In oilfield cementing, the setting time of cement slurry is one of the most important parameters affecting operational success. The cement must remain fluid long enough to be pumped from the surface, displaced through the casing, and placed accurately in the annular space between the casing and the formation.

However, it must also be set within a predictable timeframe after placement to develop sufficient compressive strength and form an effective barrier.

Balancing these requirements becomes increasingly difficult as wells reach greater depths and encounter higher formation temperatures. In deep wells, bottomhole temperatures often exceed 120°C to 200°C, dramatically accelerating the chemical reactions responsible for cement hydration.

Under such conditions, standard cement formulations may begin to set far earlier than expected. This rapid thickening can reduce slurry pumpability and increase frictional pressure losses in the wellbore. If the slurry becomes too viscous during pumping operations, it may fail to reach the target zone, resulting in incomplete annular filling or poor displacement efficiency.

Poor cement placement can lead to several long-term operational risks, including gas migration, sustained casing pressure, or formation fluid communication between zones. These issues not only compromise well integrity but can also result in costly remedial cementing operations or production losses.

For these reasons, controlling cement set time is not simply a matter of operational convenience—it is a fundamental requirement for ensuring well safety, structural integrity, and long-term production performance.

Chemical retarders such as boric acid provide engineers with a reliable method to slow down hydration reactions and extend slurry pumpability without sacrificing final cement strength.

High-pressure, high-temperature wells present a unique set of technical challenges that significantly influence cementing design. As exploration moves deeper into complex reservoirs and offshore environments, these challenges are becoming increasingly common in modern drilling programs.

One of the defining characteristics of HPHT wells is the extreme thermal environment encountered during drilling and completion operations. Temperatures exceeding 150°C can accelerate cement hydration reactions to such an extent that conventional cement systems may begin setting within minutes rather than hours.

This rapid setting behavior limits the available time for slurry placement and increases the risk of operational complications during pumping.

Another major challenge involves pressure stability and formation integrity. HPHT reservoirs often require higher-density cement slurries to maintain hydrostatic pressure control and prevent formation fluid influx. However, heavier slurries typically exhibit higher viscosity and shorter pumpability windows, further complicating placement operations.

Additionally, the long casing strings associated with deep wells increase the time required to pump cement from the surface to the target zone. If the slurry begins to thicken prematurely, the pressure required to continue pumping may exceed safe operating limits, potentially damaging the formation or causing equipment stress.

Temperature gradients within the wellbore also create variations in cement hydration rates. While the slurry may remain stable at surface conditions, it can react far more rapidly once exposed to elevated bottomhole temperatures.

These combined factors make precise control of cement hydration kinetics essential in HPHT cementing programs. Retarding agents such as boric acid help address this challenge by slowing down the chemical reactions responsible for cement setting, thereby ensuring adequate pumping time and reliable placement.

To appreciate the role of boric acid in cement systems, it is important to understand the basic chemistry of cement hydration.

Oil well cement is typically composed of Portland cement clinker, which contains several mineral compounds including tricalcium silicate, dicalcium silicate, tricalcium aluminate, and tetracalcium aluminoferrite. When water is added to the cement powder, these compounds undergo hydration reactions that gradually transform the slurry into a hardened solid matrix.

During the early stages of hydration, the slurry remains fluid and pumpable. As chemical reactions progress, the formation of calcium silicate hydrate (C-S-H) and other compounds causes the mixture to thicken and eventually set into a rigid structure.

Temperature plays a critical role in this process. Higher temperatures accelerate the rate of chemical reactions, causing the cement to set faster. While this may be beneficial in shallow wells where rapid strength development is desirable, it can be problematic in deep HPHT wells where longer pumpability windows are required.

Without proper chemical control, accelerated hydration can cause the slurry to lose its flow properties before it reaches the intended placement zone.

Boric acid functions as a cement retarder by interfering with these hydration reactions, particularly those involving calcium ions and aluminates. By slowing down the formation of early hydration products, boric acid delays the thickening process and extends the working time of the cement slurry.

This controlled retardation allows engineers to maintain stable slurry rheology during pumping while still achieving adequate strength development once the cement has been placed.

Boric acid (H₃BO₃) is a weak inorganic acid commonly used in industrial chemistry due to its buffering properties and ability to influence ionic reactions. In oilfield cementing systems, it functions primarily as a set retarder, meaning it delays the rate at which cement hydration reactions occur.

