A Probability Approach to Development of a Large Carbonate Reservoir with 
Natural Fractures and Stratiform Super-Permeabilities

Pham, T.R.; Stenger, B.A.; Al-Otaibi, U.F.; Al-Afaleg, N.I.; Al-Ali, Z.A.; Sarda, S.

doi:10.2523/81433-ms

Cited by 8 publications

(5 citation statements)

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“…The case described above is a common situation observed in many other anticlinal structures (e.g, Pham et al 2003, Johnson et al 2002, Mynatt et al 2009, Zahm and Hennings 2009; see also fractured fold examples in Iran by Mobasher andBabaie 2008 andKhoshbakth et al 2009 and also example fractures on Cupiagua anticline by Ballin et al (2001).…”

Section: Declining Curvature From Crest Towards Flanksmentioning

confidence: 68%

Stress Superposition Explains Fracture Patterns in some Middle East Oil Fields

Özkaya

2012

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractTwo main structural types can be distinguished in the oil fields of the Middle East. (i) Fields transected by regional strike slip faults (type I structures). (ii) Fields with local faults that are associated with and confined to anticlinal structures (type II structures). Type II structures are either (i) growth fold, mostly bound by deep seated faults which were reactivated under transpression or (ii) product of structural inversion, during Late Cretaceous and Late Tertiary major tectonic events. The reactivated faults have usually very small lateral displacement and the structures have very gentle dips.The characteristic fault fracture patterns of type II anticlines in the Middle East have two diagnostic aspects: (i) faults and fracture corridors have uniform strike oblique to anticlinal axis and (ii) they disappear away from the structural highs towards franks and away. These two characteristic aspects can be explained only by superposition of regional stress and local tension related to structural bending.Stress superposition not only explains the diagnostic faults and fracture patterns of type II structures, but also account for several details such as higher degree of fracturing in doubly plunging structures and fracture density as a function of the angle between fold axis and maximum horizontal stress at the time of fracturing.Fault reactivation and structural growth in discrete pulses seem to be prerequisite for the typical fault fracture corridor patterns of type II structures. In many of type II anticlines, the paleo-stress that generated fold-bound faults and fracture corridors is oblique to fold axes. This suggests folding and fracturing took place under transpression and is related to fold reactivation or structural inversion. In either case, existence of a pre-existing structural control is essential, such as regional wrench faults or deep seated basement weakness zones.

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Section: Declining Curvature From Crest Towards Flanksmentioning

confidence: 68%

Stress Superposition Explains Fracture Patterns in some Middle East Oil Fields

Özkaya

2012

All Days

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“…Since the dynamic data for Reservoir B was only available for the crestal area, with virtually no information about the other parts of the field, the model was trustworthy only within the crestal area of the field and was taken with uncertainty elsewhere. 5 Considering these limitations and challenges, the test was carefully designed to include two phases. Phase I involved the start of water injection at low rate in all Reservoir B wells simultaneously while observing pressure changes in both Reservoirs A and B wells for fifteen days.…”

Section: Interference Test Designmentioning

confidence: 99%

Field-wide Interference Test for Understanding the Hydraulic Communication between Two Stacked Reservoirs

Al-quaimi¹,

Ansah²,

Al-Shehab³

et al. 2010

Proceedings of Offshore Technology Conference

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A field-wide interference test was recently conducted to delineate the hydraulic communication between two large carbonate reservoirs separated by a thick non-reservoir formation. The reservoirs were newly developed with peripheral water injection for pressure support. This initial development stage provided an opportunity to take advantage of the undisturbed state of the two reservoirs during field commissioning to conduct this interference test prior to production. The injection start-up was, therefore, designed to inject into one reservoir while monitoring pressures at various parts of the other reservoir. Several observation wells across the field were designated to record the pressure changes during the initial water injection stage to provide the field coverage. The injection rates were also closely monitored and modified throughout the test period to record the rate of pressure change in the observation wells.The field was developed with the state-of-the-art permanent downhole monitoring systems (PDHMS) which provided the means for comprehensive monitoring of this field-wide interference test. The test showed some interesting findings within the reservoirs themselves, areas of communication were indentified and the extent of the lateral connectivity was observed. Additionally, the dynamic data acquired during this interference test will complement the static data for building improved geological and engineering models.This paper describes the test design, implementation and presents the results and findings. The test was concluded but monitoring is continuing utilizing the intelligent field (I-field) infrastructure and the results will, in future, be incorporated into reservoir simulation models for production/injection strategy optimization and accurate field performance forecasting. OTC 20571opportunity of the undisturbed state of the reservoirs, utilizing the readily available injection system, to conduct the test. The enabler was the leading-edge technologies implemented in the development.The following conclusions are drawn from the results of this field-wide test:• In addition to the central part of the field where the communication was discovered in the past, pressure communication between these two reservoirs was also seen at the southern end of the field, as this could be detected during the relatively short period of this test. • No significant pressure increase was seen in the east side suggesting no communication or very weak channels of communication in that area. • The degree of inter-reservoir communication at various parts of the field was assessed using the interference test results.With the conclusion of this field-wide interference test, the results will be used to adjust production/injection plans in both reservoirs in order to maximize hydrocarbon recovery. The potential risk of water encroachment from Reservoir B into Reservoir A will be minimized by this knowledge of more areas of communication.

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“…3,6 Probability analyses ranked reservoir parameters according to their impact on production and recovery. 3,6 Probability analyses ranked reservoir parameters according to their impact on production and recovery.…”

Section: Probabilistic Modelsmentioning

confidence: 99%

Haradh-III: Industry’s Largest Field Development Using Maximum-Reservoir-Contact Wells, Smart-Well Completions and I-Field Concept

Al-Kaabi¹,

Afaleg²,

Pham³

et al. 2007

Proceedings of SPE Middle East Oil and Gas Show and Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe development of Haradh-III in the Southernmost area of Ghawar represents a major shift in paradigm in terms of the combination of the technologies. The field development combines four main technology features which include maximum reservoir contact (MRC) wells, smart completions, extensive use of real-time geosteering and I-field initiatives. This paper describes the motivation, implementation, and post-production evaluation of this unique field development. In the case of Haradh-III, field development with smart MRC wells delays water encroachment, improves flood front conformance and recovery, lowers water production and long term development and operating costs. Bottom water encroachment into the wellbore is mitigated as down-hole Internal Control Valves (ICV), as part of the smart completion, are adjusted. This in turn lengthens the life of the well, allows sweep and recovery to take place in the reservoir below the horizontal wellbores through the most effective sweep process: the replacement mechanism by gravity. The objectives of the development are accomplished utilizing a reduced number of wells, minimizing the accompanying infrastructure therefore lowering the capital expenditure while reducing the operating cost by maintaining, on a long-term basis, a low-water producing system, all occurring in real-time and within the I-field environment.

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A Probability Approach to Development of a Large Carbonate Reservoir with Natural Fractures and Stratiform Super-Permeabilities

Cited by 8 publications

References 0 publications

Stress Superposition Explains Fracture Patterns in some Middle East Oil Fields

Stress Superposition Explains Fracture Patterns in some Middle East Oil Fields

Field-wide Interference Test for Understanding the Hydraulic Communication between Two Stacked Reservoirs

Haradh-III: Industry’s Largest Field Development Using Maximum-Reservoir-Contact Wells, Smart-Well Completions and I-Field Concept

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