Waterflood Surveillance and Control: Incorporating Hall Plot and Slope Analysis

Silin, Dmitriy; Holtzman, Ran; Patzek, Tadeusz W; Brink, J. L.; Minner, Michael L.

doi:10.2118/95685-ms

Cited by 19 publications

(6 citation statements)

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“…) should be a straight line, and any deviation from the straight line indicates a change in formation properties and wellbore injectivity due to formation damage, fracture propagation or closure (see Figure 13). 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.…”

Section: 1mentioning

confidence: 99%

“…As discussed earlier, a “maximum sustainable injection pressure” is the differential pressure that can be used in a CO 2 injection process without creating new fractures or reactivating the pre-existing faults (usually 70–90% of fracture pressure). , During a CO 2 injection process, fracturing conditions might occur as a consequence of poroelastic or thermoelastic induced stresses. The formation damage caused by plugging of the pores throughout the processes such as drying-out or fines migration can also increase the BHPs to values above the fracturing pressure of formations.…”

Section: Maximum Sustainable Pressure In Co2 Injectionmentioning

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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Section: 1mentioning

confidence: 99%

Section: Maximum Sustainable Pressure In Co2 Injectionmentioning

confidence: 99%

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

et al. 2021

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“…Ojukwu and van den Hoek [3] state version for use in quantifying damage skin. Silin et al, [4] developed slope analysis to estimate and use the varying reservoir pressure term. Izgec and Kabir [5] completely reformulated the Hall plot in a way that accounts for variable radial distance of the injection bank and pressure at the water/oil interface.…”

Section: Introductionmentioning

confidence: 99%

Modifying the Hall Plot for Analysis of Immiscible Gas Injection Wells II: IOR

Talabi¹,

Yew²

2018

IJCEA

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The Hall plot is a graph of an injection well's cumulative pressure against its cumulative injected volume, ideally presenting as straight line. Changes in the gradient of this line can indicate a change in injectivity behavior. Developed for single-phase, steady-state, radial flow of liquids, it has proven useful in the surveillance of water injection wells. However, published studies into the validity of its equations and assumptions for gas injection scenarios are limited. Utilizing the Hall plot to analyze immiscible gas injection into an oil phase for improved oil recovery poses challenges due to the near-wellbore relative permeability of gas to the oil phase. This paper presents one useful and practical approach to achieve this correction.To account for the varying near-wellbore relative permeability of gas in the oil phase, a function relating the relative permeability of gas in the oil phase to the cumulative gas injection is developed and included in previously developed equations that account for compressibility and viscosity variations. These updated equations give a modified Hall plot that accounts for the non-linearity due to relative permeability effects and allows the Hall plot to be used qualitatively by engineers to identify changes in the injectivity of gas wells.

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“…Some of the notable contributors include Buell et al (1990), who suggested the use of both bottomhole injection pressure and reservoir pressure instead of the wellhead pressure alone, as used in the conventional Hall plot. Evaluation of the reservoir pressure from a slope-analysis method was offered by Silin et al (2005aSilin et al ( , 2005b. Ideally, the Hall method is suitable for either early injection period or during the post-breakthrough period, because the notion of single-reservoir pressure is entertained.…”

Section: Introductionmentioning

confidence: 99%

Identification and Characterization of High-Conductive Layers in Waterfloods

Izgec

Kabir

2010

SPE Reservoir Evaluation &Amp; Engineering

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This study expands upon the use of modified-Hall analysis (MHA) to discern the characteristics of a high-permeability channel. Briefly, the modified-Hall plot uses three curves involving improved Hall-integral (H-I) and the two derivatives, analytic and numeric. Ordinarily, the derivative curves overlay on the integral curve during matrix injection, but separate lower when fracturing occurs. This work presents a method to identify and characterize high-conductive layers or channels between injector and producer pairs with the MHA. The distance separating the integral and derivative curves provides the required information to quantify channel properties. A simple analytical solution is presented for transforming the separation distance into channel permeabilitythickness product.The analytic derivative is based on the radial-flow-pattern assumption and the numeric derivative is correlated to the pressure response. Therefore, a comparison of these two curves reveals clues about the maturity of a waterflood at a given time. Several simulated examples verified the channel-property-estimation algorithm and identified the distinctive derivative signatures for channeling and fracturing situations. This method is also useful for identification of wormhole propagation during sand production in unconsolidated formations.

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Waterflood Surveillance and Control: Incorporating Hall Plot and Slope Analysis

Cited by 19 publications

References 20 publications

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

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

Modifying the Hall Plot for Analysis of Immiscible Gas Injection Wells II: IOR

Identification and Characterization of High-Conductive Layers in Waterfloods

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Waterflood Surveillance and Control: Incorporating Hall Plot and Slope Analysis

Cited by 19 publications

References 20 publications

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

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

Modifying the Hall Plot for Analysis of Immiscible Gas Injection Wells II: IOR

Identification and Characterization of High-Conductive Layers in Waterfloods

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

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