Unlike some organic retarders that rely on complex molecular interactions, boric acid works through relatively straightforward chemical mechanisms involving calcium ion interactions and the stabilization of hydration products. These interactions allow the cement slurry to maintain its pumpable state for a longer duration, even under elevated temperature conditions.

In cement slurry formulations, boric acid dissolves in the aqueous phase and begins interacting with the cement’s mineral compounds, particularly those associated with early hydration reactions. The compound forms complexes with calcium ions present in the slurry, effectively slowing down the formation of hydration products responsible for cement thickening.

This controlled interference with hydration chemistry allows engineers to extend slurry thickening time without significantly altering the overall cement composition. Because boric acid is effective at relatively low concentrations, it can be integrated into cement systems without dramatically changing slurry rheology or density.

Another important characteristic of boric acid is its thermal stability. Many organic retarders lose effectiveness or degrade when exposed to very high temperatures, especially in HPHT wells. Boric acid, however, remains chemically stable across a wide temperature range, making it particularly valuable for deep-well cementing operations where bottomhole temperatures may exceed 150°C.

Its predictable chemical behavior and compatibility with common cement additives have made boric acid a reliable component in cement formulations designed for challenging drilling environments.

Modern oil well cement systems rarely rely on a single additive. Instead, they are carefully engineered blends containing multiple chemical components designed to address specific operational challenges. Boric acid is particularly valuable because it exhibits strong compatibility with many of these additives, allowing it to function effectively within complex cement formulations.

In HPHT wells, silica flour is frequently added to cement slurries to prevent strength retrogression at elevated temperatures. Silica flour reacts with calcium hydroxide to form thermally stable hydration products that maintain compressive strength under high-temperature conditions. Boric acid works well alongside silica flour, allowing both additives to perform their respective roles without interfering with each other’s functionality.

Dispersants are another common additive used to improve slurry flow properties and reduce viscosity. By dispersing cement particles more evenly throughout the slurry, these agents help maintain pumpability and minimize friction during cement placement. Boric acid can be incorporated into dispersant-containing systems without significantly affecting their rheological performance.

Fluid loss control agents are also frequently included in cement formulations to prevent excessive water loss into porous formations. Excessive fluid loss can lead to premature thickening and incomplete cement placement. Boric acid complements these additives by ensuring that hydration reactions remain slow enough to maintain slurry stability throughout the pumping process.

Because of this compatibility with other additives, boric acid can be integrated into highly customized cement systems tailored to specific well conditions. Engineers can adjust additive concentrations to achieve precise control over thickening time, slurry density, and mechanical strength development.

This flexibility is particularly valuable in HPHT wells where multiple operational variables—such as temperature gradients, pressure conditions, and formation characteristics—must be carefully managed to achieve successful cement placement.

The use of boric acid in cement systems provides several operational advantages that directly contribute to the success of cementing operations in challenging environments.

One of the most significant benefits is the ability to extend thickening time without excessively increasing slurry viscosity. Maintaining manageable viscosity levels is crucial for ensuring that cement slurries can be pumped efficiently through long wellbores and complex casing geometries.

Extended pumpability also improves displacement efficiency during cement placement. When the slurry remains fluid for a longer period, it can more effectively displace drilling fluids and fill irregularities in the annular space. This improves the likelihood of achieving a continuous cement sheath capable of isolating formations and supporting casing strings.

Another advantage involves operational safety and reliability. Premature cement setting can lead to equipment damage, stuck pipe incidents, or incomplete cement placement. By controlling hydration reactions, boric acid reduces the likelihood of these complications, helping maintain smooth and predictable cementing operations.

In deep and offshore wells, where logistical costs and operational risks are significantly higher, the ability to maintain stable cement slurry behavior becomes even more critical. Boric acid provides engineers with a reliable tool for managing these challenges while preserving the structural integrity of the final cement sheath.

In high-pressure, high-temperature wells, cementing operations must be designed with exceptional precision. The deeper the well, the greater the thermal stress imposed on cement systems. Bottomhole temperatures in HPHT reservoirs frequently exceed 150°C and in some cases approach 200°C, significantly accelerating hydration reactions within conventional cement slurries.

