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Alaska Oil and Gas Conservation Commission

Alaska Department of Administration, Alaska Oil and Gas Conservation Commission
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AOGCC Pool Statistics
Prudhoe Bay Unit, Aurora Oil Pool
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Operator: BP Exploration (Alaska) Inc.
Index Map
Discovery Well: Mobil Oil Corporation
  North Kuparuk State No. 26-12-12
  Permit No. 169-057
  API No. 50-029-20032-00-00
  Sec. 26, T12N, R12E, UM

Depth: 10,311’ MD / TVD

August 24, 1969

Status: Producing
Location: Central Arctic Slope Area Location Map Pool Location Map DNR Unit Map
References: List of Orders Summary - Annotated Reference List  
Summary:

The Aurora Oil Pool ("AOP") is located within the current boundaries of the Prudhoe Bay Unit ("PBU"), and it occurs within the Kuparuk River Formation (“Kuparuk”). The pool was discovered in 1969 by the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12, where the accumulation lies between the depths of 6,765’ and 7,765’. The structure lies between 6450' and 6850' true vertical depth below sea level. Regular production from the field began in November 2000, and regular water injection began in December 2001. Production peaked at just over 14,000 barrels of oil per day (BOPD) during August and September of 2006, and then began to decline. For the second quarter of 2011, production averaged 7,900 BOPD.

 

Geology:

Within the Aurora pool, the Kuparuk comprises Early Cretaceous-aged marine shoreface and offshore sediments consisting of very fine to medium grained, quartz-rich sandstone with interbedded siltstone and mudstone. The Kuparuk is stratigraphically complex, characterized by multiple unconformities, changes in thickness and sedimentary facies, and local diagenetic cementation. In the AOP, the Kuparuk reservoir is divided into three stratigraphic intervals, that are named, from deepest to shallowest, A, B and C. The A interval contains two reservoir quality sub-intervals, the A-4 and A-5 sands, which are typically 30’ and 20’ thick, respectively. The B interval is dominated by siltstone and sandy mudstone with numerous discontinuous thin sandstone lenses, which are up to 3’ thick. The C interval contains the primary reservoir sands of the pool, and it consists of thick, amalgamated sands, with high net to gross ratios. Average layer properties range between 16% for the A sand net pay interval, and 25% for C sand net pay intervals. The average permeabilities for these layers range from 12 md to 158 md. The AOP structure is a NW to SE-trending ridge that is broken by N-S trending faults having vertical displacements ranging up to hundreds of feet. The traps for oil and gas are created by a combination of structural and stratigraphic features: the accumulation is bounded to the W by several faults, to the E and SE by unconformities, and to the SW and N by oil-water contacts. The reservoir is compartmentalized, and fluid contacts (oil-water and gas-oil) appear to be variable across the pool. The reservoir temperature is about 150 degrees F at 6700’ true vertical feet subsea. Oil gravity ranges from 25.2 to 29.1 degrees API.

 

  Strat Column Type Log
Production: Prod Chart    
  Oil (bbls) NGL (bbls) Gas (mcf) Water (bbls)
Cumulative 32,512,764 0 101,881,218 30,180,085
2005 Total
3,452,259 0 8,662,970 2,515,825
2006 Total
3,813,440 0 11,459,604 3,364,058
2007 Total
3,460,915 0 10,322,624 3,524,587
2008 Total
3,283,678 0 6,932,463 4,045,054
2009 Total
2,537,386 0 6,396,533 2,968,192
2010 Total
2,090,723 0 4,279,212 4,000,048
2011 Total
2,476,968 0 6,244,892 4,610,881
2007 Rate (b/d)
9,482 0 28,281 9,656
2008 Rate (b/d)
8,996 0 18,993 11,082
2009 Rate (b/d)
6,952 0 17,525 8,132
2010 Rate (b/d)
5,728 0 11,724 10,959
2011 Rate (b/d) 6,786 0 17,109 12,633
2008 Change (%)
-9 0 -10 5
2009 Change (%)
-23 0 -8 -27
2010 Change (%)
-18 0 -33 35
2011 Change (%)
18 0 46 15

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