Cementing Products

Cementing Products

Sprint Oil and Gas Services has a large, international network of western and eastern based chemical additive suppliers. With such a vast network, we are able to provide optimum client solutions and deploy our technology faster and more effectively than our competitors given our access to a wide range of ground-breaking technologies in the market.

  • Used for the acceleration of thickening times in all types of Portland cement slurries.
  • Solid product in flake form typically used at a concentration of up to 4% by weight of cement (BWOC).
  • Shortens the thickening time and increases early strength development of the set cement.
  • Usually added to the mix water at 2‐4% BWOC.
  • The addition of C013 increases the temperature of the mix water.
  • This must be taken into consideration when preparing a slurry as it can affect the thickening time.
  • One pound of C013 can be expected to increase the temperature of a barrel of slurry by about 1°F. 2 % BWOC C013 is considered to be the optimum concentration.
  • As a general rule, 2% C013 will reduce the thickening time by half and increase the early compressive strength by 50‐75%.
  • Care is required in measuring the amount of C013 as addition of 5% or more may cause the slurry to flash set.
  • Liquid form of calcium chloride widely used as an accelerator for cement slurries where a liquid additive is advantageous.
  • Can be used in both freshwater and seawater. In seawater however, the concentration should be limited to 0.2 gal/sk.
  • Used to provide most cement systems with optimum thickening times up to 60 deg C (140 deg F) BHCT. 
  • This BHCT limit can be extended to 85 deg C (185 deg F) when a dispersant is also incorporated in the cement system.
  • Reduces the cement slurry viscosity and aids some cement slurries in obtaining moderate fluid loss control. 
  • Used in cement slurries prepared with freshwater or seawater. It is compatible with all API classes of cement and with most cement additives.
  • Aqueous solution of Retarder C100 designed to provide greater flexibility in areas where dry-blending facilities are not available. 
  • It is useful particularly on offshore platforms where room for dry storage is limited.
  • A Lingosulphonate derived from wood. It can be used to provide cement systems with optimum thickening times in the temperature range 52°C to 121°C (125°F to 250°F) BHCT. This BHCT limit can be extended to 154°C (310°F) when used in conjunction with a retarder aid. 
  • Effectively inhibits most API cements and is compatible with all cement additives. 
  • Reduces the cement slurry viscosity without impairing the effect of fluid-loss additives. 
  • Gelation is seldom encountered in slurries containing C102.
  • Less sensitive to variations in temperature, concentration and cement quality.
  • Can be used in cement slurries prepared with fresh water or salt water with salt concentrations ranging from 3% (seawater) to 37% (salt-saturated water).
  • Liquid Retarder C103 is the liquid version of C102 with the same capabilities and operating parameters.
  • Gluconate based retarder used in cementing high temperature wells where the bottom hole circulating temperature exceeds 180 °F.
  • Provides effective retardation of the cement slurry in casing, liner, squeeze and abandonment applications.
  • Minimal dispersing properties and should be used in conjunction with dispersant C200.
  • Can also be used with dispersant C204 if slurry thinning is required.
  • Can be used in conjunction with fluid loss additive C305 or C300 for controlled fluid loss.
  • C104 is compatible with:
    • Freshwater slurries at temperatures up to 177°C (350 °F).
    • Seawater slurries at temperatures up to 177°C (350 °F) or more.
    • Salt slurries containing up to 25 % BWOW Sodium Chloride. D505 for temperatures up to 177 °C (350 °F)
  • C104 slurries are more tolerant to:
    • Small C104 concentration errors.
    • Minor variations in BHCT estimation
    • Shear, unlike other retarder systems (e.g., systems containing C110/XS5118 or C105).
  • C104 is compatible with C303 GAS-TIGHT system at temperatures up to 177°C (350 °F) under conditions that depend on the cement brand and the dispersant.
  • Must not be used with XS5118 retarder aid or any other boric acid.
  • Used to optimize thickening time at temperatures ranging from 104 °C to 149 °C (220 °F to 300 °F) BHCT in cement systems.
  • Upper temperature limit can be extended to 177 °C (350 °F) by combining C105 with C510 or to 204 °C (400 °F) by adding XS5118.
  • Due to its chemical composition and characteristics, C105 should not be used below 104 °C (220 °F) BHCT. At lower temperatures, C102 and C103 are the recommended retarders.
  • Has a mild dispersing action in cement slurries which facilitates turbulent-flow displacement techniques.
  • Very economical as low concentrations (less than 1 %) are normally required to adequately extend the thickening time.
  • Can be used in cement slurries prepared with fresh water or salt water. Salt concentrations may range from 3 % (seawater) to 37 % (salt-saturated water). C105 is however not as effective as C100 in salt saturated cement slurries. C105 is usually used in the ratio 0.1 to 1.0% BWOC.
  • It provides the following benefits:
    • Retards cement thickening at high temperatures.
    • Low retarder concentrations are adequate for most jobs.
    • Effective in conditions that are too severe for other retarders such as C102 and C100.
    • Predictable thickening time.
    • Has less effect on cement compressive strength development, especially at the top of a long cement column.
    • Compatible with most cement additives.
    • Helps extend pumping times.
    • Allows improved displacement rates.
  • A liquid synthetic retarder that can be used optimize thickening times at temperatures ranging from 60 °C to 127 °C (140 °F to 260 °F) BHCT. This BHCT limit can be extended to 191 °C (375 °F) when C108 is used in conjunction with a retarder- aid such as XS5118 Boric Acid.
  • Effectively retards all API cements and is compatible with all cement additives. It has a slight dispersing action with most cements which results in mild thinning of the cement slurry.