Under these conditions, cement that might normally remain pumpable for several hours at surface temperature can begin to thicken rapidly once it enters the high-temperature sections of the wellbore. Without the use of effective retarders, the slurry can lose mobility before it reaches the intended annular zone.

Boric acid helps mitigate this risk by delaying the hydration reactions responsible for cement thickening, allowing sufficient time for the slurry to be pumped through long casing strings and placed accurately around the casing.

In offshore wells and deep onshore drilling projects, cement often must travel thousands of meters before reaching the target placement zone. The temperature gradient encountered during this journey means the slurry experiences increasingly aggressive thermal conditions as it moves downward. Boric acid helps maintain a stable hydration rate throughout this temperature transition.

Field experience has shown that cement systems containing boric acid demonstrate predictable thickening time behavior even under elevated temperatures, enabling operators to plan pumping schedules with greater accuracy.

This predictability is crucial for ensuring proper displacement of drilling fluids and achieving complete annular coverage. A well-placed cement sheath forms the structural backbone of well integrity, preventing unwanted fluid movement between geological formations.

Designing cement systems for HPHT wells requires a careful balance of several competing factors. Engineers must consider temperature effects, hydrostatic pressure requirements, slurry density, rheology, and long-term mechanical strength.

Boric acid is incorporated into cement formulations as part of a broader additive package designed to address these complex challenges.

One of the most important considerations is thickening time control. Cement slurries must remain pumpable long enough to allow for placement, but they must also develop compressive strength within a reasonable timeframe after placement to allow drilling operations to proceed.

Boric acid helps regulate the early hydration reactions that determine this thickening window. By delaying the initial chemical reactions within the slurry, it extends the operational pumping period without preventing the cement from ultimately setting and developing strength.

Another design factor involves temperature gradients along the wellbore. Cement slurries often encounter dramatically different temperatures at the surface compared to bottomhole conditions. A retarder such as boric acid must therefore perform reliably across a broad temperature range.

HPHT cement systems frequently incorporate additional additives alongside boric acid. For example, silica flour is often included to prevent strength retrogression in high-temperature environments. Dispersants may be added to control slurry viscosity and improve flow characteristics during pumping.

Fluid loss control agents help maintain slurry stability by preventing excessive water loss into surrounding formations. Together, these additives create a cement system capable of performing reliably in extreme downhole conditions.

Boric acid’s compatibility with these additives allows engineers to design cement systems that maintain both extended pumpability and long-term mechanical integrity.

The ultimate goal of oil well cementing is to establish effective zonal isolation. The cement sheath placed between the casing and the formation acts as a permanent barrier that prevents the movement of fluids between different geological layers.

If cement placement is incomplete or poorly bonded, fluids such as gas, oil, or water may migrate through the annular space, potentially causing serious operational problems. These issues can include sustained casing pressure, cross-flow between formations, or environmental contamination.

Premature cement setting is one of the primary causes of poor cement placement. If the slurry begins to thicken before it has fully displaced drilling fluids or filled the annular space, voids or channels may remain in the cement sheath.

Boric acid helps prevent this scenario by extending the slurry’s pumpability window, allowing it to flow smoothly through the wellbore and fill irregularities in the annulus.

Proper placement ensures that the cement forms a continuous and uniform barrier capable of supporting casing strings and maintaining zonal isolation over the entire life of the well.

In HPHT wells, where extreme temperature and pressure conditions place additional stress on the cement sheath, maintaining strong bonding and structural integrity becomes even more critical.

The controlled retardation provided by boric acid allows cement systems to develop strength gradually and uniformly, reducing the risk of micro-annulus formation or structural weaknesses within the cement matrix.

This contributes directly to long-term well stability, production safety, and environmental protection.

Deepwater and offshore drilling environments present additional logistical and operational challenges for cementing operations. The extended length of casing strings, combined with complex well geometries, increases the time required to pump cement from the surface to the target depth.

In such scenarios, the margin for error becomes extremely small. If the cement slurry begins to thicken prematurely, the entire operation may be compromised.

Boric acid provides a valuable layer of operational security by ensuring that cement systems maintain their fluidity during the critical pumping phase.

The ability to extend thickening time allows operators to perform necessary operational steps—such as displacement, circulation, and pressure monitoring—without the risk of the slurry setting too early.

Furthermore, deep offshore wells often involve significant financial investment. Any failure in cementing operations may require costly remedial work, including squeeze cementing or even sidetracking the well.

