Laboratory Procedures for Optimizing the Recovery from High Temperature Thermal Heavy Oil and Bitumen Recovery Operations

Bennion, D.B.; Ma, Tao; Thomas, F.B.; Romanova, U.G.

doi:10.2118/2007-206

Cited by 16 publications

(4 citation statements)

References 19 publications

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“…Thermal recovery processes (EOR), which rely on viscosity reduction of the oil through heat that is injected or generated in situ, are well suited for unlocking these resources. For thermal production technologies, operations such as cyclic steam stimulation (CSS), steamassisted gravity drainage (SAGD) and steam drive are used on a worldwide basis to exploit large reserves of heavy oil and bitumen which will comprise the majority of future world oil production in the decades to come [3,6]. It should be mentioned that thermal EOR processes are best suited for reservoirs containing tar sands (≤ 10°API) and heavy oils (10-20°API) [5,15].…”

Section: Introductionmentioning

confidence: 99%

Optimization of Cyclic Steam Stimulation in Heavy Oil Naturally Fractured Reservoirs

Elkamel

Sedaee

2021

Arab J Sci Eng

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Steam injection in naturally fractured reservoirs provides an extremely challenging problem as well as a potentially effective and efficient improved oil recovery method. Coupling of the two distinct and contrasting matrix and fracture systems results in a highly nonlinear problem, and it gets even more complicated as a result of steep changes in fluid properties due to the thermal effects of steam injection. Modeling and designing an optimum steam injection operation in such systems requires an accurate characterization and representation of a naturally fractured reservoir and steam injection operation parameters and dynamics. In this research effort, we attempt to simulate the cyclic steam stimulation oil recovery method in a naturally fractured reservoir containing heavy oil and also analyze the influences and contribution of different operating parameters on ultimate oil recovery factor and the project net present value. A thermal numerical simulator has been utilized for the specialized application. The economic analysis was then coupled using the integrated production model. Further, the best possible scenario is conducted for this reservoir using computer modeling optimization and sensitivity analysis Toolbox.The results from the model show the advantage of a fracture system in conducting heat into the rock matrix, because of the large surface area exposed to heating. The key findings from the operating parameters sensitivity analysis were that the minimum injection period with larger steam slugs, minimum soak and production periods is required for every cycle, in order to maximize recovery and optimize the cost. KeywordsCyclic steam stimulation (CSS) • Naturally fractured reservoir (NFR) • Recovery factor (RF) • Technical and economical optimization Abbreviations EOR Enhanced oil recovery CSS Cyclic steam stimulation SAGD Steam-assisted gravity drainage CMG Computer Modeling Group RF Recovery factor NFR Naturally fractured reservoir NPV Net present value IPM Integrated production model FISAM Fully integrated and stochastic asset model CDOR Calendar day oil rate ECW Equivalent cold water B Behnam Sedaee

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Section: Introductionmentioning

confidence: 99%

Optimization of Cyclic Steam Stimulation in Heavy Oil Naturally Fractured Reservoirs

Elkamel

Sedaee

2021

Arab J Sci Eng

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“…1989, Abercrombie et-al. Bulletin of Canadian Petroleum Geology, v.27, Bennion et-al., 2007). Clays react with steam and consume sodium ion and releases hydrogen ion (Hong, 1994) resulting in higher pH of the formation water.…”

Section: Introductionmentioning

confidence: 99%

“…This phenomenon was also observed in the field during cyclic steam stimulation (Jain et-al., 2015). Mineral alterations of clays such as kaolinite may take place at higher temperatures (Bennion et-al., 2007). Kaolinite moves in the pore structures and also causes significant permeability reduction.…”

Section: Introductionmentioning

confidence: 99%

An Experimental Investigation of Steam Induced Permeability Changes in Clay Bearing Formation of North Kuwait