  • Used in slurries prepared with either freshwater or seawater.
  • Easily dispersed in the cement slurry mix water and helps early compressive strength development at top of liner temperatures.
  • A liquid synthetic retarder used to optimize thickening times at temperatures in the range 104 °C to 204 °C (220 °F to 400 °F) BHCT. 
  • Effectively retards all API cements and is compatible with all cement additives. It has a slight dispersing action with most cements which results in some thinning of the cement slurry. 
  • Used in slurries prepared with either freshwater or seawater.
  • Provides consistent and predictable retardation in cement slurries.
  • Has a constant retarder response from 220 °F to 400 °F. 
  • Easily dispersed in cement slurry mix water and helps early compressive strength development at top of liner temperatures.
  • Powdered  version of C108 synthetic retarder.
  • A synthetic retarder used to optimize thickening times at temperatures ranging from 60 °C to 127 °C (140 °F to 260 °F) BHCT. This BHCT limit can be extended to 191 °C (375 °F) when used in conjunction with a retarder-aid such as XS5118 Boric Acid.
  • Effectively retards all API cements and is compatible with all cement additives. It has a mild dispersing action with most cements which results in slight thinning of the cement slurry.
  • Used in slurries prepared with either freshwater or seawater.
  • Powdered version of C110 synthetic retarder.
  • Used to optimize thickening times in cement systems at temperatures ranging from 104 °C to 204 °C (220 °F to 400 °F) BHCT.
  • Effectively retards all API cements and is compatible with all cement additives. It has a slight dispersing action with most cements which results in mild thinning of the cement slurry.
  • Used in slurries prepared with either freshwater or seawater.
  • C402 Ceramic MicroSpheres are composed of microspheres of aluminosilicate with a narrow particle size range around 120 microns, and a specific gravity around 0.75 kg/L. 
  • The narrow particle size enables the blending of the material with cement to form a slurry with densities as low as 9.0 ppg. 
  • Since the material is hollow, increased pressure and excessive shear increase the amount of the broken spheres, resulting in higher slurry density after placement. 
  • The Ultra-Light-Weight Cement designed with C402 Ceramic MicroSpheres has improved stability and is effective up to 5,000 PSI pressure. 
  • C402 is also the preferred method for extending GasTIGHT systems since it allows low density without increasing slurry porosity
  • Solution for cementing low pressure zones where all other systems fail.
  • Can be designed for densities as low as 8.5 ppt without compromising the compressive strength. The mixed slurry shows a high level of stability with no separation of the lightweight material. Furthermore, the slurry has low rheology parameters allowing placement under low friction pressure conditions.
  • Shows high resistance to crushing under extreme pressure which allows the slurry to maintain its designed density under down hole conditions.
  • Can be mixed with C080 fiber LCM material to provide an effective cure to severe lost circulation. It can be used at temperatures ranging from 70 °F to 450 °F. C403 can bear a down hole pressure of up to 10,000 psi which is more than twice the limit of normal light weight material.
  • Extender used to produce economical, low density cement slurry. When cementing pipe in many types of wells, it usually is desirable to place a long column of cement in the annulus up into the last string of pipe, or back to the surface. The use of a neat cement slurry to fill this column is, in most cases, impractical. Pumping large quantities of neat cement is uneconomical as high‐strength is required only at the very bottom of the casing. Therefore an extended cement slurry is pumped to fill most of the annulus, followed by a higher strength, higher density, neat cement slurry to fill the area around the bottom of the pipe. This extended, lower density slurry also helps reduce the hydrostatic head of a long slurry column and prevents lost circulation across pressure‐sensitive zones. 
  • C400 is a liquid extender allowing slurries to be mixed with freshwater or seawater at densities as low as 11.4 ppg.
  • Used as a liquid substitute for blended or pre‐hydrated bentonite but gives the advantage of shorter thickening times than bentonite slurries, especially at low temperatures and low densities.
  • Clay mineral that has the unusual but useful property of expanding several times its original volume when placed in water. This increases the slurry’s viscosity and its ability to suspend solids. 
  • Can be added in concentrations as high as 20 % BWOC. Slurry density quickly decreases with increasing Bentonite concentration. However, at higher concentrations, the compressive strength is compromised.
  • Mineral composed of ultra- fine, amorphous, glassy spheres of silicon dioxide (SiO2). The large surface area (21 m2/g) and high content of amorphous silicon dioxide (89-90%) give C060 superior pozzolanic properties. The micro-silica reacts with the calcium hydroxide given off during cement hydration to form more of the calcium-silicate-hydrate (C-S-H) crystal structure that binds cement. This increases the compressive strength of the set cement.
  • These specific particle characteristics provide C060 with a number of operational benefits such as:
    • Zero free water
    • Low fluid loss
    • Low viscosity
    • Early strength development
    • High compressive strength
    • Improved bonding
    • Stable cement slurry as low as 11.00 ppg
    • Corrosion resistance
    • Reacts while cement hydrates to gives better strength and lower permeability
  • Increases the compressive strength of set cement to exceed the normal API specifications. High water adsorption combined with the super pozzolanic reaction of the silicon dioxide particles (90%) enhances the compressive strength. Higher compressive strength, especially in lightweight cement, reduces the need for a different tail cement.
  • The interstitial surface tension created by C060 and the particle packing in the slurry aids in the suspension of other materials, particularly larger and heavier particles, such as densifiers and silica flour.
  • Prevents sedimentation in adverse cases such as lightweight cements and horizontal cementing.
  • Also useful as an additive for gas migration control. With its particle size and excellent suspension properties, it is a good matrix blocking agent. It is also used in lightweight systems to enhance performance.
