Validation of lateral fluid flow in an overpressured sand-shale sequence during development of Azeri-Chirag-Gunashli oil field and Shah Deniz gas field: South Caspian Basin, Azerbaijan

Javanshir, Rashid; Riley, Gregory W.; Düppenbecker, Stephan; Abdullayev, N. A.

doi:10.1016/j.marpetgeo.2014.07.019

Cited by 37 publications

(50 citation statements)

References 20 publications

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“…Presence of hydrodynamic activity has been reported for SCB as well (Bredehoeft et al, 1988;Tozer and Borthwick, 2010;Javanshir et al, 2015). In their work, Bredehoeft et al (1988) stated that the presence of lateral regional sandstone overpressure gradient with the highest overpressures around the basin center; and indicated that, as a result, lateral fluid flow occurs from the basin center to the margins.…”

Section: Regional Hydrodynamismmentioning

confidence: 85%

“…Analysis of pressure data acquired from appraisal wells shows decreasing aquifer overpressures from the south to the north flank and defines the simple south to north water potential gradient in the aquifer (Tozer and Borthwick, 2010. Such behavior strongly suggests the existence of hydrodynamic aquifer beneath the oil leg (Tozer and Borthwick, 2010;Javanshir et al, 2015). Hydrodynamic aquifer causes tilt in contacts and that is why OWC is deeper on the north flank compared to the south flank of the Azeri field.…”

Section: Introductionmentioning

confidence: 92%

“…In this case, aquifer flow occurs towards the basin center. Sediment compaction (Dennis et al, 2000;Bredehoeft et al, 1988;Javanshir et al, 2015), tectonic activities (Estrada and Mantilla, 2000), lateral temperature gradients (Stenger, 1999;Anderson, 2005) are viewed as other possible mechanisms for lateral pressure variations.…”

Section: Hydrodynamic Aquifersmentioning

confidence: 99%

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The Hydrodynamic Aquifer Studies in Azeri Field

Asgarov¹,

Bayramov²,

Mamiyev³

et al. 2015

All Days

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The Azeri-Chirag-Gunashli (ACG) oil field is located in the hydrodynamic environment of the South Caspian Basin (SCB). The presence of lateral pressure variations in such systems results in tilted hydrocarbon-water contacts. Besides the tilt, the eastern part of the field demonstrates unexpected fluid contacts observed from several appraisal and development wells. These unexpected contacts are not in accordance with tilts and cannot be explained by hydrodynamism only.Proposed solution to explain contact anomalies in the eastern part of the structure is to analyze the effects of permeability barriers on fluid contacts in hydrodynamic environment. Analysis is done through mechanistic model simulations. It was determined that barriers influence the contacts in hydrodynamic aquifer environment and it is possible to explain aforementioned contact anomalies by plausible barrier arrangement.Incorporation of study results into the Azeri full field model (FFM) resulted in better pressure and saturation match.

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Section: Regional Hydrodynamismmentioning

confidence: 85%

Section: Introductionmentioning

confidence: 92%

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The Hydrodynamic Aquifer Studies in Azeri Field

Asgarov¹,

Bayramov²,

Mamiyev³

et al. 2015

All Days

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“…The actual mechanism to generate a 400 m tilt from South to North Flanks in Azeri was not properly understood but faults were used in the early HM models. However after recent studies, the regional impact of active hydrodynamic aquifer in the South Caspian was recognized (Javanshir et al, 2015). This phenomenon had an especially large impact EA Fasila D which was not initially well recognised.…”

Section: Dynamic Aquifer Modellingmentioning

confidence: 99%

History of History Match in Azeri Field

Ibrahimov¹

2015

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Modern reservoir development could not happen without building and using 3-phase 3-D simulation models and predicting the future performance of the field using powerful computer technologies. Long term production and injection profile forecasts for the Azeri field have been carried out through usage of simulation models from 2001. Since production from 2005 Azeri models have been history matched on an annual basis. While matching the model data to the actual field observed data, surveillance and performance learnings have been an integral part of the process in order to obtain representative and satisfactory results.In the current work, the challenges and problems faced, as well as the success of the history match process for the Azeri field are described. Along with discussion of applied techniques and obtained results, recommendations on matching complex reservoir simulation models based on several years experience of history matching process in the Azeri field are offered.

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“…(e.g. Dugan & Sheahan, 2012;Gutierrez & Wangen, 2005;Javanshir, Riley, Duppenbecker, & Abdullayev, 2015;Kvalstad et al, 2005;Leynaud, Sultan, & Mienert, 2007;Marín-Moreno, Minshull, & Edwards, 2013;Stigall & Dugan, 2010;Urgeles et al, 2010). However, studies on high-latitude margins lack information on the combined effect of ice and sediment loading.…”

Section: Introductionmentioning

confidence: 99%

Fluid flow and pore pressure development throughout the evolution of a trough mouth fan, western Barents Sea

et al. 2019

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Using a combination of geophysical and geotechnical data from Storfjorden Trough Mouth Fan off southern Svalbard, we investigate the hydrogeology of the continental margin and how this is affected by Quaternary glacial advances and retreats over the continental shelf. The geotechnical results show that plumites, deposited during the deglaciation, have high porosities, permeabilities and compressibilities with respect to glacigenic debris flows and tills. These results together with margin stratigraphic models obtained from seismic reflection data were used as input for numerical finite element models to understand focusing of interstitial fluids on glaciated continental margins. The modelled evolution of the Storfjorden TMF shows that tills formed on the shelf following the onset of glacial sedimentation (ca. 1.5 Ma) acted as aquitards and therefore played a significant role in decreasing the vertical fluid flow towards the sea floor and diverting it towards the slope. The model shows that high overpressure ratios (up to λ ca. 0.6) developed below the shelf edge and on the middle slope. A more detailed model for the last 220 kyrs accounting for ice loading during glacial maxima shows that the formation of these aquitards on the shelf focused fluid flow towards the most permeable plumite sediments on the slope. The less permeable glacigenic debris flows that were deposited during glacial maxima on the slope hinder fluid evacuation from plumites allowing high overpressure ratios (up to λ ca. 0.7) to develop in the shallowest plumite layers. These high overpressures likely persist to the Present and are a critical precondition for submarine slope failure.

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Validation of lateral fluid flow in an overpressured sand-shale sequence during development of Azeri-Chirag-Gunashli oil field and Shah Deniz gas field: South Caspian Basin, Azerbaijan

Cited by 37 publications

References 20 publications

The Hydrodynamic Aquifer Studies in Azeri Field

The Hydrodynamic Aquifer Studies in Azeri Field

History of History Match in Azeri Field

Fluid flow and pore pressure development throughout the evolution of a trough mouth fan, western Barents Sea

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