By improving slurry stability and placement accuracy, boric acid helps reduce the likelihood of such complications and supports more reliable cementing outcomes in technically demanding drilling environments.

In modern drilling operations, cementing programs must be carefully designed to ensure both operational efficiency and long-term well integrity. As wells become deeper and reservoirs more technically complex, cement additives play an increasingly strategic role in maintaining reliable cement placement and performance.

Boric acid offers several operational advantages that make it particularly valuable in challenging cementing environments.

One of its primary benefits is predictable thickening time control. Unlike some organic retarders that can behave unpredictably at extreme temperatures, boric acid provides consistent retardation performance across a wide range of thermal conditions. This predictability allows engineers to design cement systems with greater confidence, ensuring that pumping schedules remain stable and operational risks are minimized.

Another advantage lies in its chemical stability under HPHT conditions. High temperatures can degrade certain additives, reducing their effectiveness during cementing operations. Boric acid maintains its retarding properties even in elevated thermal environments, making it a reliable component in deep and offshore well cement formulations.

Boric acid also contributes to improved slurry stability. By controlling the early hydration reactions within the cement, it prevents premature thickening and allows the slurry to maintain a uniform rheological profile throughout the pumping process. This helps ensure that the cement flows evenly through the wellbore and fills the annular space effectively.

From an operational perspective, these properties reduce the likelihood of complications such as stuck casing, incomplete displacement, or early cement setting—issues that can significantly disrupt drilling schedules and increase operational costs.

Various chemical retarders are used in oilfield cementing systems, including lignosulfonates, organic acids, and synthetic polymer-based additives. Each of these retarders has specific advantages depending on the well environment and cement design requirements.

However, in high-temperature wells, certain organic retarders may lose effectiveness due to thermal degradation. As temperature increases, their chemical structures may break down, reducing their ability to control hydration reactions.

Boric acid offers a distinct advantage in this regard because of its thermal resilience and stable chemical behavior. Its retarding mechanism relies primarily on interactions with calcium ions and cement hydration products, rather than complex organic molecular structures that may degrade at high temperatures.

Another advantage of boric acid is its compatibility with silica-rich cement systems commonly used in HPHT wells. Since silica flour is frequently added to prevent strength retrogression at elevated temperatures, the retarder used must function effectively within this environment.

Boric acid works well alongside silica-based additives and does not significantly interfere with the development of long-term compressive strength.

Additionally, boric acid can be used in relatively small concentrations, making it efficient from both chemical and operational perspectives. Engineers can achieve significant retardation effects without dramatically altering slurry density or viscosity.

These characteristics make boric acid a practical and dependable option in many high-temperature cementing programs.

The continued development of advanced cement additives reflects the growing importance of chemical engineering in modern oil and gas operations.

As exploration expands into deeper and more complex reservoirs, well conditions are becoming increasingly demanding. High temperatures, extreme pressures, and extended wellbore lengths require cement systems that are capable of maintaining both pumpability and long-term durability.

Chemical additives such as boric acid allow engineers to fine-tune cement hydration reactions and adapt cement systems to specific operational conditions. This level of control helps ensure that cementing operations remain reliable even in challenging environments.

Furthermore, advances in cement chemistry are enabling the development of customized additive packages tailored to specific well conditions. Retarders, dispersants, fluid loss agents, and strength enhancers can be combined in precise proportions to create cement systems capable of meeting the unique demands of each drilling project.

Within this framework, boric acid continues to serve as an important component in cement formulations designed for HPHT wells.

Cementing operations form the structural foundation of oil and gas wells, providing the barriers necessary to isolate formations, support casing strings, and maintain long-term well integrity. In high-pressure, high-temperature wells, controlling cement hydration reactions becomes particularly critical due to the accelerated setting behavior caused by elevated temperatures.

Boric acid plays a strategic role in addressing this challenge by functioning as an effective cement retarder. Through its interactions with calcium ions and hydration reactions, it slows the rate at which cement thickens, allowing the slurry to remain pumpable for a longer period during placement operations.

This controlled retardation helps ensure accurate cement placement, improved displacement efficiency, and the formation of a continuous cement sheath capable of providing reliable zonal isolation.

Its chemical stability, compatibility with other additives, and predictable performance in high-temperature environments make boric acid a valuable tool in modern cementing programs.