  • Provides a very stable foam in various cement slurry systems even at densities as low as 6 lb/gal. 
  • Foamed cement slurry with C601 can be generated, circulated, compressed and extended without affecting its stability as long as the foam quality does not exceed 80%. Set foamed cement presents good cohesion when the quality remains below 70%. A compressive strength of 500 psi can be achieved at foam qualities lower than 50%. Above 35% quality, the permeability of foamed cement increases dramatically due to interconnection between bubbles. Foamed cement exhibits good fluid-loss properties and good durability under high-temperature and high pressure conditions.
  • Inert iron oxide mineral with high specific gravity. 
  • Useful as a weighting material because it greatly increase slurry density without adversely affecting the cementing properties of the system. The use of a dispersant is recommended only when it is desirable to reduce the water content. The dispersant should be used sparingly as the thinning action on the slurry may permit separation of the heavier C500. 
  • Although Slurries weighing more than 19 lb/gal can be prepared with C500, we highly recommend that the regional laboratory be consulted for proper slurry design. Additives, such as retarders, can critically affect the viscosity of dense slurries resulting in either settling or mixing difficulties.
  • Heavyweight additive with a high specific gravity and superior flow properties that out‐performs all comparable additives.
  • A self‐stabilizing densifier mainly composed of manganese oxide (>90% Mn3O4). C507 is produced during the manufacture of ferromanganese (FeMn), following reaction at temperatures of 1000‐1750°C.
  • Consists only of divalent and trivalent manganese (Mn[II] and Mn[III]) with no harmful tetravalent manganese (Mn[IV]). Pumpable slurries, up to a density of 22 ppg (2.64 SG) can easily be achieved using C507. The designed slurries will exhibit low rheologies and no settling.
  • Environmentally safe and classified on the PLONOR list.
  • Apart from being a weighting agent, C507 also provides a number of additional benefits:
    • Improved slurry stability.
    • Can be pre‐mixed with water.
    • Low rheology slurries.
    • Non abrasive additive.
    • Effective tracer material.
    • Non‐magnetic densifier.
  • Have very strong red‐brown color. This feature imparts the additional benefit of use as a colored tracer ideal for kick‐off plugs.
  • Prevents sedimentation in adverse cases such as lightweight cements and horizontal cementing.
  • Gives cement slurries lower rheologies and improved mixability. This means lower friction pressures and lower critical rates for turbulence.
  • C200 finds the following applications in cement slurry design:
    • Primary cement slurry placement in turbulent flow.
    • Primary cement slurry placement at minimal dynamic pressures (in the presence of a potential lost circulation zone).
    • Cementing operations involving small diameter tubulars.
    • Slurry viscosity reduction to improve pumpability.
    • Reduced water slurries.
  • The main chemical component of C200 is naphthalene sulphonate condensate. The temperature range (BHST) is up to 400°F. It is compatible with all cementing additives and can be used in salt solutions up to 18% BWOW. Salt water requires higher concentrations than needed in fresh water. In addition to being an efficient dispersant C200 provides excellent fluid loss control.
  • Normally dry-blended with the cement but can be added directly to the mix water if required.
  • A water solution of C200.
  • As with C200, it provides cement slurries with lower rheologies and improved mixability. This means lower friction pressures and lower critical rates for turbulence. C
  • Applications are similar to C200, however, C201 was developed to provide greater flexibility in areas where dryblending facilities are not available.
  • Can be used with salt saturated systems up to approximately 18 % BWOW salt solutions. In slurries containing 18 % BWOW salt or greater, C201 provides excellent fluidloss control in addition to being an efficient dispersant.
  • Non-retarding powder dispersant.
  • Used in cement slurries with or without salt or containing latex for anti gas migration purposes. It also enhances fluid loss control with most conventional fluid loss additives.
  • On its own,  enhances rheological properties thus improving flow characteristics.
  • Can be utilized at temperatures as high as 450°F BHCT. It has a minimal retarding effect on cement slurries and may be considered as the more effective dispersant for this situation.
  • Effective in providing slurry dispersibility above 85°C (185 °F) and up to 450 °F.
  • Low to mid temperature range polymer that is dry blended with cement powder or added to the mix fluid prior to preparation of the cement slurry. C300 is a mild-retarding fluid loss agent at BHCT less than 150°F.
  • Depending on the cement type and the thickening time desired, C300 may require the use of an accelerator at low temperatures or at low densities when mixed with fresh water. The fluid loss control performance of C300 is improved when used in conjunction with dispersants and most retarders.
  • Fluid-loss control agent designed for use in cement slurries prepared with fresh water, salt water and seawater. It is designed to control the rate of water loss from cement systems used in both primary and squeeze cementing operations.
  • Can be used with any brand of cement.
  • It can be used in the temperature range of 70 to 250°F but exhibits a retarding effect at the lower end of this range and at temperatures below 150 °F.
  • C303 additive is an aqueous dispersion of solid polymer particles. The dispersed polymer particles block pore spaces between cement grains reducing permeability and restricting movement of gas through the matrix. When the latex beads contact an exposed gas-liquid interface they coalesce and form a coherent, low permeability plastic film. This acts to block migration of gas and fluids into the cement. For this mechanism to occur, gas must enter the latex-based slurry. In addition, potential migration is reduced due to the improved bonding to casing and formation interfaces and excellent fluid-loss control. C303 is a liquid additive for cement slurries and is designed to give low fluid loss characteristics and to help prevent gas migration into and up to the annulus. The active component is a synthetic latex which is compatible with most other additives.
  • Aqueous based Latex polymer that is blended into the mix water prior to preparation of the cement slurry.
