Effect of Heterogeneity on the Non-Darcy Flow Coefficient

Narayanaswamy, Ganesh; Sharma, Mukul M.; Pope, Gary A.

doi:10.2118/39979-ms

Cited by 11 publications

(8 citation statements)

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“…The presence of liquid hydrocarbon and water in the vicinity of wellbores was considered as the main restricting parameter making only 10% of original gas in place recoverable from this reservoir (Engineer 1985). A large number of theoretical and experimental studies have been devoted to understanding, modeling, and predicting the condensate accumulation and its associated impaired well productivity (O'Dell and Miller 1967;Fussell 1973;Danesh et al 1991;Henderson et al 1993Henderson et al , 1998Fevang and Whitson 1996;Mott 2002;Jamiolahmady et al 2003).…”

Section: Introductionmentioning

confidence: 99%

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Fahimpour¹,

Jamiolahmady²

2015

SPE Journal

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Significant reduction in well productivity of gas/condensate reservoirs occurs because of reduced gas mobility caused by the presence of condensate/water liquid phases around the wellbore.There are certain fluorinated wettability modifiers that are capable of delivering a good level of oil and water repellency to the rock surface, making it intermediate gas-wet and alleviating such liquid blockages. The main objective of this experimental work has been to evaluate the performance of such chemicals for wettability alteration of carbonate rocks, which have received much less attention in comparison with sandstone rocks. Screening tests, including contact-angle measurements, unsteady-state-flow tests, and compatibility tests with brine, were performed by use of mainly anionic and nonionic fluorosurfactants.Results demonstrated that on positively charged carbonate surfaces, the anionic chemicals were sufficiently effective to repel the liquid phase, whereas the nonionic chemicals showed an excellent stability in brine media. A new approach of combining anionic and nonionic chemical agents was proposed to benefit from these two positive features of an integrated chemical solution. A number of low-and high-permeability carbonate-core samples were successfully treated by use of chemicals selected through screening tests. Optimization of the solution composition and its filtration before injecting it into the core proved very effective in reducing/eliminating the risk of possible permeability damage because of deposition of large chemical aggregates on the rock surface. The chemical solution optimized in this study can be considered as a potential wettability modifier for mitigating the negative impact of condensate/water banking in gas/condensate carbonate reservoirs.

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Section: Introductionmentioning

confidence: 99%

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Fahimpour¹,

Jamiolahmady²

2015

SPE Journal

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“…Finally, heterogeneity has a significant effect on , as recognized by Jones 42 and Narayanaswamy et al 43 Variable wellbore storage. Fair 5 and Hegeman, Hallford, and Joseph 6 developed type curves for wells with constant skin factor and variable wellbore storage.…”

Section: Previous Workmentioning

confidence: 89%

Estimating Non-Darcy Flow Coefficient from Buildup Test Data With Wellbore Storage

Spivey¹,

Brown²,

Sawyer³

et al. 2002

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractAn algorithm has been developed for computing the pressure response for a well with constant wellbore storage and non-Darcy skin factor across the completion. The algorithm has been used to generate type curves for drawdown and buildup tests. The buildup pressure derivative response for a well with non-Darcy flow across the completion exhibits a much steeper slope during the transition out of wellbore storage than that of a well with constant skin.No reservoir model with constant wellbore storage and skin can reproduce this steep derivative. Thus, if it is present in a buildup test, the well is experiencing either decreasing wellbore storage or decreasing skin factor, or both.With the new type curves, under favorable conditions, both Darcy and non-Darcy skin components may be estimated from a single buildup test following constant rate production. The new algorithm may also be used to model a test sequence comprising multiple flow and buildup periods.

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“…This is because in the Tangguh fields the medium transmissibility reservoir is more heterogeneous than the high transmissibility. Heterogeneity effects are a likely source of scatter seen in experimental data for β coefficient 3 .…”

Section: Theoretical Non-darcy Coefficient (D Empirical )mentioning

confidence: 99%

Correction of the Non-Darcy Coefficient for Completion Effects: Impact on the Prediction of Tangguh LNG Gas Well Deliverability

Zulfikri¹,

Abdassah²,

Adjie³

2001

Proceedings of SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Tangguh LNG gas fields are situated in the Berau Bay, Irian Jaya, Indonesia. An extensive exploration and appraisal program was performed from 1994 to 1998 which resulted in the discovery of 14.4 TCF of proved gas reserves with substantial upside reserve potential. The fields are currently at the development planning stage in support of the Tangguh LNG project, Indonesia's third major LNG center.The objective of this work was to obtain a more accurate skin and non-Darcy coefficient (D) from exploration and appraisal well tests by accounting for completion effects. The impact of corrected D coefficient on well deliverability reduced the number of forecasted development wells.In Tangguh pressure transient analyses, skin and D coefficient from well tests were first calculated based on pressure data from gauge depth. Most of the gauges were placed in gauge carriers integral to the test string and anywhere from 125 to 300 feet above the mid-point of producing interval. Because the pressure drop in the completion from the perforations to the gauge appears as additional skin, the deliverability of the formation could be underestimated if this effect were not considered in the analysis.After the pressure drop in the completion was correctly accounted for, the non-Darcy coefficient decreased in all wells. The D coefficient correction was particularly significant in high transmissibility reservoirs and agreed with theoretical D coefficient calculations. This increased the predicted gas well deliverability.

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Effect of Heterogeneity on the Non-Darcy Flow Coefficient

Cited by 11 publications

References 0 publications

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Estimating Non-Darcy Flow Coefficient from Buildup Test Data With Wellbore Storage

Correction of the Non-Darcy Coefficient for Completion Effects: Impact on the Prediction of Tangguh LNG Gas Well Deliverability

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