SPE Reservoir Evaluation & Engineering
Volume 14, Number 6, December 2011, pp. 687-701

SPE-137062-PA

Interpretation of Immiscible WAG Repeat Pressure-Falloff Tests

View full textPDF ( 3,565 KB )

DOI  More information 10.2118/137062-PA http://dx.doi.org/10.2118/137062-PA

Citation

  • Stenger, B.A., Al Kendi, S.A., Al Ameri, A.F., and Al Katheeri, A.B. 2011. Interpretation of Immiscible WAG Repeat Pressure-Falloff Tests. SPE Res Eval & Eng  14 (6): 687-701. SPE-137062-PA. http://dx.doi.org/10.2118/137062-PA.

Discipline Categories

  • 6.6.3 Pressure Transient Testing
  • 6.4.6 Chemical Flooding Methods Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex)

Keywords

  • Immiscible WAG

Summary

This paper reviewed the interpretation of repeat pressure-falloff (PFO) tests acquired in two vertical pattern injectors operating in a carbonate reservoir undergoing full-field development. Enhanced vertical-sweep conformance through phase mobility control in the presence of strong reservoir heterogeneity was the major expected benefit from an immiscible water-alternating-gas (WAG) displacement mechanism.

PFO tests were carried out during the monophasic injection phase to determine well injectivity and reservoir properties, and were subsequently acquired at the end of each 3-month injection cycle. Analytical falloff-test interpretation relied on the use of the two zone radial composite model. Multiple falloff-test interpretations indicated that the two pattern vertical injectors behaved differently even though both had been fractured. The difference in behavior was linked to different perforated intervals and reservoir properties. Gas- and water-injection rates were showing differences between both pattern injectors as a consequence. Injected gas banks had a small inner radius and were almost undetectable at the end of the subsequent water cycle. Changes in the pressure-derivative slope at the end of the subsequent water-injection cycle indicated most likely the creation of an effective mixing zone of injected gas and water in the reservoir.

Numerical finite-volume simulation was required to account for potential injected-fluid segregation and the heterogeneous multilayered nature of the reservoir. Repeat saturation logs acquired in observation wells monitored the saturation distribution away from the injection wells. Fluid saturations derived from the simulation model were showing a good agreement with the analytical results in general, although the need to account for gas trapping was confirmed. Eight planned development WAG injectors were repositioned as a consequence of WAG 1 and WAG 2 pattern performance.

© 2011. Society of Petroleum Engineers

View full textPDF ( 3,565 KB )

History

  • Original manuscript received: 29 September 2010
  • Meeting paper published: 1 November 2010
  • Revised manuscript received: 19 May 2011
  • Manuscript approved: 21 July 2011
  • Published online: 13 December 2011
  • Version of record: 28 December 2011