  • Has a mild-retarding effect when used alone below 125°F BHCT. Depending on the cement type and the thickening time desired, C303 may require the use of an accelerator at low temperatures or low densities when mixed with fresh water.
  • The recommended accelerator is sodium silicate C400.
  • The fluid loss control performance of C303 is improved when used in conjunction with dispersants and most retarders. The use of dispersant alone is sufficient to provide retardation up to about 150°F BHCT. Typically, the addition of a retarder is required above 150°F.
  • The recommended concentration of C303 depends on the slurry density as well as the bottom hole static temperature (BHST) and it ranges between 1.0 – 3.5 gallons per sack of cement (gps) to achieve less than 50 ml API fluid loss. At BHCT (Circulating Temperature) above 200°F, C020 latex stabilizer should be used in conjunction with C303 to extend its temperature application. It is usually used at around 5% of the C303 Latex loading depending on BHCT. Lab testing is required to establish the optimum ratio.
  • Used for gas migration prevention at temperatures ranging from 70 °F up to 350 °F without the need for a HT stabilizer. The C303N is a liquid, anionic cement fluid loss additive that provides highly effective fluid loss control.
  • Used in a variety of cement slurry systems due to its dispersible characteristics that impart a very low rheology.
  • In addition, it is used as an effective gas migration control additive due to its excellent fluid loss control, right angle set property and gas entrapping property.
  • Used in the formulation of Micro Fine Cement MFC, Ultra-Light Cement ULC, Light Cement LC, Heavy Weight Cement HWC, as well as normal density cement. It is also compatible with salt systems to a salt concentration of 40% C303N dosage rates vary from 0.2 to 1.0 gallon per sack of cement. In order to achieve optimum fluid loss control, slurry should be tested to determine the proper dosage. A fluid loss values as low as 15 cc/30min can be achieved with good slurry rheology and no settling.
  • A low to high temperature range polymer that is dry blended with cement powder or added to the mix water prior to preparation of the cement slurry.
  • Non-retarding fluid loss agent. The non-retarding property of C304 reduces the need for accelerators at low temperatures or with lightweight cement slurries.
  • The fluid loss control performance of C304 is improved when used in conjunction with dispersants and most retarders.
  • A low to high temperature range polymer that is added to the mix water prior to preparation of the cement slurry.
  • Non-retarding fluid loss agent. The non- retarding property of C304L reduces the need for accelerators at low temperatures or with lightweight cement slurries.
  • The fluid loss control performance of C304L is improved when used in conjunction with dispersants and most retarders.
  • A wide temperature range polymer that is dry blended with the cement powder or added to the mix water prior to preparation of the cement slurry.
  • Slightly retarding fluid loss agent.
  • Bi-functional additive that is effective both as a retarder and fluid loss control agent.
  • Used as a retarder on wells with bottom hole circulating temperatures (BHCT) of 150°F to 225°F. Fluid loss control can be achieved with slurries at normal densities or extended with bentonite or chemical extenders.
  • A fluid‐loss control agent designed for use in cement slurries prepared with fresh water or brine solution. It is a liquid additive which is added to the mix water. C305L is suited to squeeze applications with very low fluid loss values.
  • Designed to control the rate of water loss from cement systems used in both primary and squeeze cementing operations down to 25 ml/30min.
  • Can be used with any brand of cement and in the temperature range of 40 to 400°F. It has also a retarding effect at low temperatures.
  • At temperatures below 100 °F, high C305L concentrations exhibit a retarding effect. In applications where a 4 to 6 hr working time is desired, such as in the hesitation squeeze technique, very low concentration of retarder is normally needed to depths of 6000ft. If high early strengths are desired at temperatures above 100 °F, calcium chloride can be added.
  • Has a dispersing effect which minimizes the chances for gelation. 
  • Mostly used with an anti-settling agent to control settling of cement grains.
  • Stabilizer for use with C303 GasTight.
  • By increasing the stability of C303 latex at high temperature, C020 largely diminishes the risks of premature gelation for any latex‐cement slurry. Moreover, C020 has no specific effect on the thickening time, prevents ‘false setting’ due to gelation, provides a ‘right‐angle set’ and improves the cement setting hardness.
  • Since C020 does not harm any cement properties, overdosing cannot lead to job failure but under dosing could lead to drastic problems during the pumping operation.
  • Optimized in the laboratory through thickening‐time testing, so that the cement slurry does not gel up at 100 Bc but sets and hardens in a minimum period of time.
  • Pale colored liquid which is used in conjunction with C303 to extend its operational temperature to 300°F. The minimum recommended concentration of C020 is 4% by volume of C303. This should however be verified in lab testing as it may vary with well conditions and desired performance.
  • C010 and C011 are used in the mix water to act as antifoam and prevent foam generation during the mixing process.
  • Can be added directly to the slurry after foam is generated to act as a de-foamer. Foam can be risky to the continuation of the mixing process as it will affect the performance of the pumps creating cavitation which may lead to equipment damage.
  • C030 Silica Flour is a cost effective alternative usually added at a typical concentration of 35% BWOC to counter the set cement compressive strength retrogression at high temperatures. It also provides higher early compressive strength for the set cement.
  •  C031 Silica Sand is a cost effective alternative usually added at a typical concentration of 35% BWOC to counter the set cement compressive strength retrogression at high temperatures. It also provides higher early compressive strength for the set cement.
  • Bridging material that forms an interlocking net over the pores or fractures and blocks the other particles in the fluid from passing through. 
  • When added to the slurry and pumped downhole, form a mat‐like bridge over the fractures and help create the required filter cake. 
