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Home My WebLink About204-083 Drilling and Testing the DOI041A Coalbed Methane Well, Fort Yukon, Alaska By Arthur Clark, Charles E. Barker, and Edwin P. Weeks Open-File Report 2009-1064 U.S. Department of the Interior U.S. Geological Survey U.S. Department of the Interior KEN SALAZAR, Secretary U.S. Geological Survey Suzette M. Kimball, Acting Director U.S. Geological Survey, Reston, Virginia: 2009 For product and ordering information: World Wide Web: http://www.usgs.gov/ Telephone: 1-888-ASK-USGS For more information on the USGS – the Federal source for science about the Earth, its natural and living resources, natural hazards, and the environment: World Wide Web: http://www.usgs.gov Telephone: 1-888-ASK-USGS Suggested citation: Clark, A., Barker, C.E., and Weeks, E.P. 2009, Drilling and testing the DOI-04- 1A coalbed methane well, Fort Yukon, Alaska: U.S. Geological Survey Open- File Report 2009–1064, 69 p. Any use of trade, product, or firm names is for descriptive purposes only and does not imply endorsement by the U.S. Government. Although this report is in the public domain, permission must be secured from the individual copyright owners to reproduce any copyrighted material contained within this report. ii Contents Introduction…………………………………………………………………………………………...…1 Background…………………………………………………………………………………….…...2 Project Objectives………………………………………………………………………………….4 Acknowledgements………………………………………………………………………………...5 References…………………………………………………………………………………...…..…6 Section 1: Drilling and Testing Overview……………………………………………………………7 Introduction……………………………………………………………………………………….…7 Equipment…………………………………………………………………………………...…..….8 Equipment Transport……………………………………………………………………..….....…8 Drilling Operations…………………………………………………………………………..…..…9 Geophysical Logging…………………………………………………………………….........…14 Monitor Well Installation………………………………………………………………...…….…17 Well Development and Testing…………………………………………………………........…18 Spring 2005 Activities…………………………………………………………...………….……20 Results…………………………………………………………...…………………………..……22 Section 2: Canister Desorption Results………………………………………………………..…..25 Introduction………………………………………………………………...................................25 Desorption Technique………………………………………………………………..…………..28 Lost-Gas Estimate…………………………………………………………..………………...….28 Sampling Desorbed Gas…………………………………………………………..……….……29 Analysis of Desorption Data………………………………………………….………….………30 Coring Operations……………………………………………………………….…………..……30 Results………………………………………………………………….………………………….31 Desorption………………………………………………….………………………………...……31 Coal Quality………………………………………………………………..……………...………31 Desorbed Gas Analyses………………………………………………………….………...……32 Coalbed Saturation from Isotherms…………………………………………………………….33 References…………………………………………………………….………………………..…36 Section 3: Aquifer Test and Water Quality Analyses…………………………………..…………43 Introduction……………………………………………………….…………………….…………43 Hydrogeologic Setting……………………………………………………………….……...……47 Well Completion and Initial Development………………………………………………..…….48 Well Tests and Slug Test Theory…………………………………………………….…………49 Test 1……………………………………………………………………….………………...……51 Events Leading to Test 2……………………………………………………………………...…55 Test 2………………………………………………………………………………………....……56 Events Leading to Test 3…………………………………………………………………..…….56 Test 3………………………………………………………………………………….……...……57 Winter Data……………………………………………………………………………………..…58 Test 4………………………………………………………………………………………………61 Summary of Aquifer Test Analyses…………………………………………………..…………61 Water Chemistry Analyses………………………………………………………………………62 References…………………………………………………………………….…….…….………66 Summary of Results……………………………………………………………………..……………67 Fort Yukon Production Potential……………………………………………………...…………67 References………………………………………………………………………………...………69 iii iv Figures 1. Map of Alaska showing location of Yukon Flats Basin and Fort Yukon………………….…2 1-1. Photograph of drill rig at Fort Yukon CBM drill site DOI-04-1A………………………….…10 1-2. Generalized lithology of borehole DOI-04-1A………………………………………………..13 1-3. Photograph of geophysical logging winch and operating system………………………….14 1-4. Geophysical logs of drill hole DOI-04-1A……………………………………………..………16 1-5. Configuration of monitor well DOI-04-1A…………………………………………...……...…19 1-6. Photograph of Fort Yukon drill site………………………………………………….…………20 1-7. Temperature log for well DOI-04-1A………………………………………………………..…21 2-1. Geophysical logs of drill hole DOI-04-1A…………………………………………….……….27 2-2. Methane adsorption isotherm for canister 104-5…………………………………..……...…34 2-3. Methane adsorption isotherm for canister 104-33…………………………………..….……35 2-4. Temperature log for well DOI-04-1A……………………………………………………...…...36 3-1. Geologic profile and configuration of DOI-04-1A CBM well…………………………………48 3-2A. Data plots………………………………………………………………………………...………53 3-2B. Data plots…………………………………………………………………………………...……54 3-3. Graph of pressure head vs. time……………………………………………………....………60 3-4. Piper Diagram comparing water samples, drill hole DOI-04-1A……………………....……65 Tables 2-1A. Summary of canister desorption results, upper coal zone………………………….………39 2-1B. Summary of canister desorption results, lower coal zone……………………………..……40 2-2A. Summary of proximate and specific gravity analysis, upper coal zone……………………41 2-2B. Summary of proximate and specific gravity analysis, lower coal zone……………………42 3-1A. Summary of canister desorption results, upper coal zone……………………….…………45 3-1B. Summary of canister desorpton results, lower coal zone………………………………...…46 3-2. Water-level recovery following evacuation to 500-ft depth…………………………………52 3-3. Results of slug-test type curve analyses…………………………………………..…………52 3-4A. Concentrations of major ions in water samples, drill hole DOI-04-1A…………..…………64 3-4B. Concentrations of selected trace elements, drill hole DOI-04-1A………………………….64 Drilling and Testing the DOI-04-1A Coalbed Methane Well, Fort Yukon, Alaska By Arthur Clark1, Charles E. Barker2, and Edwin P. Weeks3 Introduction The need for affordable energy sources is acute in rural communities of Alaska where costly diesel fuel must be delivered by barge or plane for power generation. Additionally, the transport, transfer, and storage of fuel pose great difficulty in these regions. Although small- scale energy development in remote Arctic locations presents unique challenges, identifying and developing economic, local sources of energy remains a high priority for state and local government. Many areas in rural Alaska contain widespread coal resources that may contain significant amounts of coalbed methane (CBM) that, when extracted, could be used for power generation. However, in many of these areas, little is known concerning the properties that control CBM occurrence and production, including coal bed geometry, coalbed gas content and saturation, reservoir permeability and pressure, and water chemistry. Therefore, drilling and testing to collect these data are required to accurately assess the viability of CBM as a potential energy source in most locations. In 2004, the U.S. Geological Survey (USGS) and Bureau of Land Management (BLM), in ___________________________________________________________________________ 1 U.S. Geological Survey, Denver, Colo. phone: (303) 236-5793 aclark@usgs.gov 2 Scientist Emeritus, U.S. Geological Survey, Denver, Colo. 3 U.S. Geological Survey, Denver, Colo. phone: (303) 236-4981 cooperation with the U.S. Department of Energy (DOE), the Alaska Department of Geological and Geophysical Surveys (DGGS), the University of Alaska Fairbanks (UAF), the Doyon Native Corporation, and the village of Fort Yukon, organized and funded the drilling of a well at Fort Yukon, Alaska to test coal beds for CBM developmental potential. Fort Yukon is a town of about 600 people and is composed mostly of Gwich'in Athabascan Native Americans. It is located near the center of the Yukon Flats Basin, approximately 145 mi northeast of Fairbanks (fig.1). Figure 1. Map of Alaska showing location of Yukon Flats basin and Fort Yukon. Background The Yukon Flats basin in east-central Alaska is a 8,500 mi2 basin containing up to 10,000 ft of Cenozoic fill including upper Miocene to upper Oligocene nonmarine coal-bearing lacustrine strata (Kirschner, 1994). CBM potential in the basin was primarily based on a 1994 2 USGS climate studies core hole that was drilled to a depth of 1,282 ft near the village of Fort Yukon at lat 66.55949°N, long 145.20616°W. After setting steel casing through the top 100 ft of Quaternary gravel deposits, the well was drilled through mid-Pliocene to early-Miocene lacustrine, fluvial, and paludal deposits (Ager, T.A., 2005, unpub. data) and penetrated a thick coal bed from a depth of 1,256 to 1,282 ft. When brought to land surface and extracted from the core tube, the coal cores were visibly and audibly degassing to the atmosphere. However, no gas desorption or sampling equipment was available at the site and no analysis of the gas content or chemistry was conducted. Due to concerns about the possibility of a gas blowout, drilling was terminated at 1,282 ft prior to penetrating the full thickness of the coal. In 2000, the DOE funded the DGGS and USGS to conduct field investigations near the Alaskan communities of Wainwright, Fort Yukon, and Chignik to gather information in preparation for possible CBM exploratory drilling and testing programs. With this funding, the DGGS contracted the Kansas Geological Survey to conduct a high-resolution seismic reflection study at Fort Yukon to (1) characterize the geometry of the strata underlying the Fort Yukon area, (2) identify the lateral extent and continuity of the thick coal bed encountered in the 1994 core hole, and (3) identify deeper coal beds if present. The seven-line seismic survey, covering a 2 to 3 mi2 area, was conducted in and around Fort Yukon in March, 2001 (Miller and others, 2002). The report concluded that (1) the coal bed penetrated in the 1994 Climate Studies well appeared to be relatively flat-lying and laterally continuous throughout the study area, (2) there appeared to be at least two more thick, laterally-continuous coal beds at greater depth, (3) no major structures existed underneath the study area, and (4) the coal intervals were well fractured and exhibited seismic attributes that in other settings indicated the presence of gas. Using the information from these studies, the DGGS, BLM, USGS, and UAF decided to transport portable drilling equipment to Fort Yukon, reenter the surface casing set for the 1994 core hole, and drill and test a 2,500-ft-deep well to assess the potential for local-use CBM production. Funding for the project was provided by DOE, BLM, and USGS. 3 Project Objectives Due to the remote nature of many of Alaska’s rural communities, with few exceptions, there are little geologic, hydrologic, or chemical data available when evaluating an area’s potential for local-use CBM production. Communities located in coal-bearing basins are often a dozen or more miles away from the closest coal outcrop making it conjectural as to the depth to, and thickness of, possible coal deposits. In addition, essential reservoir properties such as hydraulic conductivity and water chemistry, which can only be determined through drilling and testing programs, are generally not known. Given this dearth of information, the primary objectives of the 2004 Fort Yukon drilling effort were to (1) determine if lightweight, portable drilling equipment could be used to effectively and economically collect the data needed to evaluate an area’s potential for local-use CBM production, (2) collect site-specific data that would allow an assessment of the CBM potential at Fort Yukon to be made, and (3) gain knowledge and experience that could be applied to future CBM drilling and testing programs conducted throughout rural Alaska and in other remote locations. This report presents the findings of the 2004 drilling program. Section 1 provides a general overview of project activities including the equipment and procedures used, a project timeline, and difficulties and problems encountered. Section 2 discusses sampling techniques and presents canister desorption, reservoir saturation, coal chemistry, and desorbed gas data. Section 3 provides results of hydraulic testing. Although substantial difficulties were encountered during aquifer testing procedures, the results of each test are analyzed and summarized to as great an extent as possible. In addition, this section provides a brief discussion concerning the chemistry of water samples collected during project operations. The Summary of Results section uses the collected data to draw preliminary conclusions as to the potential of local-use CBM production at Fort Yukon. 4 Acknowledgments Drilling, coring, geophysical logging, hydrologic testing, coal desorption, and other operations at Fort Yukon were conducted by a consortium consisting of the USGS Central Energy Resources Team (CERT), the USGS Central Region Research Drilling Project (CRRDP), the USGS Water Resources Division National Research Program (NRP), the BLM, the DGGS, and the UAF. The research team consisted of Arthur Clark, Charles Barker and Steve Roberts of the CERT, Edwin Weeks and Barbara Corland of the NRP, Bob Fisk and Beth Maclean of the BLM, Jim Clough and Karen Clautice of the DGGS, and David Ogbe and Amy Rodman of the UAF. Thanks to Fred Grub and Peter Galanis of the USGS in Menlo Park, Calif. for running the borehole temperature logs in May 2005. Special thanks go to the USGS drill crew personnel consisting of Jeff Eman, Rob Hunley, Steve Grant, Mike Williams, Mike Schulz, Thane Bird, and Andrew Ratliff for their hard work and effort, without which the project could not have been accomplished. Many thanks are owed to the community of Fort Yukon for the help and cooperation provided during the project with particular appreciation extended to Fannie Carrol (Fort Yukon City Manager), Vickie Thomas (Fort Yukon Mayor), James Kelley (Gwitchya Zhee Corporation), Davey James (Gwitchya Gwich’in Tribal Government) and Bonnie Thomas (Council of Athabascan Tribal Governments). Special thanks is extended to David Lee Thomas (Gwitchya Zhee Utility Company) for the expert and enthusiastic assistance provided throughout the project. Thanks also to Jim Merry and Norm Phillips of the Doyon Corporation for their assistance and support. The U.S. Air Force 611 CER/CERR at Elmendorf AFB in Anchorage helped facilitate permitting and logistical requirements and the members of the U.S. Air Force Fort Yukon Long Range Radar Site provided support throughout. Their help was invaluable and greatly appreciated. 