As drilling operations continue to push into deeper and more technically complex reservoirs, the importance of advanced cement chemistry will only continue to grow. Retarding agents such as boric acid will remain essential in helping engineers manage hydration kinetics, maintain operational efficiency, and ensure the long-term integrity of wells operating under extreme conditions.

Undensified micro silica, also known as silica fume, is a byproduct of the production of silicon and ferrosilicon alloys. It is made up of ultra-fine, amorphous silicon dioxide particles. While it's used across a variety of industries, undensified micro silica plays a crucial role in oil well cementing applications.

What sets undensified micro silica apart is its incredibly fine particle size. It has a surface area of about 20,000 m²/kg, which is roughly 100 times finer than cement particles. This makes it highly reactive and perfect for enhancing cement slurry performance.

Unlike densified micro silica, which is agglomerated for easier transportation and storage, undensified micro silica remains in its fine, fluffy form, allowing for better dispersion and reactivity when added to cement.

Oil and gas wells are subject to some of the harshest environments imaginable. The cement used to isolate zones and secure casing must withstand extreme pressures, high temperatures, corrosive chemicals, and shifting geological formations.

Undensified micro silica improves several aspects of cement performance:

• Reduces Permeability: The fine particles fill in the tiny voids in the cement matrix, significantly reducing its permeability.

• Improves Strength: It reacts with calcium hydroxide to form additional calcium silicate hydrate (C-S-H), which gives cement its strength.

• Resists Chemical Attack: It improves the resistance of cement to sulfates, chlorides, and other aggressive agents.

• Prevents Gas Migration: It creates a denser cement sheath, reducing the chance of gas migration post-cementing.

Here's a snapshot of the key properties of undensified micro silica used in oil and gas cementing:

These numbers are more than just data points. They define the quality, consistency, and efficiency of micro silica in oil well cementing applications.

Cementing ensures that different zones in the formation are isolated, casing is properly supported, and the wellbore is shielded from corrosive fluids. The inclusion of undensified micro silica in the cement slurry significantly enhances its overall performance:

• Increased Compressive Strength
  Micro silica reacts pozzolanically with calcium hydroxide (CH), a byproduct of cement hydration, to form additional calcium silicate hydrate (C-S-H) gel. This secondary reaction boosts the microstructure of the set cement, resulting in much higher compressive strength. This is critical in maintaining well integrity under dynamic loads and thermal fluctuations.
  
  

• Reduced Free Water Content
  The ultrafine particles fill in gaps between larger cement grains, improving particle packing density. This minimizes the amount of free water in the slurry, which is crucial for eliminating weak zones that can cause poor bonding and fluid migration.
  
  

• Improved Rheology and Pumpability
  Despite lowering water-to-cement ratios, micro silica improves the flow properties of the slurry, making it easier to pump. This results in more efficient placement, better zonal coverage, and minimal fluid loss.
  
  

In complex wells, such as high-pressure, high-temperature (HPHT) applications, these enhancements make micro silica a non-negotiable additive in the cementing recipe.

Lightweight cements are indispensable when drilling through low-pressure, fractured, or depleted formations. However, traditional lightweight cements often compromise on strength and durability.

Undensified micro silica addresses these limitations:

• Enhanced Strength-to-Weight Ratio
  Even with reduced density, micro silica enhances the structural integrity of lightweight cement. Its pozzolanic reaction ensures the matrix remains strong, reducing risks of failure in fragile formations.
  
  

• Low Permeability for Better Zonal Isolation
  Micro silica reduces the permeability of set cement by filling capillary pores and microvoids. This tighter matrix limits fluid ingress, protecting the formation and wellbore from crossflow and fluid losses.
  
  

Deepwater and HPHT wells are defined by high pressures (often exceeding 15,000 psi) and temperatures that can soar above 300°F (150°C). These environments demand cement systems with exceptional mechanical and chemical resilience.

Undensified micro silica brings key benefits:

• Thermal Stability at Elevated Temperatures
  Cement slurries containing micro silica exhibit high thermal resistance, retaining compressive strength and elasticity even under prolonged exposure to heat. This makes them ideal for deep and ultra-deep well applications.
  
  

• Resistance to Aggressive Formation Fluids
  Saline, acidic, or CO₂-rich environments can degrade ordinary cement. Micro silica densifies the matrix, reducing permeability and making the cement less susceptible to chemical attack.
  
