Reservoir Management Challenges of the Terra Nova Offshore Field: Lessons
Learned After Five Years of Production

Haugen, Eînar; Costello, James C.; Wilcox, Larry D.; Albrechtsons, Eric; Kelly, Irene

doi:10.2523/109587-ms

Cited by 3 publications

(2 citation statements)

References 4 publications

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“…Oil production from Terra Nova started in 2002 with seawater injection being required soon after ( Haugen et al, 2007 ). Souring became evident after about 8 years of seawater flooding ( Sharpe et al, 2015 ) and nitrate and nitrite were injected as a souring control strategy from 2014 onward.…”

Section: Discussionmentioning

confidence: 99%

“…For instance, in the Terra Nova field, located 350 km from the east coast of Newfoundland, oil is produced from a depth of 3200–3700 m below the sea floor, where the reservoir temperature is 95°C ( Haugen et al, 2007 ). Due to the harsh operating conditions existing in this region, the oilfield is operated through a Floating Production Storage and Offloading (FPSO) vessel from where flexible manifold pipes are connected to the subsea system ( Howell et al, 2001 ).…”

Section: Introductionmentioning

confidence: 99%

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Effect of Thermophilic Nitrate Reduction on Sulfide Production in High Temperature Oil Reservoir Samples

Okpala¹,

Chen²,

Fida³

et al. 2017

Front. Microbiol.

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Oil fields can experience souring, the reduction of sulfate to sulfide by sulfate-reducing microorganisms. At the Terra Nova oil field near Canada’s east coast, with a reservoir temperature of 95°C, souring was indicated by increased hydrogen sulfide in produced waters (PW). Microbial community analysis by 16S rRNA gene sequencing showed the hyperthermophilic sulfate-reducing archaeon Archaeoglobus in Terra Nova PWs. Growth enrichments in sulfate-containing media at 55–70°C with lactate or volatile fatty acids yielded the thermophilic sulfate-reducing bacterium (SRB) Desulfotomaculum. Enrichments at 30–45°C in nitrate-containing media indicated the presence of mesophilic nitrate-reducing bacteria (NRB), which reduce nitrate without accumulation of nitrite, likely to N2. Thermophilic NRB (tNRB) of the genera Marinobacter and Geobacillus were detected and isolated at 30–50°C and 40–65°C, respectively, and only reduced nitrate to nitrite. Added nitrite strongly inhibited the isolated thermophilic SRB (tSRB) and tNRB and SRB could not be maintained in co-culture. Inhibition of tSRB by nitrate in batch and continuous cultures required inoculation with tNRB. The results suggest that nitrate injected into Terra Nova is reduced to N2 at temperatures up to 45°C but to nitrite only in zones from 45 to 65°C. Since the hotter zones of the reservoir (65–80°C) are inhabited by thermophilic and hyperthermophilic sulfate reducers, souring at these temperatures might be prevented by nitrite production if nitrate-reducing zones of the system could be maintained at 45–65°C.

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Section: Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Effect of Thermophilic Nitrate Reduction on Sulfide Production in High Temperature Oil Reservoir Samples

Okpala¹,

Chen²,

Fida³

et al. 2017

Front. Microbiol.

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Reservoir connectivity analysis of a complex combination trap: Terra Nova Field, Jeanne d'Arc Basin, Newfoundland, Canada

Richards

Vrolijk

Gordon

et al. 2010

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Terra Nova Oil Field is formed by a complex, structural, stratigraphic and diagenetic combination trap. About 1 billion barrels Stock-Tank Oil-In-Place (STOOIP) are trapped in a faulted plunging anticline, reservoired in stacked, braided fluvial sandstones which are of varying quality and extent due to onlap, cementation and facies transitions. Terra Nova Field is unusual when compared to the other three major hydrocarbon fields in the Jeanne d'Arc Basin in that it lacks a gas leg, and hydrocarbons are confined to the deepest of four major reservoir intervals, the Jeanne d'Arc sandstones. In this reservoir interval, the highest part of the plunging anticline is wet while the lowest part has the deepest fluid contact and longest oil column. Aquifer pressures vary between hydrostatic and significantly overpressured, but are far below leak-off. This apparently unusual distribution of fluids, pressures and contacts can be understood by systematically describing the many compartments within the overall structure, defining the connections between compartments, and building a 'connectivity diagram' which ensures a disciplined analysis of the fluid system. This type of approach, used historically by the Operator, Petro-Canada, and formalized as 'Reservoir Connectivity Analysis' (RCA) at ExxonMobil, is effective and necessary at multiple scales: basin, field, producing fault block and individual sandstone, and continues to be important at Terra Nova eight years into development and production.

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Integration of 4D Monitor to Enhance Reservoir Management: A Case Study of Egina Field

Udoinyang,

Amoyedo,

Omolewa

et al. 2024

SPE Nigeria Annual International Conference and Exhibition

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The Egina field is one of the most recent deepwater assets in Nigeria. The Field was discovered in 2003 and production commenced in December 2018. The production plateau of 203 KBOPD was reached in May 2019. Egina field, which is TotalEnergies’ second operated deepwater asset in Nigeria, located in water depths of about 1500m, is composed of highly faulted turbiditic reservoir units. It lies within the transition zone between the extensional and compressional regime of the Nigerian deep-water basin. This paper presents the integration of time lapse (4D) seismic monitoring to enhance reservoir management of Egina field, with a focus on the application and challenges of the seismic monitoring. Egina 4D M1 Ocean bottom Nodes (OBN) seismic data, which was acquired in October 2021, provided valuable insights into the reservoir dynamics including injected & aquifer water movement, pressure evolution in the vicinity of water injectors and depletion patterns around producers. The 4D seismic data has been used as a static model validation tool, critical input for history match process in several reservoir units, support for well intervention program, optimization of well placement and completion, and the evaluation of infill drilling opportunities. Specifically, we share the successful application of 4D seismic for the identification and screening of well intervention candidates, identification of focus intervals for stimulation (Pseudo-PLT) and the result of the recent 4D guided drilling campaign. Furthermore, we also present the challenges and limitations associated with the applicability of the data.

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Reservoir Management Challenges of the Terra Nova Offshore Field: Lessons Learned After Five Years of Production

Abstract: fax 01-972-952-9435. AbstractThe paper describes reservoir management challenges during the first 5 years of the production from the Terra Nova oil field, located offshore Newfoundland and Labrador, Canada.

Cited by 3 publications

References 4 publications

Effect of Thermophilic Nitrate Reduction on Sulfide Production in High Temperature Oil Reservoir Samples

Effect of Thermophilic Nitrate Reduction on Sulfide Production in High Temperature Oil Reservoir Samples

Reservoir connectivity analysis of a complex combination trap: Terra Nova Field, Jeanne d'Arc Basin, Newfoundland, Canada

Integration of 4D Monitor to Enhance Reservoir Management: A Case Study of Egina Field

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