saturated salt slurries, this retarder can be used at BHCTs between 250° and 350° (121° and 177°C). When combined with certain retarder-enhancing agents, SCR-100 retarder can be used in freshwater cement systems at BHCTs as high as 430°F (221°C). When used with Halad-9 additive, Halad-22 additive, Halad-24 additive, or Diacel LWL additive, SCR-100 retarder helps the cement slurry become thixotropic. When thixotropy is not required, SCR-100 retarder can be used with any fluid-loss additive to help bridge temperature gaps.

FEATURES SCR-100 retarder is available in powder or liquid form. Because the liquid form of this retarder is a true aqueous solution, it does not cause the settling problems associated with nonaqueous suspensions. The response properties of liquid SCR-100 retarder are analogous to those of the powder version.

BENEFITS SCR-100 retarder can provide the following benefits:

• SCR-100 retarder interacts well with other cement additives. • When cured for 24 hours at BHCT, this retarder helps provide excellent compressive strength. • SCR-100 retarder is effective in lightweight cement slurries formulated with Silicalite additive.

SCR-100 Retarder—Product Specifications Part No.

516.00535

Bulk Density

Form

Off-white, solid powder

Packaging

Specific Gravity

1.420

Zonal Isolation Technology

30.00 lb/ft3 50-lb bag

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H A L L I B U R T O N

HRÒ-25 Cement Retarder HR-25 is a high-temperature retarder/ intensifier. As a stand-alone retarder, HR-25 retarder/intensifier can be used to gel cement. However, this product was primarily designed for intensifying common retarders, such as SCR-100 retarder.

APPLICATIONS HR-25 retarder/intensifier can be used at bottomhole circulating temperatures (BHCTs) between 200° and 400+°F. Normal retarder/ intensifier concentrations are 0.5 to 2.0%.

BENEFITS HR-25 retarder/intensifier can provide the following benefits: • This product is highly soluble in water. Consequently, it exhibits more uniform thickening times in the laboratory and has

less effect on cement compressive-strength development, especially at the top of a long cement column. • HR-25 retarder/intensifier can be added directly to the mixing water, or it can be dry-blended. • This product interacts well with other cement additives. • This retarder/intensifier helps extend pumping times. • It allows improved displacement rates at steady pressures. • HR-25 retarder/intensifier allow soperators to better predict thickening times. • The Environmental Protection Agency (EPA) does not classify HR-25 retarder/ intensifier a as hazardous waste.

HR-25 Retarder/Intensifier—Product Specifications Part No.

516.00558

Bulk Density

Form

Solid, white powder

pH

45.00 lb/ft3 1.7 (5% solution)

Specific Gravity

1.760

Packaging

50-lb bag

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H A L L I B U R T O N

Diacel LWL Cement Retarder/Fluid-Loss Additive Diacel LWL retarder is a molecular-weight cellulose. It can be used for retardation and fluid loss in all API classes of cement as well as Pozmix cement.

COMPATIBILITIES

APPLICATIONS

BENEFITS

Diacel LWL retarder can be used at bottomhole circulating temperatures (BHCTs) between 110° and 300°F (43° and 149°C). It can also be used at bottomhole static temperatures (BHSTs) between 260° and 320°F (126.7° and 160°C). While Diacel LWL is primarily used as a retarder, it can also reduce fluid loss. During placement, this retarder helps increase slurry viscosity. Consequently, filtration is lowered to rates comparable to muds.

Diacel LWL retarder can provide the following benefits:

Diacel LWL retarder is incompatible with calcium chloride (CaCl2).

• extended pumping times • early cement-strength development • fluid-loss reduction across thief zones • more predictable thickening times • improved slurry displacement rates at steady pressures

Diacel LWL Retarder—Product Specifications Part No.

70.15526

Bulk Density

Form

Solid, ivory powder

Packaging

Specific Gravity

1.600

Zonal Isolation Technology

29.00 lb/ft3 50-lb bag

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HALLIBURTON

Halad ® -344 Fluid-Loss Additive Halad®-344 fluid-loss additive is especially useful in lightweight cementing compositions that often have long thickening times. The material is nonretarding, thus making good compressive strength development possible at low temperatures. Halad®-344 additive performs as well in seawater as in fresh water, and is compatible with retarders, dispersants, and calcium chloride (CaCl2).

BENEFITS Halad ® -344 additive can provide the following benefits associated with low fluid loss in squeeze-cementing and primary cementing jobs. Squeeze Cementing. In squeeze-cementing jobs, Halad®-344 additive offers the following advantages:

• It helps reduce premature dehydration in

FEATURES Halad -344 additive has no temperature limitations. Laboratory testing has shown that it is effective at 400°F or higher. Other features can include the following:

tubing and casing while squeezing perforations.

®

• Excellent fluid-loss control is available with very low concentrations of Halad®-344 additive.

• Halad®-344 additive is relatively salttolerant, which can make it effective with up to 18% salt in a variety of cement compositions.

• Long perforated intervals can often be successfully squeezed in a single stage.

• Satisfactory squeeze results can be obtained at low pressures without overdisplacement.

• The additive helps protect water-sensitive shale sections that may weaken and break down because of cement filtrate.

• Halad®-344 additive helps reduce the amount of filtrate that can penetrate formations containing bentonite clays.

Halad®-344 Additive—Product Specifications Part No.

516.00227

Bulk Density

Form

white to off-white solid powder

Packaging

Specific Gravity

1.220

Zonal Isolation Technology

26.00 lb/ft3 50-lb sack

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Primary Cementing. Halad®-344 additive helps provide the following benefits during primary cementing jobs:

• It can lessen the possibilities of water and/ or emulsion blocks, and blocks caused by bentonitic clay swelling resulting from cement filtrate.

bridging in annuli, which may be caused by dehydration.

• It also helps reduce loss of water from slurry, thus maintaining lower viscosities and circulating pressures.

• Halad®-344 additive helps control gas leakage while cement is setting.

• Halad -344 additive helps protect water®

sensitive shales, and can reduce premature

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H A L L I B U R T O N

HaladÒ-413 Fluid-Loss Additive Halad-413 additive is a synthetic polymer that helps control filtrate loss in all cement conditions.

APPLICATIONS Halad-413 additive exhibits minor retardation properties at low temperatures, yet it is effective at temperatures higher than 400°F (204°C). Halad-413 additive can help control fluid losses in seawater slurries, salt-saturated slurries, and slurries containing 5% KCl or 2% CaCl2.

FEATURES Depending on the slurry design, Halad-413 additive usually acts as a mild dispersant and cement retarder. Consequently, slurry rheology is lowered, and free-water values are increased, helping eliminate the need for friction reducers.

COMPATIBILITIES Because Halad-413 additive is a nonviscosifying product, it can allow slurries containing strongly dispersed retarders to become overdispersed. Conventional fluidloss additives that impart viscosity can sometimes be added to the slurry to help prevent this problem.

BENEFITS Halad-413 additive is available as a powder or a 25% solution (Halad-413L additive). Both forms of this additive are classified as nonhazardous by the Environmental Protection Agency (EPA). In addition, Halad-413 additive can provide the following benefits: • It can help reduce horsepower requirements by controlling fluid viscosities and circulating pressures. This additive can also help maintain slurry density.

Halad-413 Additive—Product Specifications Part No.

516.00512

Form

Solid, brown/black powder pH

42.00 lb/ft3 7.5

Specific Gravity

1.480

50-lb bag

Part No.

Halad-413L Additive—Product Specifications 516.00575 (5-gal can) 30°F (1°C) Pour Point

Part No.

516.00576 (55-gal can)

Form

Black liquid

Specific Gravity

1.11

Zonal Isolation Technology

Bulk Density Packaging

pH

6.3

Bulk Density

9.26 lb/gal

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• Halad-413 additive can help control gas migration.

• Halad-413 additive can help protect water-sensitive formations.

• This additive can help improve squeeze cementing results.

• It helps secure a better cement/casing bond.

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H A L L I B U R T O N

HaladÒ-9 Fluid-Loss Additive Halad-9 additive is a blend of a cellulose derivative and a dispersant. It provides fluidloss control in all API classes of cement.

APPLICATIONS Halad-9 additive was developed for primary or squeeze operations. It can be used in wells with bottomhole circulating temperatures (BHCTs) between 60° and 300°F (15.5° and 149°C). In most cements, additive concentrations of 1% or less provide adequate fluid-loss control. However, additive concentrations can be varied for individual well requirements.

cement or as a liquid that can be added to the mixing water. As a secondary feature, Halad-9 additive acts as a cement retarder. It also imparts thixotropy to slurries containing SCR-100 retarder.

BENEFITS Halad-9 additive can provide the following benefits: • It helps keep horsepower requirements low by controlling viscosity and circulation pressures. • Halad-9 helps control gas migration and can improve squeeze cementing results. • It helps protect water-sensitive formations.

FEATURES Halad-9 additive is available as a freeflowing powder that can be added to dry

• This additive can allow a better cement/ casing bond and helps maintain slurry density.

Halad-9 Cement Additive—Product Specifications Part No.

70.15556

Bulk Density

Form

Solid, tan powder

pH

37.20 lb/ft3 5.5

Specific Gravity

1.220

Packaging

50-lb bag

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H A L L I B U R T O N

Halad®-600 E+ Fluid-Loss Additive Halad®-600 E+ additive helps control fluid loss in environmentally sensitive areas.

APPLICATIONS Halad®-600 E+ additive provides the same fluid-loss control and rheology properties as Halad®-361A additive. Halad®-600 E+ additive can be used at bottomhole temperatures (BHTs) between 125° and 300°F (50° to 150°C). Typical additive concentrations are 0.5 to 1 gal/sk (4 to 10 L/kg).

larger amounts of this additive will be required for adequate fluid-loss control. In most cases, an extender should be used to stabilize the slurry and minimize free water.

BENEFITS Halad®-600 E+ additive can provide the following benefits:

• It is compatible with seawater and saturated salt water.

• It will not degrade when contacted by air. • The Environmental Protection Agency

FEATURES

(EPA) does not list Halad®-600 E+ additive as a hazardous waste.

Halad®-600

E+ additive acts as a mild retarder and dispersant. At increased temperatures,

Halad-600 E+ Additive—Product Specifications Part No.

516.01027

Bulk Density

8.75 lb/gal

Form

Brown liquid

pH

7 to 8

Specific Gravity

1.050

Packaging

55-gal drum

Zonal Isolation Technology

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CFR-3™ Cement Friction Reducer Dispersant

H

alliburton CFR-3 friction reducer helps reduce the apparent viscosity and improve the rheological proper-

ties of a cement slurry. As a result, turbulent flow can be achieved at lower pumping rates, which results in reduced friction pressure during pumping. When a slurry’s apparent viscosity is reduced, the slurry can be mixed at a higher density by reductions in the amount of mix water added. Although the slurry is denser, it remains easy to pump and will require less (possibly no) weighting material.

Features CFR-3 friction reducers are available with or without defoamer. When defoamer is used, the mixing concentration is 0.3 to 1.5%. Without defoamer, the mixing concentration is 0.3 to 1.0%. Both products can be applied in wells above 60°F (16°C), in all API cement classes.

Benefits CFR-3 friction reducers can provide the following benefits: • Reduced hydraulic horsepower requirements

• Greater turbulence at lower pump rates CFR-3 friction reducer also helps improve fluid-loss control and can provide slight slurry retardation.

CFR-3 Cement Friction Reducer (with Defoamer)—Product Specifications Part No.

100012206

Bulk Density

Form

Red-brown solid

Packaging

Specific Gravity

1.16

3

38.00 lb/ft 50-lb bag

CFR-3 Cement Friction Reducer (without Defoamer)—Product Specifications 3

Part No.

100003653

Bulk Density

Form

Dark red-brown solid, powder

pH

38.00 lb/ft 7 to 9

Specific Gravity

1.17

Packaging

50-lb bag

Cementing

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HALLIBURTON

Hi-Dense® Weight Additives Halliburton’s Hi-Dense weight additives can be added to cement slurries to restrain high formation pressure, increase slurry density, and improve mud displacement. The two available grades of Hi-Dense additives are classified according to mesh size. These hematite-ore additives can be mixed to form 26-lb/gal slurries with an effective specific gravity of 3.15. Halliburton markets these products as Hi-Dense No. 3 and Hi-Dense No. 4.

