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  • 1
    Online Resource
    Online Resource
    Effect of Fracture Geometry on Well Production in Hydraulic-Fractured Tight Oil Reservoirs
    Society of Petroleum Engineers (SPE) ; 2015
    In:  Journal of Canadian Petroleum Technology Vol. 54, No. 03 ( 2015-05-20), p. 183-194
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 54, No. 03 ( 2015-05-20), p. 183-194
    Abstract: Tight oil production is emerging as an important new source of energy supply and has reversed a decline in US crude-oil production and western Canadian light-oil production. At present, the combination of the multistage hydraulic fracturing and horizontal wells has become a widely used technology in stimulating tight oil reservoirs. However, the ideal planar fractures used in the reservoir simulation are simplified excessively. Effects of some key fracture properties (e.g., fracture-geometry distributions and the permeability variations) are not usually taken into consideration during the simulation. Oversimplified fractures in the reservoir model may fail to represent the complex fractures in reality, leading to significant errors in forecasting the reservoir performance. In this paper, we examined the different fracture-geometry distributions and discussed the effects of geometry distribution on well production further. All fracture-geometry scenarios were confined by microseismic-mapping data. To make the result more reliable and relevant, a geomodel was first constructed for a tight oil block in Willesden Green oil field in Alberta, Canada. The simulation model was then generated on the basis of the geomodel and history matched to the production history of vertical production wells. A horizontal well was drilled in the simulation model, and different fracture-geometry scenarios were analyzed. Results indicated that the simulation results of simple planar fractures overestimated the oil rate and led to higher oil recoveries. In addition, if the secondary fracture can achieve the same permeability as the main fracture, a hydraulic fracture with branches can increase the well production (e.g., Scenario 2 under the conductivity ratio of 1:2) because of a larger effective contact area between matrix and fracture. Secondary fractures with low permeability can decrease the well productivity compared with wells with biwing planar fractures. Furthermore, the effect of hydraulic-fracture geometries on the cumulative production of the wells with higher main-fracture conductivity was more significant compared with those with lower main-fracture conductivity.
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/167761-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2015
    detail.hit.zdb_id: 2703015-5
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  • 2
    Online Resource
    Online Resource
    Experimental investigation of asphaltene adsorption in porous media due to solvent injection and effects on relative permeability
    Elsevier BV ; 2018
    In:  International Journal of Multiphase Flow Vol. 99 ( 2018-02), p. 174-185
    Details
    In: International Journal of Multiphase Flow, Elsevier BV, Vol. 99 ( 2018-02), p. 174-185
    Type of Medium: Online Resource
    ISSN: 0301-9322
    URL: Article
    DOI: 10.1016/j.ijmultiphaseflow.2017.10.005
    Language: English
    Publisher: Elsevier BV
    Publication Date: 2018
    detail.hit.zdb_id: 2013320-0
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  • 3
    Online Resource
    Online Resource
    Development of an Algorithm of Dynamic Gridding for Multiphase Flow Calculation in Wells
    Society of Petroleum Engineers (SPE) ; 2011
    In:  Journal of Canadian Petroleum Technology Vol. 50, No. 02 ( 2011-02-1), p. 35-44
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 50, No. 02 ( 2011-02-1), p. 35-44
    Abstract: Because more and more wells have been put in operation, an accurate modelling of wellbore flow plays a significant role in reservoir simulation. One requirement of a wellbore model is its ability to trace various flow boundaries in the tubing, such as those created by phase or flow regime changing. An algorithm of dynamic gridding is applied to the wellbore flow model coupled with Stanford?s general purpose research simulator (GPRS), which has the capability to simulate the isothermal black oil reservoir model to obtain detailed information that explains such important quantities as flow pattern and mixture velocity in any specific location of wellbore. A significant problem in this case is how to calculate fluid and velocity properties with a fine grid (segment) on the boundaries of different flow regimes in the wellbore. Local dynamical segment refinement in the well can accurately and effectively handle this problem. This wellbore model includes mass conservation equations for each component and a general pressure drop relationship. The multiphase wellbore flow is represented using a drift-flux model, which includes slip between three fluid phases. The model determines the pressure, mixture flow velocity, and phase holdups as functions of time and the axial position along the well or alleviation depth. In addition, this model is capable of generating automatically adaptive segment meshes. We apply the black oil model to the simulation of several cases of isothermal dynamical local mesh refinement, and compare the results with fixed coarse and fine meshes. The experiments show that using local segment refinement can yield accurate results with acceptable computational time.