  • Inert to all cement systems. Therefore, they can be added to the cement slurry continually, without affecting cement properties. This allows the fibers to be used only in the portion of the slurry which is designated to be placed across the open-hole section where losses are expected to occur. 
  • Typically used at a concentration of 0.5 ‐ 2.5 lbs/bbl of slurry depending on the type of job and severity of losses.
  • C351 HCS Agent consists of an extremely fine, amorphous, non-crystalline type of silicon dioxide. It has surface area of less than 80m2/gm (C351-80), 500m2/gm (C351-500) or 750m2/gm (C351-750). After further processing, C351 is produced as a liquid.
  • Works exceptionally well as a stabilizer, a durability enhancer, an accelerator and a strength developer. It produces extremely stable, fluid loss-free cement slurries without free water. Additionally, at higher temperatures in deep to ultra-deep well cementing applications, C351 enhances early compressive strength.
  • C351 Colloidal particles interact with the free lime (calcium hydroxide) – created during cement hydration – to create calcium silicate binders. These binders produce a cohesive gel structure that enhances cement density, reinforces the structure between cement grains and eliminates free water.
  • The low specific gravity of C351 produces lightweight slurries that allow greater control over injection. It also improves strength and shortens setting times. The interstitial surface tension created by C351 prevents other solids, including cement particles, from settling.
  • Used with other extenders such as ceramic hollow spheres to create ultra lightweight, high quality, homogeneous cement slurry.
  • The C351 suspension in water is used to improve performance of set cement. It usually reacts while cement hydrates to gives better strength and lower permeability.
  • Another application of C351 is as an additive for gas migration control where, due to its particle size and excellent suspension, it acts as a good matrix blocking agent.
  • Designed for separating cement slurries and water based drilling muds. It is compatible with both fluids.
  • Excellent fluid loss control at low and high temperatures. The filter cake that develops greatly reduces fluid leak off into formations where the mud cake has been mechanically removed by centralizers or scratchers. Ideally, the spacer should be denser and more viscous than the mud but lighter and less viscous than the cement slurry.
  • Can be displaced in laminar or turbulent flow depending on the temperature and pipe configuration.
  • A minimum of 500ft. of annular fill of spacer should normally be used ahead of the cement, and pipe movement should be attempted, where possible, to help achieve maximum mud removal. To achieve the required density, barite is added as a weighting material. Concentrated salt water inhibits hydration of the spacer and may lead to poor properties. Seawater can be used but hydration time is slightly longer and fluid loss tends to rise. With oil based muds in particular, it is a good practice to assess the compatibility of the mud, cement and spacer under down‐hole conditions prior to running the cement job.
  • The addition of C090 CemFLEX to cement slurry significantly improves the mechanical properties of the set cement in terms of impact resistance and fracture toughness when compared to conventional cement systems. It also improves the tensile strength, although to a lesser extent. CemFLEX system is therefore much harder to drill than any other cement system mixed at the same density. This makes CemFLEX an ideal cement system for kickoff operations in hard to very hard formations. It is the appropriate solution where set cement is submitted to severe dynamic stresses created by drilling, milling and cutting operations. This is achieved through post-addition of C090 CemFLEX to very specific base slurries that must be batch mixed.
  • C090 CemFLEX provides set cement with the toughness needed for cement plug placed in the wellbore to side-track above or to initiate directional drilling operations. The CemFLEX system prevents fissure propagation ensuring the cohesion of the cement sheath even at high deformation. It exhibits very good post-cracking behavior. Tests performed to evaluate the drillability of such system have shown that CemFLEX cement is much harder to drill than any other non-reinforced cement.
  • C403 Micro-fine cement can be used at temperatures ranging from 70°F to 450°F. C403 can withstand downhole pressures of up to 10,000 psi which is more than twice that of normal lightweight material.
  • Sprint Micro-fine Cement (MFC), can be used with Sprint’s wide temperature range C305 FLAC to provide a micro-fine cement system with consistent fluid loss control properties over a wide range of temperatures. This property is useful for squeezing through long mud channels.
  • MFC C053 can also be mixed with C303 or C303N GASTIGHT additives to provide a gas tight micro-fine cement system. These systems are excellent for squeezing gas zones or gas percolated channels behind the casing or liner laps. Micro-fine retarder C151 and Micro-fine Retarder/Dispersant C150 can be used with C053 MFC to control thickening time and cement rheology. The C150 and C151 provide thickening time control over a wide range of temperatures from 80°F to 212°F. C403 can also, use conventional retarders and dispersants.

Stimulation Products

Sprint Oil and Gas Services has a large, international network of western and eastern based chemical additive suppliers. With such a vast network, we are able to provide optimum client solutions and deploy our technology faster and more effectively than our competitors given our access to a wide range of ground-breaking technologies in the market.

  • Environment friendly acid corrosion inhibitor designed for use in almost all acidizing systems.
  • Compatible with most stimulation and fracturing additives.
  • Provides effective protection from corrosion in the temperature range 100°F to over 300°F. It is effective with both HCl and organic acids.
  • Synergistic blend of organic nitrogen compounds, acetylenic alcohols and surfactants.
  • High temperature, acid corrosion inhibitor used primarily in well stimulation at temperatures up to 400°F when used in conjunction with S200.
  • S1010 is a synergistic blend compound.
  • High temperature acid corrosion inhibitor used primarily in well stimulation using viscoelastic surfactants for temperatures up to 400 °F when used in conjunction with S200.
  • S103 is an aliphatic nitrogen inhibitor which effectively retards acid corrosion during oil well acidizing operations.