FEATURES

for effects of various dispersing additives that might cause the weighting additive to settle out. No more than 70% of Hi-Dense No. 3 additive will be smaller than 325-mesh (45 µm). The application range is up to 320°F. Hi-Dense No. 4. Hi-Dense No. 4 has the same chemical and physical composition as No. 3, but it has a smaller average particle size. In cementing slurries, this material helps prevent thermal thinning at high temperatures. No more than 90% of Hi-Dense No. 4 will be smaller than 325-mesh (45 µm).

Hi-Dense

weight additives consist of a nonradioactive, nonmagnetic hematite material that has a minimal effect on other additives in the slurry. It has only a slight effect on thickening time and does not significantly reduce the compressive strength of set cement. Hi-Dense No. 3. The amount of water needed to fluidize Hi-Dense No. 3 alone is about 18%, or 2.2 gal/100 lb, resulting in a slurry weight of 26 lb/gal, with an effective specific gravity of 3.15. The foregoing mixwater proportions must be varied to account

Fluidized Hi-Dense No. 4 requires 2.4 gal of water per 100 lb, resulting in a slurry weight of 25 lb/gal with a specific gravity of 3.0.

BENEFITS Hi-Dense weighting additives have the following benefits:

• They help control high formation pressures. • They increase slurry densities and improve mud displacement.

• They reduce thermal-thinning effects.

Hi-Dense® No. 3 Weight Additive—Material Specifications 70.15349 Part No. Bulk Density Fine, reddish-brown granules Packaging Form 5.00 Specific Gravity

165 lb/ft3 100-lb bag

Hi-Dense® No. 4 Weight Additive—Material Specifications 516.0601 Part No. Bulk Density Reddish-brown to reddish-gray powder Packaging Form 5.020 Specific Gravity

175 lb/ft3 100-lb bag

Zonal Isolation Technology

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H A L L I B U R T O N

MICROMAX Weight Additive MICROMAX weight additive consists of a hausmannite ore ground to an average particle size of 5 microns. This additive is primarily used to increase slurry density.

MICROMAX weight additive may also require the addition of dispersants.

APPLICATIONS

In addition to increasing slurry density, MICROMAX weight additive can help provide the following benefits:

MICROMAX weight additive can be used at bottomhole circulating temperatures (BHCTs) between 80° and 500°F (27° to 260°C). Additive concentrations depend the required slurry weight for individual wells.

BENEFITS

• In deep, high-temperature, high-pressure wells, MICROMAX weight additive can help restrain formation pressures and improve mud displacement. • Unlike most weighting materials, MICROMAX weight additive will remain in

FEATURES Because of the unusual fineness of MICROMAX weight additive, higher concentrations of retarders may be required to achieve the same thickening times provided by other types of weight additives. Slurries containing

suspension when added directly to the mixing water. • The Environmental Protection Agency (EPA) does not list MICROMAX weight additive as a hazardous waste.

MICROMAX Weight Additive—Product Specifications Part No. (50-lb bag)

516.00961

Part No. (1,500-lb bag) 516.00619 Form

Reddish-brown powder

Zonal Isolation Technology

Specific Gravity

4.8 to 5.0

Bulk Density

84 lb/ft3

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H A L L I B U R T O N

D-AIR 3000 and D-AIR 3000L Defoamers • D-AIR 3000 and D-AIR 3000L defoamers

DESCRIPTION D-AIR 3000 and D-AIR 3000L defoamers help control foaming of cement slurries.

FEATURES

are recommended for replacing the following defoamers: — NF-1 — NF-3

D-AIR 3000 and D-AIR 3000L defoamers have the following features:

— NF-7

• They offer significantly greater defoaming

— D-AIR 1

characteristics than previously available defoamers.

APPLICATIONS

• They can replace D-AIR 3 defoamer in Latex 2000 cement.

• They will not affect fluid loss, thickening time, or compressive strength.

— D-AIR 2

D-AIR 3000 and D-AIR 3000L defoamers can be used with a variety of slurries, including slurries with high yield points, and those containing additives such as HR®-12 retarder and sodium chloride (NaCl).

D-AIR 3000 Defoamer—Product Specifications Form

Powder

Packaging

50-lb sack

Color

Tan

Specific Gravity

1.35

SAP No. Part No.

101007446 516.01248

Bulk Density

25.2 lb/ft3

D-AIR 3000L Defoamer—Product Specifications Form

Liquid

Pour Point

34°F

Color

Tan

Packaging

5-gal bucket

Specific Gravity

0.93

Bulk Density

7.75 lb/gal

SAP No. Part No.

101007444 516.01249

Boiling Point

>200°F

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Recommended concentrations of D-AIR 3000 and D-AIR 3000L defoamers range from 0.0025% to 0.45% (0.005 to 0.5 gal/sk) by weight of cement (BWOC). More specific applications for D-AIR 3000 and D-AIR 3000L defoamers are outlined in Bulletin CMA-99-012, posted on the HalWorld website.

BENEFITS D-AIR 3000 and D-AIR 3000L defoamers can provide dependable foam control, even in slurries with high yield points and slurries containing additives such as HR®-12 retarder and sodium chloride (NaCl).

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HALLIBURTON

SSA-1 Strength-Stabilizing Agent SSA-1 agent (also called silica flour) is a powdered sand that helps oilwell cement maintain low permeability and high compressive strength under high-temperature conditions.

FEATURES SSA-1 agent is mined and processed in the following two forms:

• in a minus 200-mesh powder for maximum reactivity in cement concentrations of normal weight

APPLICATIONS SSA-1 agent is recommended for use in cementing wells where static temperatures exceed 230°F. Above this temperature, most cement compositions exhibit satisfactory compressive strength after the initial set but will rapidly lose strength after continued exposure to high temperatures. SSA-1 agent helps prevent this problem by chemically reacting with the cement at high temperatures. SSA-1 agent has been widely used in thermal recovery wells in combination with refractory-type cements.

• in a selected particle-gradation design for densified cements where increased weights and maximum reactivity are required

BENEFITS The greatest benefit of SSA-1 agent is its compatibility with various cementing materials and additives. SSA-1 agent is compatible with all cements as well as all commonly used retarders, friction reducers, low water-loss additives, and weighting and lost-circulation materials.

SSA-1 Agent —Product Specifications Part No.

890.51039

Bulk Density

Form

White, solid powder

Packaging

Specfic Gravity

2.630

Zonal Isolation Technology

70.00 lb/ft3 100-lb sack

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H A L L I B U R T O N

SSA-2 Coarse Silica Flour SSA-2 coarse silica flour is Oklahoma No. 1 dry sand.

APPLICATIONS SSA-2 silica is coarser grind than SSA-1 silica. It helps stabilize the strength and permeability of cement at bottomhole temperatures (BHTs) between 230° and 700°F (110° and 371°C). Typical concentrations are 35 to 100% by weight of cement (bwoc).

BENEFITS SSA-2 course silica flour can provide the following benefits:

• It helps prevent strength retrogression and can decrease permeability in cement systems.

• It is compatible with all types of cement. • SSA-2 coarse silica flour has no secondary effects on the cement slurry.

SSA-2 Coarse Silica Flour—Product Specifications Part No. (100-lb sk)

70.43106 (100002158 SAP)

Form

White to brown, solid granules

Zonal Isolation Technology

Specific Gravity

2.650

Bulk Density

100 lb/ft3

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HALLIBURTON

Latex 2000 Cement Additive Latex 2000 is a liquid additive that imparts excellent fluid-loss control, high-temperature suspension properties, and acid resistance to cement slurries. Latex 2000 additive is successful across a wide range of well conditions (80° to 380°F) and is used in both primary casing cementing operations and remedial squeeze work.

seal and superior zonal isolation. Microbond expansive agents are often incorporated into slurries containing Latex 2000 additive to help maximize bond strengths.

FEATURES

Under hot downhole conditions, Latex 2000 additive can provide excellent solids-suspension properties in high-density slurries. It can also exhibit excellent rheological properties while helping to control slurry segregation.

Latex 2000 additive helps provide strong resistance to acid. Slurries containing Latex 2000 additive can provide 10 times the corrosion resistance of standard cements.

Latex 2000 additive is an opaque white liquid packaged in a 54-gal drum. In general, Latex 2000 additive can be used at bottomhole circulating temperatures as high as 380°F.

In situations where gas migration is a concern, Latex 2000 additive can provide fluidloss control. Some evidence also suggests that the latex increases slurry zero gel time.

APPLICATIONS Cement can be treated with Latex 2000 additive to obtain slurries with excellent wetting properties, low viscosities, and increased resiliency. These properties help increase bonding strength, resulting in a tighter annular

Normally, dispersants and D-Air 3 defoamer are used with Latex 2000 additive to keep the latex suspended in the slurry and to help prevent entrained air.

Latex 2000—Product Specifications Part No.

516.00595

Boiling Point

212°F (100°C)

Form

Opaque white liquid

Pour Point

30°F (-1.1°C)

Specific Gravity

1.000

Freeze Point

32°F (0°C)

Bulk Density

8.33 lb/gal

Flash Point

>190°F (87.8°C)

pH

8.7

Packaging

54-gal drum

Zonal Isolation Technology

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BENEFITS Latex 2000 additive can provide the following benefits: • It helps increase bonding to the casing.

• It helps provide exceptionally low fluid loss, while exhibiting excellent rheological properties. • It helps control slurry segregation.

• While maximizing acid resistance, it also aids in suspension.

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H A L L I B U R T O N

Stabilizer 434B Latex Stabilizer Stabilizer 434B latex stabilizer helps prevent gas migration in Latex 2000 cement, a low fluid-loss cementing system. Latex 2000 cement is a water-internal, oil-external emulsion; in the presence of water, the system tends to come out of emulsion, losing its effectiveness against gas migration. Stabilizer 434B latex stabilizer helps prevent the de-emulsification of Latex 2000 cement.

FEATURES Stabilizer 434B latex stabilizer is a translucent liquid additive that can be applied at temperatures from 80° to 320°F (27° to 160°C).

It was developed specifically for use with Latex 2000 cement.

BENEFITS Stabilizer 434B latex stabilizer has the following benefits: • It stabilizes Latex 2000 cement to help prevent gas migration and control fluid loss. • It is applicable over a wide temperature range.

Stabilizer 434B Latex Stabilizer—Product Specifications Part No.

Packaging 516.00596 (5-gal can) 516.00597 (52-gal drum)

5-gal can 52-gal drum

Form

translucent liquid

Bulk Density

8.83 lb/gal

Specific Gravity

1.060 lb/gal

pH

7.5 to 8.5

Zonal Isolation Technology

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H A L L I B U R T O N

Spherelite Cement Additive rated into the blend. Some of the hollow spheres are pressure-sensitive, and once the resistance of the individual spheres is exceeded, liquid is forced through the pores of the beads to fill the hollow interior space. This action gradually increases the slurry density as the total pressure on the slurry is increased.

When combined with the proper type of cement, Spherelite cement additive can provide slurry densities of 9.5 to 12 lb/gal. The 24-hour compressive strength of these slurries can range from 100 to 700 psi at curing temperatures of 28° to 140°F (-2.2° to 60°C).

FEATURES

BENEFITS

Spherelite cement additive consists of hollow, fused, pressure-resistant mineral spheres that are competent up to a total exposure pressure of 12,000 psi. Lightweight slurries prepared with Spherelite cement additive generally have significantly higher 24-hour compressive strength development than equivalentdensity slurries prepared with bentonite, gilsonite, or silicate extenders.

In addition to improving early compressivestrength development, Spherelite cement additive slurries have very good thermal insulation properties and are ideally suited for geothermal cementing applications. Set cements prepared with Spherelite cement additive also have improved heat insulation properties; the Spherelite cement additive functions as a lost-circulation aid. It also increases slurry volume yields because of its bulk density (25 lb/ft3).

At any given pressure, the slurry density of a cement blend can be regulated by the quantity of Spherelite cement additive incorpo-

Spherelite Cement Additive—Product Specifications Part No. Form

516.00002 light-gray, solid powder

Specific Gravity

0.700 lb/gal

Bulk Density Packaging

Zonal Isolation Technology

25.00 lb/ft3 50-lb bag

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HALLIBURTON

Bentonite (Halliburton Gel) Viscosifier Bentonite (Halliburton Gel) is a colloidal clay mineral composed primarily of smectite. It

BENEFITS

may also contain accessory minerals, such as quartz, feldspar, and calcite. In fresh water,

Bentonite can provide the following benefits:

bentonite swells to approximately 10 times its original volume.

