Improved Steamflood Analytical Model

Abstract

The Jeff Jones steamflood model incorporates oil displacement by steam as described byMyhill and Stegemeier, and a three-component capture factor based on empirical correlations. The main drawback of the model however is the unsatisfactory prediction of the oil production peak: usually significantly lower than the actual. Our study focuses on improving this aspect of the Jeff Jones model.In our study, we simulated the production performance of a 5-spot steamflood pattern unit and compared the results against those based on the Jeff Jones model. Three reservoir types were simulated using 3-D Cartesian black oil models: Hamaca (9°API), San Ardo (12°API) and that based on the SPE fourth comparative solution project (14°API). In the first two field cases, a 45x23x8 model was used that represented 1/8 of a 10-acre 5-spot pattern unit, using typical rock and reservoir fluid properties. In the SPE project case, three models were used: 23x12x12 (2.5 ac), 31x16x12 (5 ac) and 45x23x8(10 ac), that represented 1/8 of a 5-spot pattern unit.To obtain a satisfactory match between simulation and Jeff Jones analytical model results of the start and height of the production peak, the following refinements to the Jeff Jones model were necessary. First, the dimensionless steam zone size A cD was modified to account for decrease in oil viscosity during steamflood and its dependence on the iv steam injection rate. Second, the dimensionless volume of displaced oil produced V oD was modified from its square-root format to an exponential form.The modified model gave very satisfactory results for production performance up to 20 years of simulated steamflood, compared to the original Jeff Jones model.Engineers will find the modified model an improved and useful tool for prediction of steamflood production performance.v DEDICATIONThis thesis is dedicated to my family in Indonesia, especially to my mother, Sia Soei Hwa, for her endless love.vi ACKNOWLEDGEMENTS

A statistical approach to investigate oil displacement efficiency in thermal recovery techniques for heavy oil based on one-dimensional core experiment

“…In many analytical models of dynamic prediction of thermal recovery, there is a parameter , that is, the oil saturation change value of reservoir before and after steam displacing (Myhill and Stegemeier, 1978;Butler and Stephens, 1981;Chandra and Mamora, 2005;Huang et al, 2016). It is a core and indispensable parameter of the analytical model, such as steam drive and steam Assisted gravity oil discharge.…”

Effects of Solvent Properties and Injection Strategies on Solvent-Enhanced Steam Flooding for Thin Heavy Oil Reservoirs with Semi-Analytical Approach

“…In the second stage, the production rate remains virtually stable because the hot water zone between the steam zone and boundaries alleviates the heat loss. After the steam condensate reaches the production well, the oil production rate begins to decrease sharply; in this stage the steam zone and hot water zone stop expanding at the point when the heat loss rate to the overburden and understrata equals the heat injection rate [31,32].…”

Mathematical analysis of oil displacement by steam in porous media

“…Several attempts have been made to develop analytical models for evaluating steam floods (Marx and Langenheim, 1959;Landrum et al, 1960;Boberg and Lantz, 1966;Mandl and Volek, 1969;Neuman, 1975;Myhill and Stagemeier, 1978;Gomaa, 1980;Jones, 1981 andChandra, 2005). Unfortunately, most of these methods considered direct steam drive of oil and neglected steam condensation and the very important hot water zone.…”