5 6 References Kirschner, C.E., 1994, Interior basins of Alaska, in Plafker, G., and Berg, H.C., eds., The Geology of Alaska, The Geology of North America, v. G-1, Geological Society of America, p. 469–493. Miller, R.D., Davis, J.C., Olea, Ricardo, Tapie, Christian, Laflen, D.R., and Fiedler, Mitchell, 2002, Delineation of coalbed methane prospects using high-resolution seismic reflections at Fort Yukon, Alaska: Kansas Geological Survey, Lawrence, Kansas, Open-File Report 2002-16, 47 p. Section 1: Drilling and Testing Overview of the DOI-04-1A Coalbed Methane Well, Fort Yukon, Alaska By Arthur Clark1 Introduction In the spring of 2004, the Alaska Department of Geological and Geophysical Sciences (DGGS), using funds from the U.S. Bureau of Land Management (BLM), and working with the U.S. Geological Survey (USGS), purchased an Atlas Copco-Christensen CS-1000 P6LTM drilling rig and accessories, 3,000 ft of Atlas Copco-Christensen lightweight HCTTM wireline core rods, and a hydraulically-powered 35 gallon per minute (gpm) triplex mud-pump to conduct coalbed methane (CBM) test drilling at selected rural Alaska villages as part of the cooperative Alaska Rural Energy Project. The equipment, along with other drilling equipment owned and operated by the USGS in Denver, Colo., was transported to Fort Yukon, Alaska, where a 2,287-ft CBM test well was drilled, and select strata cored, from August 21 through September 9, 2004. Two significant coal zones were penetrated and partially cored in this well. The upper zone extended from 1,256 to 1,345 ft and contained individual coal beds from 1,256 to 1,315 ft and 1,340 to 1,345 ft. The lower zone extended from 1,878 to 1,926 ft and contained an individual coal bed from 1,900 to 1,920 ft. A partial set of geophysical logs were run on the full borehole thickness and a small-diameter monitor well was set in the upper coal bed for the collection of hydraulic properties. 1 U.S. Geological Survey, Denver, Colo. Phone: (303)236-5793 aclark@usgs.gov 7 Equipment In addition to the drilling rig, the wireline core rods, and the coring mud-pump, several transport and supply trailers were purchased specifically for this project. Other USGS-owned equipment including a large-capacity water truck, a 150 gpm duplex mud-pump, and a 1,000 gallon capacity mud-handling system, was used for drilling operations. Primary equipment included:  CS-1000 P6L drilling-core rig  HCT wireline core system including core rods, barrels, bits, and accessories  3,200-gallon Autocar water truck  Bean 35 gpm triplex core pump  Gardner-Denver 5 in. x 6 in. 150 gpm duplex mud-pump  1,000-gallon capacity mud recirculation and cleaning system  Pickup truck with welder, torches, fuel tank, and tool boxes  25-ft flatbed supply trailer for transport of core rods, barrels, and accessories  25-ft flatbed trailer for transport of the drill rig  16-ft cargo trailer for transport and storage of tools, equipment, and supplies  Light tower and 6 kW generator-trailer  Washington Rotating Control Heads Inc. non-rotating diverter system  Century Geophysical portable logging system and tools Equipment Transport On April 22, 2004, all equipment, with the exception of the drilling rig, was loaded onto Union Pacific railcars in Denver, Colo. for transport to Seattle, Wash. The drilling rig was delivered to the USGS on April 20 but needed to be assembled and tested prior to shipment. After initial testing, the rig was loaded onto a 25-ft flatbed trailer and driven from Denver to the 8 Alaska Railroad Barge Terminal in Seattle, Wash., arriving on May 3, where it was stored with the rest of the equipment awaiting barge transport to Alaska. All of the equipment was then transferred to the Alaska Railroad Corporation and loaded on an ocean-going barge for transport to Whittier, Alaska. At Whittier, the railcars were removed from the barge and transported by rail to Nenana, Alaska where they were unloaded at the Yutana Barge Lines facility. Yutana Barge Lines then loaded the equipment onto a river barge and transported it down the Tanana River to its confluence with the Yukon River, then up the Yukon River to Fort Yukon where it arrived on June 14. The equipment was unloaded from the barge and moved approximately two miles to the U.S. Air Force Fort Yukon Long Range Radar Site where it was stored until the drill crews arrived to commence drilling operations on August 19. Drilling Operations Drill-site planning, supervision, and operations were conducted by the USGS Central Region Research Drilling Project (CRRDP) based in Denver, Colo. Two 3-person drill crews, and one drill-site supervisor conducted 24-hour per day operations between August 19 and September 13, 2004. The crews flew from Denver to Fort Yukon on August 19, equipment was unpacked and prepared on August 20, drilling commenced on August 21, and a total depth of 2,287 ft was reached on September 3. Geophysical logging was conducted on September 4 and 5 and monitor well installation and hydraulic testing were conducted from September 5 through September 9. September 10 through 12 were spent cleaning, packing, loading, and storing equipment, and the crews returned to Denver on September 13. The drill rig was set up over an abandoned USGS test hole that had been cored for a USGS Climate Studies project in 1994 to a depth of 1,282 ft (fig.1-1). 9 Figure 1-1. Drill rig at Fort Yukon CBM drill site DOI-04-1A, August, 2004. The hole had an 8 5/8 –in. outer-diameter steel conductor casing cemented from ground surface to a depth of approximately 100 ft through unconsolidated Quaternary gravel deposits. By reentering the same casing, the 2004 project avoided having to drill, case, and cement these same deposits. Upon completion, the 1994 hole had been backfilled from the bottom of the well to ground surface with bentonite-abandonment grout and cement and these materials needed to be drilled and flushed from the hole before drilling could proceed to greater depths. After the initial setup of equipment, the cement was drilled from the inside of the conductor casing and the abandonment grout was flushed from the well by reaming to a depth of 1,282 ft using a 6 ¾- in. full-hole polycrystalline diamond composite (PDC) bit. Due to the unconsolidated and fluidized nature of the strata, it was anticipated that shortly after drilling through the conductor casing, the drill bit would wander from the 1994 well bore and a new hole would be drilled 10 roughly parallel to the abandoned 1994 bore-hole. If this happened, coal core could be retrieved from the top of the upper coal bed through its full thickness for gas desorption and analysis. Although some abandonment grout was flushed from the well during the reaming process, fresh silt and clay drill cuttings made it appear as though the drill bit had deflected from the 1994 hole as anticipated and that a new hole was being drilled. Therefore, at a depth of 1,205 ft, the rotary bit was pulled and the wireline coring system installed so that, in addition to the coal bed, approximately 50 ft of overlying strata could be cored. However, while tripping the core system into the hole, a hoist bail came unthreaded from the core rods, allowing them to fall to the bottom of the mud-filled hole. During subsequent retrieval efforts, it was discovered that rather than coming to rest at a depth of 1,205 ft as expected, the bottom of the core system had come to rest at a depth of 1,282 ft. This meant that rather than drilling a fresh parallel hole as thought, the drill string had reentered the original 1994 well bore which was full of abandonment grout but still open to its total depth. Because of this, the upper coal bed interval from 1,256 to 1,282 ft could not be cored and desorbed as desired. After pulling the retrieved core rods from the well and cleaning and flushing the well to a depth of 1,283 ft with the 6 ¾-in. rotary bit, wireline coring operations began using the HCT wireline core system (2.4-in. diameter core) with an oversized 4 ¼-in. outside-diameter PDC core bit. Continuous core was taken from 1,283 to 1,835 ft with 91 percent core recovery in coal, silt, and clay intervals and 38 percent recovery in unconsolidated sand intervals. Little attempt was made to maximize core recovery in the sand as there was little project-priority information to be gathered in these sections. Rather, an emphasis was placed on maximizing borehole depth at the expense of core recovery in non- coal bearing zones. At a depth of 1,835 ft, the wireline retrieval cable became stuck in the core rods, requiring the rods to be pulled from the well. Rather than proceeding with continuous coring operations, it was decided to ream the previously cored section of the hole to a 6 ¾-in. diameter and to open-hole rotary drill until another significant coal bed was encountered. A second significant coal bed was penetrated at a depth of 1,900 ft, and, after drilling to 1,910 ft to 11 confirm the presence of the coal and to collect coal cuttings for desorption analysis, the rotary bit was removed and the wireline system reinstalled. Continuous core was taken from 1,910 to 1,965 ft through coal (1,910 to 1,920 ft) and interbedded clay, silt, and carbonaceous shale. In an attempt to reach as great a depth as possible, a decision was made to resume rotary drilling with the 6 ¾-in. bit at 1,965 ft and to resume coring only if another significant coal bed was encountered. The rotary bit was reinserted, the previously cored portion of the hole was reamed, and open-hole rotary drilling was resumed. At a depth of 2,165 ft a thick, indurated, coarse-grained to conglomeratic sandstone was encountered causing a significant decrease in drill-penetration rates. Drilling continued through interbedded sandstone, siltstone, and claystone layers, but with no further significant coal beds encountered, and with penetration rates greatly reduced, a decision was made to discontinue drilling at a depth of 2,287 ft. The drill rods were pulled back to a depth of 1,600 ft and the hole reamed back to bottom. The well was then flushed with thin, clean drill mud and prepared for geophysical logging operations. Finally, the drill rods were removed from the well so that logging operations could begin. A generalized lithologic log of the penetrated strata, based on geophysical log interpretation and unpublished core descriptions by the USGS (Ager, T.A., and Fouch, T.D., 1995, unpub. data) and Alaska DGGS (White, J.G., and Clough, J.G., 2005, unpub. data) is shown in figure 1-2. 12 Up p e r C o a l Z o n e Lo w e r C o a l Z o n e Total Depth 2,287 ft Figure 1-2. Generalized lithology of borehole DOI-04-1A, Fort Yukon, Alaska based on geophysical log interpretation and unpublished core descriptions. 13 Geophysical Logging The well was logged using a portable Century Geophysical Corporation logging system. A logging winch with 5,000 ft of logging cable was purchased specifically for the project and the rest of the operating system was provided by the CRRDP (fig.1-3). Figure 1-3. Geophysical logging winch and operating system. Century logging tools consisted of a 9074 caliper-natural gamma tool, and a 9044 multi-function tool (16-in. normal, 64-in. normal, fluid, lateral, and single-point resistivity, spontaneous potential, temperature, and natural gamma). Additionally, Mt. Sopris Instrument Company density and sonic tools were borrowed from the USGS Borehole Geophysics Research Project in Denver. A MGX II box was utilized to provide the electronic conversion between the Century operating system and the Mount Sopris tools. Logging operations started at 15:00 hours on September 4. The 9074 caliper-gamma tool was the first tool run and, due to tight sticky spots in the drill hole, could only be lowered to a depth of 2,000 ft. While logging, the tool experienced operational difficulties at a depth of 380 ft and was not run above that point. The 8044 multi-function tool was run next and, with great effort, was lowered to the bottom hole depth of 2,287 ft. Logs of the full borehole were obtained 14 using this tool (fig.1-4). However, numerous problems were encountered when attempting to operate the Mt. Sopris tools with the Century system. Both the tool calibrations and the recorded borehole footages were off by a considerable amount and, even with repeated attempts to rectify the problem, could not be reconciled. Both tools were run from a depth of approximately 2,200 ft but, due to the various calibration and compatibility problems, the data gathered were of marginal quality. Logging operations were completed at 03:00 hours on September 5. 15 Figure 1-4. Geophysical logs of drill hole DOI-04-1A, Fort Yukon, Alaska 16 Monitor Well Installation After reviewing core, desorption, and geophysical data, a decision was made to set a monitor well and collect hydraulic information from the upper coal bed. To seal the well below 1,315 ft, drill rods were lowered to a depth of 2,275 ft and abandonment grout was mixed and pumped from the bottom up to a depth of 1,330 ft. Bentonite pellets and chip were then poured through the rods, using tremie-suction methods, to a top depth of 1,313 ft. Several 5-gallon buckets of cleaned and sorted river gravel were poured on top of the bentonite to a top depth of 1,307 ft. A 2 ½-in., schedule 80, threaded flush-joint, polyvinyl chloride (PVC) monitor well with a 5-ft section of stainless steel pipe attached to the bottom was installed in the well with the open bottom of the pipe set at a depth of 1,272 ft and a set of rubber formation packers set at 1,265 ft. At ground surface, a coupler was attached to the top of the PVC pipe using glue and screws and a carbide-impregnated sandwich clamp was secured to the PVC pipe immediately below the coupler. The clamp was then set on the 8 5/8-in. steel surface casing so that the full weight of the PVC pipe was suspended from the clamp. A 1 ½-in. stainless steel tremie pipe was inserted into the annular area between the borehole wall and the PVC pipe and ten 5-gallon buckets of ¼-in. bentonite pellets poured through the pipe and placed on top of the rubber packers. Abandonment grout was then mixed and pumped through the pipe from the top of the bentonite pellets to within 20 ft of ground surface. Portland cement was mixed and poured in the top 20 ft. This left the well with 42 ft of isolated open-hole monitor zone in the coal from 1,265 to 1,307 ft., with gravel extending to a depth of 1,313 ft (fig. 1-5A). The 1 ½ -in. tremie pipe was removed from the annular area, cleaned, and lowered into the monitor well to a depth of 1,300 ft. Fresh water was then slowly circulated through the well to remove drill mud and other material from the coal and the well. 17 Well Development and Testing After circulating the drill mud from the monitor well, a portable air compressor (350 psi, 185 cfm) borrowed from the Air Force facility was used to develop the well using air lift methods. The