• It is easily obtained and can be an effective lost-circulation material when mixed with other common oilfield materials.

APPLICATIONS

• The overall cost for treatment can be less than that of other lost-circulation methods.

Bentonite is used in most cement slurries for decreasing slurry weight and increasing

• This material can be effective in regular and cavernous lost-circulation zones and

slurry volume. In bentonite-cement diesel-oil (BCDO) and bentonite diesel-oil (BDO)

where drilling with fibrous, granular, or flake materials has been ineffective.

slurries, bentonite forms a thick, paste-like material that helps prevent lost circulation.

COMPATIBILITY Bentonite is compatible with slurries containing fibrous, granular, and flake-type lostcirculation materials.

Bentonite (Halliburton Gel)—Product Specifications Part No. (50-lb bag)

516.00415 (100003682 SAP)

Specific Gravity

2.350

Form

Gray-white to green solid powder

Bulk Density

60 lb/ft

Zonal Isolation Technology

3

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H A L L I B U R T O N

Flo-Chek ® A Additive Flo-Chek® A additive is a colorless liquid that can be used for preparing the Flo-Chek process.

near-wellbore area in temperature ranges from 40° to 550°F (4° to 288°C).

COMPATIBILITIES

APPLICATIONS

When used with the Flo-Chek process, FloChek® A additive instantly reacts with fluids containing multivalent cations, such as calcium or magnesium.

When used as a conditioning flush before cement on a primary cementing job, the FloChek process helps control subsurface brine flow, seal lost-circulation zones, and improve cement bonding and displacement. FloChek® A additive, when used as the primary

BENEFITS When used in the Flo-Chek process, FloChek® A additive can provide the following benefits:

component of the Flo-Chek process, instantly forms a stiff gel when it mixes with reactive brines. The gel seals off lost-circulation zones by blocking flow channels and fractures and can also help prevent slurry migration downhole away from the plug location.

• It helps improve mud displacement and cement bonding.

• It helps control downhole fluid loss. • It helps prevent lost circulation and slurry

FEATURES

migration downhole.

The Flo-Chek process is externally catalyzed. Its matrix-penetration depth is limited to the

®

Flo-Chek A Additive—Product Specifications 11.66 lb/gal cargo tank

Specific Gravity

70.15644 Bulk Density clear, colorless to hazy Packaging liquid 1.400 pH

Boiling Point

213°F (100°C)

30°F (-1°C)

Pour Point

35°F (1°C)

Part No. Form

Freeze Point

Zonal Isolation Technology

11.3

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H A L L I B U R T O N

Silicalite Cement Additive Silicalite cement additive is made from a finely divided, high surface-area silica.

APPLICATIONS Silicalite additive can be used as an extender for lightweight cements and a compressivestrength enhancer for low-temperature, lightweight cements. This product also imparts thixotropy to some cement slurries. Silicalite additive can be used in wells with bottomhole circulating temperatures (BHCTs) between 50° and 500°F (10° and 260°C).

FEATURES Silicalite additive is available as a powder, a liquid, a Pozmix cement blend, or a compacted material. Compacted Silicalite additive does not have the same performance properties as the liquid or powder forms. Therefore, designs including compacted Silicalite additive should be subjected to laboratory testing before being used in the field.

Silicalite Additive (Powder Form)—Product Specifications Part No. Form Specific Gravity

516.00445 Solid, black powder 2.300

Bulk Density pH Packaging

18.00 lb/ft3 6 to 8 50-lb bag

Silicalite Additive (Liquid Form)—Product Specifications 516.00514 11.6 lb/gal Part No. Density Black liquid 6 to 8 Form pH 1.39 55-gal drum Specific Gravity Packaging Silicalite Additive (50:50 Pozmix Cement Blend)—Product Specifications 516.00443 Part No. Bulk Density 35 lb/ft3 Solid, black powder 6 to 8 Form pH 2.49 50-lb bag Specific Gravity Packaging Silicalite Additive (Compacted Form)—Product Specifications 516.00444 Part No. Bulk Density 44 lb/ft3 Solid, black powder 6 to 8 Form pH 2.52 50-lb bag Specific Gravity Packaging

Zonal Isolation Technology

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Silicalite has a viscosifying effect in most compositions. This additive is frequently used with CFR-2 friction reducer or CFR-3 friction reducer. At static temperatures above 230°F (110°C), a strength-stabilizing agent, such as SSA-1 fine silica flour or SSA2 coarse silica flour should be incorporated into the slurry design.

BENEFITS Because Silicalite additive imparts thixotropy to the slurry, it can help control lost circulation and gas migration. In addition, this product can provide a degree of fluid-loss control and can act as a low-temperature accelerator for saturated salt slurries.

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H A L L I B U R T O N

Microblock Cement Additive Microblock is a liquid cement additive made from a finely divided, high surface-area silica.

APPLICATIONS Microblock cement additive can be used as an extender for lightweight cements and a compressive-strength enhancer for lowtemperature, lightweight cements. This product also imparts thixotropy to some cement slurries and acts as a low-temperature accelerator for salt slurries. Microblock cement additive can be used in wells with bottomhole circulating temperatures (BHCTs) between 60° and 400°F (16° and 204°C).

FEATURES Microblock cement additive can help prevent high-temperature strength retrogression. However, an additional retrogression additive should be included in cementing designs for temperatures above 280°F (138°C).

BENEFITS Because Microblock cement additive imparts thixotropy to the slurry, it can help control lost circulation and gas migration. In addition, this product can provide a degree of fluid-loss control.

Microblock Cement Additive—Product Specifications Part No.

516.00618

Bulk Density

11.66 lb/gal

Form

Gray liquid

pH

6

Specific Gravity

1.400

Packaging

55-gal drum

Zonal Isolation Technology

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H A L L I B U R T O N

Dual Spacer System Dual Spacer system’s primary application is as a low-viscosity, weighted spacer (flush) for primary and secondary cementing operations. Dual Spacer system can also be designed to displace water- and oil-based muds.

pits or after batch-mixing operations featuring bulk-blended Dual Spacer system. Retarders. When Dual Spacer system is pumped at elevated temperatures, a retarder should be added to counteract the dilution effect occurring at the cement-spacer interface. Otherwise, pump time will be significantly reduced.

FEATURES Dual Spacer system can be formulated with fresh water, seawater, 3% KCl, and salt concentrations as high as saturation in well temperatures ranging from 60° to 500°F (16° to 260°C). Its rheological properties typically allow it to be pumped in turbulence at reasonable displacement rates. These properties help improve mud displacement while maintaining drilling fluid/cement slurry isolation.

Surfactants. When oil-based muds are displaced, surfactants reduce interfacial viscosity and preferentially water-wet the pipe surface, which promotes better cement bonding. Defoamers. Adding D-Air 3 defoamer helps combat the foaming tendencies of a surfactant-laden Dual Spacer system. When surfactants are not used, other defoamers, such as NF-3 or D-Air 2, can also be applied.

APPLICATIONS

BENEFITS

Dual Spacer system interacts with the following supplementary additives:

Dual Spacer system has the following benefits:

Dual Spacer Mixing Aid additive. Dual Spacer Mixing Aid additive helps improve surface suspension properties during lowshear mixing operations in offshore sludging

• It helps improve mud displacement while maintaining drilling fluid cement/slurry isolation. • It can be used over a wide temperature range.

Dual Spacer System—Product Specifications Part No.

516.00177

Bulk Density

Form

tan, solid powder

Packaging

Specific Gravity

2.270 lb/gal

Zonal Isolation Technology

31.10 lb/ft 51-lb bag

3

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H A L L I B U R T O N

Dual Spacer Mixing Aid Additive water or 1.5 to 3 gal Dual Spacer Mixing Aid additive per 10 bbl seawater.

Dual Spacer Mixing Aid additive is a lightbrown liquid gel disposed in a low-toxicity oil. It minimizes solids setting, which frequently occurs when Dual Spacer system is mixed in a low-sheer environment, such as an offshore sludging pit. Dual Spacer Mixing Aid additive helps improve the surface suspension properties of a Dual Spacer system design.

It increases pump rates required for Dual Spacer system to achieve turbulence. Its effect is less at higher temperatures. Dual Spacer Mixing Aid additive is also capable of being crosslinked with a chrome source.

BENEFITS

FEATURES

Dual Spacer Mixing Aid additive provides the following benefits:

Dual Spacer Mixing Aid additive can be used in temperatures ranging from 60° to 500°F (16° to 260°C) in concentrations of 1 gal Dual Spacer Mixing Aid additive per 10 bbl fresh

• It helps minimize solids setting. • It helps improve the surface suspension properties of Dual Spacer system.

Dual Spacer Mixing Aid Additive—Product Specifications Part No.

516.01058

Packaging

2-gal can

Form

light-brown liquid gel

Boiling Point

406°F (208°C)

Specific Gravity

1.013

Flash Point

160°F (71°C)

Bulk Density

8.44 lb/gal

Pour Point

0°F (-17°C)

Zonal Isolation Technology

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HALLIBURTON

Dual Spacer B Surfactant Dual Spacer B surfactant is commonly used in water-based spacers to water-wet casing and help displace oil-based drilling fluids from the wellbore.

BENEFITS Dual Spacer B surfactant has the following benefits: • It helps reduce interfacial viscosity.

FEATURES Dual Spacer B surfactant is a clear liquid packaged in a 5-gal can. It can be used at temperatures up to 500°F (260°C) when used in a properly designed blend of surfactants. It is normally used at a concentration of 0.2 to 2 gal/bbl.

• It preferentially water-wets the pipe surface and helps promote better cement bonding. • It can be used as a single, water-wetting surfactant even if interfacial viscosity is not a problem.

Dual Spacer B Surfactant —Product Specifications Part No.

516.00208

Boiling Point

290°F (143°C)

Form

Clear liquid

Freeze Point

49°F (9°C)

Specific Gravity

1.062

Flash Point

600°F (315.6°C)

Bulk Density

8.85 lb/gal

Packaging

5-gal can

pH (1% solution)

5 to 7

Zonal Isolation Technology

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HALLIBURTON

SEM-7 Emulsifer SEM-7 emulsifier is designed to keep sandstone formations and proppant in a water-wet condition, thus improving the ability of oil to flow.

APPLICATIONS Cementing applications use SEM-7 emulsifier in chemical washes and spacers that come into contact with oil-based mud (OBM). Formulations for OBM containing 1 gal/bbl of SEM-7 emulsifier, 0.5 gal/bbl of Musol® A, and 0.1 to 0.2 gal/bbl of Dual Spacer B Surfactant act as a degreaser and leave both the formation and the pipe in a water-wet condition. Pen-5 can be used as a substitute

SEM-7 emulsifier also is used as a foamer in foam fracturing applications that include carbon dioxide or nitrogen.

BENEFITS The greatest benefit of SEM-7 emulsifier is its capability to leave formations and proppant water-wet. In addition, SEM-7 emulsifier will emulsify in almost any type of water that can be gelled, including brines. SEM-7 emulsifier can be chemically broken or allowed to break by adsorption. SEM-7 emulsifier also provides stability at high temperatures.

for SEM-7 emulsifier in cementing applications.

SEM-7 Emulsifier—Product Specifications Part No.

70.15625

Form

Clear, pale yellow liquid Pour Point

-7°F (-21°C)

Specific Gravity

0.98

Flash Point (PMCC)

74°F (23°C)

pH

7.7

Packaging

55-gal drum

Stimulation Technology

Bulk Density

8.25 lb/gal

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H A L L I B U R T O N

Tuned Spacer™ Material Optimized Rheology Spacer range. The rheology is constant from 80° to over 200°F.

Tuned Spacer™ Material is a costeffective, water-based spacer that can provide variable viscosity and optimized rheology.

This spacer is thermally stable at wellbore temperatures up to 350°F, and it retains 60% of its original consistency after exposure to a temperature of 350°F for 1 hour.

APPLICATIONS Tuned Spacer™ Material can be used to displace water- or oil-based drilling fluids. It can also help provide uncontaminated recovery of drilling fluids such as expensive, synthetic-based drilling muds.

A customized Tuned Spacer™ Material Mixing Calculations Spreadsheet is available for determining the amount of spacer blend, barite, and water needed to prepare the mix at specific densities. The correct mixture will help ensure the viscous properties needed to effectively displace drilling fluids.