  • Effectively retards acid corrosion in all hydrochloric and hydrochloric-hydrofluoric acids. The addition of 0.3% to 6.0% of S103 can reduce the corrosion rate by up to 95%.
  • An aliphatic nitrogen inhibitor, which effectively retards acid corrosion during oil well acidizing operations.
  • Low to mid temperature acid corrosion inhibitor used primarily in well stimulation projects at temperatures up to 300 °F. The addition of 0.1% to 2.0% of S102 can reduce the corrosion rate by up to 95%.
  • An aliphatic nitrogen inhibitor which effectively retards acid corrosion during oil well acidizing operations, pickling and acid cleaning.
  • Specially formulated to inhibit corrosion of organic acids such as sulfuric, sulfamic, citric, formic, acetic and phosphoric acids at temperatures up to 300°F. S104 is the corrosion inhibitor of choice for all CarboCLEAN formulations.
  • Synergistic blend of organic nitrogen compounds and surfactants. It is a high temperature acid corrosion inhibitor, used in conjunction with S200 acid inhibitor aid, primarily in well stimulation projects at temperatures up to 325°F.
  • Provides corrosion inhibition by forming a protective layer on metal surface.
  • Typically used for inhibiting metallic acids such as HCl and sulfuric acids as well as organic acids such as formic and acetic acids.
  • Can also be used to inhibit CarboCLEAN solutions.
  • Synergistic blend of organic acid compounds. It works as a corrosion inhibitor aid for S101.
  • Used to extend the working temperature range of most corrosion inhibitors such as S100, S101, S102, S103 and S104.
  • Increases the efficiency and performance of corrosion inhibitor S101 at high temperatures. S200 is recommended at up to 7.5% HCl with temperatures above 250 °F. It is also used at temperatures as low as 200°F with HCl and HF based fluids.
  • S260 chelating agent prevents precipitation of ferric hydroxide in spent hydrochloric acid. Ferric hydroxide begins to precipitate as a voluminous gelatinous material as the pH of hydrochloric acid rises above 2.2. Ferrous hydroxide however, does not precipitate until pH is above 7.7. Spent acid rarely has pH above 5.5. The concentration of complexing agent required depends on the amount of ferric iron expected to dissolve in the acid.
  • An anionic liquid solution containing 40% S260 (5 lbm of S260/gal).
  • An iron-sequestering agent designed for use in the acid treatment of wells. During acid treatment of wells, containing significant quantities of iron, live acid puts much of the iron into the solution. As the acid spends, ferrous ions again become insoluble and will precipitate unless an iron chelating agent is present in the acid mixture.
  • Concentrated aqueous solution of technical grade tetra-sodium salt of ethylene-diamine-tetra-acetic (EDTA) acid.
  • Functions as an iron sequestrant by forming a soluble complex with the divalent metal ion utilizing a strong chelating action.
  • Essentially odorless and soluble in freshwater and brine.
  • Iron-reducing agent specifically designed for use in non-damaging acid (NDA) systems. NDA system reduces fluid loss during acid fracturing treatments.
  • Iron-control additive used at a concentration of 10lb/1000 gal will reduce up to 6,000ppm of ferric iron.
  • Additional amounts of S262 can be used if more iron and iron sulfide deposition is encountered to ensure that iron is retained in a soluble form.
  • Ferric hydroxide damages formation permeability and is a potential problem during any acidizing treatment.
  • Blend of iron sequesters that prevents gelatinous ferric hydroxide precipitation.
  • Useful in a wide variety of application where iron control is required.
  • Controls the pH of the spending acid to help prevent precipitation of iron in the acid. The additive concentration can be doubled when treating formations containing Siderite or a high concentration of soluble iron.
  • S507 is an efficient reducing agent that converts ferric ions to ferrous ions. It is a very effective additive that prevents precipitation of ferric hydroxide from spent acid.
  • Iron is dissolved during any acidizing treatment. The source of iron could be steel acid transport tanks, treating lines, pumps, tubing, casing and iron-containing minerals in the formation. Upon spending of the acid, the dissolved iron may precipitate as ferric hydroxide [Fe(OH)3].
  • A mixture of Iron chelating agent S530 and stabilizing agent XS5119 can be used to prevent precipitation and stabilize the spent-acid solution.
  • S530 and XS5119 prevent ferric hydroxide precipitation at low to moderate temperatures.
  • GLDA and MGDA-based chelating agent which dissolves minerals and controls metal ions reactivity.
  • Reduces the detrimental effect of metal catalysts and is highly effective in preventing scale formation.
  • Ideal for high temperatures (up to 400°F), expensive metallurgy, sensitive formations and complex well geometry. One of the benefits of this product it its superior HSE profile.
  • S2000 meets the health, safety and environmental requirements, being biodegradable, non toxic and safe to handle. Moreover, it is a cost effective product, suitable for multiple applications; it improves productivity by reducing downtime, maintaining well integrity and lengthening asset life.
  • A multipurpose product that can function as a foaming agent for water or acid and as an acid retarder.
  • An excellent surfactant in water, acid and brines. It provides silt suspension properties and can be used in aqueous or acid foam frac jobs and well clean outs.
  • Creates a very stable xylene-in-acid dispersion with minimum agitation and lower loading rates. The spent acid foam blanket generated by S515 also functions to insulate live acid from acid soluble materials, thereby retarding reaction rates.
  • A highly effective foaming agent designed for use in water, acid or fracturing fluids. It provides high quality foams and good stability as compared to most foaming agents.
  • Enhances flow-back of stimulation fluids and improves oil and gas production by reducing the surface tension of the flow back fluids.
  • Can also function as a flowback additive in completion brines used in water sensitive sands.