tremie pipe was pulled to within 200 ft of land surface and compressed air was circulated through the pipe from progressively greater depths. On September 7, well development was conducted from depths of 200, 300, 400, and 500 ft with minimum water being produced from the well. After monitoring water-level recovery at 500 ft with a hand-held water-level meter, development was continued at a depth of 600 ft. However, as fluid inside the casing was removed from progressively greater depths, the pressure differential between the outside and the inside of the casing increased correspondingly. As a result, during air development at 600 ft, the downward pressure exerted on the rubber formation packers exceeded the holding capacity of the coupler secured to the top of the PVC pipe. As a result, the coupler sheared and the casing slipped through the carbide sandwich clamp, falling approximately 35 ft into the well before coming to rest on the gravel at 1,307 ft (fig. 1-5B). Due to the cold ground temperatures, the Portland cement that had been pumped into the upper 20 ft of the annular area had not properly cured and thus did not prevent the pipe from falling down the hole. Rather than latching onto the casing and attempting to pull it back to land surface, which would likely have resulted in the fracture of the casing and the total loss of the well, two 20-ft sections of 2 ½-in. PVC pipe, with a coupler attached face down, were lowered down the well and slipped over the top of the existing casing at 35 ft. This effectively extended the top of the well back to ground surface but theoretically decreased the monitored area in the well to the open zone between 1,300 and 1,307 ft and the gravel-filled zone between 1,307 and 1,313 ft (fig. 1-5C). The air development pipe was then pulled back to 300 ft and, using the air compressor, the well was cleared of fluid in 100 ft intervals to a depth of 800 ft. With only a minimal amount of water being produced, development was discontinued and a 1,000 psi pressure transducer placed in the well to a depth of 780 ft to collect overnight water recovery data. 18 lignite: 1,257-1,315 ft Lignite Cement Bentonite grout Gravel pack Bentonite pellets Open hole - air ABC Open hole - water KEY Figure 1-5. A. Initial configuration of monitor well DOI-04-1A; B. Configuration of monitor well after casing had slipped; C. Configuration of monitor well after casing was extended back to land surface. On the morning of September 8, after reviewing the water recovery data, air development resumed at depths of 800, 900, and 1,000 ft with small water samples being collected for water-quality analysis. After installing the pressure transducer to 1,020 ft and collecting water-recovery data for two hours, a decision was made to again flush the well with fresh water in an attempt to clean the gravel and improve water production. The development pipe was ultimately lowered to a depth of 1,280 ft and fresh water circulated through the well before pulling the pipe back and continuing air development from 200 and 300 ft. With the well still producing minimal water, the development pipe was removed from the well and the transducer installed to a depth of 400 ft to collect overnight recovery data. 19 On September 9, after reviewing the overnight data, it was apparent that the amount of water being produced from the well was so small that further efforts at well development were futile. A pressure transducer was placed in the well to a depth of 600 ft to collect over-winter pressure data. Additionally, two lengths of heat trace were placed in the well to depths of 275 ft and 350 ft so that the permafrost portion of the well (approximately 300 ft) could be thawed and the transducer recovered in the spring of 2005. A 5-ft section of vented 14-in. diameter pipe was placed and cemented over the well to serve as a protective cover during the winter months (fig.1-6). The equipment was then cleaned, winterized, packed, and parked at the Air Force facility. Figure 1-6. Fort Yukon drill site at conclusion of 2004 drilling operations with protective cover placed over well. Spring 2005 Activities A two-man crew flew to Fort Yukon on May 7, 2005 to thaw the well, remove the transducer, decommission the well, and prepare the equipment to be barged back to Nenana. After installing batteries and getting the equipment running, the heat traces were plugged in 20 and, within several hours, the well was thawed. The transducer was removed and a temperature log of the well was taken by a USGS Geothermal Project crew from Menlo Park, Calif. (fig.1-7). After running the temperature log, water was bailed from the well to a depth of approximately 850 ft and water samples were collected from the bottom of the well using a stainless steel discrete-zone sampler. The well was then decommissioned by pumping a Portland cement slurry into the well from the surface. Steel and plastic well casings were cut 3 ft below land surface and a metal plate and cement cap placed over the well. All well abandonment operations were observed and approved by a representative of the Alaska Oil and Gas Conservation Commission (AOGCC). The area was cleaned and raked and all equipment loaded and prepared for barge transport to Nenana. The equipment was loaded onto the Yutana Barge Lines barge on June 10 and arrived in Nenana, Alaska on June 17, 2005. Figure 1-7. Temperature log for Well DOI-04-1A made in May 2005. 21 Results The drilling of the 2004 Fort Yukon CBM test well confirmed that portable drilling equipment can effectively be used to conduct initial CBM assessment drilling in remote areas where little-to-no subsurface information exists. Although numerous difficulties were encountered during the project, the data required to make a preliminary determination concerning the viability of local-use CBM production were collected in a timely and economic fashion. However, as with any such project, there were lessons learned that can be applied to similar future operations. Given more time, it would have been preferable to collect continuous core through the entire well bore rather than selectively coring in coal-bearing zones only. This is especially important in areas such as Fort Yukon where virtually no subsurface data exists. Even with the collection of drill cuttings, it is often difficult to quickly identify borehole lithology when conducting rotary drilling operations. This allows for the possibility of drilling through relatively thin coal beds or other strata before identifying them as zones of interest. Even though the coal bed encountered at 1,900 ft during rotary drilling in DOI-04-1A was quickly identified so that adequate core samples could be obtained, the upper ten ft of the bed were not cored and therefore not available for desorption or analyses. In areas that contain relatively thin coal beds, rather than the substantial coal beds encountered at Fort Yukon, this could prove problematic. Although the selective core approach may continue to be necessary for future projects due to time or budgetary constraints, the increased data gathered during continuous coring operations is probably worth the increased effort and cost. Due to the portable nature of the equipment used during the drilling operations, the drill/core rods purchased and used for this project were thin-walled and light-weight in nature. This does not pose a problem for continuous core drilling operations and allows for a maximum well-bore depth to be obtained. However, when using these rods for open-hole rotary drilling, the increased torque and stress transferred to the rods significantly increases the possibility of 22 rod and (or) rod thread fatigue and failure. Although no rods were fractured during the 2004 project, several hundred feet of rods suffered non-repairable thread damage due to excessive torque and “snap” exerted on them during rotary drilling and could no longer safely be used. Although the time and money involved in rotary drilling is significantly less than core drilling, if fracture of the light-weight core rods does occur, the possibility exists of losing the entire borehole. If this does happen, it will become necessary to utilize the core rods for coring purposes only. Due to time and budget constraints, a decision was made to drill the Fort Yukon borehole, desorb the coal cores, and obtain geophysical logs, before choosing one coal bed from which to collect hydraulic data. Based primarily on its greater thickness, it was decided to collect hydraulic data from the upper coal bed at 1,256 ft rather than the lower bed at 1,900 ft. Therefore, no hydraulic data was collected from the lower coal bed even though it ultimately contained more methane on a standard cubic feet per ton (scf/ton) basis than did the upper bed (see section 2, p. 31). In hindsight, the collection of hydraulic data is of such importance when analyzing reservoir properties and production potential that priority efforts should be made to collect such data from all significant gas-bearing coal beds. This can be accomplished in one of two ways: (1) upon coring through the base of a significant gas-bearing coal bed, discontinue the drilling process, isolate the zone using a single inflatable pneumatic packer system, and collect discreet-zone hydraulic data; or (2) at the completion of all drilling, coring, and geophysical logging operations, use an inflatable straddle-packer system to isolate individual coal beds and collect the required data. Although leaving packers inflated in a fluid-filled borehole during the data collection process increases the risk of sticking the rods and losing the well, the importance of the data is such that, with proper precautionary measures, the benefits probably outweigh the risks involved in the collection process. 23 24 All core and cuttings samples collected from borehole DOI-04-1A have been transferred to the Alaska Geologic Materials Center in Eagle River, Alaska (contact Dr. John Reeder, 907- 696-0079) and released to the public. Section 2: Canister Desorption Results from the DOI-04- 1A Well, Fort Yukon, Alaska By Charles Barker1, Arthur Clark2, Beth Maclean3, Karen Clautice4, and Amy Rodman5 Introduction The Fort Yukon coalbed methane (CBM) assessment study was conducted by reentering a 1994 USGS core hole to sample coal found in Tertiary strata in the Yukon Flats Basin (Ager, T.A., 2005, unpub. data). The 1994 well encountered a coal bed at 1,256 ft and cored 26 ft of coal before drilling was stopped at 1,282 ft, still in coal. In 1994, it was noted that gas was bubbling from the coal core but desorption testing of the coal was not possible at that time. Consequently, the reentry of the 1994 well, now officially named DOI-04-1A, was designed to test the methane content of the coal. DOI-04-1A well (API no. 50-091-20001) is located at lat 66.55949°N. and long 145.20616°W. The total depth of the well was 2,287 ft. The strata encountered consisted of about 100 ft of gravel, followed primarily by sandstone, shale, siltstone, and coal associated with Pliocene to Miocene lake beds deposited some 1.5 to 15 million years ago (Ager, T.A., 2005, unpub. data). Permafrost was encountered in the well from just below the surface to a depth of about 300 ft. The well penetrated two primary coal zones: the shallower coal zone extended from 1,256 to1,345 ft and contained one major coal bed from 1,256 to 1,315 ft and a second ________________________________________________________________________________________________________________________ 1 Corresponding author, Scientist Emeritus, U.S. Geological Survey, Denver, Colo., phone: (303) 236-5797 email: barker@usgs.gov 2 U.S. Geological Survey, Denver, Colo. 3 Alaska Division of Geological and Geophysical Surveys, Fairbanks, Alaska 4 Bureau of Land Management, Anchorage, Alaska 5 University of Alaska, Fairbanks 25 coal bed from 1,340 to 1,345 ft. The deeper coal zone extended from 1,878 to 1,926 ft with a major coal bed from 1,900 to 1,920 ft. The net coal thickness for the primary coal beds in the two coal zones was 84 ft. Thin or high-ash coals, as picked from geophysical logs (fig. 2-1) at 1,061 to 1,063 ft, 1,878 to 1,882 ft, and queried coal at 2,024 ft, 2,030 ft, 2,038 ft, and 2,056 ft were not sampled for desorption. 26 Figure 2-1. Geophysical logs of drill hole DOI-04-1A, Fort Yukon, Alaska 27 DesorptionTechnique Coal desorption followed a modified U.S. Bureau of Mines (USBM) canister desorption method as described by Diamond and Levine (1981), Close and Erwin (1989), Ryan and Dawson (1993), McLennan and others (1994), Mavor and Nelson (1997), and Diamond and Schatzel (1998) as adapted and modified by Barker and others (1991, 2002) for the use of PVC canisters. Another major modification of the USBM technique in this study was the use of zero- headspace canisters (Barker and Dallegge, 2005) in which the headspace is filled with distilled water rather than with helium gas as described in Barker and others (2002). For this study, the distilled water was chilled to the approximate drilling mud temperature of 45 to 50 °F prior to adding it to the canister to minimize the time required to equilibrate the can and coal core to the lost-gas temperature. Because it is not necessary to measure internal can temperature for a headspace correction when using zero headspace canisters (Barker and Dallegge, 2005), a desorption log form modified from Barker and others (2002) was used to allow for this difference. All canisters were pressure tested for leaks at 6 PSI over a period of at least 24 hours prior to use. Lost-Gas Estimate Lost gas is the unmeasured gas desorbed from coal core from the time it is lifted from the bottom of the well until it is sealed within the canister. Lost gas is controlled by the coal diffusivity, cleat spacing, and the length of time required to retrieve a given sample and is estimated by measuring the apparent early rate (first two to four hours) of gas desorption from the sample sealed within the canister. Lost gas is estimated by plotting cumulative desorbed gas volume versus the square root of time since the core was lifted off bottom (zero time), and 28 extrapolating the early data, which should form a straight line, back to zero time. The absolute value of the cumulative volume at the zero-time intercept of this straight line indicates the volume of lost gas. In coalbed methane drilling conducted in the Maverick basin in Texas, the Nenana and Cook Inlet basins in Alaska, and again at DOI-04-1A, the temperature measured at the center of a freshly opened core face closely tracks the drill mud temperature used to cut the core (unpub. USGS data), implying that as the core is being cut in the drill hole, it quickly equilibrates to the drill mud temperature. As a result, once the core retrieval process starts and sample desorption begins (assumed to be at time zero in the USBM method), the mud temperature to which the core has equilibrated is the relevant temperature for estimating gas diffusion from the coal matrix during the lost-gas period rather than the in-situ reservoir temperature. Therefore, during the period used to determine lost gas, the canisters were desorbed at ambient mud temperature as discussed in Barker and others (2002). Digital infrared thermometers were used to monitor drilling mud, core-face, and tank temperature throughout the project. Towards the conclusion of the project, tank temperatures were allowed to rise to room temperature (65 to 70 °F) in preparation for canister transport from the drill site to the laboratory in Denver, Colo. Sampling Desorbed Gas After the lost gas period had ended, selected core canisters were not measured for several hours allowing them to accumulate enough gas to collect for analysis. Gas samples were collected in evacuated 75 ml stainless steel cylinders equipped with needle valves to control gas flow and seal the cylinder after sampling, by attaching the cylinders directly to the desorption canister via quick-connect fittings, opening the needle valve for a few seconds, and then closing the valve and disconnecting the cylinder. This method of gas sampling provided a sealed sample in a sturdy, transportable container and minimized atmospheric contamination. 