This spacer system can be used at temperatures ranging from ambient temperature to a bottomhole circulating temperature (BHCT) of 325°F.

COMPATIBILITIES Tuned Spacer™ Material is compatible with most cement slurries, water-based drilling fluids, and brines. If laboratory testing shows

FEATURES The rheology profile of the Tuned Spacer™ Material is relatively flat across a broad shear

Tuned SpacerSystem—Product Specifications Part No.

516.01168

Bulk Density

Form

Gray, solid powder

Packaging

Specific Gravity

2.370

40.00 lb/ft3 40-lb bag

Tuned Spacer Additive Dispersant Specifications Part No.

516.01169

Bulk Density

Form

White, solid powder

pH

52.50 lb/ft3 7 to 9 (in water)

Specific Gravity

1.200

Packaging

20-lb box

Zonal Isolation Technology

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incompatibilities with a water-based drilling fluid, Tuned Spacer™ Material dispersant should be used. This spacer can also be used with oil-based muds, but suitable surfactants will be required. This spacer is compatible with CleanBore™ A and CleanBore™ B surfactants when the surfactants are previously run with other spacer systems. A strong surfactant concentration (0.1 to 0.2 gal/bbl) can help ensure that the pipe and formation are water-wet. These surfactants, however, may not work well with newer synthetic-oil drilling fluids. Mixing the spacer with anything other than fresh water can result in a spacer fluid with different viscous properties. For example, high surfactant loading generally produces a more viscous spacer, whereas mutual solvents tend to reduce viscosity. When the spacer is mixed in bulk cement equipment, predissovling Fe-2 Agent (Part No. 70.15538) will offset cement contamination from the bulk plant.

BENEFITS The Tuned Spacer™ System offers the following benefits: • The concentration of the base spacer mix can be increased or decreased to adjust the viscosity to the demands of the drilling muds. • The formula can be customized to satisfy the requirements of any wellbore geometry. • The volume of dispersant can be adjusted to achieve the most effective rheological level. • The constant rheology can provide operators with complete control over mixing, pumping, and equivalent circulating densities. • Because rheological properties develop early during mixing, viscosifiers that can prevent settling are not recommended. • The uniform flow velocity creates better displacement efficiency.

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

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H A L L I B U R T O N

EZ-FLO Blending Additive EZ-FLO blending additive can improve typical pneumatic equipment’s ability to provide fluid-like flow for bulk materials. Cement particles treated with EZ-FLO additive separate more easily. Consequently, surging can be reduced, resulting in a smoother cement flow and better density control.

APPLICATIONS Positive and negative charges are distributed across the surfaces of cement particles, resulting in forces of attraction and repulsion. These forces are largely responsible for a cement blend’s ability or inability to flow well in a pneumatic transfer system. When EZ-FLO additive contacts cement particles, it reacts with charged particle surfaces, causing repulsion to be the dominant force within the blend. For certain cement blends that have historically exhibited material losses between 30 and 60%, EZ-FLO additive can reduce losses to less than 10%.

COMPATIBILITIES EZ-FLO additive treatment concentrations are typically very low, so materials must be measured carefully and blended thoroughly. Because of the chemical reactions that occur between EZ-FLO additive and cement, using EZ-FLO additive is a treatment process and not simply additive blending. When blending

Zonal Isolation Technology

lime cements such as HTLD, add the EZ-FLO additive to the cement and box it before adding lime. Do not vacuum EZ-FLO additive through the additive lines while vacuuming other materials such as retarders, fluid loss additives, lime, VersaSet additive, ECONOLITE additive, bentonite, etc. EZFLO additive can preferentially react with these materials before it treats the cement, rendering the treatment ineffective. In addition, improper mixing can prevent additives from performing as designed.

BENEFITS EZ-FLO additive can provide the following benefits:

• It can greatly improve the transfer of bulk materials.

• It can reduce surging. • It alters the pack-set index (PSI) of the cement blend.

• It can help improve flow by reducing the effect of environmental factors such as temperature and humidity, and transfer conditions, such as system pressure and tank design.

• It can help offset the effect of tanks with a low angle of repose, such as horizontal or marine tanks.

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EZ-FLO Additive—Physical and Chemical Properties Bulk-flow enhancer 0.0741 gal/lb Description Absolute Volume Dry powder 120°F Form Flash Point White 516.01217 Color Part No. 1.62 101002314 Specific Gravity SAP No. 0.04 to 0.2% Concentration Range Price Reference No. 508-137 2.6 to 3 (1% solution) Packaging 225-lb steel drum pH Bulk Density 32 lb/ft3

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

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H A L L I B U R T O N

MicroBond M Cement Additive BENEFITS

MicroBond M is a chemical expansive additive developed for use at temperatures from 130° to 210°F.

MicroBond M additive provides the following benefits:

APPLICATIONS

• It helps provide more expansion than MicroBond additive at temperatures from 130° to 170°F.

MicroBond M additive can be used in freshwater slurries, or salt slurries up to saturation. It can also be used in saltsaturated slurries at temperatures up to 300°F when MicroBond HT develops expansion too slowly.

• MicroBond M additive helps provide quicker expansion than MicroBond HT additive at temperatures from 170° to 190°F. • MicroBond M additive can provide improved bonding and zonal isolation. • It is nonhazardous in normal working conditions.

MicroBond M Additive—Product Specifications Part No. Form

516.00513 Tan to dark brown, solid grain

Specific Gravity

3.600

Bulk Density

65.00 lb/ft3 50-lb bag

Packaging

Zonal Isolation Technology

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H A L L I B U R T O N

MicroBond HT Cement Additive MicroBond HT is an expansive cement additive developed for use at temperatures above 170°F.

APPLICATIONS MicroBond HT additive helps control microchannels, which provide a pathway for interzonal communication.

FEATURES The expansion provided by MicroBond HT additive develops as a function of temperature, which accelerates expansion.

BENEFITS MicroBond HT provides the following benefits: • MicroBond HT additive is functional in all API cement classifications. • This additive should perform well in areas with suspected microchanneling problems with minimal design and job-execution problems. • It is nonhazardous in normal working conditions.

MicroBond HT Additive—Product Specifications Part No. Form Specific Gravity

516.00446 Tan to dark brown, solid powder or grain 3.570

Zonal Isolation Technology

Bulk Density

112.00 lb/ft3

Packaging

50-lb bag

Flash Point

None

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Tuned Cementing Solutions

TM

Lightweight Systems ust as we use a graphic equalizer to optimize music for our listening environment we can use Tuned Cementing Solutions to tune cement slurries to provide the optimal performance for a given well environment. It is simplistic to say one product will solve every problem. Such a theory is even more dangerous when dealing with oil and gas wells. There is certainly no single slurry that is correct for every well condition. Slurry choices are based on a combination of conditions and special needs. Important requirements such as logistics, cost, value, potential hazards, and long term zonal isolation expectations should also be considered.

HAL14050

J

Use Tuned Cementing Solutions to analyze all of the key drivers and tune in on the best solution for each well.

With Tuned Cementing Solutions (TCS) we recognize the inherent complexity of every well, and that a competent cementing slurry design requires marshalling an array of resources that include the latest slurry design software, an accurate and efficient delivery system, and the Halliburton tradition of attention to detail.

To date, Halliburton has pumped over 700 Tuned Light jobs with design densities as low as 6.8 lb/gal. – so we are ready to apply a Tuned Cementing Solution to your well today.

Halliburton is the only service company that enables you to choose from all three primary categories of lightweight cements, so your choices can be based on your requirements, such as: • Water-extended – Use water-extended slurries when cost are your primary concern. These slurries can provide the required levels of fill if conditions are not too demanding.

• Foam – Use the ZoneSeal™ Isolation Process (foam cement) when gas migration, or shallow water flow potentials are problems. Foam is also the best choice when long-term stress protection is a primary driver.

Cementing

HAL14051

• Hollow microspheres – Use Tuned Light™ (hollow microspheres) slurries, when high strength or achieving the lowest permeabilities are the main drivers or when a premium cement is required and foam is not an option.

6.7 lb/gal (50 lb/ft3 or 0.8 sg) and >1,200 psi in 48 hours

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Tuned LightTM Mixing System A 1.0

DHole Density C

Water Ratio A

Solids Ratio A

B

Tub Level B

C 14

40

0.9 0.8

35

12

0.7 30

10

25

8

20

6

(lb/gal)

0.6 0.5 0.4 0.3 0.2 0.1 08:45

08:50

08:55

09:00

09:05

09:10

09:15

09:20

09:25

8/27/2003

4

09:30 8/27/2003

Halliburton’s Tuned™ delivery system allows ultra-lightweight cement to be pumped at the correct cement to water ratio. Regardless of how the downhole rate changes, the Tuned™ delivery system keeps the mixing water delivered at the correct rate. By supplying the solids at a rate corresponding to this slaved water rate, the solids to water ratio is delivered as designed.

Global Champion – [email protected] Fluids Division/Cementing Product Service Line

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www.halliburton.com

HAL14052

15

0.0

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HALLIBURTON

Foam Cement Delivers Long-Term Zonal Isolation and Decreases Remedial Costs Foam cementing offers a truckload of benefits. But you may never realize them unless you do the job right. That’s what Halliburton’s ZoneSeal™ Isolation Process is all about. Because Halliburton is the world’s largest nitrogen fracturing company, the world’s largest cementing company, and the world’s premium supplier of foam cement, we’ve been able to put all the pieces together to make sure that you capitalize on all the advantages intrinsic to foam cement.

Advantages: Ductility and Tensile Strength

HNO2654

Ductility and tensile strength are the most crucial properties for long-term zonal isolation. The foam cement system exhibits improved ductility over conventional cements. This ductility allows the cement sheath to withstand higher hoop stresses from casing pressure and temperature cycling. This feature allows the cement sheath to "give" as the well’s casing expands, helping prevent long-term cement-sheath cracking.

HNO2655

Conventional

The illustrations, left, show sectioned samples from cyclic stress tests. In each test, the cement was allowed to cure, after which the internal casing was pressurized simulating actual well conditions. The conventional high strength neat cement (top left) failed when the pressure in the inner pipe reached Foam 4,500 psi. When foam cement (bottom left) was tested in the same way, it maintained integrity when cycled to more than 9,000 psi.

Advantages of Foam Cement

The useful life of a foam cement sheath to provide zonal isolation is measured in hundreds of stressrelaxation cycles compared to conventional cement, which will crack in two to ten stress-relaxation cycles. Result: Lasting zonal isolation that means no sustained casing pressure; less produced water for treatment and disposal; fewer workovers; and more efficient production.

Advantages: Helps improve mud displacement, prevent gas migration and protect the formation • Foam cement under compression is a high-ener gy, high-viscosity system that is more efficient than conventional slurries in displacing mud. Result: Cement-formation bonds that really hold up because all the mud has been removed. • The compressed gas bubbles in foam cement shrink or expand, but they don’t move around or coalesce. Instead, they maintain pressure while the cement hydrates. Result: Virtually no gas migration into the cement, ever – while cement is being placed or while it sets. • Foam cement has lower thermal conductivity. Result: Retention of heat as fluid is injected into the well – and fewer problems with paraffin, asphaltene and gas hydrate precipitation when the crude is produced. • The bubbles actually "plate out" against the for mation and form a barrier. Result: Lower water loss to the formation, which helps prevent formation swelling, washouts and other damage. • The tensile strength and mechanical properties of foam cement makes it ideal in many hydraulic-fracturing operations.

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Foam cement does not increase the risk for fracture initiation and propagation during hydraulic-fracturing treatments. Result: Improved zonal isolation in productive sections.

The Advantages are Clear Foam cement is simply the right way to complete a well. It can be the best insurance of trouble-free operation and long productive life that you’ll ever have. But unless it is applied the right way, its potential benefits may never be realized. Get the benefits you expect from foam cement now, by taking advantage of the ZoneSeal Isolation Process from Halliburton.

Success Story Data from six deep gas wells in Wyoming indicate that foam cement outperforms conventional cement for zonal isolation. Two of the six wells were cemented across the production zones with conventional cements. In the four other wells, the foam cement sheath provided zonal isolation even after the sheath was perforated and stimulation treatments were performed.

HNO2656

• The density of foam cement can be varied using the same base slurry. Result: Hydrostatic pressure that can be tailored to protect fragile formations and help prevent high-pressure zones from coming in – all within the same job.

