Reservoir Performance of a Gravity-Stable, Vertical CO2 Miscible Flood: Wolfcamp Reef Reservoir, Wellman Unit

Bangia, Vijay; Yau, F.F.; Hendricks, G.R.

doi:10.2118/22898-pa

Cited by 39 publications

(23 citation statements)

References 7 publications

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“…Investigations in the laboratories and in the field [11][12][13][14][15][16][17][18] suggest the importance of the gas-oil gravity segregation in CO 2 EOR. Kulkarni and Rao [16] presented the effect of important dimensionless groups on the final oil recovery obtained from a number of miscible and immiscible CO 2 gravity drainage experiments.…”

Section: Introductionmentioning

confidence: 99%

Investigation of CO2 Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Tabrizy

2014

Journal of Petroleum Engineering

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The paper addresses enhanced oil recovery in chalk and sandstone rocks by CO 2 injection, with different wettability, porosity, and permeability as well as injection rate and flooding conditions. Results indicate that an increase in Bond number has a positive effect on oil recovery whereas for capillary number, there is a limit in which recovery is improving. This limit is estimated when the pressure drop by viscous force is approximately equal to the threshold balance between capillary and gravity forces. A dimensionless group is proposed that combines the effect of capillarity, injection rate, permeability, and CO 2 diffusion on the oil recovery. Recovery from all experiments in this study and reported data in the literature shows a satisfactory relationship with the proposed group.

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Section: Introductionmentioning

confidence: 99%

Investigation of CO2 Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Tabrizy

2014

Journal of Petroleum Engineering

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“…For immiscible flow, displacement efficiency could depend on the wetting properties of the fluids, the rate of gas injection and oil production, the difference of oil and gas density, their viscosity ratio, and the oil relative permeability. Investigations in the laboratories and in the field (Hagoort 1980;Chatzis et al 1988;Da Sle and Guo 1990;Bangla et al 1991;Kantzas et al 1998;Rao et al 2004;Kulkarni and Rao 2006;Jadhawar and Sarma 2008) suggest the importance of the gas-oil gravity drainage process in improving the recovery characteristics of gas injection EOR methods. Majority of studies investigate the effect of dimensionless groups on recovery performance (Grattoni et al 2001;Gharbi 2002;Kulkarni and Rao 2006;Wood et al 2008;Jadhawar and Sarma 2008).…”

Section: Introductionmentioning

confidence: 99%

Identification of Fluid Dynamics in Forced Gravity Drainage Using Dimensionless Groups

et al. 2009

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A number of forced gravity drainage experiments have been conducted using a wide range of the physical and operational parameters, wherein the type, length, and permeability of the porous medium as well as oil viscosity and injection rate were varied. Results indicate that an increase in the Bond number has a positive effect on oil recovery whereas the capillary number has an opposite effect. These trends were observed over a two-order of magnitude change in the value of the dimensionless groups. Furthermore, it was found that use of each number alone is insufficient to obtain a satisfactory correlation with recovery. A combined dimensionless group is proposed, which combines the effect of all the three forces. Recoveries from all the experiments conducted in this study show a very good correlation with the proposed group. The exponent of the Bond number in the proposed group is larger than the capillary number suggesting a larger importance for the former. We then show that the same group provides a good correlation for recovery from additional experiments conducted in this study (in the presence of connate water) with that of another set of experiments in the literature.

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“…For example, hydrocarbon miscible floods have been carried out in a number of Canadian reefs (1)(2)(3)(4)(5) . Vertical gravity-stable carbon dioxide floods were reported in three US fields (4)(5)(6)(7)(8) , also with excellent additional oil recoveries.…”

Section: Introductionmentioning

confidence: 95%

Effect of H2S and Pressure Depletion on the CO2 MMP of Zama Oils

Sayegh

Huang

Zhang

et al. 2007

Journal of Canadian Petroleum Technology

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Phase behaviour and minimum miscibility pressure measurements were carried out to evaluate the potential of applying miscible CO2/H2S flooding in the Zama reefs of NE Alberta, Canada. Since there is some variability in the properties of oils from different wells or reefs, the measurements were carried out on recombined reservoir fluids from two different wells. The injection solvent will be supplied from a nearby gas plant that is expected to produce CO2/H2S streams with a range of compositions due to a number of operational factors. Accordingly, three solvent injection gases were considered: pure CO2 and CO2 containing 20 and 40 mol% H2S. Minimum miscibility pressure (MMP) measurements were carried out using the rising bubble apparatus (RBA). The MMP decreased almost linearly with the amount of H2S in the injection gas in the range of compositions studied. Some evidence of precipitation of solids was observed. Measurements were also carried out to determine the CO2 MMP of these reservoir fluids as they were depleted of gas through a differential liberation procedure. The results show that the MMP decreased with decreasing liberation pressure. Key properties of the liberated reservoir fluids were also measured and compared with those of the recombined reservoir fluids. The results show that miscible flooding with sour acid gas is feasible in this case, and could provide an excellent means of storing/sequestering these gases while improving oil recovery. Introduction Vertical gasfloods have an excellent track record for producing additional oil. For example, hydrocarbon miscible floods have been carried out in a number of Canadian reefs(1–5). Vertical gravity-stable carbon dioxide floods were reported in three US fields(4–8), also with excellent additional oil recoveries. The Zama Field(9) is located in northeastern Alberta and contains a large number (600 – 800) of relatively small pinnacle reefs with up to 1.5 ? 106 m3 (10 mmbbl) of original oil in place (OOIP). The wells selected for this study produce from the Keg River Formation. Al-Dilwe and Asghari(10) described the reservoir and its production history from the 1960's. The produced oil and gas are sour and contain an appreciable amount of carbon dioxide. The centrally located Zama Gas Plant (operated by Apache Canada Ltd.) removes the H2S and CO2 from the produced gases by amine absorption. These acid gases constitute an excellent miscible flooding agent for the field, thereby achieving the double advantage of increasing the oil recovery and providing storage capacity for these gases. Trivedi et al.(9) simulated different strategies for solvent injection to maximize oil recovery and gas storage as well as delaying breakthrough, and found that pressure maintenance is a key factor in the operation. A significant degree of acid gas breakthrough is expected to occur due to the reservoir heterogeneity represented by these Zama/Keg River pinnacles. Breakthrough will occur at H2S concentrations that are too high to process through the existing amine systems. To accommodate early breakthrough, recycle compression is to be installed in order to bypass the amine systems and re-inject acid gas back into miscible flooded pinnacles.

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Reservoir Performance of a Gravity-Stable, Vertical CO2 Miscible Flood: Wolfcamp Reef Reservoir, Wellman Unit

Cited by 39 publications

References 7 publications

Investigation of CO2 Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Investigation of CO2 Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Identification of Fluid Dynamics in Forced Gravity Drainage Using Dimensionless Groups

Effect of H2S and Pressure Depletion on the CO2 MMP of Zama Oils

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