Nitrate-Based Souring Mitigation of Produced Water—Side Effects and Challenges From the Draugen Produced-Water Reinjection Pilot

Abstract

fax 01-972-952-9435. AbstractCurrently, the application of nitrate/nitrite is considered one of the most promising souring mitigation solutions during Produced Water Re-Injection (PWRI). Norske Shell tested nitrate based souring mitigation as part of a PWRI feasibility study in the Draugen field. Prior to the pilot, the application of both nitrite and nitrate had been tested on Draugen using a Souring Mitigation Cabinet (SMC) specially developed to mimic the microbial activity in the near well reservoir. From this pre-study, the dosage of nitrate was selected based upon bio-available carbon and the required stoichiometric concentration of nitrate.During the PWRI pilot, corrosion rates were measured continuously Downstream (D/S) the Water Injection (WI) pumps in the High Pressure (HP) system, and after three months testing, significant increases in corrosion rates were seen. These were thought to be related with the addition of nitrate to the Produced Water (PW). To investigate this more closely, the SMC was modified by including a dedicated Low Pressure (LP) Corrosion Sidestream Monitoring (CSM) system. The results obtained in the CSM system verified the results obtained in the HP corrosion monitoring system in place on Draugen.The results of the Draugen PWRI pilot also showed that the addition of nitrate to the PW was efficient to control near-well reservoir souring. However, as mentioned above the corrosion rates increased logarithmically when nitrate was used. At the same time, a few ppm nitrite was seen in the nitrate treated PW water. The addition of biocide resulted in an instantaneous decrease in nitrite and corrosion rates to background levels. The result clearly indicates that bacterial activity, resulting from the addition of nitrate, was the causative agent of the increased corrosion seen in the Draugen PW treated for re-injection. It was concluded that the increase in corrosion rates most likely was Microbiologically Influenced Corrosion (MIC). Details of the PWRI pilot and the observed effects when applying nitrate are discussed in this paper.Because of the negative side-effects observed when applying nitrate to PW, Norske Shell re-evaluated the requirement to mitigate souring with nitrate. The testing during the PWRI pilot showed a low tendency to develop SRB activity, probably because of the low VFA concentration in the PW. Consequently it was decided to terminate the application of nitrate to PW on Draugen and control bacterial activity in the surface facilites with biocide.As nitrate is still promising to be applied in PW in other field applications, dedicated research has been initiated to learn more about the mechanisms leading to the increased corrosion rates seen when applying nitrate in PW.

A Post-Genomic View of the Ecophysiology, Catabolism and Biotechnological Relevance of Sulphate-Reducing Prokaryotes

“…Use of nitrate in sour above-ground facilities of an oil field in the North Sea indicated increased corrosion rates, suggesting the formation of sulphur (Vik et al, 2007). Formation of corrosive elemental sulphur is not a problem at the injection end of an oil field, where waters enter the subsurface formation, but is clearly not desired at the production end where treated waters enter the pipeline system.…”

Competitive Oxidation of Volatile Fatty Acids by Sulfate- and Nitrate-Reducing Bacteria from an Oil Field in Argentina

“…Waters produced from Ekofisk, a high-temperature North Sea oil field (19), contained 136 to 152 mg/liter of acetate, up to 14 mg/liter of propionate, up to 27 mg/liter of butyrate, and 800 to 1,100 mg/liter of sulfate, the high concentration being due to seawater injection (6). Lower VFA concentrations were reported in produced water from the Draugen field in the Norwegian sector of the North Sea with a downhole temperature of 71°C with 3 to 10 mg/liter of acetate, 1 to 11 mg/liter of propionate, less than 2 mg/liter of butyrate, and 400 to 600 mg/liter of sulfate (33). Interestingly, the field from which the samples used in the current study were obtained also had very high sulfate concentrations (Table 2), despite not being injected with seawater.…”

Thermodynamic analysis of an upstream petroleum plant operated on a mature field

“…Concluding remarks are outlined in Section 5. Vented gas Figure 1: Process flow diagram of the processing plant of the Norwegian Sea offshore platform investigated in this work, based on data available at [26][27][28][29][30][31] and input by Norske Shell A/S. Reservoir fluid, oil and condensate streams are indicated in brown, gas streams in orange, produced water in green, seawater in blue and glycol in indigo.…”