This microscopic photo, left. shows how foam bubbles prevent fracture initiation in stable foam. logs indicated communication on most of the zones. The second well that was cemented experienced casing damage during the completion phase, causing a lower zone to be abandoned. At this point, the cementing program was thoroughly evaluated. Foam cement was reviewed and determined to be the best alternative for achieving effective zonal isolation on this program. The cement evaluation logs from the four foam cemented wells showed zonal isolation between the low- and higher-pressure zones. In general, the initial production rates from the four foam cemented wells were 2.5 to 5 times higher than the two wells cemented with conventional cements. These four wells hold the distinction of being the deepest foam cemented liners in the region.

The first well was cemented with the hollow-sphere and conventional cement systems. Radioactive tracer

For more information on the benefits this technology can bring to your operations, contact your local Halliburton representative – your Solution ConnectionSM. Visit our website at www.halliburton.com

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WellLife Service SM

Advanced Technology for Long Term Zonal Isolation

43 11 L1 HA

Cementing

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Executive Summary

alliburton’s WellLifeSM Service is the analysis, design and delivery of an engineered cementing system that can withstand the stresses that occur from various operations throughout the life of the well. Conventional cement job designs focus mainly on dynamic slurry properties and occasionally on the compressive strength and permeability. The WellLifeSM Service, in addition to designing for effective cement slurry placement, utilizes advanced Finite Element Method to analyze the casing, cement sheath, and surrounding formation to help determine the optimum mechanical properties that your sealant will need in order to go the distance.

Rock Casing Cement

Why do you need the WellLifeSM Service? It is becoming more and more apparent that a substantial percentage of wells that have maintained their annular pressure integrity after slurry placement are now showing sustained annular casing pressure due to damage to the cement sheath.

is placed and cured. If these changes are severe, the cement sheath could be damaged, leading to zonal isolation failure.

In the Gulf of Mexico, the MMS (Minerals Management System) reports that sustained casing pressure occurs in over 11,000 strings in over 8,000 wells on the outer continental shelf. One recent North Sea operator forum listed their number one concern for wellbore integrity as the migration of hydrocarbons up the outer annuli.

During the drilling phase, the cement sheath should be able to withstand the continuous impact of the drill string, particularly in directional wells.

While ineffective cement placement, due to poor hole cleaning of the drilling fluid and/or drill cuttings, contributes to zonal isolation failure, there is a growing number of wells showing sustained casing pressure due to damage to the cement sheath. Damage to the sheath could be in the form of: debonding at the casing and/or formation interfaces; cracking; and/or compressive shear. The damage could be caused by stresses on the cement sheath brought on by well events such as cement hydration, well completion, and hydrocarbon production. These events change the temperature and pressure under which the cement slurry

During well completion, a heavyweight drilling fluid is often replaced by a light-weight completion fluid creating a negative pressure differential that can cause debonding at the casing-cement and/or cement-formation interface. The cement sheath should be able to withstand stresses

Rock Cement Casing The Finite Element Analysis grid shows the effect of stresses in the major downhole structures

from perforating operations and resist cracking under the extreme pressures encountered during hydraulic fracturing operations. Production cycling in many HPHT wells has been the culprit for cement sheath damage and eventual casing failure. Unconsolidated formations are prone to subsidence and stress effects of drawdown and depletion should be accounted for in the sealant design.

HAL11144

H

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H A L1 11 46

H A L1 59 4

H A L1 11 45

Life of the Well Events

Completion

Stimulation

Perforation

11 L1 A H

H

H

A

A

L1

L1

11

11

47

48

49

Drilling

Reservoir

Production to Abandonment

Modes of Annular Sealant Failure Casing

Drilling Fluid

Completion Fluid

Above is a graphic depiction of a cement sheath that has shattered due to extreme pressure effects encountered during a fracturing operation. Depending on the length and location of the crush zone, interzonal communication could be a distinct possibility.

HAL11151

HAL11150

Casing

This scenario depicts debonding of the cement sheath due to casing contraction caused by replacing a heavy-weight drilling fluid with a light weight completion fluid.

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HAL11153

Technical Details

A tri-axial cell is used to evaluate the stress-strain behavior of cement sheath.

Volumetric 3000 2500

Axial

2000

Radial

1500 1000 500 0

0

0.5

1

1.5

2

2.5

HAL11154

-0.5

Stress Strain Comparisons

3500 3000 2500 2000 1500 1000 500 0 0

0.005

The volumetric change occurring during cement hydration is an important parameter and determines the (initial) stress state of the cement sheath. The change in volume during hydration is input into the WellLifeSM analysis. Figures 1 to 4 (next page) show stresses in the cement sheath when the pressure inside the casing is increased by 10,000 psi.

E

0.01

0.015

Stress Strain showing Young’s Modulus

0.02

0.025

0.03

HAL11162

Additionallly, tensile strength, porosity and permeability are also determined. The material properties of the cement sheath, along with its thermal properties, are input into the WellLifeSM

analysis to determine the integrity of the cement sheath. Other input into the WellLifeSM analysis are rock and casing material and thermal properties, formation in-situ stresses and well events.

3500

Stress (psi)

A tri-axial cell is used to evaluate the stress-strain behavior of the cement sheath. The tests are conducted unconfined, and also at different confining pressures. Hydrostatic and uni-axial strain (Oedometer) tests are also conducted. Cement sheath elastic parameters such as Young’s modulus (Ε), Poisson ratio (ν) and Mohr-Coulomb yield parameters such as cohesion (Co) and friction angle (µ) are determined from the stress-strain data.

Stress (psi)

HAL11152

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*1E8

Radial Stress, Pa

Figure 1 shows radial stresses in the casing, cement sheath, and the rock. The sign convention used is that negative values are compressive. This graph shows that the radial stress becomes more compressive in the casing, cement sheath, and the rock when the pressure inside the casing is increased.

0

.6

0 -.2 -.4 -.6 -.8 -1 -1.2 -1.4 -1.6

1

1.5

2

2.5

3

3.5

4

4.5

5

Rock

-ve: compressive

Pi Pf > Pi Cement Casing

Pf

HAL11155

Length Rock Casing Cement

Figure 2 shows tangential stresses in casing, cement sheath, and the rock. This shows that the tangential stress becomes less compressive when the pressure inside the casing is increased. The tangential stress in the casing has become tensile. It should be noted that the tangential stress in casing is less than what would have been obtained without the cement and formation behind the casing. Hence, the burst resistance of the cemented pipe is greater than the un-cemented pipe.

Tangential Stress, Pa

Figure 1 – Radial Stress when pressure inside the casing is increased from Pi to Pf

3 2.5 2 1.5 1 .5 0 -.5 -1 1.5

Pf Pf > Pi Casing

0

.5

1

Rock

Cement

Pi 1.5

2

2.5

3

3.5

4

4.5

5 HAL11156

Length

-7

Pf

-7.2

Pf > Pi

Cement

-7.4 -7.6 -7.8

Pi

-8 -8.2 0

.25

.5 .75

1 1.25 1.5 1.75 2 2.25 2.5

Length Figure 3 – Tangential Stress in the cement sheath when the pressure inside the casing is increased from Pi to Pf

HAL11157

Figure 3 shows tangential stress in the cement sheath. As stated earlier, the tangential stress becomes less compressive as the pressure inside the casing increases. For a certain combination of the cement sheath properties, down hole conditions and well events, as the tangential stress gets less compressive, it could become tensile. If this value is greater than the tensile strength of the cement sheath then the cement sheath will crack and could lead to zonal isolation failure.

Tangential Stress, Pa

Figure 2 – Tangential Stress when pressure inside the casing is increased from Pi to Pf

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Tangential Stress

+ve

Cement is less elastic

Pf Pf Pf

-ve

Cement is more elastic

Pi

HAL11158

Figure 4 gives a qualitative comparison of the tangential stresses of different cement sheaths. This shows that, for everything else remaining the same, as the cement sheath is more elastic (or less stiff) the tangential stress remains more compressive than in the less elastic cement sheath. This is why a less stiff cement sheath is less likely to be damaged when subjected to changes in pressure and/or temperature.

Length

µ

Co

τ=Co+µσ

HAL11159

Shear Stress,

Once the WellLife analysis has provided an optimum set of mechanical properties for a particular well and casing string; tri-axial stress testing is employed to develop and confirm the specific cement/sealant system.

τ

Figure 4 -- Qualitative comparison of tangential stresses in different cements when pressure inside the casing is increased from Pi to Pf

Normal Stress, σ

UCS

Mohr-Coulomb yield parameters from stress-strain data

Example of Results from WellLifeSM Analysis – I Events

Well Two

Well One Cement System One

Cement System Two

Cement System Three

Cement System One

Cement System Two

Cement System Three

4% Volume Decrease

No Volume Change

No Volume Change

4% Volume Decrease

No Volume Change

No Volume Change

Cement Sheath

FAILED

INTACT

INTACT

FAILED

INTACT

INTACT

Well Completion Fluid Swap —

3,775 psi Decrease

3,775 psi Decrease

3,775 psi Decrease

6,656 psi Decrease

6,656 psi Decrease

6,656 psi Decrease

Cement Sheath

FAILED

INTACT

INTACT

FAILED

FAILED

INTACT

Hydraulic Fracturing

10,000 psi Increase

10,000 psi Increase

10,000 psi Increase

10,000 psi Increase

10,000 psi Increase

10,000 psi Increase

Cement Sheath

FAILED

INTACT

INTACT

FAILED

FAILED

INTACT HAL11160

Hydration

The figure above illustrates the condition of three cement systems during different well operations.

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Remaining Cement Capacity (%)

Example of Results from WellLifeSM Analysis – II

100 90

100% Intact

100% Intact

80 70 60 50 40 30 20 10 Failed 0 Cement System 1

Cement System 2

Cement System 3

Cement Type Temperature Increase (200˚C)

Pressure Increase (80MPa) HAL11161

Events: Curing

Cement Capacity Remaining after an Event

In Summary The main deliverables of the Halliburton’s WellLifeSM Service is the optimum cement system to reduce the risk of damage to the cement sheath and hence zonal isolation failure. This should benefit the operator in the following ways: Minimize the safety and environmental risks associated with drilling for and producing hydrocarbons. Minimizing the risk of damage to cement sheath should reduce the risk of sustained casing pressure and hazardous material discharge to the surface. Maximize the commercial viability of the reservoir. Minimizing the risk of damage to cement sheath should reduce remedial costs, non-productive time, early water production and losses from individual zones.

WellLifeSM Analysis evaluates the risk of damage to the cement sheath when subjected to various well events. The analysis, in combination with operator risk tolerance, can be used to select optimum cement systems to provide for safe and economic production of hydrocarbons. Related papers; SPE 56536, SPE 74497, SPE 75700, August 5, 2002 Oil & Gas Journal, page 43 – 47, JPT August 2002 pages 60-61. For more information contact: [email protected] or [email protected]

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Produced by Halliburton Communications H03265 08/02 © 2002 Halliburton All Rights Reserved Printed in U.S.A.

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

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OptiCem RT TM Cement Job Design and Simulation System Now, See What’s Happening While You Can Still Do Something About It.

T

his advanced software program simulates the job while it is actually going on, letting you adjust the displacement rate as needed and telling you how fast you can safely pump. Because that information can be transmitted to another location and monitored there, OptiCem RT cuts down on the need to travel to remote locations. One person can handle several jobs in different parts of the world—all from one central control center. OptiCem RT also lets you: • See where your fluids are downhole

OptiCem RT Succeeds Where Others Fail Recently, Halliburton Energy Services planned a foam job in western Oklahoma. The job design required constant density. As a result the N2 rate would need to be ramped, therefore, a good foam plan meant the inclusion of redundant systems. During the foam job, the primary system went down and Halliburton’s OptiCem RT system was called upon to continuously

recalculate the required N2 rate. OptiCem RT based its real time calculations on the planned N2 schedule, the real time pump rate, and the stage volume already pumped when the automated system went down. The client was extremely pleased with the results. OptiCem RT allowed the entire job to be pumped as planned under difficult conditions.

• See ECD in real time, enabling you to pump as fast as safely possible • Compare what was planned versus what is actually occurring, allowing any necessary corrections to become obvious in time to respond

How It Works At the well site during cementing, OptiCem RT gathers data from the slurry (as well as from nitrogen and chemical units, for foam cement jobs). It then formats this data for analysis by the OptiCem RT module. This module reruns the cement job simulation using the actual well data. The results give the on-site specialist downhole information that is invaluable when last minute decisions must be made.