29 Analysis of Desorption Data Correction of the data to standard temperature and pressure (STP) and preparation of a lost-gas estimate uses a spreadsheet described in Barker and others (2002). Coring Operations The 2004 reentry well, DOI-04-1A, was spudded on August 22, 2004 by reentering the existing 100 ft steel casing set for the 1994 USGS well. After reaming to the bottom of the 1994 borehole (see Section 1, p.11) and collecting reamed cutting samples for desorption from the 27 ft of coal cored at the bottom of the 1994 borehole (1,256 to 1,283 ft; canister sample cuttings 1, 2, 3 in table 2-1A), core drilling began on August 26 at a depth of 1,283 ft. Because the first 27 ft of the upper coal bed was not cored, and the full thickness of the bed was not known, all coal recovered from the first two core runs were placed in canisters for desorption to ensure that adequate data from this bed were collected. After eight canisters had been filled, a decision was made to only desorb every other foot of coal. Although core recovery in the coal zone was very good (91 percent), some coal core was lost during the coring and core retrieval process. In some cases the lost coal cores were recovered on the next core run and placed in canisters since they should have retained their gas by staying at the hydrostatic pressure extant at the bottom of the well. Continuous core was drilled to a depth 1,835 ft with coal encountered from 1,283 to 1,315 ft and 1,340 to 1,345 ft. Thus, the upper major Fort Yukon coal zone lies at depths from 1,256 to 1,345 ft (fig. 2-1) and contains 64 ft of net coal. In an attempt to maximize the final depth of the well, and because no coal had been encountered for almost 500 ft, a decision was made to discontinue coring activities at 1,835 ft and to resume open-hole drilling until another significant coal bed was reached. A second significant coal bed was encountered at 1,900 ft and was penetrated for 5 ft before drilling was stopped. All drill cuttings were circulated from the well and another 5 ft drilled 30 to confirm the presence of a significant coal bed. The resulting cuttings from 1,905 to 1,910 ft confirmed the presence of a significant coal bed and were collected and placed into canisters 104-31 and 104-32 for desorption. Coring commenced at 1,910 ft and continued to 1,965 ft with a total of 10 ft of additional coal core being taken from 1,910 to 1,920 ft. This core was placed in canisters 104-33 to 104-42 (table 2-1B) for desorption. With the subsequent gamma log indicating the presence of a thin high-ash coal or carbonaceous shale at a depth of 1,878 to 1,882 ft, and a thin carbonaceous shale at 1,925 ft, the lower coal zone extends from approximately 1,878 to 1,926 ft (fig. 2-1) and contains 20 ft of net coal and 5 ft of high-ash coal or carbonaceous shale. Rotary drilling was resumed at 1,965 ft and the borehole reached a final depth of 2,287 ft on September 3 with no further coal beds encountered or core samples collected. Results Desorption The raw gas content of the upper coal bed core samples average 13.1 standard cubic feet (scf)/ton with a standard deviation of 3.5 scf/ton for 21 samples (table 2-1A). The raw gas content of the lower coal bed core samples average 19.1 scf/ton with a standard deviation of 4.0 scf/ton for 10 samples (table 2-1B). Coal Quality The upper coal bed, as determined from 21 coal core samples, has a moisture content averaging 41.25 wt.-percent, consistent with its lignite rank (table 2-2A). This coal bed also averages 4.10 wt.-percent ash and has an average specific gravity of 1.34, a typical value for low-ash coal. 31 The lower coal bed, as determined from 10 coal core samples, has a lower moisture content averaging 31.98 wt.-percent, an ash yield averaging 15.73 wt.-percent and a specific gravity of 1.48 (table 2-2B). Desorbed Gas Analyses Four gas samples taken from canisters 104-1, 104-18, 104-37 and 104-40 were sent to Isotech Laboratories, Champaign, Ill. for their NG-1 level compositional and isotopic analyses plus CO2 carbon isotope analyses. All of the gas samples have a significant content of O2, N2, and CO2 that might represent either release of these gases from in situ sorption sites, from atmospheric contamination of the coal cores while exposed to air during sampling, or a combination of the two sources. However, the proportion of in-situ O2, N2 and CO2 versus these gases absorbed from exposure to air during sampling is difficult to separate. Consequently, the CH4 and CO2 contents, which are key gases in determining the quality of the gas for sales, were arbitrarily corrected to an O2- and N2-free basis to provide a qualitative assessment of gas quality. This method presumes that all O2 and N2 are contaminants and that all CH4 and CO2 are natural coalbed gas components. After correction to an O2- and N2-free basis, the CH4 content of the four gas samples ranges from 90 to 96 mol-percent and averages 94 mol-percent. The CO2 content ranges from 3.7 to 9.5 mol-percent and averages 5.4 mol-percent. The CH4-rich character of the gas is reflected in the calculated calorific content of the gas that ranges from 910 to 970 BTU/Mscf and averages 950 BTU/Mscf on an O2- and N2-free basis. Pure methane has a calorific content of 1,015 BTU/Mscf. The δ13CCH4 of the four samples ranges from -72 to -76 o/oo and averages -73 o/oo . The δ2HCH4 for these samples ranges from -318 to -331 o/oo and averages -324 o/oo. Methane with this isotopic signature suggests a biogenic source for the gas (Whiticar, 1999), with no apparent thermogenic component. 32 Coalbed Saturation from Isotherms Methane adsorption isotherms are measured by reintroducing methane to a coal sample and measuring the equilibrium gas content at a given pressure and at a constant temperature, generally the reservoir temperature. Sorption isotherms were developed for one sample each from the upper and lower coal beds, both at a temperature of 15 ºC, since a temperature log for the well after it had thermally re-equilibrated with the formation was not available at the time isotherm analyses were conducted. The resulting curves (figs. 2-2, 2-3) can be used with the measured gas content from canister desorption (tables 2-1A, 2-1B) to estimate degree of saturation and the reduction in reservoir pressure needed to saturate the coal with methane, important factors when evaluating coal bed production potential. The sorption isotherm for the upper coal bed should be reliable as the May 2005 temperature log indicates a formation temperature at a depth of 1,260 ft of about 14 ºC (fig. 2-4), nearly the same as the isotherm temperature. The degree of saturation for the upper coal bed, as calculated in figure 2-2, is 31 percent and the reduction in reservoir pressure required to saturate the coal bed with methane is 435 psi. The sorption isotherm for the lower coal bed (fig. 2-3) may overstate its in-situ sorption capacity, as the May 2005 temperature log indicates a geothermal gradient for the interval between the bottom of the permafrost zone and the depth of 1,260 ft of about 5 ºC/100 m or 2.7 ºF/100 ft. Assuming that gradient persists to the depth of the lower coal bed, its temperature would be about 24 ºC. Sorption capacity decreases with increasing temperature, and the degree of saturation for the lower coal bed of 37 percent, as calculated in figure 2-3, may be somewhat low. The curve also indicates that the reduction in reservoir pressure required to saturate the coal bed with methane is about 580 psi, a value that may be somewhat high, due to the temperature effect on the isotherm. Regardless, these values indicate that the coal beds are undersaturated and imply that reservoir pressure would have to be reduced by several hundred PSI before methane would be desorbed from the coals. 33 Canister 104-5 , upper coal bed 1,287–1,288 ft depth Gas content on as-received basis = 11.6 scf/ton Indicated methane storage capacity = 37 scf/ton Percent saturation = (11.6 / 37) X 100% = 31% Figure 2-2. Methane adsorption isotherm for canister 104-5 at 1,287–1,288 ft depth in the upper coal bed, DOI-04-1A well, Fort Yukon, Alaska. Isotherm conditions were: 15 oC, coal at equilibrium moisture. Absorbed methane values reported on an as-received basis. Coal bed pressures calculated using a fresh water hydrostatic gradient of .433 psi per ft projected to the sample depth. 34 Canister 104-33, lower coal bed 1,919–1,920 ft depth Gas content on as-received basis = 20.9 scf/ton Indicated methane storage capacity = 57 scf/ton Percent saturation = (20.9 / 57) X 100% = 37% Figure 2-3. Methane adsorption isotherm for canister 104-33 at 1,910–1,911 ft depth in the lower coal bed, DOI-04-1A well, Fort Yukon, Alaska. Isotherm conditions were: 15 oC, coal at equilibrium moisture. Absorbed methane values reported on an as-received basis. Coal bed pressures calculated using a fresh water hydrostatic gradient of .433 psi per ft projected to the sample depth. 35 Figure 2-4. Temperature log for well DOI-04-1A made in May 2005. REFERENCES Barker, C.E., Johnson, R.C., Crysdale, B.L., and Clark, A.C.,1991, A field and laboratory procedure for desorbing coal gases: U.S. Geological Survey Open-File Report OF 91– 0563, 14 p. Barker, C.E., Dallegge, T.A., and Clark, A.C., 2002, USGS coal desorption equipment and a spreadsheet for analysis of lost and total gas from canister desorption measurements: U.S. Geological Survey Open-File Report OF 2002–496, 13 p. plus spreadsheet. 36 Barker, C.E., and Dallegge, T.A., 2005, Zero-headspace coal-core gas desorption canister, revised desorption data analysis spreadsheets and a dry canister heating system: U.S. Geological Survey Open-File Report OF 2005–1177, 9 p. Close, J.C., and Erwin, T.M., 1989, Significance and determination of gas content data as related to coalbed methane reservoir evaluation and production implications: Proceedings of the 1989 Coalbed Methane Symposium, paper 8922, p. 37–55. Diamond, W.P., and Levine, J.R., 1981, Direct method determination of the gas content of coal: procedures and results: U.S. Bureau of Mines Report of Investigations 8515, 36 p. Diamond, W.P., and Schatzel, S.J., 1998, Measuring the gas content of coal: a review, in Flores, R.M., ed., Coalbed methane: from coal-mine outbursts to a gas resource: International Journal of Coal Geology, v. 35, p. 311–331. Mavor, M., and Nelson, C.R., 1997, Coalbed reservoir gas-in-place analysis: Gas Research Institute Report no. GRI-97/0263, 134 p. McLennan, J.D., Schafer P.S., and Pratt, T.J., 1994, A guide to determining coalbed gas content: Gas Research Institute, variously paginated. Ryan, B.D., and Dawson, F.M., 1993, Coalbed methane canister desorption techniques; in Grant, B. and Newell, J.M. eds., Geological fieldwork 1993: B.C. Ministry of Energy, Mines, and Petroleum Resources, Paper 1994-1, p. 245–256. 37 Whiticar, M.J. 1999, Carbon and hydrogen isotope systematics of bacterial formation and oxidation of methane: Chemical Geology v. 161, p. 291–314. 38 Table 2-1A. Summary of canister desorption results, upper coal zone. Canister number Depth interval Canister sample lithology Raw coal mass Lost gas estimate Total raw gas content Upper coal zone Top Bottom (as-received basis) (feet) (feet) % coal (g) (cc) (scf/ton) CORE 104-1 1,283 1,284 100 1,056 60 14.1 104-2 1,284 1,284.5 50 490 40 13.5 104-3 1,285 1,286 100 907 85 10.8 104-4 1,286 1,287 100 905 80 9.8 104-5 1,287 1,288 100 951 80 11.6 104-6 1,288 1,289 100 1,009 115 21.1 104-7 1,289 1,290 100 1,149 85 7.0 104-8 1,290 1,290.7 70 471 85 14.5 104-9 1,295 1,296 100 961 85 13.4 104-10 1,304.5 1,305.5 100 1,087 110 13.8 104-11 1,306.5 1,307.5 100 1,193 95 12.1 104-12 1,308.5 1,309.5 100 1,115 130 13.6 104-13 1,310.5 1,311.5 100 1,132 130 13.9 104-14 1,312.5 1,313.5 100 842 80 11.0 104-15 1,315 1,316 100 1,038 80 12.9 104-16 1,319 1,320 100 1,171 85 8.6 104-17 1,324 1,325 100 1,518 100 9.0 104-18 1,339.7 1,340.7 100 1,082 100 18.7 104-19 1,342 1,343 100 749 100 19.5 104-20 1,343 1,344 100 1,028 110 15.2 104-21 1,344 1,345 100 1,098 100 10.9 Statistics: Sample mean 13.1 Standard deviation 3.5 CUTTINGS Cuttings-1* 1,265 1,270 80 575 45 7.7 Cuttings-2* 1,270 1,275 80 609 20 4.6 Cuttings-3* 1,275 1,280 80 886 20 2.0 Statistics: Sample mean 4.8 Standard deviation 2.9 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly, thought to lead to the spuriously low raw gas content. Abbreviations: g, grams; cc, cubic centimeters; scf, standard cubic feet 39 Table 2-1B. Summary of canister desorption results, lower coal zone. Canister number Depth interval Canister sample lithology** Raw coal mass Lost gas estimate Total raw gas content Lower coal zone Top Bottom (as- received basis) (feet) (feet) % coal (g) (cc) (scf/ton) CORE 104-33 1,910 1,911 n.r. 100? 1,006 120 20.9 104-34 1,911 1,912 n.r. 100? 1,037 100 22.5 104-35 1,912 1,913 n.r. 100? 1,105 100 19.4 104-36 1,913 1,914 n.r. 100? 994 120 20.4 104-37 1,914 1,915 n.r. 100? 996 120 20.9 104-38 1,915 1,916 n.r. 100? 1,239 120 12.8 104-39 1,916 1,917 n.r. 100? 1,118 120 17.8 104-40 1,917 1,918 n.r. 100? 1,115 125 21.7 104-41 1,918 1,919 n.r. 100? 993 85 23.1 104-42 1,919 1,920 n.r. 100? 