Optimum Water Alternate Gas Injection Schemes for Stratified Reservoirs

Surguchev, L.M.; Korbøl, Ragnhild; Krakstad, O.S.

doi:10.2118/24646-ms

Cited by 22 publications

(17 citation statements)

References 17 publications

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“…Because of various reservoir factors, the optimum conditions may occur in the reservoir to a limited extent, usually in the water/gas-mixing zone. 13 Thus the optimum WAG design is different for each reservoir and needs to be determined for a specific reservoir and possibly fine-tuned for patterns within the reservoir.…”

Section: Overview Of Wag Injection Processmentioning

confidence: 99%

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A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process

Grigg

2000

SPE/DOE Improved Oil Recovery Symposium

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TX 75083-3836, U.S.A., fax 01-972-952-9435. 3. 3 nitrogen-miscible projects 4. 1 hydrocarbon-immiscible 5. 1 nitrogen-and hydrocarbon-immiscible 6. 6 nitrogen-immiscible CO 2 projects continue to grow in numbers. Immiscible CO 2 projects have dropped to zero while ten new miscible CO 2 projects were planned as of January 1998. Brock and Bryan 2 presented a summary of CO 2 EOR projects and reviewed the performance of 30 full-scale field projects and field pilots up to 1987. In 1992 there were 45 active CO 2 projects in the U.S. 3 Initially the industry outlook was pessimistic; however, by 1992 most projects had been shown to be technically and economically successful. In a number of projects, the production performance has been better than was anticipated. 3 At the beginning of 1998 and based on 1997 production figures, the U.S. production from gas injected EOR was estimated at 307,544 b/d or approximately 4.7% of the total oil production in the US. Oil production from CO 2 activity alone contributed nearly 179,000 b/d, which is an increase of 4.9% over 1996 production attributable to CO 2 production and represents 2.8% of the 1997 US oil production of 6.4 MM bopd. 1 The Permian Basin of west Texas and southeastern New Mexico remains a very active area for CO 2 projects. Eight of the ten planned projects are in the Permian Basin. 1 However, new CO 2 EOR projects are possible for areas of California,

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Section: Overview Of Wag Injection Processmentioning

confidence: 99%

“…Fluid properties 9,13,44,45,58,59 4. Miscibility conditions 8,9,13 5. Injection techniques 8,9,13 (tapered WAG design as opposed to a constant WAG design) 6.…”

Section: Overview Of Wag Injection Processmentioning

confidence: 99%

A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process

Grigg

2000

SPE/DOE Improved Oil Recovery Symposium

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“…Former study considered down dip water injection and up dip gas injection to improve the displacement efficiency, however it has been shown that up dip water injection and down dip gas injection are suitable for the reservoir with high permeable layer on top or for the reservoir with thin oil rim layer. [4][5][6][7][8][9][10][11][12][13][14][15][16][17][18][19] III. METHODOLOGY…”

Section: Literature Reviewmentioning

confidence: 99%

Simulation modeling of different I-WAG schemes toward optimization of displacement efficiency

Mirkalaei

Demiral

Hosseini

et al. 2011

2011 National Postgraduate Conference

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The success of the hydrocarbon recovery improvement via Water Alternative Gas injection process is closely related to the microscopic displacement and macroscopic sweep efficiency. Effectiveness of the successive displacements by water and gas injections, maximizing the three phase zones by optimum force balancing in the reservoir, WAG injection cycle, double displacement and film drainage process are among the important parameters that affect the sweep and displacement efficiency in WAG process. Water and gas injection scheme play an important role in optimization of these parameters. Different schemes of WAG injection have been reported in open literature including gas injection up dip, water injection down dip and vice versa.In this paper, the efficiency of various WAG injection schemes toward improvement of the above important parameters will be presented. Detailed theoretical investigation and simulation study are conducted. A new injection scheme is proposed. In the proposed methodology, water is injected from down dip and gas is injected from up dip in the first cycle. In the second cycle, gas is injected from down dip and water is injected from up dip. Water and gas injection location will alternatively change in each cycle of injection. Different design parameters are considered and studied including mobility ratio between water and oil phases, location of the water and the gas injectors, injection rate, WAG injection cycle. The results show that the proposed methodology has significant improvement on the displacement efficiency and three phase zone size and hence yield higher hydrocarbon recovery.

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“…Reduction of water injectivity can also be the result of the redistribution of pressure profiles when the injecting is changed from gas to water and vertical permeability is limited. For the case of WAG injection in non-communicating layers, Surguchev et al 1 showed that the effective fluid mobility is reduced in the highest permeability layer as well as in all the other layers. This results in a larger fraction of gas entering the highest permeable layer with WAG.…”

Section: Modeling Wag In a Stratified Reservoirmentioning

confidence: 99%

The Performance of WAG in a Stratified Reservoir, Hassi-Messaoud Field, Algeria

Drid

Tiab

2004

SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractWater Alternating Gas (WAG) process has been the subject of research, development, and field testing for a long time in Hassi Messaoud (HMD) field. There is still some disagreement in the interpretation of laboratory, field test data and in the selection of optimum parameters of injection such as (water/gas ratio, cycle period and miscibility conditions). The major reason for these problems is that the reservoir model does not mach the reference model. This work describes a method for designing an effective water/gas flooding in a stratified reservoir, and particularly in HMD. The proposed approach is based on a more realistic numerical model that takes into account the effect of threephase flow, gravity and viscous forces in anisotropic media, which allows the determination of optimum parameters of water/gas injection. In addition, the performances of different WAG injection options were compared with the performance of waterflooding and gas injectionThe simulation results illustrate the influence of WAG injection parameters, such as water-gas ratio, injection rates and cycle period on recovery process and select the optimum WAG ratio and WAG cycle. A more realistic reservoir model is the key to evaluate the performance of WAG injection in stratified reservoir, such as HMD.Based on the simulation results, Water-Alternating-Gas injection is the most successful process as compared to waterflooding and gas injection. The incremental oil recovery using WAG technique can reach 7% of OOIP and the GOR is more easily controlled than in conventional methods.

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Optimum Water Alternate Gas Injection Schemes for Stratified Reservoirs

Cited by 22 publications

References 17 publications

A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process

A Literature Analysis of the WAG Injectivity Abnormalities in the CO2 Process

Simulation modeling of different I-WAG schemes toward optimization of displacement efficiency

The Performance of WAG in a Stratified Reservoir, Hassi-Messaoud Field, Algeria

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