Injection profiling in horizontal wells using temperature warmback analysis
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ORIGINAL PAPER
Injection profiling in horizontal wells using temperature warmback analysis Refaat G. Hashish 1 & Mehdi Zeidouni 2 Received: 6 April 2020 / Accepted: 9 September 2020 # Springer Nature Switzerland AG 2020
Abstract Horizontal wells have been used for water flooding operations for the purpose of pressure maintenance and improved oil recovery, e.g., in tight oil reservoirs. Injection profiling along the well lateral is required to determine the effectiveness of water flooding operations and to maintain high sweep efficiency. Recent improvements in downhole temperature monitoring tools allow monitoring the transient temperature along horizontal waterflooding wells at a relatively low cost. Temperature data can be analyzed to infer the injection profile along wellbore and locate high permeability regions that cause non-uniform rate distribution along the wellbore. In this work, an analytical model is developed to describe the transient temperature in the reservoir during cold fluid (water) injection via a horizontal well during injection and warmback periods. The analytical solution assumes linear flow in the reservoir and accounts for heat transfer by different mechanisms including convection, conduction, and heat gain from the surrounding impermeable strata. The inversion procedure is introduced to evaluate injection profiling using analytical solution–based type curves. Different cases are considered using a thermally coupled numerical reservoir simulator to verify the analytical approach and illustrate the potential application of the inversion technique. We show that the analytical approach introduced in this work is an efficient and robust technique to infer the injection profile along horizontal wells. Keywords Injection profiling . Horizontal wells . Temperature warmback analysis . Analytical modeling
Abbreviations αt thermal diffusivity of reservoir, L2/t,ft2/s[m2/s] β dimensionless convection parameter BVP boundary value problem Cr, Cw, Cs heat capacity of reservoir system, reservoir fluid, and solids, L2/(t2 T), Btu/lbm F [J/kg K] DTS distributed temperature sensing Df hydraulic front position, L, ft [m] Erfc (−) complementary error function h reservoir thickness, L, ft [m]
* Mehdi Zeidouni [email protected] Refaat G. Hashish [email protected] 1
Craft and Hawkins Department of Petroleum Engineering, Louisiana State University, 2242 Patrick F. Taylor Hall, Baton Rouge, LA 70803, USA
2
Craft and Hawkins Department of Petroleum Engineering, Louisiana State University, 3209 P Patrick F. Taylor Hall, Baton Rouge, LA 70803, USA
IBVP k κ Lw ℒ−1 PLT PTA P Pe q S Sw So Sw t tinj Δt tDinj ΔtD T Tm
initial–boundary value problem reservoir permeability, L2, md [m2] dummy integration variable involved in Eq. (36) lateral section of wellbore, L, ft [m] inverse Laplace transformation operator production logging tool pressure transient analysis Laplace dummy variable (see Eq. (37)) Péclet number injection rate, L3/t, bbl/day [m3/s] Laplace dummy variable (see Eq. (37)) water saturation oil saturation ave
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