1,233 85 11.2 Sample mean 19.1 Standard deviation 4.0 Cuttings 104-31* 1,900 1,905 100 1,104 100 8.1 104-32* 1,905 1,910 100 1,080 110 8.3 Sample mean 8.2 Standard deviation 0.1 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly, thought to lead to the spuriously low raw gas content. **Lithology about 100 percent coal from gamma log interpretation Abbreviations: g, grams; cc, cubic centimeters; scf, standard cubic feet; n.r., not reported 40 Table 2-2A. Summary of proximate and specific gravity analysis with dry, ash free (DAF) basis canister desorption results, upper coal zone. Canister Number Depth interval Specific gravity Total moisture Ash yield DAF gas content Upper coal zone Top Bottom As received basis As received basis (feet) (feet) Wt.-% Wt.-% (scf/ton) CORE 104-1 1,283 1,284 1.31 42.30 2.62 25.6 104-2 1,284 1,284.5 1.29 39.29 3.45 23.5 104-3 1,285 1,286 n/a 42.83 2.91 19.9 104-4 1,286 1,287 1.20 46.36 2.37 19.2 104-5 1,287 1,288 n/a 40.85 2.85 20.6 104-6 1,288 1,289 1.33 40.78 2.81 21.5 104-7 1,289 1,290 1.30 45.08 2.75 13.5 104-8 1,290 1,290.7 1.49 39.08 3.33 25.1 104-9 1,295 1,296 1.30 41.10 2.85 24.0 104-10 1,304.5 1,305.5 1.26 41.38 3.17 24.9 104-11 1,306.5 1,307.5 1.20 41.66 5.05 22.8 104-12 1,308.5 1,309.5 1.28 39.93 2.33 23.5 104-13 1,310.5 1,311.5 1.27 41.29 1.76 24.4 104-14 1,312.5 1,313.5 n/a 41.59 2.05 19.6 104-15 1,315 1,316 1.27 41.88 2.34 23.2 104-16 1,319 1,320 1.37 52.04 5.58 20.3 104-17 1,324 1,325 1.81 42.65 15.45 21.6 104-18 1,339.7 1,340.7 n/a 31.54 3.9 29.0 104-19 1,342 1,343 1.25 36.33 2.61 31.9 104-20 1,343 1,344 1.48 38.29 5.05 26.8 104-21 1,344 1,345 1.40 39.95 10.92 22.2 Statistics: Sample mean 1.34 41.25 4.10 23.0 Standard deviation 0.15 3.89 3.26 3.8 CUTTINGS Cuttings-1* 1,265 1,270 1.35 63.20 2.52 22.6 Cuttings-2* 1,270 1,275 1.22 61.71 3.16 13.0 Cuttings-3* 1,275 1,280 1.20 59.42 5.54 5.6 Statistics: Sample mean 1.26 61.44 3.74 13.7 Standard deviation 0.08 1.90 1.59 8.5 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly thought to lead to the spuriously low raw gas content. Abbreviation: n/a = not analyzed; scf, standard cubic feet 41 Table 2-2B. Summary of proximate and specific gravity analysis with dry, ash free (DAF) basis canister desorption results, lower coal zone. Canister number Depth interval Specific gravity Total moisture Ash yield DAF gas content Lower coal zone Top Bottom As received basis As received basis (feet) (feet) Wt.-% Wt.-% scf/ton CORE 104-33 1,910 1,911 n/a 35.08 7.74 36.5 104-34 1,911 1,912 1.14 34.11 3.78 36.2 104-35 1,912 1,913 1.23 35.73 3.62 32.1 104-36 1,913 1,914 1.39 34.73 5.50 34.1 104-37 1,914 1,915 1.24 34.66 7.75 36.3 104-38 1,915 1,916 1.85 30.17 30.48 32.5 104-39 1,916 1,917 1.81 28.87 27.55 40.9 104-40 1,917 1,918 1.74 27.88 22.64 43.9 104-41 1,918 1,919 1.41 31.16 7.72 37.8 104-42 1,919 1,920 n/a 27.37 40.57 35.0 Sample mean 1.48 31.98 15.73 36.5 Standard deviation 0.28 3.24 13.37 3.6 CUTTINGS 104-31* 1,900 1,905 1.25 55.69 2.8 12.8 104-32* 1,905 1,910 n/a 51.75 3.0 13.1 Sample mean 53.72 2.9 13.0 Standard deviation 2.79 0.1 0.2 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly thought to lead to the spuriously low raw gas content. Abbreviations: n/a, not analyzed; scf, standard cubic feet 42 Section 3: Aquifer Test and Water-Quality Analyses, DOI- 04-1A Well, Fort Yukon, Alaska By Edwin P. Weeks1, Arthur Clark2, and Cindy A. Rice2 Introduction Methane production from coal requires that the hydraulic pressure maintaining sorption of the methane on the coal be reduced by co-producing water by pumping. Prediction of the hydraulic pressure response to pumping within the coal bed and assessment of the potential for methane production requires knowledge of the coal bed hydraulic properties, to be determined using aquifer tests. Based on the drilling schedule, only one coal bed was tested. The thick coal bed in the upper coal zone at a depth of 1,256 to 1,315 ft is substantially thicker than the thickest coal bed in the lower coal zone, and was initially estimated to have a slightly higher methane content (refuted after desorption experiments were completed; see tables 3-1A, 3-1B). Hence, an attempt was made to finish the borehole as a production well in that coal bed, followed by performance of a single-well aquifer test. Events described below precluded a true aquifer test, but several sets of recovery data were collected during the development phase, four of which were analyzed to provide estimates of the coal hydraulic properties. Production of coalbed methane (CBM) is also contingent on management of coal bed water co-produced with the methane, requiring knowledge of the quality as well as the quantity of coalbed water. Consequently, water samples were collected for chemical analysis from the upper coal bed during well-testing and upon retrieval of the pressure transducer in May 2005. These samples are less than ideal, as water samples should be taken only after extensive well ________________________________________________________________________________________________________________________ 1 Corresponding author, U.S. Geological Survey, Denver, Colo. phone: (303) 236-4981 epweeks@usgs.gov 2 U.S. Geological Survey, Denver, Colo. 43 development to ensure that no drilling fluids or suspended solids alter the formation water characteristics. However, waiting was not possible during this test, due to the problems outlined below. Nonetheless, the resulting chemical analyses, augmented by analyses of a squeeze sample from a siltstone underlying the coal bed, and of water used in the drilling mud and in flushing the well, appear to be reasonably representative of coal bed waters determined in other areas, and presumably, then, reliable indicators of the upper coal bed water chemistry. 44 Table 3-1A. Summary of canister desorption results, upper coal zone. Canister number Depth interval Canister sample lithology Raw coal mass Lost gas estimate Total raw gas content Upper coal zone Top Bottom (as-received basis) (feet) (feet) % coal (g) (cc) (scf/ton) CORE 104-1 1,283 1,284 100 1,056 60 14.1 104-2 1,284 1,284.5 50 490 40 13.5 104-3 1,285 1,286 100 907 85 10.8 104-4 1,286 1,287 100 905 80 9.8 104-5 1,287 1,288 100 951 80 11.6 104-6 1,288 1,289 100 1,009 115 21.1 104-7 1,289 1,290 100 1,149 85 7.0 104-8 1,290 1,290.7 70 471 85 14.5 104-9 1,295 1,296 100 961 85 13.4 104-10 1,304.5 1,305.5 100 1,087 110 13.8 104-11 1,306.5 1,307.5 100 1,193 95 12.1 104-12 1,308.5 1,309.5 100 1,115 130 13.6 104-13 1,310.5 1,311.5 100 1,132 130 13.9 104-14 1,312.5 1,313.5 100 842 80 11.0 104-15 1,315 1,316 100 1,038 80 12.9 104-16 1,319 1,320 100 1,171 85 8.6 104-17 1,324 1,325 100 1,518 100 9.0 104-18 1,339.7 1,340.7 100 1,082 100 18.7 104-19 1,342 1,343 100 749 100 19.5 104-20 1,343 1,344 100 1,028 110 15.2 104-21 1,344 1,345 100 1,098 100 10.9 Statistics: Sample mean 13.1 Standard deviation 3.5 CUTTINGS Cuttings-1* 1,265 1,270 80 575 45 7.7 Cuttings-2* 1,270 1,275 80 609 20 4.6 Cuttings-3* 1,275 1,280 80 886 20 2.0 Statistics: Sample mean 4.8 Standard deviation 2.9 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly, thought to lead to the spuriously low raw gas content. Abbreviations: g, grams; cc, cubic centimeters; scf, standard cubic feet 45 Table 3-1B. Summary of canister desorption results, lower coal zone. Canister number Depth interval Canister sample lithology** Raw coal mass Lost gas estimate Total raw gas content Lower coal zone Top Bottom (as- received basis) (feet) (feet) % coal (g) (cc) (scf/ton) CORE 104-33 1,910 1,911 n.r. 100? 1,006 120 20.9 104-34 1,911 1,912 n.r. 100? 1,037 100 22.5 104-35 1,912 1,913 n.r. 100? 1,105 100 19.4 104-36 1,913 1,914 n.r. 100? 994 120 20.4 104-37 1,914 1,915 n.r. 100? 996 120 20.9 104-38 1,915 1,916 n.r. 100? 1,239 120 12.8 104-39 1,916 1,917 n.r. 100? 1,118 120 17.8 104-40 1,917 1,918 n.r. 100? 1,115 125 21.7 104-41 1,918 1,919 n.r. 100? 993 85 23.1 104-42 1,919 1,920 n.r. 100? 1,233 85 11.2 Sample mean 19.1 Standard deviation 4.0 Cuttings 104-31* 1,900 1,905 100 1,104 100 8.1 104-32* 1,905 1,910 100 1,080 110 8.3 Sample mean 8.2 Standard deviation 0.1 * Depth interval estimated from lag time. These cuttings were not screened and the coal fines lose their gas quickly, thought to lead to the spuriously low raw gas content. **Lithology about 100 percent coal from gamma log interpretation. Abbreviations: g, grams; cc, cubic centimeters; scf, standard cubic feet; n.r., not reported 46 Hydrogeologic Setting The well penetrates about 100 ft of coarse surficial gravel deposited by the Yukon River, and deeper deposits tapped by the well consist of lacustrine deposits of interbedded clay, silty clay, silt, silty sand, and sand, with occasional coal beds. Permanent permafrost extends from about 25 to 300 ft, providing a hydrologic confining layer for the underlying materials. The main interest of this hydrologic investigation is of the tested upper coal bed and the beds immediately above and below it, as shown in figure 3-1. The coal bed is immediately overlain by a thin clay bed, separating it from a sand bed. A thicker clay bed separates the upper coal bed from an underlying thinner coal that is, in turn, underlain by another thick clay bed. These overlying and underlying clay beds should provide hydrologic confinement for the upper coal, allowing well test theory developed for confined aquifers to be applied. 47 A BC 1,200 1,250 1,300 1,350 1,400 De p t h ( f t ) Sand Clay Lignite Bentonite grout Gravel Open hole (water) ca s i n g ca s i n g Figure 3-1. A. Geologic profile for 1,200–1,400 ft depth interval in DOI-04-1A CBM well, Fort Yukon, Alaska; B. Original well construction; C. Well configuration after the casing had slipped downhole by 35 ft. Scale approximate. Well Completion and Initial Development Well completion is described in detail in Section 1, but details relevant to interpretation of the hydraulic tests are briefly summarized here. To complete the well for testing, the borehole below the base of the upper coal was backfilled with Volclay™ abandonment grout mixed with thick bentonite, bentonite pellets, and bentonite chips to a depth of 1,313 ft, about 2 ft above the bottom of the coal bed, providing the bottom depth that would yield water to the well. Gravel was 48 added to a depth of 1,307 ft to prevent bentonite from being pumped up into the planned open- hole interval. The lead section of well casing (2.5-in. schedule 80 PVC pipe) was equipped with five 6-in. shale baskets attached 7 ft above the bottom of a stainless steel tail section. The casing was hung from a clamp at land surface so that the shale baskets (packer) bottomed at 1,265 ft, about 9 ft below the top of the coal. Including the open hole surrounding the tail pipe and the 6-ft gravel-filled section, the well section open to the coal should have been 48 ft. Ten buckets of bentonite pellets were placed by tremie pipe immediately above the shale baskets, and the remainder of the annulus around the well casing was filled with abandonment grout. Details of well completion through the 1,200–1,400 ft zone are illustrated in figure 3-1. Following completion of the well, drilling mud remaining in the open portion of the hole (1,265–1,307 ft) was flushed with fresh water using a tremie pipe installed to a depth of 1,302 ft. The driller reported that 400 gallons of fresh water were pumped down the casing before mud began to flow at land surface. The loss of this fluid may have resulted in additional formation damage and the apparent large skin effect described below. Well Tests and Slug Test Theory Following completion of the well, air-lift pumping was initiated to remove fines from the invaded zone surrounding the well bore in anticipation of the performance of an aquifer test. Several brief sets of recovery data were collected at various stages of development to provide data for test planning, but various problems that occurred during development precluded conducting the aquifer test. However, data for three of the recovery data sets, as well as head recovery following the end of development were analyzed using slug test theory to obtain estimates of the hydraulic properties of the upper coal bed. The slug test theory used was that of Cooper and others (1967), as modified by Butler (1997, p. 173) to account for the effects of well-bore clogging or the development of a well skin. The analysis procedure was also modified to that of Earlougher (1977, p. 99) to better analyze data that represent water level recovery of only a few percent of its initial drawdown.The analysis relies on matching test data to a selected member of a family of theoretical log-log type curves of 1-H/H0 vs. KDt/rc2 for various values of , defined as (Butler, 1997, p. 173): )2exp(*2 2 sr Sr c w , 49 where H is the remaining water level displacement, (length); H0 is the initial (instantaneous) water level displacement, (length); K is aquifer hydraulic conductivity, (length/time); D is screen or open hole length; t is elapsed time since the instantaneous displacement; rc is casing radius, (length); rw is the open hole radius, (length); S is the aquifer storage coefficient; and s is dimensionless skin. Dimensionless skin is defined (Matthews and Russell, 1967, p. 19–21) as:             w skin s r r K Ks ln1 where Ks is hydraulic conductivity of the clogged annular layer surrounding the borehole, (length/time); and rskin the outside radius of the clogged layer, (length). In theory, transmissivity, T, equal to Kb, where b is aquifer thickness, should be the parameter determined by slug test analysis. However, practice indicates that the T determined from slug tests represents the KD product, indicating that, at the scale of the slug test, flow to the well bore is governed by the screen or open-hole length, rather than by the full aquifer thickness (Butler, 1997, p. 52–53). For analysis, a data plot of 1-H/H0 vs. t, as determined from measurements, is prepared to the same scale as the type-curve plot. To match the curves, values of 1-H/H0 for the data plot must coincide with those for the type-curve family, but the logarithmic data time axis is shifted, by use of a multiplier M, to provide a match of the data to a selected member of the type-curve family. M is equal to tr KDt c /2      , where       2 cr KDt is the type-curve match line value as read from the x axis, and t is the time at which the match data point was read. M has the unit of time-1. KD is then found as . Selection of the type-curve to be matched can be quite subjective, as the type-curves are of nearly constant shape over a significant range of values. 2 cMrKD Hydraulic conductivity, K, is widely used by hydrogeologists as the hydraulic property governing the movement of water through porous media. However, because of the need to consider the flow of various fluids through porous media, petroleum engineers generally use permeability, k, in units of Darcies, as the parameter-governing porous-media fluid flow. As this practice has been followed in most of the literature on coal-bed methane development, k values will also be presented. A permeability of one ft/d is equivalent to 0.43 Darcy at the temperature of 14 ºC prevailing at the depth of the upper coal bed, as determined from the temperature log (fig. 1-2) obtained in 2005. 