Process stage and chemical function map

Process stage	Typical chemical functions	Main selection inputs
Drilling fluid system	Viscosity, fluid loss, shale control, weighting, pH, lubrication and contamination treatment	Well design, formation, mud type, temperature and fluid properties
Cementing and completion	Retardation, acceleration, fluid loss, spacer, brine control and cleanup	Well temperature, pressure, fluids, metallurgy and job programme
Well and flowline production	Corrosion, scale, wax, hydrate, foam and H2S control	Fluid composition, temperature, pressure, flow and material
Separation and crude treatment	Demulsification, foam control, solids wetting and water clarification	Crude, water cut, temperature, shear and residence time
Produced water	Oil removal, scale, corrosion, bacteria and oxygen control	Discharge or injection requirement, water chemistry and solids
Storage and export	Corrosion, sludge, vapour and quality control	Tank condition, residence time, product specification and handling

Drilling chemicals

Drilling chemicals create and maintain the required drilling fluid properties. The programme can include viscosifiers, fluid loss additives, shale inhibitors, weighting materials, lubricants, defoamers, lost circulation materials and pH control. Selection depends on the well section, formation, mud system, temperature and the required hydraulic and solids control performance. See the dedicated oilfield drilling chemicals guide.

Production and flow assurance chemicals

Produced water treatment chemicals

Produced water treatment can use coagulants, flocculants, reverse emulsion breakers, scale inhibitors, corrosion inhibitors, biocides and oxygen scavengers, depending on the treatment objective. The chemical must work with the separation equipment and meet the discharge, reuse or injection requirement. Jar tests, flotation tests or other representative methods should match the process.

How chemical functions are verified

Function	Useful test or monitoring approach	Common error
Demulsification	Bottle test with representative fluid and temperature	Using aged or unrepresentative samples
Corrosion inhibition	Laboratory screening plus coupons, probes or iron monitoring	Judging from dose alone
Scale control	Water analysis, modelling and dynamic or static testing	Ignoring pressure and temperature path
Biocide treatment	Planktonic and sessile monitoring with system review	Relying on one sample point
Water clarification	Representative jar or process simulation test	Optimising clarity without checking downstream impact

Chemical handling and injection

• Review the safety data sheet and site risk assessment.
• Verify storage temperature, segregation, bunding and shelf life.
• Use compatible tanks, seals, tubing and injection pumps.
• Calibrate pumps and confirm the actual delivered dose.
• Prevent unintended mixing in common injection lines.
• Record batch, usage, interruptions and monitored result.

From application map to product selection

After identifying the function, build the selection brief around the field data, test method, compatibility, injection point, documentation and commercial supply. Use the production chemicals selection guide for the detailed evaluation process.

Is one chemical able to solve several production problems?

Some products have more than one function, but each claimed benefit should be verified under the actual fluid and process condition.

Why can a laboratory winner fail in the field?

The field may differ in temperature, shear, residence time, contamination, injection quality or interaction with other chemicals. The trial must control these differences.

For supply enquiries, visit oilfield and production chemicals in Nigeria.