  • Designed to enhance the recovery of stimulation fluids and improve gas production. It is a nonionic surfactant used to lower surface tension of water-based fluids. This helps counteract the high capillary pressures characteristic of tight shale gas formations.
  • A water wetting agent which provides great carrying capacity to acids and other fluids for fine particles invading formation matrix.
  • Advanced surfactant formulations allowing for as low as 15 dyne/cm of fluids surface tension.
  • Promotes superior treatment fluids flow back and formation pores cleanout.
  • Can be added to almost all stimulation and fracturing fluids and are compatible with all stimulation additives.
  • Can be added to various brines, spacers and completion fluids to improve cleanout if allowed to enter the formation.
  • A high molecular weight, anionic, AMPS copolymer designed to reduce friction in water based fracturing, acidizing and brine applications.
  • Specially effective in high hardness fluids and in fluids with temperatures of 40° F or less, without the need of an additional activator.
  • Dosage rates vary depending on temperature and fracturing fluid characteristics. It can be batch mixed or added on the fly.
  • A guar derivative gelling agent designed to reduce friction in water based fracturing, acidizing and brine applications.
  • Particularly effective in high hardness fluids and in fluids with temperatures of 40 °F or less without the need of an additional activator.
  • S303-H, cellulose derivative, is used when a very clean fluid is desired.
  • Used to prepare very low residue, water-based gels.
  • Does not develop a filter cake and is not as effective with fluid-loss agents.
  • Nonionic polyacrylamide polymer used as a friction-reducing agent for acid.
  • Can be continuously mixed through a disperser into the acid or may be batch mixed.
  • A liquid polymer that produces smooth, homogeneous gels in 15% and 28% acid using standard field blending equipment.
  • Can also be used as the base fluid for Sprint’s Deep Penetrating Gelled Acid (DPGA) fluid.
  • Nonionic solvent commonly known as Ethylene Glycol Monobutyl Ether.
  • Easily soluble in acid, hydrocarbons or water.
  • Used as a wetting agent and surface tension reducer in acid stimulation.
  • Normally used at a concentration of 10% by vol. of carrying fluid.
  • High concentration and high solubility allows S282 to deeply penetrate the formation with the treating fluid as compared to other surfactants.
  • An effective Xylene solvent for a broad range of “paraffins” including highly asphaltic paraffin deposits as well as those more paraffinic in nature. Paraffin is a descriptive term used in the oil field to describe heavy crude-oil deposits such as asphaltic tars, waxes (true paraffins) and other sludge-like hydrocarbon compounds. These substances can form deposits which may restrict fluid flow in an oil well.
  • Applied directly as paraffin solvent to clean the formation and well equipment.
  • Particularly beneficial when used as a pre-flush ahead of acid treatments in formulations with mutual solvents and especially in combination acid hydrocarbon solvent dispersions.
  • A toluene solvent particularly effective for highly asphaltic “paraffin” deposits as well as those more paraffinic in nature. “Paraffin” is a descriptive term used in the oil field to describe heavy crude-oil deposits such as asphaltic tars, waxes (true paraffins) and other sludge-like hydrocarbon compounds. These substances can form deposits which may restrict fluid flow in an oil well.
  • Applied directly as paraffin solvent to clean the formation and well equipment.
  • Particularly beneficial when used as a preflush ahead of acid treatments, in formulations with mutual solvents and especially in combination acid hydrocarbon solvent dispersions.
  • A flake benzoic acid that is soluble in oil and slowly soluble in water, but has limited solubility in acid.
  • Recommended for gas, oil and water-injection/disposal wells.
  • A flake benzoic acid that is soluble in oil, slowly soluble in water, but has limited solubility in acid.
  • May be used at fluid temperatures up to 275 °F (135 °C).
  • Recommended for gas wells, oil wells and water-injection/disposal wells. It is recommended for use when the type of production fluid is unknown.
  • Dissolves in oil or water but the solubility is much higher in oil than water. A water-based fluid should therefore be used as a carrier.
  • A cationic, high molecular weight, polyacrylamide copolymer that viscosifies hydrochloric (HCl) acid for use in carbonate acidizing treatments.
  • Main component of a cross-linked acid system. It is used in combination with S410, S411 and an iron control agent to develop a self diverting, cross-linked acid system. The cross-link forms as the acid spends and the pH rises. The cross-linked acid greatly reduces fluid loss to the existing permeability. This creates longer, higher conductivity fractures in fracture acidizing treatments or improved etching in matrix acid applications.
  • S410 is a low pH solution of a proprietary organic buffer that provides pH control for the S310 cross-linked acid system. As the gelled acid spends and the pH rises to 2.5 – 3.0, S410 temporarily locks the pH in this range to allow for complete cross-link viscosity development.
  • S411 is a low pH solution of a proprietary metal chloride cross-linker for S310 cross-linked acid system. The metal supplies the means for the acid gelling polymer to form longer polymer chains, increasing the apparent viscosity of the cross-linked gel. A cross-linked acid system provides better fluid loss control and diverts live acid to parts of the formation face preventing "wormhole" development.
  • A polymer free acid gelling agent and retarder.
  • Used when acidizing carbonate formations using hydrochloric acid up to 15%.
  • Gives a low initial viscosity upon addition which reduces the friction pressure during pumping.  As the gelled acid starts to react with the calcium in the formation, the viscosity increases dramatically through formation of a worm-like micelle surfactant structure which plugs fissures and wormholes in the formation. This retards the reaction rate of the acid allowing greatly improved acid penetration.
