Plugging Agent N,N'-Methylenebisacrylamide MBA CAS 110-26-9 Oilfield Water Shutoff Powder

High permeability streaks and natural fractures channel injection water straight from injector to producer, and mechanical isolation is often impossible in horizontal or multi layer completions. Crosslinked polyacrylamide gel placed as a low viscosity fluid and gelled in situ remains the most economical way to block those channels, and MBA is the crosslinker that gives the gel its strength and its long term stability in brine.

Our oilfield grade is specified around field behaviour rather than laboratory convenience. Gelation time can be tuned from two to twelve hours by adjusting crosslinker and accelerator dosage, the resulting gel keeps more than ninety percent of its volume after ageing in brine at 120 degrees C, and the fluid penetrates sandstone cores before it sets because viscosity stays below 30 mPa.s during injection.

• Adjustable gelation time: two to twelve hours at 60 to 90 degrees C, tuned by dosage so the gel reaches the target zone before it sets
• High salinity tolerance: stable in brines up to 200,000 mg/L total dissolved solids and tolerant of calcium and magnesium hardness
• Thermal stability to 120 degrees C: gel strength retained above 90% after 30 days of ageing in synthetic formation water
• Deep penetration: system viscosity stays under 30 mPa.s during injection, allowing treatment of low permeability layers
• Strong rock adhesion: effective in both sandstone and carbonate matrices, with measurable reduction in water cut after treatment
• Batch tested gel strength: every lot is checked by bottle testing and core flooding before dispatch, with results printed on the COA

Typical treatments include profile control in waterflood injection wells, water shutoff in naturally fractured carbonate reservoirs, and conformance control in horizontal wells with heel to toe permeability contrast. The same chemistry is used to build temporary diverting gels during acidising and to seal casing leaks where cement cannot be placed.

Because gel time and strength depend on polymer molecular weight, brine composition and temperature, we supply a formulation worksheet and a bench test protocol with each technical enquiry. Field service engineers can validate a candidate recipe in our laboratory using your formation water before the job is scheduled.

The Certificate of Analysis for each lot records assay, moisture, gelation time at 70 degrees C and gel strength in a standard sandpack, so the drilling and completion team receives numbers that map directly to the treatment design. Retention samples are kept for 24 months and are available for independent verification after any job.

We warrant the material for 12 months from shipment when stored as recommended. Because downhole performance also depends on water chemistry and placement, we support each project with laboratory compatibility testing and will replace any batch that fails the agreed specification.

Material is supplied in 25 kg fibre drums with double polyethylene liner for field mixing units, or in 1 kg foil bags for laboratory and pilot testing. Drums are marked with lot number, net weight, CAS number and the recommended storage instruction in English.

Shipments to oilfield service bases leave within 5 to 8 working days by air or sea, with MSDS, COA and packing list prepared for customs and HSE review. We can palletise and shrink wrap to suit yard handling equipment on request.