Real Time Cementing

In addition to the above comparisons of planned vs. actual, OptiCem RT allows you to view graphically any desired combination of planned job parameters, predicted results, measured sensor data, and real-time calculations based on the actual sensor data. Summary data is also available that tracks the minimum, maximum, and average values, per stage for both measured and calculated parameters such as pressure, rate, density, ECD, and nitrogen.

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Immediately upon completion of the job, a Halliburton field representative will be able to present you with a color summary of your complete job.

In addition to your typical pressure, rate and density summary, because you can see equivalent circulating density (ECD) in real time, OptiCem RT allows you to pump as fast as safely possible.

For more information on how OptiCem RT can improve your next cement job by making it safer and more effective, contact your local Halliburton representative—your Solution ConnectionSM . www.halliburton.com

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. H02637 10/00

© 2000 Halliburton All Rights Reserved

Printed in U.S.A.

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Cementing

High Wiping Efficiency (HWE®) Cement Plugs Another Halliburton Innovation, Offering Improved Efficiency, Drillability and Utility alliburton has designed a whole new class of cementing plug to meet the requirements of deeper, hotter and more hostile reservoirs. The Halliburton HWE® plugs meet this challenge with improved performance and the best value available today.

Increased Drillability

The new cup design provides more fin contact while reducing overall rubber and plastic content. The result is a plug that has both enhanced wiping efficiency and improved drillability.

Increased Utility

H

• Reduced rubber and plastic content • No metal components

• HWE plugs feature common geometry among top and bottom plugs • High-temperature – high-pressure is standard

HWE plugs are also suitable for high-pressure/hightemperature environments and both water- and oil-based drilling fluids.

• 750 psi rupture disk in bottom plug standard

The bottom plug is supplied with a rupture disk rated to 750 psi, and, after rupture, the flow area within the plug is unobstructed.

These features – along with common geometry, state-of-theart tooling and consolidation of sizes – offer the best value in cementing plugs available today.

• Spans greater weight range per size.

Improved Wiping Efficiency • Deep cup design • Greater wiper contact area • Greater wear resistance

HAL15305

The new HWE plug set is available in a wide variety of sizes.

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HWE® Cementing Top Plug Specifications Casing ID in. (mm) 4 1/2 (114.3) 5 (127.0) 5 1/2 (139.7) 7 (177.8) 7 5/8 (193.7) 8 5/8 (219.1) 9 5/8 (244.5) 10 3/4 (273.1) 13 3/8 (339.7) a

Casing Weight lb/ft (kg/m) 9.5 to 15.1 (14.1 to 22.5) 11.5 to 18.0 (17.1 to 26.8) 13.0 to 23.0 (19.4 to 34.2) 17.0 to 32.0 (25.3 to 47.6) 20.0 to 39.0 (29.8 to 58.0) 24.0 to 49.0 (35.7 to 72.9) 29.3 to 53.5 (43.6 to 79.6) 32.8 to 65.7 (48.7 to 97.8) 48.0 to 72.0 (71.4 to 107.2)

Min./Max. IDa in. (mm) 3.65/4.14 (92.7/105.2) 3.83/4.69 (97.3/119.1) 4.38/5.09 (111.3/129.3) 5.66/6.54 (143.8/161.5) 6.24/7.13 (158.5/181.1) 7.20/8.10 (182.9/205.7) 8.16/9.06 (207.3/230.1) 9.09/10.09 (230.9/256.3) 11.79/12.72 (299.5/323.0)

Top Plug Part No. 101241019 101213834 101237390 101229888 101236216 101227839 101214575 101235483 101235693

The IDs shown represent nominal casing IDs. Under certain conditions, plugs can be pumped through smaller IDs. For information about these conditions, contact Tools Systems at the Duncan Technology Center (DTC).

HWE® Cementing Bottom Plug Specifications Casing ID in. (mm) 4 1/2 (114.3) 5 (127.0) 5 1/2 (139.7) 7 (177.8) 7 5/8 (193.7) 8 5/8 (219.1) 9 5/8 (244.5) 10 3/4 (273.1) 13 3/8 (339.7)

Casing Weight lb/ft (kg/m) 9.5 to 15.1 (14.1 to 22.5) 11.5 to 18.0 (17.1 to 26.8) 13.0 to 23.0 (19.4 to 34.2) 17.0 to 32.0 (25.3 to 47.6) 20.0 to 39.0 (29.8 to 58.0) 24.0 to 49.0 (35.7 to 72.9) 29.3 to 53.5 (43.6 to 79.6) 32.8 to 65.7 (48.7 to 97.8) 48.0 to 72.0 (71.4 to 107.2)

Min./Max. IDa in. (mm) 3.65/4.14 (92.7/105.2) 3.83/4.69 (97.3/119.1) 4.38/5.09 (111.3/129.3) 5.66/6.54 (143.8/161.5) 6.24/7.13 (158.5/181.1) 7.20/8.10 (182.9/205.7) 8.16/9.06 (207.3/230.1) 9.09/10.09 (230.9/256.3) 11.79/12.72 (299.5/323.0)

Bottom Plug Part No. 101240191b 101213832b 101237389 101229886 101236215 101227837 101214570 101235482 101235691

The IDs shown represent nominal casing IDs. Under certain conditions, plugs can be pumped through smaller IDs. For information about these conditions, contact Tools Systems at the Duncan Technology Center (DTC). b Flow through 4 1/2-in. and 5-in. bottom HWE plugs should not exceed 2 hours at 10 bbl/min or 4 hours at 6 bbl/min. No pump time limit on rates below 5 bbl/min. Contact DTC for additional information. a

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HALLIBURTON

Super SealTM II Floating Equipment Maximum Performance With Economic Value The Challenge: The energy industry demanded maximum performance from floating equipment under any conditions— shallow wells, deep wells, extreme temperature and pressure ranges, sour gas—and abrasive flow resistance. The Solution: Halliburton’s Super SealTM II line of floating equipment.

Super Seal II Double Valve Float Collars and Shoes

• Induces turbulence at shoe for better filter cake removal

• Non-rotating feature available

• Eliminates the need to squeeze most shoe joints 1

• 7.12-in. (4 ⁄4-in. valve) flow area allows high turbulence cementing rates 2

• Available in all casing sizes • Allows 40% of fluid discharge out of bottom of shoe to wash past ledges and other wellbore restrictions

• 7.12-in.2 (41⁄4-in. valve) allows maximum cementing rates • Available with 23⁄4-in. valve in 5-in. and larger casing sizes • Available with 41⁄4-in. valve in 7-in. and larger casing sizes • Premium threads and different casing grades available

Super Seal II Acid Service • Can be used in openhole completions requiring acid flushes and in slotted liner applications

Super Seal II High

• Available in 31⁄2-in. and larger sizes

Super Seal II Load Carrying Float Collars and Shoes • Carries scab liner downhole • 400,000 lb load capacity • Allows reciprocation during cementing

HN00471

Super Seal II equipment is designed to perform reliably under the harshest downhole conditions. In fact, the Super Seal II valve, contained in all Super Seal II floating equipment, is certified by Lloyd’s Register to meet API RP 10F Category IIIC specifications. Category III requires the device to withstand a 24-hour flow of 10 bbl/min with a 2 to 4% sand-laden 12.0 to 12.5 lb/gal mud. Category C requires the device to withstand a 5,000-psi backpressure or an 80% casing burst pressure (whichever is smaller) after an 8-hour, 400°F heat soak. And, Super Seal II provides economic benefits and performance features that allow you to custom design the cementing string to your specific requirements. With these qualifications, why even consider another brand of floating equipment?

Super Seal II High-Port Upjet Float Shoe

Super Seal II Float Collar

Casing Equipment

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Strength Float Collars • Allows pressure testing of casing to 80% of yield strength • Non-rotating feature reduces drill-out time • Allows use of multiple bottom plugs • PDC drillable—all components manufactured from high strength plastics • Available in 95⁄8-, 103⁄4-, and 133⁄8-in. casing sizes • Premium threads available • Exceeds API RP10F requirements

Inner String Cementing With Super Seal II Equipment

• Large diameter cementing plugs are not required • By pumping through the smaller inner string, you can reduce cement contamination resulting from channeling inside casing • Cement is discharged outside the casing much faster after mixing, reducing the risk of the cement slurry within the casing having a highly accelerated setting time • Reduces amount of cement that has to be drilled out of large diameter casing • Less circulating time required with inner string cementing

available with premium threads and can be adapted for acid service. Our high-port float shoe is also available in a down-jet configuration.

To find out more about these options and Halliburton’s complete highperformance line of Super Seal II floating equipment, contact your local Halliburton representative— your Solution ConnectionSM.

Halliburton also offers a variety of additional service capabilities to fit any application. For example, Super Seal II equipment is available in a double valve configuration. And all Super Seal II equipment is

HN00472

Halliburton’s Super Seal II floating equipment can also be used for inner string cementing. This process allows cementing large diameter strings through drillpipe or tubing that is inserted and sealed in floating equipment. This method is sometimes less costly than cementing large

casing using the conventional plug displacement method. Other advantages include:

Super Seal II Float Shoe

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. C1443R 11/97

© 1997 Halliburton Energy Services Inc

All Rights Reserved

Printed in U S A

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ThermaLock TM Cement For Corrosive CO2 Environments • Resists corrosion caused by CO2 • Protects pipe and casing • Good for all temperatures • Non-Portland cement formulation

• Doesn’t require special cementing equipment or techniques • Greatly expands operators’ cementing options and opportunities for new applications

• High strength development and weight retention

Proven in Indonesia and Japan

The Challenge: Eliminate Cement Carbonation

During the field testing of the new calcium phosphate formulation, Unocal used ThermaLock cement on several geothermal wells in Indonesia. The largest of eight jobs used about 600 bbl of slurry. The slurry’s density was 14.7 lb/gal with a yield of 2.74 ft3 per sack (100 lb). Bottomhole circulating temperatures ranged from 110oF to 150oF. Bottomhole static temperatures ranged from 150oF to 300oF. Unocal claimed 100% success on all eight jobs.

Carbon dioxide (CO2) is a common element in downhole fluids, whether naturally occurring in ground waters or the result of CO2 injection processes. When CO2 comes into contact with the Portland cement that is used to cement well casings, it produces a deterioration phenomenon in the cement called carbonation. Over time, the loss of cement due to carbonation can cause serious damage to downhole tubulars and destroy zonal isolation integrity, resulting in costly remedial services or even abandonment of a well.

The Solution: Develop A CO2-Resistant Formulation

At a site in Japan, the slurry density was lowered to 11.4 lb/ gal through the addition of Spherelite. Bottomhole circulating temperature was 210oF. Because of ThermaLock’s corrosion resistant properties and successful placement, the operator—JGK—plans to use ThermaLock on its next steam producing well.

ThermaLockTM cement is a specially formulated calcium phosphate cement that is both CO2 and acid resistant. Originally developed jointly by Halliburton, Brookhaven National Laboratory, and Unocal for high temperature, geothermal wells, ThermaLock is now being promoted as an alternative for Portland cement wherever CO2 may be encountered. It has been laboratory tested and proven at temperatures as low as 140oF and as high as 700oF. Under test conditions that cause Class G, H, and latex-containing Portland cements to lose up to half their weight, ThermaLock’s properties are only slightly affected or may actually improve. (See chart on back)

Bottom-Line Benefits For Operators HN01725

• Greatly reduces concerns about the long-term affects of CO2 and acid in operators’ wells • Saves high remedial operation costs • Saves abandonment, redrilling, and recompletion costs

Advanced Cementing Solutions

A visual comparison of ThermaLock cement (right) and Portland cement (left) shows how CO2 deteriorates Portland cement over time, while leaving ThermaLock cement virtually unaffected.

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Weight Change vs Time in 140˚F Acidic CO2 Solution 0

Weight Change (%)

-10

-20

-30

-40

-50 0

20

ThermaLock

Days of Exposure

40

Latex

60

Class H

This chart shows the results of ThermaLock cement tested against neat Class H cement and Class H cement containing 2 gal of latex additive.