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/131019-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2011
    detail.hit.zdb_id: 2703015-5
    SSG: 19,1
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  • 4
    Online Resource
    Online Resource
    Transient Nonisothermal Fully Coupled Wellbore/Reservoir Model for Gas-Well Testing, Part 2: Applications
    Society of Petroleum Engineers (SPE) ; 2011
    In:  Journal of Canadian Petroleum Technology Vol. 50, No. 09 ( 2011-09-13), p. 51-70
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 50, No. 09 ( 2011-09-13), p. 51-70
    Abstract: After the development of a numerical fully implicit nonisothermal wellbore/reservoir simulator in Part 1 of this study (Bahonar et al. 2010), this simulator is implemented for a close and detailed study of gas-well pressure-drawdown (DD) and -buildup (BU) tests. Overall, the developed simulator is an accurate and strong tool for design and analysis of transient gas-well testing, particularly for high- pressure/high-temperature (HP/HT) gas reservoirs. Several numerical results will be presented. This includes demonstration of the behaviour of the wellbore-fluid pressure, temperature, density, and velocity and an overall heat-transfer coefficient during DD or shut-in tests for nonisothermal reservoirs and conceptual comparisons with the isothermal counterparts. Thermal effects on the behaviour of derivative plots and the sandface-flow rate of deep nonisothermal gas reservoirs will be studied. A significant effect of neglecting the heat capacity of tubular and cement materials on the wellhead-temperature simulation, and thus transient well tests, will be demonstrated. A sample case to show that neglecting the thermal effects in the gas-well tests of composite reservoirs leads to unreliable results in well-testing analysis will be presented. Several other numerical experiments, including the presence of a variable wellbore-storage coefficient, gas backflow from the wellbore to the reservoir, and other thermal effects during the gas-well tests, are also presented. Hundreds of millions of dollars are spent every year on well testing around the world (Hawkes et al. 2001). A proper design and truthful interpretation of these tests can be achieved by a reliable coupled wellbore/reservoir simulator, which in turn can save a large portion of the required costs.
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/149618-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2011
    detail.hit.zdb_id: 2703015-5
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  • 5
    Online Resource
    Online Resource
    A New Approach To Simulate the Boundary Layer in the Vapour Extraction Process
    Society of Petroleum Engineers (SPE) ; 2011
    In:  Journal of Canadian Petroleum Technology Vol. 50, No. 11 ( 2011-11-1), p. 11-18
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 50, No. 11 ( 2011-11-1), p. 11-18
    Abstract: The vapour extraction (VAPEX) process, as a nonthermal process, may be suitable for the recovery of heavy oil and bitumen. In this process, the injected solvent diffuses into the heavy oil/bitumen, reduces its viscosity, and drains it to the producing well. The VAPEX process is more acceptable than other processes because of its environmental friendliness, low capital and operating costs, and suitability for thin reservoirs. Most of the efforts in the modelling of the VAPEX process have concentrated on the application of fluid-flow equations to the solvent and the diluted oil inside each gridblock used in the simulation of the VAPEX. This is adequate when very fine gridblocks are chosen to simulate the process in which the boundary layer (transition zone) occurs over a number of gridblocks. Fine gridblocks, however, require a large amount of simulation time, which is not applicable for field-scale simulation even with today's computing power. To deal with this problem, a new approach is introduced that is based on the application of the fluid-flow equations to three phases: solvent, diluted oil, and heavy oil/bitumen. With this approach, it becomes possible to have mobile solvent, mobile live oil, and immobile or slow-moving heavy oil/bitumen inside a gridblock. The main feature of the proposed model is its ability to capture the boundary layer within a gridblock, making very fine gridblocks unnecessary in the simulation of the VAPEX process. In addition, this approach can be applied to model the viscous fingering inside gridblocks.
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/148055-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2011
    detail.hit.zdb_id: 2703015-5
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  • 6
    Online Resource
    Online Resource
    Transient Nonisothermal Fully Coupled Wellbore/Reservoir Model for Gas-Well Testing, Part 1: Modelling
    Society of Petroleum Engineers (SPE) ; 2011
    In:  Journal of Canadian Petroleum Technology Vol. 50, No. 09 ( 2011-09-13), p. 37-50
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 50, No. 09 ( 2011-09-13), p. 37-50
    Abstract: A numerical fully implicit nonisothermal wellbore/reservoir simulator is developed. The model entails simultaneous solution of transient coupled mass-, momentum-, and energy-balance equations within the wellbore; energy-balance equations for the tubular and cement materials and the formation surrounding the wellbore; and mass-balance and flow-rate/pressure equations for the reservoir formation. A wellbore heat-loss model that is a strong feature of this study is developed and employed in the model to improve the accuracy of the simulator and to be able to estimate the casing temperature and formation-temperature distribution. The model formulation is completed with an equation of state (EOS) to estimate fluid properties and appropriate friction-factor correlations in the wellbore tubing to compute the frictional pressure drop for different flow regimes. The developed model has several applications in the petroleum industry, particularly in the gas-well testing design and interpretation of both isothermal and nonisothermal gas reservoirs. This nonisothermal simulator is validated through comparisons to both analytical models and an equivalent numerical isothermal coupled wellbore/reservoir simulator that is also developed in this paper. Applications of this simulator to analyzing gas-well testing problems, in addition to several important observations, are extensively studied in Part 2 of this research work (Bahonar et al. 2010). Currently, it has been well accepted that the applicability and significance of a reservoir simulator depend on the behaviour of the wellbore and interaction between the wellbore and reservoir. A robust, accurate coupled wellbore and reservoir simulator is an invaluable tool for the petroleum engineer to help the petroleum industry understand production behaviour, make a meaningful prediction, and make correct decisions in all field-development and production stages.