Jain

Ahmed

Ferdous

et al. 2016

Day 1 Mon, March 21, 2016

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The Neogene of North Kuwait comprises of unconsolidated sandstone reservoir having viscous crude. The field is to be developed by way of injecting steam into the reservoir. The XRD and SEM studies revealed that variety of the detrital clay minerals like Illite, Smectite, Chlorite, and Palygorskite commonly occurring within the formation. An experimental study was carried out to understand the implications of steam injection on the clay bearing formations and to determine temperature-dependent water-oil relative permeability to provide an indication of the recoverable reserves under steam injection. Sensitivity to different pH and salinity were also analyzed.Detailed laboratory study was conducted on nine plugs to determine the effect of hot water and steam injection on the permeability, relative permeability, residual oil saturation and mineralogical changes in the reservoir. The baseline steamflood was carried out to determine the residual oil saturation and evaluate the permeability changes due to clay swelling/dispersion in contact with brine and steam. The other six sensitivity steamfloods were carried out to determine the potential permeability damage resulting from clay swelling/dispersion when contacted with different pH fluid, salt concentrations (TDS) and clay stabilizers. Pre and post XRD and SEM analysis were done to see the effects of each steamflood on the core sample.This paper presents the discussion on results of core flood experiments conducted on nine preserved core samples at reservoir conditions. The results show that clays when contacted with steam induce significant permeability reduction. High salinity and pH control may not be sufficient to eliminate the loss of permeability. However, some clay stabilizers are found to be useful to improve the permeability and recovery.

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“…The critical nature of this decision is recognized within the industry, and lab testing has been studied for numerous years, for thermal applications of liner and screen sizing 1,2,3 . Liner/screen sizing is a critical decision that needs to be properly tested based on the particle size distribution (PSD) of the area.…”

Section: Introductionmentioning

confidence: 99%

Using Prepack Sand-Retention Tests (SRT's) to Narrow Down Liner/Screen Sizing in SAGD Wells

Devere-Bennett

2015

Day 3 Wed, November 25, 2015

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Due to the unconsolidated nature of the Athabasca Oil Sands in the Western Canadian Sedimentary Basin, it is common practice to complete Steam Assisted Gravity Drainage (SAGD) well pairs with the use of standalone screens (SaS's). The sizing of the liner/screen types are commonly determined by: first, getting a particle size distribution (PSD) by dry-sieve analysis and/or Laser Particle Sand Analysis (LPSA); and second, running a number of prepack Sand-Retention Tests (SRT's).In this Nexen Long Lake study, five batches of unconsolidated McMurray Formation sand were collected from six different cored wells. Using these batches of sand, more than twenty SRT's were run with a variety of fine-tuned modifications to the traditional test protocols to best duplicate fluid production conditions as observed in the field. Some of these modifications included: altering the injected fluid/gas rate and reconfiguring the order in which the fluids / gas were injected.The SRT results were then plotted to identify if they passed the general criteria for a successful sand control device design. Unexpectedly, many of the SRT results did not meet the pass criteria for solids production and therefore, altered the direction in which future tests were run. However, when reviewing the solids production with the cumulative fluids / gas injected, the outcome commonly reverted to being favourable.Understanding the laboratory derived test results, and how they applied to the field, was instrumental in the lab testing process. By redefining the tests results and pass/fail criteria, based upon observed in-situ production conditions, it was possible to make both qualitative as well as quantitative analysis and therefore, more confidently decide on the optimal reservoir completion type.The study discusses an alternative approach to interpretation of conventional SRT results relative to observed field production conditions and how ultimately, this analysis influenced the choice of liner/ screen sizing selected for implementation in future Long Lake field development projects.

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Laboratory Procedures for Optimizing the Recovery from High Temperature Thermal Heavy Oil and Bitumen Recovery Operations

Cited by 16 publications

References 19 publications

Optimization of Cyclic Steam Stimulation in Heavy Oil Naturally Fractured Reservoirs

Optimization of Cyclic Steam Stimulation in Heavy Oil Naturally Fractured Reservoirs

An Experimental Investigation of Steam Induced Permeability Changes in Clay Bearing Formation of North Kuwait

Using Prepack Sand-Retention Tests (SRT's) to Narrow Down Liner/Screen Sizing in SAGD Wells

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