The role of rock physics for the Enfield 4D seismic monitoring project

Wulff, Angelika-M.; Gerhardt, Andre; Ridsdill-Smith, Tom; Smith, Megan M.

doi:10.1071/eg08015

Cited by 8 publications

(2 citation statements)

References 8 publications

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“…The velocity-pressure relationship is described by an empirical model fitted to dry core ultrasonic measurements. Finally, fluids are added using Gassmann equation and elastic properties representing the in-situ state are calculated (Wulff et al, 2008).…”

Section: Calibrating the Rock Physics Modelmentioning

confidence: 99%

Quantitative 4D interpretation – Relating the seismic to production changes at Enfield, North West Shelf, Australia

Smith¹,

Gerhardt

Thomas

2010

ASEG Extended Abstracts

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Section: Calibrating the Rock Physics Modelmentioning

confidence: 99%

Quantitative 4D interpretation – Relating the seismic to production changes at Enfield, North West Shelf, Australia

Smith¹,

Gerhardt

Thomas

2010

ASEG Extended Abstracts

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“…The Enfield oil reservoirs occur within the Upper Jurassic to Lower Cretaceous age Macedon member, comprising generally clean, high permeability unconsolidated sandstones contained within the crest of a north-easterly plunging fault bounded terrace that covers an area of approximately 16km 2 with a total relief of 350m 2 (Fig. 2).…”

Section: Introductionmentioning

confidence: 99%

Early Reservoir Management Insights from the Enfield Oil Development, Offshore Western Australia

Hamp

Bada

Mee

et al. 2008

SPE Asia Pacific Oil and Gas Conference and Exhibition

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Integration of key information in the early life of the Enfield water-flood development project led to improved understanding of the reservoir's architecture and dynamic behavior. This paper provides an overview of the field and a review of the first two years of production from the Enfield reservoir including start up of the field, water injection optimisation, acquisition and interpretation of Australia's first time lapse '4D' seismic survey, key well and reservoir performance learnings, use of chemical tracer technology to monitor fluid movement, and the benefits of comprehensive real time field data transmission to shore.The Enfield field, discovered in April 1999, is located offshore North West Cape, Western Australia in license WA-28-L. Water depths range from 325m to 550m across the field. Following appraisal drilling and development studies the field was sanctioned for water-flood development in March 2004. The Upper Jurassic Macedon reservoir comprise generally clean, high permeability, unconsolidated sandstone containing a 22° API, moderate viscosity, relatively low GOR oil which is overlain by a significant gas cap. The field has been developed to date via a total of fourteen sub-sea production, water injection and gas re-injection wells producing to a new-build, double hulled FPSO (the 'Nganhurra'). All five production wells, including three high rate horizontal wells, are completed with open-hole gravel packs for sand control. Key challenges during the development execution phase were operating in an extremely environmentally sensitive, cyclone prone deepwater area, in which there was no existing infrastructure or production operations experience.Production commenced on 24 th July 2006 with oil rates peaking at 74,000 bbl/day in September of that year. Initial production rates were constrained by the slower than expected establishment of pressure support from water injectors and then fell to about 43,000 bbl/day in October when a key production well was shut-in due to high levels of sand production. Significantly different water breakthrough and water cut development in two of the production wells coupled with dynamic pressure data and insights from 4D seismic across the field have started to reveal reservoir complexity greater than previously expected, although overall reservoir connectivity appears to be good.During the first two years of production operations the reservoir and facility performance has generally been good and in line with pre-development reservoir models, with the exception of sand control in all three key horizontal production wells, each of which were eventually sidetracked in order to install effective open-hole gravel packs in ~600m horizontal sections.Key successes to date have included the ability to monitor well and facility operating conditions virtually in real time from the Operators onshore offices, the reservoir insights gained from a very early monitor 4D survey, and the organisational integration between the Reservoir Development team and the Production Operations tea...

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Shaly sand rock physics analysis and seismic inversion implication

Widyantoro¹,

Saul

2014

The APPEA Journal

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The analysis of well data from the Enfield field of the Exmouth Sub-basin, WA, indicates that both cementation and pore-filling clay appear to have a stiffening effect on the reservoir sands. The elastic contrast between brine sand and the overlying shale is often small and the large amplitudes observed from seismic data are associated with hydrocarbon content. More detailed rock physics and depth trend analysis of elastic and petrophysical properties, however, indicate significant spatial variability in the cap rock shales across the field with different sand shale mixtures, causing changes in the elastic response of the rock. Areas where shales are softer produce weak seismic amplitude contrasts even with high hydrocarbon saturation; the amplitude response being similar to areas with stiffer shales and brine-filled sands. The variations in reservoir quality are, therefore, masked by the distribution of the brine, oil and gas, as well as the variations in the cap rock. The Enfield rock physics analysis provides an example of reducing amplitude ambiguity over lithology-fluid variation and improves the chance of successful interpretation of the results of seismic inversion.

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The role of rock physics for the Enfield 4D seismic monitoring project

Cited by 8 publications

References 8 publications

Quantitative 4D interpretation – Relating the seismic to production changes at Enfield, North West Shelf, Australia

Quantitative 4D interpretation – Relating the seismic to production changes at Enfield, North West Shelf, Australia

Early Reservoir Management Insights from the Enfield Oil Development, Offshore Western Australia

Shaly sand rock physics analysis and seismic inversion implication

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