Reservoir Management of a Giant Lower Burgan Reservoir in North Kuwait - 
Reservoir Monitoring and Production Enhancement by Innovative Tracking of 
Bypassed Oil and Time-Lapsed Data Integration

Chetri, Hom; Khan, Ali; Al-Ajmi, Moudi; Srivastava, Sanjeev K.; Al-Anzi, Ealian H.D.; Hajeri, Mubarak Al-

doi:10.2523/78513-ms

Cited by 4 publications

(1 citation statement)

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“…In 2000, 35-ppk seawater flooding was commenced to maintain reservoir pressure. The Burgan [8] has been producing since 1960s. The massive Middle Sand produces by vertical sweeping from an aquifer while the interbedded Lower Sand mainly by lateral edge sweeping.…”

Section: Field Overviewmentioning

confidence: 99%

An Integrated Downhole Production Logging Suite for Locating Water Sources in Oil Production Wells

Bhagavatula

Al-Ajmi

Awad

et al. 2015

SPE Oil &Amp; Gas India Conference and Exhibition

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Understanding of fluid movement in and near the wellbore is a crucial factor for effective reservoir management including successful remedial actions and field development planning. One of the key objectives in well surveys is to detect and locate sources of fluid flows behind multiple pipe barriers. The conventional Production Logging Tool (PLT) is run to detect fluid flow and identify the type of fluid under downhole conditions, but is limited to measurements only inside the wellbore. Similarly, other diagnostic techniques, such as cement bond logging, give insight only into the cement integrity and also have limited capabilities to detect cross flows behind casing.Recent developments in temperature and noise logging tools and advanced interpretation techniques have provided higher resolution and sensitivity, enabling the detection of previously undetectable leaks and fluid flow behind casing [1].In the present case, a water zone has been identified in a producing formation with High Precision Temperature (HPT) logging and Spectral Noise Logging (SNL) followed by advanced numerical temperature modelling using the TermoSim software application. SNL identifies flowing zones and differentiates between rock-matrix and fracture flows, and TermoSim then numerically models heat exchange between the wellbore fluid and the surrounding rocks and reservoirs. The resulting model quantifies fluid production from each reservoir unit. Conventional production logging (PLT) locates fluid entry points in the wellbore. The integrated HPT-SNL and PLT logging suite can trace the entire water path from the reservoir into the wellbore. This paper describes water source identification by an HPT-SNL-PLT logging suite deployed in several production wells of a Kuwait oil field. In some of the wells in this field, it has been found that water encroached into the perforations from a watered reservoir below through a channel behind the casing. In other wells, it has been found that cold water breakthrough occurred laterally from nearby water injectors. The exact identification of water sources is a crucial step in any further well remedial work to reduce or eliminate them from oil producing wells. [2]

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Section: Field Overviewmentioning

confidence: 99%

An Integrated Downhole Production Logging Suite for Locating Water Sources in Oil Production Wells

Bhagavatula

Al-Ajmi

Awad

et al. 2015

SPE Oil &Amp; Gas India Conference and Exhibition

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Coning Control Completion Technology for Water Management

AlSubaiei,

Al-Mousawi,

Kumar

et al. 2024

Day 3 Thu, March 07, 2024

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Early in the well's life, the presence of formation water under strong water drive supports oil production. Eventually with time, this will become a problem that is challenging to manage. Maintaining and growing North Kuwait's oil production year after year made it impossible to continue producing well with high water production caused by conning effect. The critical coning rate required for lower Burgan (LB) to eliminate the conning effect and continue producing with low water cut (WC), as determined by Chappelear and Hirasaki correlation, is ± 300 BLPD. In order to prevent coning, an LB well should be produced at a rate lower than 300 BOPD. Producing wells at a rate lower than 300 BLPD is not feasible due to the high requirement of oil rate that north Kuwait targets. Coning Control Completion (CCC) is a cutting-edge technology used in North Kuwait to solve Lower Burgan formation (LB) coning problems. A reversible Electric Submersible Pump (ESP) is part of this completion system that is positioned below the oil-water contact (OWC). In order to control the progression of the water cone inside the oil zone, the reverse ESP generates a counteractive pressure drop below the OWC. Redirecting water into the underlying reservoir by drawing it below the desired zone's OWC is a crucial function of the reverse ESP. The quantity of generated water that rises to the surface is reduced by this process keeping the same liquid rate. Water cut (WC) has been decreased as a consequence of the effective use of CCC in North Kuwait, going from 90% to around 40 %. The successful implementation of CCC in North Kuwait has helped and enhanced the development plan for lower Burgan and will help controlling conning issue world wide