50 Recovery data were either collected by use of an electric tape, by which depth to water (DTW) was measured directly, or by use of two absolute pressure transducers, one (an In-Situ Minitroll™ transducer) emplaced at some depth below the water surface in the well and the other (an In-Situ Barotroll™ transducer) at land surface to record barometric pressure. For the transducer data, DTW was computed as (DT-[TR-BP]) where DT is depth of emplacement of transducer below land surface, TR is the transducer pressure reading in ft of water, and BP is barometric pressure in ft of water as read from the Barotroll transducer. For all tests, the static water level (SWL) was assumed to be 6 ft below land surface, based on the approximate depth to water after the well was thawed in May 2005. Starting times for each test were assumed to coincide with the time at which air-lift pumping was stopped to allow for the test. This represents an approximation, as slug test theory assumes instantaneous displacement of the initial water level, whereas air-lift pumping for development was occurring for several hours prior to each water-level measurement period. However, in each case, the period of air-lift pumping was small relative to the time required for full water level recovery, and the assumption of instantaneous displacement was assumed to be adequately met. The initial head displacement was assumed to be the DTW when pumping was stopped minus the SWL. However, heads were not monitored during air lift, so the initial DTW was estimated by linearly extrapolating the average rate of head increase during the test back to the start time. For each of the short recovery tests, the rate of head recovery was quite uniform with time, so this extrapolation should create little error. Test 1 This data set is the first reliable one available and was collected after the casing had been evacuated of water by air-lift pumping to a depth of 500 ft. Evacuation was accomplished in stages, beginning with a 200-ft evacuation starting at 08:18 hours on September 7. Measurements of recovery of the water level for this evacuation were made with an electric tape, but the readings were later recognized to have been affected by water draining down the inside wall of the casing, and hence were not reliable. The casing was evacuated in two additional stages to a depth of 500 ft, and recovery was again measured, after pumping halted at 11:30 hours. This time, the problem of false readings was noted after a false start, and a series of six good measurements was obtained, beginning at 11:43:15 hours, and lasting about 51 6 minutes. These data constitute test 1, which is the only test available for the full open hole interval of 48 ft. The water level at 11:30 hours was computed to be 496 ft (rounded) by assuming that the average recovery rate of 0.86 ft/min. extended over the preceding 13.25 minute interval. Subtraction of an assumed SWL below land surface of 6 ft provides an H0 value of 490 ft. The length of drained column at each time t was computed as DTW-SWL. Table 3-2. Water-level recovery following evacuation to 500-ft depth 09/07/04. Time DTW (Depth to Water, in ft) Elapsed time, sec. H/H0 11:43:15 485 795 0.9776 11:44:25 484 865 0.9755 11:45:36 483 936 0.9735 11:46:45 482 1005 0.9714 11:47:53 481 1073 0.9694 11:49:01 480 1141 0.9674 Data for test 1 are listed in table 3-2 and shown as the open triangles in figs. 3-2A and 3- 2B. Also shown in fig. 3-2 are type curves and test 1 matches for log10  = -4, -9, -15, and -30. For the test interval, both the data and the type curves form straight lines, with slope of the type curves increasing with decreasing *. Data for test 1 match the type curve for *=10-9 reasonably well. This match was achieved by multiplying the data curve t values, which are in days, by 11.3, so 2 3.11 cr KD day . Simplifying, KD=11.3 rc2 /day, and, for the 1.125-in. (0.09375 ft) rc, KD=0.1 ft2/d. For the 48-ft thick open-hole section, K=2X10-3 ft/d. This value translates to a permeability of about 0.9 mD (milliDarcy) (table 3-3). Table 3-3. Results of slug-test type curve analyses for tests performed on the Fort Yukon well. Test KD, ft2/dX10-2 K, ft/dX10-3 k, millidarcies b, ft Type Curve =10-4 1 3.1 0.6 0.3 48 Type Curve=10-9 1 9.9 2 0.9 48 2 1.8 1.4 0.6 13 Type Curve =10-30 1 30 6 3 48 3,4 0.9 1.5 0.6 6? 52 10-2 10-1 100 Time, in days or KDt/rc 2 10-2 10-1 1- H / H 0 Lo g 10 α =- 4 -9 -1 5 -3 0 Te s t 1 Te s t 2 Te s t s 3 , 4 c o m b i n e d Figure 3-2A. Data plots (labeled, open symbols) at an expanded scale for real time in days and as matched (filled symbols) to selected type curves. 53 10-2 10-1 100 101 102 Time, in days or KDt/rc 2 10-2 10-1 100 1- H / H 0 Lo g 10 α =- 4 -9 -1 5 -3 0 Te s t 1 Te s t 2 Te s t s 3 , 4 c o m b i n e d Figure 3-2B. Same as figure 3-2A, but showing the type curves to include complete recovery. Type curves generated using Fortran program of Greene and Shapiro (1995). The * value of 10-9 was chosen as the maximum value that matched the steepness of the data curve. The * value that should be matched in the absence of well-bore clogging (s=0), 2 2 c w r Sr, may be determined from well construction data and an estimate of S. Three well- controlled aquifer tests conducted on sub-bituminous coal beds in the Powder River Basin provide a specific storage (Ss) for coals of about 6X10-6/ft (Weeks, 2005, p. 254). Although the 48-ft thick (b) coal bed at this site is of lower rank, we assume, due to a lack of other data, a similar Ss, so we compute S=Ss b=3X10-4. For this well, rw= 3.5 in., and rc=1.125 in. Thus, =3X10-3, and a match to the *=10-9 type curve indicates substantial clogging. As a plausibility check, the exp(-2s) value needed to reduce * to 10-9 from 3X10-3 is 3.3X10-7, results in s = 7.5. 54 Assuming a 1-in. thick clogged zone, ln (rskin/rw) is 0.25, so, based on the equation             w skin s r r K Ks ln1 , Ks is about 0.03 times that of the formation. The fact that the log-log plot of head recovery for test 1 is steeper than the type curve plots for larger *values could be due to ongoing well development as water entering the well removes fine materials from the well bore wall. In that case, use of the *=10-9 type curve to analyze the test may over-estimate clogging, and the computed KD value may thus be too large. To obtain a probable minimum estimate for KD and K, the earliest data were also matched to the  curve, as that may be about the maximum * that would still allow well development to occur. For this match, KD=3.5rc2, or about 0.03 ft2/d, providing a minimum K value of 0.6X10-3 ft/d or about 0.3 mD. A maximum estimate of KD and K for this test is more difficult to estimate. A match of the data to the *=10-30 curve provides a K of 6X10-3 ft/d or 3 mD. A 1-in. clogged layer would have to be about 100 times less permeable than the formation, within the realm of possibility, but perhaps unlikely at this stage of well completion and development. Events Leading to Test 2 Following the end of electric tape recovery measurements at 11:50 hours, tremie pipe was added and the well was air-lift pumped from a depth of 600 ft until about 13:00 hours, when the casing slipped through the clamp and fell about 35 ft down the hole, the bentonite grout presumably slipping with it. Based on the various initial depths of packer, tail section bottom, and gravel top, the bottom of the well casing was now resting on the gravel surface, with 7 ft of open hole above the casing bottom. The resulting well configuration is shown in figure 3-1C. Two new sections of casing were installed over the tremie pipe to salvage the well. Following the well collapse, a water level depth of about 48 ft was measured in the casing. Air-lift pumping in the salvaged well was resumed at 15:30 hours, and water levels were lowered to 500 ft by 16:30 hours. Water level recovery was monitored for several minutes beginning at 16:45 hours, but recovery was quite slow (about 0.2 ft/min.), with somewhat erratic behavior, possibly due to water running down the casing. Consequently, no attempt was made to analyze these data. Pumping resumed about 17:00 hours, and the well was evacuated to a depth of 780 ft by 18:30. Pumping from that depth continued until 20:10 hours. At that time, 3 55 sections of tremie pipe were added, and the pressure transducer was emplaced at the 780-ft depth to record recovery overnight, beginning at 21:00 hours. Test 2 The record of overnight water level recovery constitutes test 2. Water levels were recorded every five minutes, and were found to be rising, based on a regression analysis, at a fairly uniform rate of about 0.23 ft/min. until 01:05 hours on September 8. After that time, the pressure head demonstrated major oscillations, presumably due to a well cave-in. After these oscillations, the rate of water level rise dampened, and by 03:00 hours, had stopped completely, with an indicated DTW of about 667 ft. Data for the period 21:00 to 01:00 hours were chosen for slug test analysis. The initial water level, at 20:10 hours, was computed to be 758.4 ft, rounded to 758 ft. For the assumed static water level of 6 ft, H0 becomes 752 ft. Transducer data were converted to DTW as described above, and SWL subtracted to provide H/H0 at 5-minute intervals. Times were converted to days elapsed since 20:10 hours. Data for test 2 are shown as the open inverted triangles in figure 3-2. The early data (solid inverted triangles) match the type curve for *=10-9 reasonably well, resulting in KD=2.0 rc2/d, or 1.8X10-2 ft2/d. Assuming that the aquifer thickness had been diminished by an amount equal to the 35-ft drop of casing in the well, the aquifer thickness is now 13 ft (7 ft open hole plus 6 ft gravel zone), resulting in K=1.4X10-3 ft/d or 0.6 mD. This value is, considering uncertainties in the analysis, basically the same as that of 2X10-3 ft/d determined from the short recovery test of the full open-hole section. This result indicates that the main factor affecting the results of test 2 relative to test 1 was a diminution in the section of hole providing water to the well. Later data for this plot show a somewhat steeper slope than any of the type curves. This may occur because of minor spalling that resulted in some well development prior to the hypothesized major spalling and cave-in occurring at about 01:05 hours on September 8. Events Leading to Test 3 Prior to the resumption of air-lift pumping on September 8, it was noted that the well casing had risen about 1 ft overnight, probably at the time of the hypothesized well cave-in. Presumably, fine materials surged into the 7-ft open hole section surrounding the steel tail pipe 56 at that time, creating substantial pressure on the bottom of the packer that lifted the well. The caved materials likely later settled on the gravel, effectively sealing the previous open-hole section from the bottom of the tail pipe, thus reducing the well section supplying water from the coal to no more than the gravel-filled section of 6 ft. Air-lift pumping was conducted from 09:30 to 11:00 hours, lowering the water level from 667 ft to about 1,000 ft. The transducer was installed at the 1,020-ft depth from 11:16 until 13:00 hours to measure recovery. The water level recovered about 1.5 ft during this interval, indicating that severe clogging, probably associated with the well cave-in, had occurred. No attempt was made to analyze these data, but it was decided to circulate fresh water in an attempt to reduce clogging. While lowering tremie pipe through the casing to circulate, a plug was encountered at a depth of about 1,077 ft, or about 190 ft above the bottom of the casing. The plug was washed out, with particles of coal and of fine gravel being suspended in the return flow. Flushing was continued until the tremie pipe had reached the gravel installed during well completion. Circulation was continued at that depth for about an hour to clean out the remaining open hole. However, fine materials may have sifted into the gravel, clogging the surficial gravel now surrounding the bottom of the casing. Test 3 Following flushing of the well, air-lift development, taking the water level down to 300 ft in two stages, starting about 19:00 hours on September 8. Air lift was halted at 20:15 hours, and the pressure transducer installed to monitor water levels overnight. The transducer was programed to read pressure head at 5-minute intervals starting at 21:00 hours, and was retrieved at 08:00 hours on September 9. These overnight readings were used to develop test 3. DTW, as measured with the electric tape, was 302.75 ft at 20:19:45 hours. Assuming a DTW at 20:15 hours of 303 ft, and subtracting the 6-ft assumed SWL, H0 = 297 ft. The initial transducer reading at 21:00 hours translated to a depth to water of 302.2 ft, for a column length of 295.2 ft. Times were converted to days elapsed since 20:15 hours, and H/H0 computed for hourly readings extracted from the record. Results for test 3 are shown as the open circles in figure 3-2A, which fall on the =10-30 type curve, providing KD (=rc2 /d) of 9X10-3 ft2/d. For this match, the thickness to provide a K of 0.0015 ft/d d or 0.6 mD is 6 ft. This is equal to the thickness of the gravel layer, which would be 57 consistent with the isolation of the well in the gravel by creation of a low-permeability layer at the gravel surface. Plausibility of the indicated well skin is difficult to assess, as the geometry of the bottom of the well casing resting in possibly clogged gravel does not fit the model of a radial annular clogged layer assumed in the development of slug test theory. Nonetheless, it seems reasonable that the effect of the low-permeability layer extending into the top of the gravel might mimic that of a clogged annular layer. Although the results of test 3 and 4 are not inconsistent with those for tests 1 and 2, the agreement may be fortuitous, and should be considered inconclusive. Winter Data Following removal of the transducer to obtain data for test 3, preparations were made to collect pressure head data from the well during the winter months of 2004–2005. The remaining annular space around the well casing, voided when the casing sank down the borehole, was back-filled with bentonite grout and with drill cuttings. Two 10-W/m heat tapes, one 270 ft and the other 350 ft in length, were installed to allow ice that would freeze in the well above the permafrost depth to be