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/149617-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2011
    detail.hit.zdb_id: 2703015-5
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  • 7
    Online Resource
    Online Resource
    Lessons Learned and Experiences Gained in Developing the Waterflooding Concept of a Fractured Basement-Granite Reservoir: A 20-Year Case Study
    Society of Petroleum Engineers (SPE) ; 2011
    In:  Journal of Canadian Petroleum Technology Vol. 50, No. 09 ( 2011-09-13), p. 10-23
    Details
    In: Journal of Canadian Petroleum Technology, Society of Petroleum Engineers (SPE), Vol. 50, No. 09 ( 2011-09-13), p. 10-23
    Abstract: Naturally fractured reservoirs (NFRs) represent more than 20% of the world's oil and gas reserves. However, their characterization is complex and presents unique challenges in comparison with conventional reservoirs. It is immensely difficult to achieve the best results in the secondary-recovery process for NFRs. This paper presents a successful development of waterflooding to overcome the complex geological characterization of the White Tiger field, the largest fractured basement reservoir to date on the continental shelf of Vietnam. This reservoir has a complicated geological structure, with high heterogeneity, high temperature, and high closure stress. The total oil initially in place (OIIP) of this field reached nearly 4 billion bbl from 2000 m of oil-bearing thickness, and the field has been produced by more than 100 wells, 10 of which have flowed at the rate of approximately 1,000 B/D. The geological study and fractured model have been carefully investigated in both micro- and macroscale to improve waterflooding performance. The authors have analyzed the advantages and disadvantages of injection systems in this basement reservoir during 20 years of production history, and an artificial water buffer solution has been proposed to improve the waterflooding process. The authors have described the establishment and association of local artificial water buffer in the basement reservoir. An effective method to optimize the injected-water volume has also been discussed. Promising results from the White Tiger field have shown that the average reservoir pressure and total oil recovery have increased significantly in comparison with previous injection schemes. This paper presents useful guidelines to solve some typical problems of waterflooding in fractured basement reservoirs: What can be applied in waterflooding for a fractured basement reservoir? What is the optimal injection rate and injected volume for the fractured basement reservoir? How do we evaluate the probability of high water cut in production wells during the waterflooding process? How do we predict the rise of an artificial water/oil contact (AWOC)?
    Type of Medium: Online Resource
    ISSN: 0021-9487
    URL: Article
    DOI: 10.2118/137561-PA
    Language: English
    Publisher: Society of Petroleum Engineers (SPE)
    Publication Date: 2011
    detail.hit.zdb_id: 2703015-5
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  • 8
    Online Resource
    Online Resource
    Mathematical and Numerical Modeling of Flow and Transport
    Hindawi Limited ; 2011
    In:  Journal of Applied Mathematics Vol. 2011 ( 2011), p. 1-4
    Details
    In: Journal of Applied Mathematics, Hindawi Limited, Vol. 2011 ( 2011), p. 1-4
    Type of Medium: Online Resource
    ISSN: 1110-757X , 1687-0042
    URL: Article
    DOI: 10.1155/2011/901380
    Language: English
    Publisher: Hindawi Limited
    Publication Date: 2011
    detail.hit.zdb_id: 2578385-3
    SSG: 17,1
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  • 9
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    Online Resource
    Calculation method of deep-water surface conductor bearing capacity based on jetting operation parameters
    Elsevier BV ; 2024
    In:  Geoenergy Science and Engineering Vol. 234 ( 2024-03), p. 212625-
    Details
    In: Geoenergy Science and Engineering, Elsevier BV, Vol. 234 ( 2024-03), p. 212625-
    Type of Medium: Online Resource
    ISSN: 2949-8910
    URL: Article
    DOI: 10.1016/j.geoen.2023.212625
    Language: English
    Publisher: Elsevier BV
    Publication Date: 2024
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  • 10
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    Online Resource
    Introduction
    Wiley ; 2014
    In:  Numerical Methods for Partial Differential Equations Vol. 30, No. 5 ( 2014-09), p. 1425-1426
    Details
    In: Numerical Methods for Partial Differential Equations, Wiley, Vol. 30, No. 5 ( 2014-09), p. 1425-1426
    Type of Medium: Online Resource
    ISSN: 0749-159X , 1098-2426
    URL: Issue
    URL: Article
    DOI: 10.1002/num.v30.5
    DOI: 10.1002/num.21902
    Language: English
    Publisher: Wiley
    Publication Date: 2014
    detail.hit.zdb_id: 2012605-0
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