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Testing the Mobility of Oil below the OOWC of a Multi-layered Matured Clastic Reservoir in North Kuwait: Tapping the Reserves & Production Growth Opportunity

Chetri¹,

Al-Ajmi²,

Khan³

et al. 2004

Abu Dhabi International Conference and Exhibition

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Lower Burgan, a giant clastic reservoir in Sabiriyah field of North Kuwait was discovered during mid 50s (Location map shown in Figure-1). An integrated performance analysis recently carried out indicated that the reservoir has a much higher potential than anticipated earlier. Though the cumulative recovery till date was more than 70% of the initial recoverable reserves, the reservoir pressure decline was insignificant with average water cut of about 20% only in this active water drive reservoir. Significant additional open hole data in new well penetrations, cased hole log data, seismic re-interpretation, additional production performance and pressure data acquired since last major reservoir update in 1998, has considerably improved the reservoir potential understanding of Lower Burgan. Although reservoir performance suggested possibility of larger STOIIP base, lack of sufficient mapped net pay area impacted the deterministic STOIIP estimation negatively in the past. The additional information obtained in the new wells has opened up a large additional pay area by way of structural refinement, lowering of OOWC and additional net sands mostly in L-member. Whilst number of wells drilled in southwest flank and in north and south indicated possible occurrence of a deeper OOWC than earlier interpretations, SA-X1, the well drilled and tested beyond the reservoir limit in southern area, produced dry oil from sands with high Sw. In order to assess the full potential of new reservoir area and to test the mobility of oil below the hitherto OOWC, a detailed testing program was formulated and implemented. MDT sampling was undertaken at several wells with successful results to prove the mobility of oil. Rigless perforation/ testing job were done at one of the identified wells, showing only traces of oil. Cores were cut with full suite of open hole logs and the RFT data. Production testing at newly completed wells, long term build up tests, PLT data and RST logs confirmed the additional potential for this mature reservoir, which was supposed to be on decline as per earlier predictions. The paper is a classic example as to how a mature reservoir has been re-assessed and brought to the development limelight in terms of enhanced STOIIP, Reserves and production. Reservoir Description The Lower Burgan comprises a broadly transgressive succession of paralic clastic- sediments. Fluvial processes dominate in the lower part of the formation; influences from marine processes became stronger upwards. Higher frequency changes in sea level become more important in the upper part of the formation, making this part of the reservoir more complex.The reservoir architecture was defined by the depositional processes, which were mostly channel processes. The internal make-up of these channels depended on the relative degree of marine influence, and they range from fully fluvial channels, through deltaic channels, tidally influenced channels, and more marine estuarine channel fills. Reservoir Layering Sequence Stratigraphy is used as main basis for layering scheme of this reservoir. The key correlatable surfaces that mark significant landward or basinward shifts are identified on the basis of core study and distinctive characteristics on wireline logs. Based on the above Lower Burgan was divided into six layers-LB25, 50,55,70,80 & 100 (Badely Ashton). Later on it was felt that the Badley Ashton layering was not sufficient to define flow property of the reservoir. Therefore, based on reservoir pressure and flow behavior, the lower Burgan reservoir has been divided into as many as thirteen layers /flow units. It includes the key stratigraphic surfaces identified by Badley Ashton, together with some additional intermediate surfaces, which were later found, by Badley Ashton, not to have stratigraphic significance. Figure 2 compares the new, and Badley Ashton correlation schemes, and relates them to the traditional division of the Lower Burgan into a massive lower sand unit, called the M member, and an upper interbedded unit of sands and shales, called the L member. The boundary between L and M varies from well to well and cuts across the stratigraphy.

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Reservoir Management of a Giant Lower Burgan Reservoir in North Kuwait - Reservoir Monitoring and Production Enhancement by Innovative Tracking of Bypassed Oil and Time-Lapsed Data Integration

Cited by 4 publications

References 0 publications

An Integrated Downhole Production Logging Suite for Locating Water Sources in Oil Production Wells

An Integrated Downhole Production Logging Suite for Locating Water Sources in Oil Production Wells

Coning Control Completion Technology for Water Management

Testing the Mobility of Oil below the OOWC of a Multi-layered Matured Clastic Reservoir in North Kuwait: Tapping the Reserves & Production Growth Opportunity

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