melted. Recovery data were recorded hourly over the winter, starting with installation of the transducer at 17:00 hours on September 9, 2004 and ending with its retrieval at 16:55 hours on May 7, 2005. The transducer was installed at a depth of 610 ft, and had been recording a barometric pressure of about 33.4 ft before it was installed. Pressure head above land surface was determined from the transducer readings by subtracting 643 ft, the depth (rounded) of the transducer plus the barometric pressure, from the initial pressure transducer reading (in ft). The resulting hydrograph (fig. 3-3) shows very strange behavior. For about the first 50 days, pressure head follows the trend that would be expected for its recovery from the air-lift pumping that occurred on September 8. Beginning at 01:00 hours on October 30, the pressure head spiked up, rising more than 22 ft in seven hours, followed by a decline of about 17 ft in 3 hours. Pressure head rose slowly, with one minor excursion, until November 1, when another sharp rise occurred, raising the pressure head from about at land surface to a height of about 65 ft above land surface by November 11. Pressure head remained quite stable at that magnitude until 01:00 hours on February 28, when it began to rise rapidly, reaching a peak of about 360 ft above land surface on March 18. After that time pressure head fluctuated and declined slowly until April 27, when it began to decline rapidly. Pressure head 58 had declined to a reading putting it about 35 ft above land surface on May 7, the date the transducer was retrieved. Retrieval involved powering the heat tapes, the longer one at 10:30 hours, and the shorter one at 11:45 hours. The pressure head declined rapidly once the ice column in the well partially thawed between 13:00 and 14:00 hours. The transducer was pulled up after 14:00 hours, but became stuck at a level at which the pressure read about 250 ft for two hours, after which time it was retrieved. Upon retrieval, the transducer was reading a barometric pressure of about 23 ft of water, rather than the 33+ ft that it had read on installation. The transducer had been significantly over-ranged during the period of high pressure head, and may be significantly out of calibration. An electric tape reading following retrieval of the transducer at 17:00 hours indicated a depth to water of 6 ft below land surface. 59 Figure 3-3. Graph of pressure head (in ft) vs. time for the Fort Yukon well, September 2004 to May 2005. The pressure heads read by the transducer must represent a well phenomenon, indicating (possibly) that the bottom of the casing, sitting in the clogged gravel layer, became completely isolated from the coal aquifer at about the time that the water level fully recovered. The first pressure spike, on October 30, may have occurred as water froze over at some point in the well, sealing it from the surface. As the freezing front advanced downward, the expansion due to freezing may have pressurized the well, but this first ice seal may have fractured or slipped later that day. The well may have frozen over for good on November 1, with the freezing front again migrating downward to stabilize after about 10 days. The rise beginning February 28 is more problematic. Possibly bacterial action began to generate gas that overpressured the ice- capped water column, with the well beginning to make some re-connection with the aquifer in 60 early May. The pressure clearly was released completely when the ice in the well was thawed. The above are merely conjectures, and the true cause of the strange well behavior may never be known. Nonetheless, it is extremely unlikely that the recorded pressure heads represent those in the formation. Test 4 Despite these problems, the early data, extending to October 30, appear to represent recovery from the air-lift pumping on September 8, and will be analyzed as such. Pressure head was computed as 638 ft (depth of 610 ft+ barometric pressure of 34 ft-6 ft SWL), minus the transducer reading. H0 of 297 ft, the same as for test 3, is assumed. The resulting plot of 1-H/H0 versus time is a continuation of the data plot for test 3, as it should be. The match points and determined KD and K values are the same for the two tests. After about 30 days and 80 percent recovery, the pressure head recovery is more rapid than predicted by slug test theory. The cause of this is unknown, but has been observed by the authors for a few other slug tests on coal beds in the Powder River Basin of Montana and in central Alaska. Summary of Aquifer Test Analyses In summary, the testing regime for this well was fraught with difficulties and uncertainties. Development of the well was in progress when the casing slipped 35 ft, precluding an extensive test on the fully developed well open to 48 ft of coal. Depressuring for the second test led to a cave-in of the well, further reducing its production capacity and effective KD. Despite these problems, the resultant slug tests provide a range of values that may bracket the true hydraulic conductivity or permeability of the coal. The results of matching the data for test 1 to a maximum probable  value indicate a minimum K (k) of 6X10-4 ft/d (0.3 mD). The maximum hydraulic conductivity is less easily obtained. A 1-in. thick clogged layer that is 100 times less permeable than the coal would result in a computed K (k) of about 6X10-3 ft/d (3 mD). Such a permeability reduction is within the realm of possibility, but may overstate conditions for test 1. A good estimate of the permeability of the coal at this site, based on reasonable agreement of k values for tests 1 and 2, may be about 0.6 mD. This permeability is lower than that determined from aquifer tests and slug tests conducted on several coal beds by the authors in the Powder River Basin in Montana, but is not anomalously low compared to k values for coal beds in the 61 San Juan and Black Warrior Basins (McKee and others, 1988). Coal bed methane development in those basins is accomplished by extensive hydraulic fracturing of the coal beds (Zuber, 1996, p. 3.18–3.19), a practice that almost certainly will be required for the development of coal bed methane at Fort Yukon. The relatively low methane content and low permeabiliity of the coal indicate that the potential for methane development at Fort Yukon is limited, and plans for a multiple well aquifer test were abandoned. The well was plugged and abandoned following retrieval of the transducers, temperature logging, and water sampling in May 2005. Water Chemistry Analyses The water-chemistry analyses related to the upper coal bed are based on 3 water samples, two from the well and one from a core sample. Sample Well_1 was captured during air-lift development of the coal from a depth of about 1,300 ft and sample Well_2 was bailed from this same depth after the well was thawed in May 2005. The siltstone sample was obtained by squeezing a core sample collected from a depth of 1,400 ft, 55 ft below the bottom of the upper coal zone. For comparison, two samples of surface water used in the drilling operation (Truck A and Truck B) were also analyzed to ensure that the water samples from the well were not affected by the drilling fluids. Unfiltered samples were refrigerated after collection prior to returning them to the USGS laboratory in Lakewood, Colo. At the laboratory, the samples were filtered through a 0.45 mm filter and the sample for cations was acidified to a pH of less than 2. Cations were analyzed by standard inductively-coupled plasma emission spectroscopy (ICP_AES) and anions were determined by standard ion chromatography. Tables 3-4A and 3-4B give the composition of major ions and selected trace elements respectively. The data on water quality presented here should be viewed as qualitative only because of the lack of stringent sampling and collection protocols. The 3 samples from the coal and siltstone are Na-HCO3 type waters with total dissolved solids (TDS) ranging from 880 to 1,480 mg/L, and display the dominant characteristics of typical CBM waters: sodium and bicarbonate as dominant cation and anion, low sulfate values, implied 62 low redox potential, and high sodium adsorption ratio 1 (SAR) (Table 3-4A). This similarity is demonstrated in fig. 3-4, which compares the analyses with those for a large suite of water samples collected from methane-bearing coal beds in the Powder River Basin, Wyoming and Montana (Rice and others, 2002). Surprisingly, the siltstone sample most closely resembles CBM water typified from the Powder River Basin (fig. 3-4). The sulfate value is very low (<10 mg/L), and, because of the low sulfate value, the Ba++ value is high (4.7 mg/L). The high Fe concentration suggests that the water was reducing, also consistent with typical CBM produced waters. The biogeochemical processes that produce water typical of CBM developments are discussed by Rice and others (2002) and by Van Voast (2003). The samples collected from the coal and siltstone are distinctly different in both composition and TDS compared to the truck samples, which are representative of water used to drill the well (fig. 3-4, table 3-4A). The truck samples represent a low TDS (<400 mg/L) Ca-Mg- SO4-HCO3 type water with low concentrations of Na (<20 mg/L), small SAR values (<1), and major anions comprising both sulfate and bicarbonate. Lack of a discernible mixing trend between the well samples and the truck samples (fig. 3-4) indicates that contamination of the formation water samples by drilling fluid is minimal. The water chemistry data suggest that problems associated with the disposal of water co-produced with methane from the upper coal bed would be minimal. Total dissolved solids for the formation waters are somewhat, but not drastically higher, than the primary drinking water standard of 500 mg/L, and the SAR is high enough that the water might not be suitable for irrigation applications, an unlikely use of the water. Trace elements for the well samples are below drinking water standard criteria, but those squeezed from the siltstone for Fe, Ba, and Al are above them. A final determination of needed disposal practices, assuming methane development was implemented, would require additional water quality sampling and analysis. 63 1 2/][MgCaNaSAR , where concentrations are in milliequivalents. Table 3‐4A. Concentrations of major ions in water samples from drill hole DOI‐04‐1A, Fort Yukon, Alaska. The concentration of HCO3 is estimated from charge balance and represents total alkalinity. CO O PO Sample TDS Na Ca Mg SAR K Cl SO4 H3 N3 4 mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L Well_1 978 310 37 27 9.45 20.0 12 130 900 bdl bdl Well_2 881 280 24 11 11.87 17.0 14 210 660 4 1.9 Siltstone 1478 430 55 75 8.85 45.0 25 8 1710 bdl bdl Truck_A 390 15 45 55 0.35 4.1 14 120 280 bdl bdl Truck_B 323 12 23 52 0.32 4.3 13 120 200 bdl bdl Abbreviations: mg/L, milligrams per liter; bdl, below detection limit Table 3‐4 . Concentrations of selected trace elements in water samples from drill hole DOI‐04‐1A, Fort Yukon, Alaska. B Sample Si Al Fe Mn Ba Sr Zn mg/L g/L g/L g/L g/L g/L g/L Well_1 4.4 110 58 110 430 290 120 Well_2 na na 90 na 110 390 Na Siltstone 25 7100 1580 <60 4700 820 480 Truck _A 9.4 1150 <250 87 100 210 290 Truck_ B 3.4 <625 <250 <60 92 190 270 Abbreviations: mg/L, milligrams per liter; g/L, micrograms per liter 64 Figure 3-4. Piper Diagram comparing water samples from drill hole DOI-04-1A, Fort Yukon, Alaska to water samples from CBM wells in the Powder River Basin (PRB), Wyoming and Montana. 65 References Butler, J.J., 1997, The design, performance, and analysis of slug tests: Lewis, Boca Raton, Florida, 252 p. Cooper, H.H., Bredehoeft, J.D., and Papadopulos, I.S., 1967, Response of a finite- diameter well to an instantaneous charge of water: Water Resources Research, v. 3 no. 1, p. 263–269. Earlougher, R.C. Jr., 1977, Advances in well test analysis: Society of Petroleum Engineers Monograph, v. 5, 264 p. Greene, E.A., and Shapiro, A.M., 1995, Methods of conducting air-pressurized slug tests and computation of type curves for estimating transmissivity and storativity: U.S. Geological Survey Open-File Report 95–424, 43 p. Matthews, C.S., and Russell, D.G., 1967, Pressure buildup and flow tests in wells: Society of Petroleum Engineers Monograph, v. 1, 167 p. McKee, C.R., Bumb, A.C., and Koenig, R.A., 1988, Stress-dependent permeability and porosity of coal and other geologic formations: SPE Formation Evaluation, v. 3, no. 1, p. 81–91. Rice, C.A., Bartos, T.T., and Ellis, M.S., 2002, Chemical and isotopic composition of water in the Fort Union and Wasatch Formations of the Powder River Basin, Wyoming and Montana: Implications for coalbed methane development, in Schwochow, S.D., and Nuccio, V. F., eds., Coalbed Methane of North America, II: Rocky Mountain Association of Geologists, p. 53–70. Van Voast, W.A., 2003, Geochemical signature of formation waters associated with coalbed methane: American Association of Petroleum Geologists Bulletin, v. 87, p. 667–676. Weeks, E.P., 2005, Hydrologic properties of coal beds in the Powder River Basin, Montana II. Aquifer test analysis: Journal of Hydrology, v. 308, p. 242–257. Zuber, M.D., 1996, Basic reservoir engineering for coal, in Saulsberry, J.L., Schafer, P.S., and Shraufnagel, R.A., eds., A Guide to Coalbed Methane Reservoir Engineering: Gas Research Institute, Chicago. Ill., variously paginated. 