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Unconventional Energy Resources: 2013 Review thickness, hosted primarily within the Leduc Forma- tion carbonates (ERCB 2012). A number of factors (including economic, environmental, and technological criteria) are ap- plied to the initial in-place volumes of crude bitu- men to attain the established reserves. In Alberta there are two types of reserves for crude bitu- men—those that are anticipated to be recovered by surface mining techniques (generally in areas with <65 m (<213 ft) of overburden in the Athabasca area), and those to be recovered by underground in situ technologies (in areas with >65 m or >213 ft overburden) (largely thermal, for Athabasca, mainly steam-assisted gravity drainage (SAGD); for Cold Lake, cyclic steam stimulation (CSS); and for Peace River, thermal and primary recovery) (Tables 6, 7). Alberta is CanadaÕs largest producer of mar- ketable gas (71% in 2011) and of crude oil and Table 6. Mineable Crude Bitumen Reserves in Alberta for Areas Under Active Development as of December 31, 2011 (from ERCB 2012) Development CNRL Horizon Fort Hills Imperial/Exxon Kearl Shell Muskeg River Shell Jackpine Suncor Project Areaa (ha) 28,482 18,976 19,674 13,581 7,958 19,155 44,037 Initial Mineable Volume In Place (106 m3) 834 699 1,324 672 361 990 2,071 6,951 Initial Established Reserves (106 m3) 537 364 872 419 222 687 1,306 4,407 Cumulative Production (106 m3) 13 0 0 70 7 300 430 820 Remaining Established Reserves (106 m3) 524 364 872 349 215 387 876 3,587 Syncrude Total 151,863 1 ha = 2.47 acres; 1 m3 = 35.31 cubic feet. aThe project areas correspond to the areas defined in the project approval. Table 7. In Situ Crude Bitumen Reservesa in Alberta for Areas Under Active Development as of December 31, 2011 (from ERCB 2012) Development Peace river oil sands area Thermal commercial projects Primary recovery schemes Subtotalc Athabasca oil sands area Thermal commercial projects Primary recovery schemes Enhanced recovery schemesd Subtotalc Cold lake oil sands area Thermal commercial (CSS)f Thermal commercial (SAGD)g Primary recovery schemes Subtotalc Totalc Initial Volume In Place (106 m3) 63.7 160.8 224.5 391.8 1,026.2 (289.0)e 1,418.0 1,212.8 33.8 6,257.5 7,504.1 9,146.6 Recovery Factor (%) Initial Established Reserves (106 m3) Cumulative Productionb (106 m3) Remaining Established Reserves (106 m3) 40 25.5 10 16.1 41.6 11.1 14.4 12.3 3.8 23.4 18.2 50 5 10 25 50 5 195.9 51.3 28.9 276.1 303.2 16.9 312.9 633.0 950.7 89.1 23.1 18.9 131.1 226.6 2.6 90.6 319.8 474.3 106.8 28.2 10.0 145.0 76.6 14.3 222.3 313.2 476.4 1 m3 = 35.31 cubic feet. aThermal reserves reported in this table are assigned only for lands on which thermal recovery is approved and drilling development has occurred. bIncludes amendments to production reports. cAny discrepancies are due to rounding. dSchemes currently on polymer or waterflood in the Brintnell–Pelican area. Previous primary production is included under primary schemes. eThe in-place number is that part of the initial volume in place for primary recovery schemes that will see incremental production due to polymer or waterflooding. fCyclic steam simulation projects. gSteam-assisted gravity drainage projects.PDF Image | Unconventional Energy Resources
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