Waterflooding surveillance: real time injector performance analysis using Hall plot method &amp; derivative

Ratnaningsih, Dyah Rini; Danny, I L

doi:10.1088/1755-1315/212/1/012074

Cited by 5 publications

(4 citation statements)

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“…The trajectory of D HI tracking below HI represents the occurrence of fracture and the generation of negative skin. By contrast, D HI tracking above HI is due to the plugging or positive skin [24,32,33].…”

Section: Design Of Hydraulic Stimulation: Water Injectionmentioning

confidence: 99%

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Lee

Bae

Permadi

et al. 2023

International Journal of Energy Research

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This paper discusses a case study on the enhanced geothermal system (EGS), which entails a hydraulic stimulation at Patuha geothermal field, West Java, Indonesia. Patuha field is a volcano-hosted vapor-dominated geothermal system. A hydraulic stimulation was designed with 6,360 m3 (=40,000 barrels) of water injection to evaluate the enhancement in steam production. The water injection was conducted in three phases: a step-up period, a plateau period with a constant rate, and a step-down period, which raised the bottom hole pressure effectively and positively influenced formation. In addition, in EGS, rapid restorations of pressure and temperature to their pretest values near the bottom hole were observed, unlike in a typical nonvolcanic system. Hall plots, i.e., the Hall integral and Hall derivative, confirmed that the geothermal reservoir was stimulated, and thus, the hydraulic stimulation increased the steam production up to 11.4% at other production wells that were located near the cold-water injector.

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Section: Design Of Hydraulic Stimulation: Water Injectionmentioning

confidence: 99%

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Lee

Bae

Permadi

et al. 2023

International Journal of Energy Research

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“…181,264,265 Generally, a Hall plot is accepted as the most effective method for injection well performance analysis due to the steady-state condition of analysis and inexpensive data acquisition, as the only required information are the recorded daily wellhead pressures and injection rates. 266 Transient methods, such as PFO, are more expensive, as they require running gauges on wireline to depth and only provide the reservoir properties at one point in time, while the Hall plot identifies the injection effects occurring throughout an extended period of time. 267 Note that the periodic running of PFO is still necessary to use a Hall plot effectively through determination of the individual values of skin and transmissibility.…”

Section: 1mentioning

confidence: 99%

“…267 Note that the periodic running of PFO is still necessary to use a Hall plot effectively through determination of the individual values of skin and transmissibility. 266,267 Despite the mentioned benefits, Hall-plot analysis can only identify significant slope changes and the subtle changes might be neglected. To solve this, Izgec and Kabir 259 suggested a real-time injection performance analysis method, called a derivative Hall plot, in which Hall-plot derivatives, coupled with the primitive Hall integral, are plotted versus cumulative injected volume, and even subtle changes can be simply identified.…”

Section: 1mentioning

confidence: 99%

“…Transient methods, such as PFO, are more expensive, as they require running gauges on wireline to depth and only provide the reservoir properties at one point in time, while the Hall plot identifies the injection effects occurring throughout an extended period of time . Note that the periodic running of PFO is still necessary to use a Hall plot effectively through determination of the individual values of skin and transmissibility. , …”

Section: Co2 Injection Monitoring and Surveillancementioning

confidence: 99%

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Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

et al. 2021

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Deep saline aquifers are among the most favorable geological sites for short-and long-term carbon geosequestration. Injection of CO 2 into aquifers causes various hydro-physical, chemical, and geomechanical interactions that affect the injectivity of wellbores. Despite the extensive research conducted on carbon capture and storage (CCS), there exists a lack of focus on the concept of injectivity. The present study aims to identify the gaps by reviewing the major factors contributing to CO 2 injectivity in deep saline aquifers. Moreover, the existing analytical and numerical mathematical models to estimate maximum sustainable injection pressure and pressure build-up are critically reviewed. Concerning the analytical models, the main controversies are related to the general shape of the CO 2 −brine interface that stems from neglecting or assuming CO 2 compressibility, mutual solubility of CO 2 and water, and drying-out effects. Besides, the models predicting waterflooding processes cannot accurately evaluate the injectivity of CO 2 due to the unique features of CO 2 . Furthermore, most models have concentrated on CO 2 storage capacity at the reservoir scale and not on wellbore injectivity. Thermo-poro-elastic effects influencing the in situ stresses and constraining the maximum sustainable injection pressures are also neglected in some cases. Despite the numerous numerical modeling workflows or tools, some mechanisms have not yet gained the desired attention, especially the chemical aspects of CO 2 -rich brine. Finally, while the field data demonstrate the applicability of CO 2 geosequestration in saline aquifers, regular wellbore injectivity monitoring and surveillance is deemed necessary.

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Reconciliation of Production Data and Geology for Robust Development Plan

Goyal

Koeck

Bensadok

et al. 2019

Day 1 Tue, September 17, 2019

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This paper discusses the re-construction of the long-term development plan for an offshore giantfield located in Abu Dhabi with the aim to mitigate the rising challenges in the maturing field. The primary objective is to understand the reservoir behavior in terms of fluid movement incorporating the learning from the vast history while correlating with the geological features. The field has been divided into segments based on multiple factors considering the static properties such as facies distribution, diagenesis, faults, and fractures while incorporating the dynamic behaviors including pressure trends and fluid movements. On further analysis, various trends have been identified relating these static and dynamic behaviors. The production mechanism for each of the reservoirs and the subsequent sub reservoirs were analyzed with the help of Chan plots, Hall plots and Lorentz plots which distinctly revealed trends that further helped to classify the wells into different production categories. Using the above methodology the field has been categorized in segments and color coded to indicate areas of different ranking. The green zone indicates area of best interest which currently has strong pressure support and wells can be planned immediately. The wells in this area are expected to produce with a low risk of water and gas. The yellow zone indicates areas of caution where special wells including smart wells maybe required to sustain production. This area showed relatively lower pressure support owing the location of the water injectors and the degraded facies quality between the injectors and the producers. The red zone highlights areas which are relatively mature compared to the neighboring zones and will require new development philosophy to improve the recovery. The findings from this study were used as the basis for a reservoir simulation study using a history matched model, to plan future activities and improve the field recovery. This study involved an in-depth analysis incorporating the latest findings with respect to the static and dynamic properties of the reservoir. This has helped to classify the reservoir based on the development needs and will play a critical role in designing the future strategies in less time.

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Waterflooding surveillance: real time injector performance analysis using Hall plot method & derivative

Cited by 5 publications

References 0 publications

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Reconciliation of Production Data and Geology for Robust Development Plan

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Waterflooding surveillance: real time injector performance analysis using Hall plot method & derivative

Cited by 5 publications

References 0 publications

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Hydraulic Stimulation of Enhanced Geothermal System: A Case Study at Patuha Geothermal Field, Indonesia

Well Injectivity during CO2 Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Reconciliation of Production Data and Geology for Robust Development Plan

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Product

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Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects