Building the Case for Raw Seawater Injection Scheme in Barton

Flatval, K.B.; Sathyamoorthy, Sekhar; Kuijvenhoven, Cornelis; Ligthelm, D.J.

doi:10.2118/88568-ms

Cited by 9 publications

(2 citation statements)

References 4 publications

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“…This tool can be incorporated into any full-field model by including a number of extra components and reaction equations, which describe the souring process. Both tools had been used for the Barton field, offshore North Sabah, when building the case for a raw seawater-injection scheme for that field (Flatval et al 2004).…”

Section: Reservoir-souring Predictionsmentioning

confidence: 99%

Use of Nitrate to Mitigate Reservoir Souring in Bonga Deepwater Development Offshore Nigeria

Kuijvenhoven

Noirot²,

Bostock³

et al. 2006

SPE Production &Amp; Operations

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The Bonga field, located in deep water off the Nigerian coast, needs pressure support to effectively recover hydrocarbons. The strategy is to inject 300,000 BWPD of seawater from the start of oil production. During the field development in 1999, it was concluded that Bonga was expected to suffer from reservoir souring and that mitigation would be necessary.Initial data gathering indicated that the H 2 S content resulting from reservoir souring was not expected to exceed 50 parts per million(volume-based) [ppm(v)] in the gas phase. Initially nanofiltration to reduce the sulfate level in the seawater was identified to mitigate reservoir souring, but because of the high capitalexpenditure (CAPEX) costs, it was dropped and, because there were no other proven mitigation techniques available, it was decided to operate without mitigation. The strategy for this project was to let the reservoir sour and handle the H 2 S with sour-service materials and scavenging facilities topside. The facilities were designed to handle a maximum level of 50-ppm(v) H 2 S.As detailed design progressed and more field data became available, doubts were raised on the suitability of this approach. The strategy to let the reservoir sour and handle the H 2 S at surface was re-evaluated in 2003. It was found that H 2 S levels are likely to exceed 50 ppm(v). Since then, a new strategy with mitigation was adopted. Several operators had verified that nitrate injection is an effective mitigation technique to control H 2 S development. However, to date, the main application for nitrate had been the reduction of H 2 S in already-sour fields, and the experience for the use of nitrate from the start of the water-injection scheme was limited.This paper presents a detailed evaluation of the potential for reservoir souring resulting from biogenic reservoir souring in the Bonga field and the work done to predict H 2 S levels. The paper focuses on the selection of nitrate as a mitigation method. Reservoir-Souring Potential in BongaThere is uncertainty about the expected severity of reservoir souring in Bonga because there is no detailed information available for the produced-water composition from the main reservoir to be

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Section: Reservoir-souring Predictionsmentioning

confidence: 99%

Use of Nitrate to Mitigate Reservoir Souring in Bonga Deepwater Development Offshore Nigeria

Kuijvenhoven

Noirot²,

Bostock³

et al. 2006

SPE Production &Amp; Operations

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“…The water depth in this area is approximately 130ft. The Barton field is part of the North Sabah 96 PSCs, is valid until 31 st December, 2019, with 50% SM-EP and 50% Petronas Carigali (PCSB) equity interest [1][2][3] At present, many oilfields have reached the secondary and tertiary recovery period. According to the provided statistics, there are about millions tons of oily waste water having yet to be handled.…”

Section: Introductionmentioning

confidence: 99%

Greenhouse gas forecast in Barton Water injection reinstatement project

Goh

Thong

Chua

et al. 2015

2015 IEEE International Conference on Control System, Computing and Engineering (ICCSCE)

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Discovery the most effectual resolution to control the greenhouse gases (GHG) emissions is one of the most essential long-term challenges sophisticated by the society. Efficacious frameworks for CO 2 management will definitely advantageous on reducing CO 2 emission while promoting the technologies and investments to enhance energy efficiencies and decrease the CO 2 intensities. Therefore, the GHG management from oil and gas facilities is still a priority. Continuous various efforts such as reduction in flaring, waste-water treatment before discharging to the environment, and oil spill prevention have encouraged the waste management to follow the model of prevention, such as reuse, recycle, recovery, etc. Those countermeasure techniques are widely implemented by oil and gas industries towards environmental performance at the work site and its surrounding area. This paper is mainly focused on the Barton field located at the off coast of Sabah, Malaysia. Due to the advancement at Barton field, overabundance of GHG emission is one of the main issues. Therefore, the main intension of this paper is to provide the forecasted GHG emissions for Barton Water Injection Reinstatement Project (BTWI). The predicted GHG emissions will be very handy to provide an insight for the future improvement on water injection system in BTWI project. Index Terms-Greenhouse gas, oil recovery technology, Barton Water Injection Reinstatement Project (BTWI)978-1-4799-8252-3/15/$31.00 ©2015 IEEE

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Metals, Inorganic Salts and Other Inorganics

2018

Oilfield Chemistry and Its Environmental Impact

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Building the Case for Raw Seawater Injection Scheme in Barton

Cited by 9 publications

References 4 publications

Use of Nitrate to Mitigate Reservoir Souring in Bonga Deepwater Development Offshore Nigeria

Use of Nitrate to Mitigate Reservoir Souring in Bonga Deepwater Development Offshore Nigeria

Greenhouse gas forecast in Barton Water injection reinstatement project

Metals, Inorganic Salts and Other Inorganics

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