To learn more about Halliburton’s new ThermaLock cement, contact your local Halliburton representative—your Solution ConnectionSM.

www.halliburton.com

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. H01458R 06/99

© 1999 Halliburton Energy Services, Inc. All Rights Reserved

Printed in U.S.A.

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FlexPlug Service SM

Stop Lost Circulation, Hold Your Bottom Line When lost circulation occurs, you need a fast, proven response to keep your drilling program and your well costs under control. Lost circulation can hinder and stall wellsite operations, adding greatly to the overall cost of drilling and completing a well. Halliburton developed FlexPlug as a quick and costeffective solution for stopping lost circulation in natural or induced fractures, vugs, channels in weak zones, or flowing over-pressured zones (cross-flows and underground blowouts). FlexPlug offers several advantages to solve lost circulation problems and keep your drilling plan on track. • Effective in a wide range of drilling and formation fluids • Can be formulated for environmentally sensitive areas • Can be pumped through BHAs (bit, motor, MWD/LWD tools) • Reduces or eliminates trip time as well as waiting time • Controls crossflows and underground blowouts

• Seals multiple weak zones in a single treatment • Material remains flexible to withstand surge and swab pressures and maintain the seal in the lost circulation zone Three FlexPlug fluid systems are available to meet a wide range of downhole conditions. FlexPlug material selected for your particular application will depend upon the type of drilling fluid, environmental concerns, type of lost circulation problem, and the types of fluids that FlexPlug will contact after it is placed. FlexPlugSM W Service An oil-based system that rapidly reacts downhole with water-based drilling/completion fluids or formation waters regardless of salinity or pH. FlexPlug W can be formulated with diesel, kerosene, mineral oils, synthetic oils and esters. For situations where additional strength of the reacted material is required, cement can be added to the system.

Lost Circulation Solutions

HN01367

• Increases formation integrity to allow heavier mud weight

FlexPlug provides a quick and cost-effective solution for stopping lost circulation in natural or induced fractures, vugs, channels in weak zones, or flowing over-pressured zones (cross-flows and underground blowouts).

FlexPlugSM OBM Service A water-based system that reacts downhole when mixed with oil-based drilling fluids (diesel-based invert muds, synthetic oil muds, ester-based muds). FlexPlugSM R Service A water-based system that reacts downhole when mixed with a water-based activator fluid. FlexPlug R is recommended when a highly flexible sealing material is required or when dry gas crossflows are encountered.

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FlexPlug SM OBM Saves Exploration Well A south Texas operator was in the process of drilling a wildcat prospect to 19,200 ft. After setting a 7 5/8-in. drilling liner at approximately 14,300 ft, complete losses of 17.6 lb/ gal oil-based mud occurred at 14,500 ft while drilling the 6 1/2-inch hole. Experience on a previous well indicated that unless wellbore integrity was restored to an 18.4 lb/gal equivalent mud weight, this exploration well could not be completed as planned. Halliburton was contacted and asked to apply its FlexPlugSM service. Two 10-bbl pills of FlexPlug OBM were pumped, the first increasing wellbore integrity to 17.9 lb/ gal, the second achieving the desired 18.4 lb/gal equivalent. Drilling was then resumed with no further problems. Thirty-five days and 4,900 ft later, the operator successfully ran the 5-in. liner, which was also successfully cemented by Halliburton. The very narrow window between the mud weight (18 lb/gal), pore pressure (17.8 lb/gal), and fracture gradient (18.4 lb/gal) proved to be an especially tough test of the FlexPlug OBM’s ability to withstand high-temperature conditions for the duration of the drilling operation. Additionally, Halliburton applied its OptiCemTM software to ensure a successful cementing of the 5-in. production liner. Halliburton’s FlexPlug service was successful in achieving the operator’s objectives. Rather than trying to apply conventional LCM solutions and possibly losing days or even weeks of rig time, the customer immediately turned the problem over to Halliburton. In addition to stopping mud losses, the well was able to be drilled to total depth without further losses and was successfully cemented. Without FlexPlug service, the targeted, very prolific gas reservoir could not have been reached and completed.

Operator saves well in a prolific but problematic reservoir with new FlexPlugSM treatment A targeted 14,400-ft well in south Texas had lost all circulation and was taking gas kicks, with the risk that the operator might lose control of the well. The operator needed to seal the weak points in the open hole producing intervals, regain circulation with 18 lb/gal oil-based mud, and increase the equivalent fracture gradient of the weak zones to allow the production casing to be safely run and cemented. If he couldn’t accomplish these objectives, the successful completion of the well was seriously threatened and even the continuation of the development of the field. Halliburton recommended performing its new FlexPlugSM treatment. Four treatments were designed and run using a dual injection squeeze method. Each application increased formation integrity up to a final 22.7 lb/gal equivalent mud weight (EMW) squeeze pressure. Halliburton’s FlexPlug material successfully sealed the weak zones, which enabled the well to be circulated without additional mud loss. In the process of controlling mud losses, the high-pressure (non-commercial) gas zone was also squeezed off. This allowed the mud weight to be lowered to 17.5 lb/gal, thereby increasing the safety margin for initiating new mud losses. The casing was safely run and cemented with complete returns. Good cement bonding allowed the hydraulic fracturing process to proceed as planned. An unsuccessful well in this reservoir may have led to the operator’s abandonment of the prospect. The final EVC for the operator could be tens of millions of dollars. Due to the success of this process, the operator has included a FlexPlug contingency for future developments in this and other fields with similar characteristics.

For more information on how FlexPlug Service can help fight lost circulation and improve your bottom line, contact your local Halliburton representative—your Solution ConnectionSM. http//www.halliburton.com

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. H00767 04/98

© 1998 Halliburton Energy Services, Inc. All Rights Reserved

Printed in U.S.A.

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Cementing

FlexPlug® W Lost-Circulation Material lexPlug® W service consists of applying a reactive, nonparticulate lost-circulation material. This material is specifically designed for use with water-based drilling muds. It reacts with the drilling mud to help create a sealant that can cure mud losses into the fracture.

F

Applications Treatment volumes for FlexPlug W material vary according to loss rates. Generally, the minimum required slurry volume is 10 bbl with an average slurry volume of 50 bbls.

• This material is effective in essentially all aqueous drilling fluids and can be formulated for use in environmentally sensitive areas. • FlexPlug W material can be pumped through bottomhole assemblies. • After reacting with drilling mud, it can provide moldable consistency in 5 seconds to 30 seconds, helping to eliminate trip time as well as waiting time. • FlexPlug W material can improve wellbore pressure containment over fracture gradient.

Features Because of its reactive nature, FlexPlug W material requires the use of a compatible spacer ahead of and behind the slurry. Ahead of the treatment, at least 1,500 ft of spacer is recommended. Behind the treatment, a spacer volume of 1,000 ft is usually sufficient. FlexPlug W material should not be used to stop losses in vugular formations.

Benefits FlexPlug W service can provide the following benefits: • The material in this service can help control lost circulation while only minimally penetrating the formation matrix. Consequently, this service can be less damaging to potentially productive formations. • FlexPlug W material can react with formation fluids to help combat underground crossflows.

FlexPlug® W Material – Product Specifications Part Number Form Specific Gravity Bulk Density pH Packaging

516.0117 Solid, pale-yellow powder 2.260 53.40 lb/ft3 9.9 40-lb bag

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Produced by Halliburton Communications H01494 08/04 © 2004 Halliburton All Rights Reserved Printed in U.S.A.

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

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The Halliburton ChannelSealTM Process. Preventing Expensive Casing Shoe Remediation in Deepwater Environments. typical shoe squeeze caused by channeling or contaminated cement can easily take several days to achieve an acceptable leak-off test while costs soar into the millions. By utilizing the Halliburton ChannelSeal Process prior to running casing, you enhance the ability of the slurry to fill washouts and to completely surround the casing prior to cementing. In addition, the ChannelSeal slurry remains fluid with low gel strength for extended periods and reacts shortly after the cement is placed. That means

A

Count on the ChannelSeal process to:

HAL9314

a ChannelSeal slurry can provide isolation in channels created by poor displacement efficiency during the primary cementing process. Water-based ChannelSeal process sample, sectioned four days after placement.

• Improve shoe integrity • Minimize low side channeling in highly deviated wellbores • Help control cross flow • Temporarily plugging sidetracking spotted through the bottom hole assembly • Assist in directionally drilling a new wellbore

Designed Around Your Well’s Mud System The ChannelSeal process is designed for use in wells with temperatures ranging from 110° F to 300° F and is available in both water- and synthetic-based slurries. ChannelSeal slurries are formulated for: • Fluid compatibility • Formation compatibility • Maximum displacement efficiency • Maintaining a stable wellbore during casing runs • Minimizing channels and contamination over the interval of interest

Cementing

Fluid and Formation Compatibility The ChannelSeal slurry is built with the same fluid base utilized in the openhole section. Water-based slurries can either use seawater or fresh water, depending on the mud system. The synthetic-based system is mixed using the same base oil and emulsifiers as the mud system. That helps to minimize hole stability problems caused primarily by swelling or sloughing shales. The ChannelSeal process also eliminates the need for spacers to separate the fluid interface between the slurry and the mud.

Maximize Displacement Efficiency To help ensure maximum displacement during primary cementing, ChannelSeal slurries are designed to have low gel strength development of less than 25 lbm/100 ft2 over three days. Because the slurry remains fluid, it contributes to wellbore hydrostatic pressure transmission and helps to maintain control while casing is run in the well. Typically, an application incorporates a balanced column of 250 feet to 500 feet placed across an interval of interest.

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Minimize Channel and Cement Contamination Since the ChannelSeal slurry is placed prior to running casing, only ChannelSeal slurry is located in the annulus when the casing reaches TD. Once casing is landed, the well is cemented utilizing Halliburton best practices, and most of the ChannelSeal slurry is displaced up-hole. Any remaining ChannelSeal slurry remaining in the

ChannelSeal slurry is designed to be compatible with the cement and will cause minimal compressive strength reductions to primary cement. Cement will activate the slurry through release of heat and free lime during the curing process. Any residual ChannelSeal slurry left in the mud system will be absorbed by the mud and can be treated out of the system, utilizing the same techniques employed to treat the mud for low density drillable solids.

HAL9313

channels sets and builds sufficient compressive strength to allow zonal isolation.

CBL of synthetic-based ChannelSeal slurry. Depth 11,150 feet, Deviation81°, Temperature 220° F.

ChannelSeal - Product Performance Form Density Range Temperature Range Compressive Strength

Bulk or 50 lb sack 11.7 ppg – 17 ppg 75° F – 300° F 75 psi – 500 psi

< 10 cc 9 / 10 1 day – 14+ days 8-9

* API Low Pressure Test

Produced by Halliburton Communications H03194 05/02 © 2002 Halliburton All Rights Reserved Printed in U.S.A.

Fluid Loss * Rheology (10s/10m) Set Time PH

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Increased Integrity with the StrataLock Stabilization System Advanced, New Technology to Increase Formation Resistance to Shear Failure With StrataLock, you’re not stretching the envelope, you’re changing the rules. This revolutionary, new system lets you alter the physical properties of the strata around the wellbore, permitting you to undertake more aggressive programs.

StrataLock Is the Right Solution By modifying wellbore properties, the StrataLock Stabilization System increases tensile and compressive strength in unconsolidated formations. The results allow you to: • Eliminate intermediate casing and liners • Deepen shoe points • Increase the formation’s resistance to tensile failure • Prevent fluids lost to the formation • Save trips by performing the treatment through most existing bottom hole assemblies • Use drilling mud as the base system for mixing • Employ conventional cement systems without fracturing the formation or losing circulation • StrataLock drillability has been established through tests conducted by an independent testing laboratory

A Highly Flexible and Adaptable Process The StrataLock system can be used at temperature ranges of 50° to 200° F BHCT. The typical treatment volume is 1 bbl of StrataLock per foot of formation with a wide variety of placement, mechanical properties and density choices available. Relatively high modular drilling fluid and StrataLock combinations have been successfully formulated with both water-based and oil-based drilling fluids.

Get the key to increased formation integrity and higher productivity with the new Halliburton StrataLock system.

Advanced Systems for Formation Stability

HN01631

The resulting combination penetrates into the formation to impart mechanical integrity. Once the StrataLock treatment hardens, the tensile strength and fracture gradient of the formation are appreciably increased. With StrataLock, drill past unconsolidated zones

HN01632

HN01633

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HN01635

A StrataLock treatment is introduced to the drilling fluid and applied through the bit.