  

• Improved Elasticity
  High elasticity reduces the risk of micro-annulus formation, especially when thermal expansion or casing movement occurs. Micro silica imparts flexibility to the set cement, helping it accommodate mechanical stresses without cracking.
  
  

In these frontier operations, micro silica isn’t just a performance enhancer—it’s a safeguard against failure.

Gas migration is one of the most dangerous risks during well cementing. It occurs when formation gas invades the cement column before the slurry has developed sufficient strength to resist intrusion.

Micro silica plays a preventative role by:

• Creating a Dense Cement Matrix
  The extremely small particle size of micro silica (often <1 µm) allows it to fill voids and form a more compact, impermeable structure, limiting pathways for gas movement.
  
  

• Accelerating Initial Set and Strength Gain
  Micro silica contributes to early strength development by accelerating the hydration process. This shortens the window during which gas can migrate into the unset slurry.
  
  

• Enhanced Gel Strength Development
  Rapid gel strength build-up enables the cement to resist gas influx at earlier stages, effectively sealing off annular space before the cement fully hardens.
  
  

By minimizing the risk of gas migration, micro silica directly contributes to safer drilling operations and better environmental compliance.

Micro silica’s true strength lies in its versatility. It can be seamlessly integrated into a wide variety of cement formulations, making it suitable for different drilling environments and operational goals.

• Retarders for High-Temperature Control
  In HPHT applications, controlling the set time is crucial. Micro silica works well with retarders, ensuring that cement remains pumpable while still benefiting from strength enhancements.
  
  

• Dispersants for Improved Flowability
  To maintain good rheology without increasing water content, dispersants are added to reduce slurry viscosity. Micro silica complements these agents by improving flow characteristics while maintaining a tight particle distribution.
  
  

• Weighting Agents for Density Customization
  Whether it's barite, hematite, or other heavy materials, micro silica mixes well without destabilizing the slurry. Engineers can increase or decrease density as needed without sacrificing strength or durability.
  
  

This broad compatibility means micro silica can be used across the full spectrum of cementing operations—from shallow surface casing jobs to deep reservoir completions.

With the industry under increasing pressure to reduce its carbon footprint, micro silica offers some sustainability advantages:

• Byproduct Utilization: As a byproduct of silicon alloy manufacturing, it contributes to waste reduction.

• Enhanced Cement Durability: Longer-lasting wells mean fewer repairs and workovers, lowering overall emissions.

• Reduced Water Requirement: Better particle packing allows for lower water content in the slurry.

These factors make undensified micro silica not only an effective additive but also an environmentally responsible one.

At Trident Energy International, we specialize in delivering high-purity, undensified micro silica engineered for critical oil well cementing applications. Our product undergoes rigorous quality control to ensure optimal particle size distribution, pozzolanic activity, and consistency—making it the preferred choice for challenging environments such as HPHT wells, deepwater operations, and gas migration zones. Backed by deep industry expertise and a commitment to technical excellence, we help our clients achieve superior cement integrity, enhanced durability, and long-term well performance. When it comes to oilfield-grade micro silica, Trident Energy International brings you the best version—reliable, performance-driven, and globally trusted.

Undensified micro silica has come a long way from being an industrial byproduct to becoming a key performance enhancer in oil well cementing. Its ability to increase strength, reduce permeability, prevent gas migration, and improve durability makes it an irreplaceable material in the oil and gas sector.

Whether you're drilling onshore or offshore, dealing with HPHT conditions, or cementing shallow wells, undensified micro silica offers a versatile, reliable, and cost-effective solution.

As the industry continues to evolve with a focus on safety, performance, and sustainability, additives like undensified micro silica will only grow in importance.

For oilfield professionals, understanding how to leverage this powerful material could be the difference between a well that lasts decades and one that fails prematurely. The future of oil well integrity might just lie in a handful of silica dust.

Yes, it is generally safe but should be handled using standard industrial hygiene practices. Dust masks and protective gear are recommended.

Absolutely. Undensified micro silica has proven effective in both environments.

It varies, but typically ranges between 5% to 15% by weight of cement (BWOC).

If stored properly in dry conditions, it can be used for extended periods without significant degradation.

When used with proper dispersants, it actually improves the rheological properties of cement slurries.