|AOGCC Pool Statistics||Prudhoe Bay Unit, Aurora Oil Pool|
||Operator:||BP Exploration (Alaska) Inc.|
|Discovery Well:||Mobil Oil Corporation|
|North Kuparuk State No. 26-12-12|
|API No. 50-029-20032-00-00|
|Sec. 26, T12N, R12E, UM|
||Depth: 10,311 MD / TVD|
||August 24, 1969|
|Location:||Central Arctic Slope||Area Location Map||Pool Location Map|
The Aurora Oil Pool ("AOP") is located within the current boundaries of the Prudhoe Bay Unit ("PBU"), and it lies within the Kuparuk River Formation (Kuparuk). The pool comprises the accumulation of hydrocarbons that is common to, and correlates with, the interval between 6859' and 7254' measured depth in PBU V-200. The pool was discovered in 1969 by the Mobil Oil Corporation Mobil-Phillips North Kuparuk State No. 26-12-12, where the same accumulation lies between the measured depths of 6,765 and 7,765. Development of the pool is from the PBU S-Pad. Production from pool began in November 2000, and has continued without interruption. As new producers have been added (from one in November 2000 to 14 in December 2004), production has steadily increased, but water production has also increased significantly since September 2003.
Within the pool, the Kuparuk comprises early Cretaceous-aged marine shoreface and offshore sediments that consist 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 appears to be compartmentalized, and fluid contacts (oil/water and gas/oil) appear to be variable across the pool. 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. Original oil in place (“OOIP”) is estimated to be 110 to 146 MMSTB.
|Orig. Oil in Place:||110 to 146 MMSTB (CO 457)|
|Production:||Prod Chart||Prod Report||Prod Data|
|Oil (bbls)||NGL (bbls)||Gas (mcf)||Water (bbls)|
|2003 Rate (b/d)||10,362||0||32,796||3,370|
|2004 Rate (b/d)||8,819||0||27,038||7,862|