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Alaska Gas Line Project

Well Analysis 2002-2016 North Slope

May 2017 latest North Slope Presentation

Petroleum filling history of central Alaskan North Slope fields
Masterson, Dallam W.1 , Albert G. Holba2 3 and Leon I. P. Dzou2 b , Phillips Alaska, Inc., P.O. Box
100360, Anchorage, AK 99510-0360, U.S.A; moc.ocpp|retsamw#moc.ocpp|retsamw, 2 aARCO Exploration and Production
Technology; current address: Phillips Petroleum Company, Plaza Office Building, Bartlesville, OK
74004, U.S.A., 2 b ARCO Exploration and Production Technology; current address: BP Upstream
Technology Group, 501 Westlake Park Blvd., Houston, TX 77079, U.S.A.

The petroleum filling history of the central Alaskan North Slope was reconstructed with burial
history models that were calibrated with source rock and oil geochemistry in the area surrounding the
Prudhoe Bay, Kuparuk, West Sak, Pt. Mclntyre, Tarn, and Alpine Fields. Prudhoe Bay and Kuparuk are
the two largest currently producing oil fields in the United States. Oil in the Prudhoe Bay Field is
interpreted as a mixture co-sourced from three source rocks: Upper Triassic marine carbonate, shale, and
phosphorite (Shublik Formation), Lower Cretaceous marine shale (HRZ Formation), and Lower Jurassic
marine shale (Kingak Shale). The total expelled oil volume within the Prudhoe Bay Field fetch area of
4,000 square miles is modeled to be 168 billion barrels and consists of 59% Shublik, 28% HRZ, and
13% Kingak source rock contribution. The carbon isotopic composition, API gravity, and sulfur content
of the Prudhoe Bay main field oil accumulation closely match the modeled oil composition in the
Prudhoe Bay fetch area. The estimated 40 to 50 billion barrels of original oil in place in the Prudhoe Bay
and West Sak Fields imply a Prudhoe Bay fetch area migration efficiency of 25 to 30%. Spillage of
Prudhoe oil into the West Sak Field occurred during post-Eocene uplift and 1-2 degrees of eastward
tilting that decreased the hydrocarbon column at Prudhoe Bay Field from 2400 to 1000 feet and created
the structural trap at the Prudhoe Bay West End. The Prudhoe Bay main field tar mat formed when gas
deasphalted the oil column in Tertiary time, and carbonates in the Carboniferous Lisburne Formation are
interpreted as the source of most of the carbon dioxide in the Prudhoe Bay gas cap. Kuparuk Field oils
were predominantly sourced from Shublik source rock. The HRZ Formation is interpreted as the
primary source for Tarn Field oils and the Kingak Shale is interpreted as the primary source for Alpine
Field oils. The West Sak Field accumulation is interpreted as a mixture of moderately biodegraded oil
that spilled from the Prudhoe Bay Field and lightly biodegraded gas/condensate that leaked from the
underlying Kuparuk Field.
Alaska Geological Society Symposium - April 2001 7
Alaska Geological Society 2001 Geology Symposium
Copyright © 2014 Alaska Geological Society

North Slope Activity Map April, 2017

Baker Hughes Rig Count Map

"When is a rotary rig "active" ?

To be counted as active a rig must be on location and be drilling or 'turning to the right'. A rig is considered active from the moment the well is "spudded" until it reaches target depth or "TD". Rigs that are in transit from one location to another, rigging up or being used in non-drilling activities such as workovers, completions or production testing, are NOT counted as active."

So once the rig reaches TD, it is no longer counted as active. That means that any later activities - logging, running casing, running a completion, testing, setting cement plugs to abandon or suspend, are not counted in the active period. So the rig could still be working for Armstong but we won't see it and it will only see it when Icewine #2 is spudded.

USGS Report 2005

Bob Swenson AOGA Alaska Onshore Oil Resources

Activity on The North Slope

Armstrong Oil & Gas takes over North Slope project

Repsol Discovery on North slope 09/03/17

repsol press releaseThu 20:04
The Horseshoe-1 discovery well was drilled to a total depth of 6,000 ft. (1,828 meters) and encountered more than 150 ft. of net oil pay in several reservoir zones in the Nanushuk section. The Horseshoe-1A sidetrack was drilled to a total depth of 8,215 ft. and encountered more than 100 ft. of net oil pay in the Nanushuk interval as well.

Repsol drilled 16 wells on the North Slope that were basically wildcat wells and all 16 showed.

(The “discovery,” Myers was careful to note, was “multiple different reservoirs, not just one major reservoir as in the case of the original Kuparuk and Alpine discoveries.”)

750,000 acres - 1P/2P/3P of over 5.5B barrels, all conventional.

So, not an identical play to 88E, but similar enough and close enough to be encouraging.

Our Neighbours to the North are private company Great Bear, Otto Energy and Red Technology alliance have working interests on GB leases.

Spill Protection Plan Application, including details of Dalton Road Plan Nov, 2016
Red Technology Alliance LLC is a partnership with Halliburton that invests in upstream oil and gas development projects that benefit from the products, services, and technologies of Halliburton. RTA has an initial focus on the Rocky Mountain region and U.S. waters of the Gulf of Mexico.

Drill Data Merak 1
Drill Data Alcor 1
Formation Evaluation of an Unconventional Shale Reservoir- Stanford University
Drill Data Alkaid1
Available via vog.aksala|lhug.htiderem#vog.aksala|lhug.htiderem

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