Reservoir souring, the microbiological conversion of sulphate in injection water into hydrogen sulphide in the reservoir, can have significant impact on finances and safety in oil operations.
Sulphide causes integrity issues due to increased corrosion, the presence of H2S possesses a potential HSE issue, iron sulphide causes plugging and increased sulphur levels lower the value of the oil.
Understanding microbial growth in the reservoir is vital in order to correctly assess the souring risk, choose the appropriate technical solution, and effectively monitor souring development to ensure safe and efficient operation of an oil reservoir.
Establishing an appropriate H2S management strategy is key to choosing the right solutions and lower total life time cost. DTI assist oilfield operators with pre-assessment and prediction of the souring level that can be expected in new fields, and designing and implementing mitigation and management strategies for already sour fields.
We offer our clients a range of services within reservoir souring
- Evaluation of souring potential in new discoveries and current producing fields
- Impact of water injection and produced water reinjection on souring
- Source tracking and system mapping based on state-of-the-art tools
- Field monitoring solutions
- Training of operator personnel
- Microbiological testing of EOR and production Chemicals
- Consultancy on souring management and mitigation
- Lab-based testing of souring potential and mitigation strategies under field-relevant conditions
- Application and effect of H2S scavenging chemicals, biocides and nitrate