  • Also used to produce NDP (Non-Damaging Pill) gels used as carrier fluids for wellbore cleanup and placing sand/chips plugs. Gel produced by S1000 is homogenous, easy to mix and non-damaging to the formation making it an ideal fluid for use in onshore/offshore oil and gas wells.
  • Completely non-damaging to the formation unlike polymer based gelling agents which can bridge the formation and cause blockages. When the acid containing S1000 is contacted by hydrocarbons produced from the well, the gel breaks down immediately allowing the fluid to be easily recovered.
  • S1001 HT surfactant based gelling agent has a wide range of applications such as HT NDA-S acid system formulation, Non-Damaging Acid Frac (NDA-F) fluid, Non-Damaging Gravel (NDG) packing carrier fluid and Non-Damaging Frac (NDF) base gel.
  • It is important to include S1005 (Breaker) to ensure complete gel structure break down in the absence of hydrocarbons.
  • A highly effective clay stabilizer, designed for use in cross-linked systems.
  • This product finds application in acids, brines, and water-based fracturing fluids.
  • Can be batch mixed or added on-the-fly. In order to achieve optimum results, it is recommended that every fluid be tested to determine the proper dosage of S412.
  • A cost effective clay stabilizer, designed for use in cross-linked systems. It finds application in acids, brines, and water-based fracturing fluids.
  • Highly effective in preventing clay swelling and migration.
  • Can be used in acidizing services to maintain the permeability obtained via matrix services stimulation treatment.
  • When used ahead of fracturing services, F220 stabilizes the undamaged area around the new fracture. It can be applied as part of gravel packing in sand control services.
  • An anionic acid, anti-sludge and non-emulsifying agent.
  • A highly effective surfactant designed to help prevent sludging in acidizing operations. It acts as a chemical barrier between asphaltene particles and acid solutions.
  • Prevents acid solutions from reacting with crude oils and forming an insoluble sludge that blocks channels or reduces permeability.
  • Commonly used in formations that produce asphaltic crude to prevent sludging and loss of well productivity.
  • Water and oil soluble.
  • Highly dispersible in acid.
  • Can be added directly to the acid holding tanks prior to use or on the fly as the treating fluid is being pumped downhole.
  • A liquid, multi-component, nonionic surfactant.
  • Developed to provide non-emulsifying, water-wetting, surface and interfacial tension-reducing properties to stimulation fluids including acids and hydraulic fracturing fluids.
  • Specially effective in limestone reservoirs.
  • Extensive field testing has proven S243 to be a cost-efficient additive for preventing difficult-to treat emulsions, normally generated during acidizing treatments.
  • It can also be used to break existing emulsions.
  • S243 preferentially water-wets sandstone and limestone rock and is compatible with most cationic and anionic additives.
  • S331 is a powdered Ammonium Bifluoride Intensifier / HF agent used to prepare SRA HCl:HF acid. It reacts with HCl to produce HF acid in situ.
  • Used to control the corrosive effects of H2S. H2S may be present in acidizing fluids due to dissolution of sulfide scale or from contact with sour well fluids.
  • Reacts with H2S to form stable compounds removing it from the acid. This product was developed to aid the inhibition of hydrochloric acid (5% to 28%), mud acid (6% HCl + 1.5% to 12% HCl + 3% HF) and special acid systems (SRA, XDA and Clay Acid) in sour environments.
  • Must be used with corrosion inhibitors S101 and S102/S103, at the recommended concentration, in an H2S environment.
  • Methanol is used in alcoholic acid formulations as a mixture of acid and alcohol. The acids usually employed are hydrochloric acid (HCl) or mud acid (HCl + HF).
  • It can also be used with organic acids such as formic or acetic. Alcohol is not intended to replace mutual solvents in most applications.
  • Used for internal gel breaking in cases where no hydrocarbons exits for breaking S1000/S1001/S1002 gel systems. This is typical for water wells treatment or for acid and propped fracturing using Non Damaging Frac (NDF) fluids.
  • S288 is used to produce a meta-stable, acid-in-oil emulsion that retards the action of hydrochloric acid on acid-soluble formation rock. This retarded acid penetrates deeper into the formation in acid fracturing and matrix acidizing applications. The emulsion formed by S288 is not permanent; flowback is therefore free of emulsions.
  • A cationic surfactant developed as an acid emulsifier. It is compatible with acid corrosion inhibitors, HCl acid and the normal hydrocarbons used for this application.
  • Used to raise the pH of a fluid.
  • Used to neutralize live flowing back acids or remaining acid not pumped into the well. After the neutralization, a pH meter or pH paper should be used to determine the pH of the resulting solution. If the pH is still below 7.0 then more S327 should be added until the pH is in the 7.0 - 7.5 range.
  • XS5720 is a strong oxidizing solution designed to restore permeability to formations damaged by non-petroleum organic residues. These residues may be naturally occurring bacterial slimes or gums and polymers which have been introduced into the well.
  • A Polyhydric Alcohol Phosphate Ester (PAPE) based scale and corrosion inhibition product. It is a new generation, scale and corrosion inhibitor which is more environment friendly than the phosphonated carboxylic acids or polymers.
  • Has more than one polyethylene glycol groups introduced into the molecule which greatly improves the scale and corrosion inhibition function of the product. It has good inhibition effectiveness for calcium carbonate, calcium sulfate, barium and strontium scales.
  • Can mix well with polycarboxylic acids, organophoronic acids, phosphates and zinc salts (other inhibitors).
  • Mainly used as scale inhibitor for oilfield and water treatment plants. S600 inhibitor is pumped into a water producing zone where it is attached to the formation matrix by chemical adsorption and returns with the produced fluids at sufficiently high concentrations to avoid scale precipitation.