Reviewing Mature Fields - A Case History

Martino, Luis; Iuliano, Alberto; Ucan, Sezai; Hern, Caroline

doi:10.2118/152715-ms

Cited by 3 publications

(1 citation statement)

References 5 publications

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“…The main goal of this section is to summarize the key findings that were obtained and/or implemented during Phase 2. Geologic and dynamic modeling techniques (incorporating surface facilities also) have been widely used in the petroleum industry for decades (Adelu et al, 2019;Dehghani et al, 2006;Gonzalez et al, 2008;Lurprommas et al, 2016;Mantopoulos et al, 2015;Martino et al, 2012;Ringrose and Bentley, 2015;Sarkar et al, 2015;Spagnuolo et al, 2018;Waskito et al, 2015). It should be noted that the use of new, data-driven methods is spreading in several industries, including the energy sector.…”

Section: Discussionmentioning

confidence: 99%

Challenges of a mature Russian field's redevelopment – Advantages and disadvantages of quick-look geologic modeling

Nemes

Sebők

Csató

2021

CEuGeol

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Due to the global oil price crisis in 2014, one of the MOL's preventive/reactive measures was to identify geologically or commercially risky elements within their portfolio. This involved reevaluation of all geologic data from Field A in the Volga-Urals Basin. In re-evaluating Field A, several unexpected challenges, problems and pitfalls were faced by the interdisciplinary team performing the task of building a new database, quality checking, and interpreting data dating back to 1947. To overcome these challenges related to this mature field, new approaches and fit-for-purpose methods were required in order to achieve the overall goal of obtaining a reliable estimation of remaining hydrocarbon potential. In the first phase a first-pass 3D geologic model was constructed, along with wrangling, cleaning and interpreting 70 years of subsurface data. This paper focuses on the main challenges involved in evaluating or reevaluating reservoir aspects of a mature field.The primary challenges were related to the estimation of remaining in-place hydrocarbon volumes, the optimization of infill well placement, the identification of primary and secondary well targets, the identification of critical data gaps, and the planning of new data acquisitions. The hands-on experience gained during the development of the geologic model provided invaluable information for the next steps needed in the redevelopment of the field.

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Section: Discussionmentioning

confidence: 99%

Challenges of a mature Russian field's redevelopment – Advantages and disadvantages of quick-look geologic modeling

Nemes

Sebők

Csató

2021

CEuGeol

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Quantifying Thin-Bed Modeling Contribution on Characterization of Bypassed Oil for Improved Oil Recovery

Martino¹,

Loss²,

Ucan³

et al. 2014

SPE Latin America and Caribbean Petroleum Engineering Conference

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Improved oil recovery is more sensitive to sub-log scale heterogeneity than primary recovery processes. Determination of porosity, net-to-gross, saturation and permeability, both magnitude and direction, at scales below log resolution is often required in secondary and tertiary processes and can have an impact on the estimation of original hydrocarbon in place, by-passed oil and recovery factors. Conventional log interpretation and conventional static modeling workflows may not capture sub-scale log heterogeneities, often due to the averaging involved in the upscaling process. Even though log values have been generally calibrated to plug scale (cm3) measurements, they are averaged over volumes much larger than their scale(s) of key heterogeneity. This paper compares the simulated response derived from conventional and from effective property and lamina-scale modeling in three different oil bearing formations in the Argentinian Neuquen Basin, namely Quintuco, Sierras Blancas and Lotena Formations. All three Formations are candidates for waterflood developments and enhanced recovery processes options are being examined. Permeability, porosity, saturation and net-to-gross ratio were determined by constructing high resolution models that enabled capturing sub-log scale heterogeneities. These models were subsequently upscaled at representative elementary volumes and the derived effective properties were used in building simulation models through different upscaling methodologies. Results of the two scale models for each reservoir are compared. Strengths and weakness of the applied methodology, as applied to these specific cases, are evaluated and discussed.

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Improved Waterflood Recovery for a Mature Oilfield with Challenging Reservoir Conditions and Complex Development Status

Lu,

Sun,

Shan

et al. 2023

Day 2 Tue, October 03, 2023

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Taking the North Saertu Development Area (NSDA), La-Sa-Xing oilfield in Daqing, China as an example, this paper presents best practices to improve mature field waterflood recovery. Placed onstream in 1963, development of the multi-layer sandstone reservoir experienced three-round infill drillings, EOR polymer flood and ASP flood. Strong reservoir heterogeneities, producing at water-cut >90% starting in 1999, various IOR/EOR activities and several well-pattern types overlapping vertically led to extreme challenges for further improving waterflood recovery. This paper first introduces the general reservoir geology, reservoir heterogeneity characteristics, fluid properties and reservoir conditions, followed by illustrating its 60-year development history and key IOR/EOR activities implemented. The focus of this paper is to illustrate the strategy, fit-for-purpose technologies, and effective reservoir management practices to further improve waterflood recovery at extra-high water-cut development stage. The discussed improved recovery practices are based on deliberate reservoir characterization and remaining oil study by integrating wireline logging, 3D seismic, production logging, sealed core data, production performance data and various other performance monitoring data. Several pilots on water-controlling, producing by-passed thick pay sands as well as re-arranging individual well pattern were conducted, providing a basis for field-wide application. Key strategy and technologies adopted are: 1) subdivision of individual injection-production interval and reduction well spacing; 2) improving water injection at individual well pattern and single flow-unit level; 3) combining waterflood and polymer/ASP flood by utilizing the same wellbore or well pattern to develop marginal pay sands in a cost-effective way; 4) improved zonal water injection by reducing individual injection thickness and permeability contrast within the injection interval; 5) improved injection profile through profile modification; 6) integrated approach to mitigate injected water channeling in thick pay sand; 7) cyclic water injection; 8) well drilling along fault plane producing by-passed oil; and 9) horizontal wells producing poorly swept or attic oil. The IOR and reservoir management activities have successfully arrested production decline, mitigated water-cut rising, leading to an increased waterflood recovery by >2.5%. Mainly implemented at development stage with extra-high water cut of 92%-95%, the integrated IOR and reservoir management activities discussed in this paper are all feasible, proved technically successful and cost-effective. These practices provide a road map and solutions for extending oilfield life or rejuvenation of a waterflood mature oilfield.

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Reviewing Mature Fields - A Case History

Cited by 3 publications

References 5 publications

Challenges of a mature Russian field's redevelopment – Advantages and disadvantages of quick-look geologic modeling

Challenges of a mature Russian field's redevelopment – Advantages and disadvantages of quick-look geologic modeling

Quantifying Thin-Bed Modeling Contribution on Characterization of Bypassed Oil for Improved Oil Recovery

Improved Waterflood Recovery for a Mature Oilfield with Challenging Reservoir Conditions and Complex Development Status

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