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Chapter I, Northwest Arctic Fossil Fuel and Geothermal Energy Sources for Local Use in Alaska The Tertiary coals in the Chicago Creek area are exceptionally thick and warrant additional consideration as a potential long-term source of energy. The existing subsurface data for this area has sufficiently documented the resource and a robust cost estimate and engineering plan for development of a modern mine could be calculated. Nevertheless, the existing geologic information indicates there would still be uncertainty associated with efforts to exploit this resource. Perhaps most importantly, a detailed understanding of the distribution of faults and folds in the area would greatly reduce the risk associated with predicting coal distribution. Additional drilling or geophysical techniques, such as detailed magnetometer surveys (Ramsey and others, 1986), might supply the necessary constraints on the structural geology. It is also important to note that the low grade of this coal will require more lignite to be mined than would be required for a bituminous coal that has a much higher energy density. Further, the high moisture content may increase processing costs. Depending on the scale of a proposed mine in this area and the preferred method of power transmission, this resource could potentially support several communities bordering Kotzebue Sound. Unconventional oil and gas resource recommendations Coalbed methane. The abundance of terrestrial organic matter in the form of coal gives rise to possible coalbed methane prospects in the region, particularly in the deeper parts of the Selawik trough. The better studied and thickest seams in the region are undermature, whereas those with adequate maturity are poorly known and likely to be structurally disrupted. Seismic data would be helpful in evaluating the lateral continuity of coal bearing-sections and the total thickness of basin fill in the Selawik trough. This type of data would also be useful for inferring burial history and maturity—key parameters in identifying viable targets for coalbed methane exploration. Tight gas sands. The complex geological history of the Northwest Arctic Energy Region suggests that the tight gas sand resource potential is low. Shale gas. Early reports from shale gas exploration near the Red Dog mine appear promising and may ultimately yield sufficient gas for local and even regional use. If a sufficient resource can be documented and the considerable development challenges overcome, this may entice a larger exploration effort to document the extent of shale gas. It should be noted that exploration in the immediate Red Dog area leverages decades of detailed geologic study and dense mineral prospect drilling. An expanded search for this type of resource would require a substantial geologic field program to better map the regional geology of the western Brooks Range. Gas hydrates. Due to the lack of extensive, continuous permafrost in the Northwest Arctic, the likelihood of finding gas hydrates in the region is very low therefore no further action is recommended. Conventional oil and gas resource recommendations The regional potential for oil accumulations is considered low due to the lack of identified oil-prone source rocks. Conventional gas prospects are considered fair due to the abundance of terrestrial organic matter. Due to the limited outcrops, the acquisition of expensive subsurface data (seismic and wells) would be most useful in evaluating the region’s potential. The region’s Native corporation (NANA) recently reached an agreement with Trio Petroleum to drill as many as four exploration wells in the Kotzebue Sound area (Petroleum News, 2009); the results of this program will provide much-needed new constraints on the ultimate potential of this area to host conventional oil and gas resources. Geothermal resource recommendations The southernmost part of the region is likely to be the most prospective, based on regional, though isolated, surface indications of elevated geothermal activity across central and western Alaska. Unfortunately, identified resources are all at least 40 miles from the nearest settlement, meaning power transmission costs would likely be prohibitive. However, further geologic studies of known sites such as Granite Mountain and Division, may extend the subsurface footprint of the resource and shorten the ultimate distance between power generation and consumption. In particular, soil surveys and possibly remote geophysical techniques may assist in improved delineation of the geothermal anomalies (Kolker, 2009). REFERENCES CITED AND SELECTED BIBLIOGRAPHY Alaska Division of Oil and Gas, 2006, Approving the Sakkan unit application—Findings and Decision of the Director: Alaska Department of Natural Resources, Division of Oil & Gas, 42, p., http://www.dog.dnr.state.ak.us/oil/progr ams/units/2006/sakkan_unit_finding.pdf Alaska Energy Authority (AEA), 2009, Alaska energy—A first step toward energy independence: Alaska Energy Authority, 245 pages. Available online at http://www. akenergyauthority.org/pdf files/AK Energy Final.pdf (ac- cessed November 12, 2009). Alaska Oil & Gas Conservation Commission (AOGA), 1981, Visual kerogen and thermal maturation (vitrinite) data for the SOCAL Cape Espenberg #1, SOCAL Nimiuk Point #1, and SOCAL Benedum Nulato wells, Alaska: Alaska Department of Natural Resources, Division of Geological & Geophysical Surveys Geologic Materials Center Data Report 15, 76 p., http://www.dggs.alaska.gov/webpubs /dggs/gmc/text/gmc015.PDF Northwest Arctic Page 90PDF Image | FOSSIL FUEL AND GEOTHERMAL ENERGY SOURCES FOR LOCAL USE
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