Department of Administration

Alaska Oil and Gas Conservation Commission

Alaska Department of Administration, Alaska Oil and Gas Conservation Commission
Administration >  AOGCC >  Statistical Reports >  Annual Pool Statistics - 2004 >  Prudhoe Bay Unit, Pt McIntyre Oil Pool
AOGCC Pool Statistics
Prudhoe Bay Unit, Pt.McIntyre Oil Pool
Page:   1  >  2  >  3

Operator: BP Exploration (Alaska) Inc.
Discovery Well: Arco / Exxon
  Point McIntyre No. 3
  Permit #189-003
  API No. 50-029-21779-90-00
  Sec. 15, T12N, R14E, UM

Depth: 11,035' MD / 10,483' TVD

March 22, 1988
Status: Producing
Location: Central Arctic Slope Area Location Map Unit Location Map DNR Unit Map
Orders: Complete List
Discovered in 1993, the Pt. McIntyre Oil Pool lies in the northernmost portion of the Prudhoe Bay Unit. It lies within the Cretaceous-aged Kuparuk River and the Kalubik Formations. The pool is the accumulation of oil and gas that are common to and correlate with the interval from 9,908' to 10,665' measured depth in the Pt. McIntyre No. 11 well. Regular oil production began in October 1993, peaked at an average rate of 172,995 barrels of oil per day (“BOPD”) in December 1996, and then began to decline rapidly. Production dropped from 152,000 BOPD in December 1997 to 45,000 BOPD in December 2001. Since then, the production decline has slowed: in December 2004, production from the pool averaged 36,953 BOPD.


The Kuparuk River Formation is present throughout the Pt. McIntyre area and is characterized by rapid changes in thickness, lithology, and degree of cementation. The Kalubik formation exhibits abrupt changes in lithology and thickness with oil-bearing sandstones restricted to the western portion of the Pt. McIntyre area.  The Pt. McIntyre reservoir is controlled by a north plunging anticline with fault closure to the south across the large displacement Pt. McIntyre fault, peripheral reservoir quality degradation and stratigraphic truncation of the reservoir along its eastern flank. Numerous moderate displacement normal faults cut the reservoirs. Fluid contact and pressure data indicate these faults are non-sealing.  Average porosity ranges from 19 to 25% in the Kuparuk River sands.  Average horizontal permeabilities range from 50 to 300 millidarcies in the Upper Kuparuk and 100 to 600 millidarcies in the Lower Kuparuk sands.  Reservoir oil gravity is 27 degrees API.  Initial reservoir temperature ranges from 176 to 184 deg F at 8800' true vertical depth subsea.

A gas cap is present. Primary drive mechanisms are gas cap expansion and solution gas drive. Estimates of original oil in place ("OOIP") in the Pt. McIntyre reservoir range from 750 to 800 MMSTBO, and original gas in place (“OGIP”) estimates range from 750 to 870 billion standard cubic feet (“BSCF”), of which 160 to 240 BSCF is non-associated free gas.


Structure Map Strat Column
Orig. Oil in Place: 750 to 800 MMSTB (CO 317)
Orig. Gas in Place: 750 to 870 BSCF (CO 317)
Production: Prod Chart Prod Report Prod Data

  Oil (bbls) NGL (bbls) Gas (mcf) Water (bbls)
Cumulative 376,071,984
8,031,145 638,764,638 334,176,621
2001 Total 18,093,813 599,667 56,250,983 46,803,394
2002 Total 14,744,141 471,841 57,465,383 39,713,550
2003 Total 13,319,766 517,815 51,776,642 36,254,498
2004 Total 13,321,984 744,105 64,807,760 54,117,725
2003 Daily Rate 36,493 1,419 141,854 99,327
2004 Daily Rate 36,499 2,039 177,556 148,268
Change (%) 0% 44% 25% 49%

Continued:   1  >  2  >  3