HN01634

An unconsolidated zone is encountered. Drilling ceases. Bit and drill pipe must be pulled to remedy the situation or . . .

A squeeze forces the StrataLock/drilling fluid mixture into crevices-and StrataLock filtrate into the pore spaces beyond.

After StrataLock heals the unconsolidated formation, drilling continues.

For more information on how the StrataLock system can help increase formation integrity, contact your local Halliburton representative — your Solution ConnectionSM.

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. H01015 09/98

© 1998 Halliburton Energy Services, Inc. All Rights Reserved

Printed in U.S.A.

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StrataLock™ Wellbore/Formation Stabilization System

T

he StrataLock wellbore/formation stabilization system is used to modify wellbore properties by changing the for-

the density of the mud in the hole. (Additional barite can be added to maintain or exceed the original mud density.)

mation’s mechanical properties. Specifically, it helps reduce formation permeability and increase tensile strength, Young’s

Laboratory tests have demonstrated how the filtrate from a StrataLock system/drilling fluid mixture can penetrate

modulus, and compressive strength to make the formation more resistant to shear failure. The StrataLock system consists

through a mud cake into a rock matrix.

of water-dispersible resins and resin activators. The StrataLock system can be pumped as:

• • •

Discussion High-permeability formations with low tensile strength are

A neat resin A resin/sand slurry

very susceptible to shear failure. When crossflow exists between zones, the potential for shear failure is even greater.

A dispersion in a drilling fluid (water- or oil-based)

These problems are particularly evident in offshore templates, where drilling operations can disturb adjacent wells

A neat resin is most often used in matrix treatments for altering the formation’s mechanical properties. Sand can be

and cause cemented casing to collapse.

added to the resin to increase viscosity, provide a bridging agent, or increase the density of the mixture.

When a conventional cement slurry is pumped into such a

During drilling operations, drilling fluid/resin mixtures can help consolidate weak zones that may result in lost circulation, hole collapse, etc. By mixing the resin with drilling fluid, an operator can strategically spot a pill without altering

well, the hydrostatic pressure exerted on the wellbore can exceed the fracture gradient of the formation, causing the slurry to be lost into the zone. Although lightweight cementing compositions are available, the fracture gradients of some areas may be too low for even lightweight systems.

The StrataLock system is used to modify formation properties and increase the fracture gradient so that operators can place conventional cement systems without fracturing the formation or risking lost circulation. Figure 1 shows the projected increase in fracture gradient that can be obtained

OM00075

with a StrataLock system treatment. The curves are based on a freshwater pore gradient, different penetration depths of the StrataLock system treatment, and the well depth of the Figure 1—StrataLock system integrity increase vs. well depth

Cementing

weak zone.

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Increasing a formation’s mechanical properties can achieve the following:

•

Can help prevent formation movement, which can lead to collapsed pipe and the loss of a well.

•

Can help protect formations that have been weakened by high production rates over long periods,

•

and prevent subsidence problems. Can help stabilize a formation before a fracturing treatment for better control of fracture initiation and lower sand production.

Application The StrataLock system can be used at bottomhole circulating temperatures (BHCTs) of 40° to 200°F, and it allows a wide variety of placement options, mechanical properties, and density choices (fillers, drilling fluids, etc.). The StrataLock system has been successfully formulated with many oil- and water-based drilling fluids. The low viscosity of the StrataLock system (or the resulting filtrate from the StrataLock system/ drilling fluid combinations) can allow the StrataLock system to penetrate the formation. Once the StrataLock system hardens, it helps substantially increase the tensile strength and fracture gradient of the formation. The StrataLock system can be used to shut off small leaks in tubulars or to eliminate gas flow in sustained casing pressure (SCP) applications. For these types of applications, the volume and injection rate can be extremely low (i.e., less than 1 bbl of StrataLock resin applied over a period of 30 hr at approximately 2,600 psi.) One key factor for obtaining a successful treatment is ensuring that a StrataLock system has enough pump time to allow placement. Recently, a StrataLock system was designed to meet the above criteria at a bottomhole temperature of 110°F. The system contained the following additives:

• •

StrataLock Z resin StrataLock D activator (28% by volume of the

•

resin) StrataLock E accelerator (1.25% by volume of the resin)

Placement Methods The volume of StrataLock resin used for SCP applications is very small, requiring precise placement at the point of injection. An effective placement method will also help minimize the risk of contamination. Three methods for placing resin follow:

•

Spot the resin to a safe depth above the total depth (TD) of the injection string. Shut in the bradenhead

•

or set the packer to allow injection. Use a dump bailer to help ensure accurate place-

•

ment. Use coiled tubing with a mobile injection point.

Components Two resins (StrataLock Y and StrataLock Z resins), two activators (StrataLock B and StrataLock D activators), and one accelerator (StrataLock E accelertor) are available for use at the following temperature ranges:

•

Either resin can be used across the entire temperature range of 40° to 200°F.

•

StrataLock B activator can be used at temperatures between 40° and 100°F.

•

StrataLock D activator can be used at temperatures between 100° and 200°F.

•

StrataLock E accelerator can be used across the entire temperature range.

The weight requirements are based on the chemical stoichiometry of the resin reaction. For example, 100 g of StrataLock Z resin requires 26 g of StrataLock B activator for complete reaction. The amounts of activator and accelerator can be varied for obtaining specific pump and set times.

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Test Results Examples of thickening times and compressive strengths are provided in Tables 1 and 2. For resin/mud formulations, a surfactant (StrataLock F surfactant) is used to disperse the resin in the mud. The recommended amount of surfactant is 24% by weight of resin (StrataLock Y or StrataLock Z resins) for either oil-based or water-based muds. The volume ratio of StrataLock system to mud can vary; however, mud volumes should not exceed 30%. Important

Volumes of mud exceeding 30% will result in unacceptably low compressive strengths.

StrataLock Z resin formulations typically exhibit the highest 24-hour strengths in laboratory tests. As indicated in Table 2, the StrataLock Z resin formulation had the highest 24-hour compressive strength in these tests. However, the StrataLock Y resin formulation gave the highest fluid-loss value (Table 2), and the lowest rheological values (Table 3). Fluid loss into the formation is a key factor in these formulations. Compressive strength, fluid loss, and rheological variables should always be considered in the design of a resin/mud formulation. Data for neat resin formulations are shown in Tables 4 and 5 (Page 4). Table 5 shows typical rock property modifications after treatment with a StrataLock system.

Table 1—StrataLock System Mixed with 13.7-lb/gal Water-Based Mud (70/30 StrataLock System:Mud Ratio by Volume; Density = 13.7 lb/gal) StrataLock Z StrataLock D StrataLock E StrataLock F Barite (g) Surfactant Accelerator Activator Resin (g) (g) (g) (g) 100 100 100 a

28 28 28

2 4 5

24 24 24

134 136 137.5

Mud (g) 98.6 100.3 103.6

122˚F 145˚F 24-hr Thickening Compressive Timea (hr:min) Strength (psi)b 5:40 3:27 2:48

— 61 355

Time to 100 Bc

b

After slurry achieved 100 Bc, it was removed from the HTHP consistometer. It was then placed in a 100-mL container and transferred to a 145 F water bath. These strengths are for the StrataLock system/mud mixture.

Table 2—StrataLock System Mixed with 11.9-lb/gal Water-Based Mud (70/30 StrataLock System:Mud Ratio by Volume; Density = 11.9 lb/gal; 100 g Resin) 98˚F Resin StrataLock D StrataLock E StrataLock F Barite Mud 117˚F 24-hr (g) (g) Thickening Surfactant Accelerator Activator Compressive (g) (g) (g) Timea (hr:min) Strength (psi)b Z 28 6.5 24 80 91.4 3:26 163 Y 33 10 24 93 97.1 3:55 36

a

117˚F Fluid Loss (cc/30 min)c 102 138

Time to 100 Bc

b

After slurry achieved 100 Bc, it was removed from the HTHP consistometer. It was then placed in a 100-mL container and transferred to a 145 F water bath. These strengths are for the StrataLock system/mud mixture.

c

Standard cement fluid-loss test on a 325-mesh screen, collected volume × 2

Table 3—Rheological Data for StrataLock System/Mud Formulations (11.9-lb/gal Water-Based Mud; Final Density = 11.9 lb/gal) 117˚F Fann Reading (rev/min) Resina 600 300 200 100 6 3 42 — — StrataLock Z 232 112 76 24 3 3 StrataLock Y 121 61 43 a

Formulation from Table 2

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Table 4—Neat Resin and Resin/Sanda Formulations (All Tests Conducted at 117˚F) Resin

a

24-hr Compressive Strength (psi)

Neat resin 40/70 sand

6,800 3,670

Neat resin 40/70 sand

13,380 4,710

48-hr Compressive Strength (psi)

72-hr Compressive Strength (psi)

72-hr Tensile Strength (psi)

14,030 14,600

6,297 —

13,000 16,180

6,739 —

StrataLock Y Resinb 14,690 10,210 StrataLock Z Resinc 9,210 12,860

40/70-mesh sand was placed in a tube and the resin formulation was poured over the sand until it was completely covered. The tube was then transferred to a water bath and cured for the specified time.

b

Resin Formulation Y = 100 g StrataLock Y resin, 33 g StrataLock D activator, 10 g StrataLock E acclerator

c

Resin Formulation Z = 100 g StrataLock Z resin, 28 g StrataLock D activator, 6.5 g StrataLock E accelerator

Table 5—Strength, Elasticity, and Permeability Data (Resin Formulation = 100 g StrataLock Y Resin and 31 g StrataLock B Activator Cured for 3 Days at 140˚F) Young’s Poisson’s Permeability Material Compressive Tensile Modulus Ratio to H2O (md) Tested Strength Strength (psi) (E × 106 psi) (psi)a Sandstone Neat Resin Formulation Sandstone Treated with Resin Formulation

10,434

417

1.5556 ± 0.0023 0.357377 ± 0.003519

11,743

2980

0.418 ± 0.0003

0.481125 ± 0.001567

< 0.001

23,791

2,770 (5,940)

2.092 ± 0.0084

0.110611 ± 0.002495

< 0.001

b

908.6

a

Confining hydrostatic pressure: 1,000 psig

b

Strength after 2-week curing

Produced by Halliburton Communications. H03689 10/03 ©2003 Halliburton All Rights Reserved Printed in the U.S.A.

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

www.halliburton.com

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M-Seal Introduction M Seal cement system is highly resilient and has better elasticity and ductility than conventional systems. It can be used in deep hot liners and in horizontal, deviated, and multilateral wells where the shear and compressional stresses exerted on the set cement could otherwise result in cement sheath failure. Sheath failure can result in annular pressure problems and the influx of formation fluids. Under high temperature and stress conditions, sheath failure occurs when the tensile strength of the cement cannot withstand the stress-induced fracturing within the sheath matrix. On the basis of extensive fluid-influx investigations, systems such as the M-Seal system were developed to overcome sheath-failure problems.

Base Cement System A typical M-Seal base cement system consists of the following components: Standard, Premium, or Premium Plus cement Compacted Silicalite additive Latex 2000 cement Microbond M or HT SCR-100

Properties Density: Thickening Time PV YP: Fluid Loss Young’s Modulus

15.0 ppg 5-7 hrs 40 / 2 < 50 (less than 50) 1,500,000 psi

Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale.

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WiperBall Applications/Functions

Advantages

Properties

Available Sizes

Recommended Size

• •

Wipe drill pipe clean of cement or other fluids

•

Simply loaded into a Drill Pipe connection

• •

Can pump multiple balls Can be pumped through various restrictions such as mechanical setting tools, diverters, liner running tools, etc.

•

Compatible with all types of mud

•

Material

Caoutchouc (rubber), natural

•

Parting Stretch

380% - 440%

•

Temperature Max / Min

150 °C (5 hrs) / -40°C

•

Deformation Pressure

22 N/cm – 45 N/cm

Separating fluids

2

mm

(in)

Material no.

80

(3.15)

151923

100

(3.94)

152014

125

(4.92)

152015

150

(5.91)

152016

175

(6.89)

152017

2

Recommended compression ratio is 1.4 (i.e. 175 mm ball in 125 mm ID pipe)

.

Halliburton M & S Ltd • Halliburton House • Pitmedden Road • Dyce • Aberdeen • Tel 01224 776000