66 Summary of Results: Coalbed Methane Production Potential in Fort Yukon, Alaska as Derived from the DOI-04-1A Well By Edwin P. Weeks1, Arthur Clark2, and Charles E. Barker3 Fort Yukon Production Potential The permeability estimates provided for the upper coal bed in table 3-3, assumed to also apply to the lower coal, may be used in conjunction with the methane desorption data (tables 2-1A, 2-1B) and adsorption isotherms (figs. 2-1, 2-2), to roughly evaluate the potential for methane production at Fort Yukon. In particular, the results can be used to estimate the number of wells and well spacing required to produce 225,000 standard cubic feet of pure methane per day (scf/d), the estimated requirement for power generation and home heating at Fort Yukon (Ferguson and Ogbe, 2003, p. 14). An absolute control on coalbed methane availability is imposed by the volume of gas initially in place per unit area. Volumetric gas in place can be determined from the equation: , where IGIP is initial gas in place, Mscf/acre; 1.359 is a conversion factor, [(Mscf)(ton)(cm3)]/[(ac-ft)(scf)(gm)]; C is average as-received gas content of the coal, scf/ton; c is mean raw coal density, g/cm3; h is coal bed thickness, ft; and  is the mole fraction of methane in the desorbed gas. For the upper coal, C=13.1 hCIGIPc359.1 scf/ton (table 2-1A), c=1.34 g/cm3 (table 2-2A), h= 59 feet, and =0.94, resulting in IGIP=1.3 MMscf methane/acre. For the lower coal, the average gas content of 19.1 scf/ton (table 2-1B), coal density of 1.48 g/cm3 (table 2-2B), combined with a coal ______________________________________________________________________________________________________________ 1 Corresponding author, U.S. Geological Survey, Denver, Colo. phone: (303) 236-4981 epweeks@usgs.gov 2 U.S. Geological Survey, Denver, Colo. 3 Scientist Emeritus, U.S. Geological Survey, Denver, Colo. 67 thickness of 20 ft, results in IGIP of about 700 Mscf/acre. For a pure methane fuel requirement for the village of 225 Mscf/d or 80 MMscf/yr, the village would require 1.6 billion scf over a 20-year period. Assuming a 100 percent recovery efficiency, all of the gas, if derived from the upper coal, would have to be removed from an area of about 1,200 acres, or, if dual completion of wells tapping the two zones is feasibile, could be obtained from a 800-acre area. However, complete gas recovery is not possible, and a rigorous evaluation of the 20-year recovery efficiency would require reservoir simulation, which is beyond the scope of this study. Nonetheless, a rough estimate of the number of wells needed to supply the village energy requirements may be obtained by analogy with results of simulations performed to evaluate recovery efficencies based on San Juan Basin coal properties. Zuber (1996, p. 3.18–3.19) provides illustrations for well spacings of 80, 160, and 320 acres, showing simulated 20-year recovery efficiencies vs. permeability and hydraulic fracture length for San Juan Basin coals. Zuber’s curves indicate that computed recovery efficiency is nearly zero without hydrofracing for permeabilities less than 1 millidarcy, but increases sharply with diminishing well spacing and with stimulated fracture length. Simulated efficiencies undoubtedly would be smaller for the low level of methane saturation for the Fort Yukon coals than those derived for methane-rich San Juan Basin coals. Nonetheless, estimates of the minimum number of hydrofraced vertical wells needed to meet the requirements can be made from recovery efficiencies illustrated in these figures, test-based permeability estimates, and the IGIP estimates. For the preferred estimate of coal permeability of 0.6 mD (table 3-3), the simulated curves for a spacing of 80 acres and an arbitrarily chosen stimulated fracture length of 200 ft (Zuber,1996, p. 3.18) indicate a 20-year recovery efficiency of about 30 percent. Based on this efficiency, about 50 wells tapping the upper coal, covering an area of 4,000 acres, would be required to meet village needs. For dual completion in the upper and lower coals, but the same recovery efficiency, about 30 wells in an area of 2,700 acres would be required. Zuber’s curves also indicate that, for a given fracture length, recovery efficiency increases, at low K values, by about 12 percent for each halving of well spacing. Thus, 20-year recovery efficiency might be about 42 percent for a 40-acre 68 69 spacing, indicating that about 50 dual-completion wells covering about 2,000 acres might be able to meet the village requirements. Recent developments involving the use of horizontal wells indicates that the number of wells required might be decreased by a factor of three to five or more, reducing the number of wells required to as few as 5 to 10. However, the actual feasibility of developing the Fort Yukon coals using dual-completion hydrofraced horizontal wells would require thorough evaluation using a reservoir model. The above analyses only provide a basis for indicating whether such a study might be useful. References: Ferguson, J.C., and Ogbe, D.O., 2003, Fuel gas utilization and economic study: Application to Fort Yukon, Alaska: Petroleum Development Laboratory, University of Alaska, Fairbanks, 17 p. Zuber, M.D., 1996, Basic reservoir engineering for coal in Saulsberry, J.L., Schafer, P.S., and Shraufnagel, R.A., eds., A Guide to Coalbed Methane Reservoir Engineering: Gas Research Institute, Chicago Ill., variously paginated. DATA SUBMITTAL COMPLIANCE REPORT 2/812013 Permit to Drill 2040830 Well Name /No. D01-04 1A Operator U S DEPT OF INTERIOR API No. 50 -091- 20001 -00 -00 MD 2287 TVD Completion Date Completion Status Current Status UIC N REQUIRED INFORMATION Mud Log Yes Samples Nits, Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Density, Resisitivity, Sonic, Porosity, gamma (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / • Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED V/ Las 12965 Gamma Ray 372 2092 Open 3/8/2005 GR Caliper (Electronic Transfer) ED Las 12966 Induction /Resistivity 3 2288 Open 3/8/2005 GR, Temp, Res(16N), Res(64N), Del Temp, Res Lateral (Electronic Transfer) Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cores and /or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 6/1/2004. ADDITIONAL INFORMATION Well Cored? 13/ N Daily History Received? N Chips Received? Y /® Formation Tops N Analysis Y /(p Received? Comments: No (3la... L: Y.. / Color 1164 Copy ku ., � (r•.►;�l'Q I N• f4 014)&0- 4..4 1.c /Lt, C rS 4. L .. y t Ale et / /V • CA.A. -1 i H T e� ` Compliance Reviewed By: G"> Date: 1 110 USGS - BLM Wells III Missing Required Information Well Name Permit to Drill Number Missing Information Prior Requests DOI -04 -1A (Ft. Yukon) 2040830 Core analysis Requested 11/5/2009 2040830 Core chips Requested 11/5/2009 2040830 Cuttings samples Requested 11/5/2009 2040830 Mud log Requested 11/5/2009 2040830 Open hole logs - Paper Print Requested 11/5/2009 2040830 Open hole logs - Reproducible Requested 11/5/2009 Franklin Bluffs 1 2051050 As built survey plat Requested 11/5/2009 2051050 Core description and analysis Requested 11/5/2009 2051050 Mud log Requested 11/5/2009 2051050 Open hole logs - Digital Requested 11/5/2009 2051050 Open hole logs - Paper Print Requested 11/5/2009 2051050 Open hole logs - Reproducible Requested 11/5/2009 Wainwright 01 2070650 Core analysis Requested 11/5/2009 2070650 Core chips Requested 11/5/2009 2070650 Location information (coordinates as metes & bounds, Required on Completion Report form coordinates in AK State Plane NAD 27) 2070650 Location information (lat /long datum) Wainwright 02 2071060 Cuttings samples Requested 11/5/2009 2071060 Inclination survey Requested 11/5/2009 2071060 Lithology log Requested 11/5/2009 2071060 Location information (coordinates as metes & bounds, Required on Completion Report form coordinates in AK State Plane NAD 27) 2071060 Location information (lat /long datum) Wainwright 09 2080770 Core chips Requested 11/5/2009 2080770 Core description and analysis Requested 11/5/2009 2080770 Lithology log - Paper Print Requested 11/5/2009 2080770 Location information (lat /long datum) Wainwright 10 2090350 Core chips Requested 11/5/2009 2090350 Core description and analysis Requested 11/5/2009 2090350 Cuttings samples Required on Completion Report form 2090350 Inclination survey Requested 11/5/2009 2090350 Location information (coordinates as metes & bounds, Required on Completion Report form coordinates in AK State Plane NAD 27) 2090350 Location information (lat /long datum) 2090350 Mud log (required by permit to drill; drilling history states "will Requested 11/5/2009 not collect mud -gas log at this site. ") Wainwright 03 2080710 In compliance Wainwright 04 2080720 In compliance Wainwright 05 2080730 In compliance Wainwright 06 2080740 In compliance Wainwright 07 2080750 Expired permit: never drilled Wainwright 08 2080760 In compliance Wainwright 11 2090360 Cancelled permti: never drilled AOGCC February 17, 2011 • 0 - b'b5 C tl � , � .' �0 g � -� f f � 1� p (�(- ` `` � + � ;L\ gg d _ I' 6 �' g f' R b4 ' w h I' t+ � II a t 5 ' ! y � `• J ! / SEAN PARNELL, GOVERNOR tai d d � vr ` c� ! c i \ . ne= 6 r ALASKA OIL AND GAS rB 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 November 6, 2009 Greg Noble Section Chief — Energy Section Bureau of Land Management 4700 BLM Road Anchorage, Alaska 99507 Dear Mr. Noble: This letter responds to your November 9, 2009 email expressing displeasure with my November 5, 2009 letter. While the November 5 letter may not have been what you were expecting, the AOGCC is statutorily charged with assuring compliance with our drilling regulations. The AOGCC remains amenable to resolving this matter without the necessity of a public hearing. To that end, Guy Schwartz, an AOGCC petroleum engineer, will contact Art Clarke to discuss the situation with him. If you would care to participate in that dialogue, please contact Guy Y at 907 - 793 -1226. Sincerely, Daniel T. Seamount, Jr. Chair • a q. o 3 ,L, \ A \ L, I6t 3 j r k t N ° (, i 5 P C SEAN PARNELL, GOVERNOR �_ 1 � a 1 ,1 02) . W I ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 November 6, 2009 Greg Noble Section Chief — Energy Section Bureau of Land Management 4700 BLM Road Anchorage, Alaska 99507 Dear Mr. Noble: This letter is a follow -up to discussions regarding the USGS's ongoing violations of AOGCC regulations at the Wainwright, AK exploratory coal bed methane project. In those discussions you questioned the AOGCC's support for the coal bed methane project. AOGCC strongly supports the project. However, that support is predicated on compliance at Wainwright with AOGCC regulations. Wainwright well operations are continually conducted in violation of AOGCC regulations. Some of those violations, including well work undertaken without a permit, are very serious. The AOGCC's prior efforts to obtain regulatory compliance have essentially been ignored. The AOGCC remains amenable to resolving these issues informally. But as much as the AOGCC supports the project, we are rapidly approaching a point where other options need to be considered, including a public hearing regarding the violations. To the extent you may be able to obtain or encourage USGS compliance with AOGCC regulations, we welcome your support. In closing, let me again express the AOGCC's support for the program and the hope that once the compliance issues are resolved it is a resounding success. Sincerely, Daniel T. Seamount, Jr. Chair Enclosure Art Clark, Supervisory Physical Scientist USGSCRRMWRD Box 25046, Denver Federal Center Mail Stop 939 Denver, CO 80225 -0046 Gary Reimer, District Manager USGS, Anchorage District Office 4700 BLM Road Anchorage, AK 99507 Leslie Holland- Bartels, Regional Executive - Alaska Area USGS WR AA DO 4210 University Drive Anchorage, AK 99508 -4626 Anne Kinsinger, Western Regional Director USGS WR -- DO 909 1st Avenue, Suite 704, 7th Floor Seattle, WA 98104 -1055 Peter Lyttle, Acting Associate Director for Geology USGS HQ -- GD 12201 Sunrise Valley Drive, Mail Stop 911 Reston, VA 20192 -0002 Thomas P. Lonnie, State Director Bureau of Land Management Alaska State Office 222 W 7th Avenue #13 Anchorage, Alaska 99513 Bob Abbey, Director BLM Washington Office 1849 C Street NW, Rm. 5665 Washington DC 20240 t ` n j � t t - r ! —" i L-' r j \ " r 1 SEAN PARNELL, GOVERNOR ALASKA ALASKA O IL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 November 5, 2009 Art Clark, Supervisory Physical Scientist Gary Reimer, District Manager USGS CR RM WRD USGS, Anchorage District Office Box 25046, Denver Federal Center Mail Stop 939 4700 BLM Road 0 Cg3 Denver, CO 80225 -0046 Anchorage, AK 99507 Dear Mr. Messrs: On September 9, 2009 the Alaska Oil and Gas Conservation Commission (AOGCC) wrote to request compliance with AOGCC regulations at the Wainwright, AK exploratory coal bed methane project. The USGS provided no response. Because Wainwright well operations are being conducted in violation of AOGCC regulations, and because some of those violations, including well work undertaken without a permit, are very serious, the AOGCC is making a final attempt to resolve these issues informally. The following actions are required in order for the USGS to bring its Wainwright operations into compliance with AOGCC regulations: Wainwright #6 (PTD 208 -074 ) - Submit AOGCC forml0 -407 documenting 2009 activities in detail. (as per 20 AAC 25.070 (3)) - Submit a current wellbore drawing. (as per 20 AAC 25.300) - Submit hard and digital copies of all logs obtained drilling and completing the well. (as per 20 AAC 25.071 (6)) Wainwright #9 (PTD 208 -077) - Submit AOGCC form 10 -407 documenting all activities including the P & A. (as per 20 AAC 25.070 (3) ) - Submit a current wellbore drawing. (as per 20 AAC 25.300) - Submit hard and digital copies of all logs obtained drilling and completing the well. (as per 20 AAC 25.071 (6)) - Submit Core sample chips. (as per 20 AAC 25.071 (4) ) - Submit Core description and analysis (as per 20 AAC 25.071 (3)) - Submit Lithology log (as per 20 AAC 25.071(3)) Wainwright #10 ( PTD 209 -035) - Submit AOGCC form 10 -407 documenting all activities including the P & A. (as per 20 AAC 25.070 (3) ) - Submit a current wellbore drawing. (as per 20 AAC 25.300) - Submit hard and digital copies of all logs obtained drilling and completing the well. (as per 20 AAC 25.071 (6)) - Submit Core sample chips. (as per 20 AAC 25.071 (4) ) - Submit Core description and analysis (as per 20 AAC 25.071 (3)) - Submit Lithology log (as per 20 AAC 25.071(3)) - Submit inclination log (as per 20 AAC 25.050 (2)) Additional wells out of compliance as referenced in Attachment #1 — September 9, 2009 letter are: Wainwright # 1 (PTD 207 -065) - No hardcopies of open hole logs were submitted (as per 20 AAC 25.071 (6)) - No core chip samples submitted(as per 20 AAC 25.071 (4) ) - No core description submitted(as per 20 AAC 25.071 (3)) - No core analysis submitted(as per 20 AAC 25.071 (3)) - No header information on the .pdf digital graphics files submitted on dataset number T14024. (as per 20 AAC 25.071 (7)) Wainwright #2 (PTD 207 -106) - No washed and dried samples submitted (as per 20 AAC 25.071 (2)) - No lithology / sample log submitted as per 20 AAC 25.071 gY p g ( (1)) ()) - No core chips submitted(as per 20 AAC 25.071 (4) ) - No core description submitted(as per 20 AAC 25.071 (3)) - No core analysis submitted(as per 20 AAC 25.071 (3)) - No header information on the .pdf digital graphics files submitted on dataset number T14024 (as per 20 AAC 25.071 (7)) - No directional survey submitted. (as per 20 AAC 25.050 (2)) Franklin Bluffs 1 (PTD 20-7=k96) S — 1 5 No mud logs submitted. (as per 20 AAC 25.071 (1)) - No dry samples submitted (as per 20 AAC 25.071 (2)) - No as -built submitted (as per 20 AAC 25.070(2)) - No core analysis submitted(as per 20 AAC 25.071 (3)) - No core description submitted(as per 20 AAC 25.071 (3)) - No open hole logs submitted (hardcopy nor digital) (as per 20 AAC 25.071 (6)) DOI -04 1A (PTD 29„7.4106) U — o1 g - No mud logs submitted. ( pe 20 AAC 25.071 (1)) - No dry samples submitted (as per 20 AAC 25.071 (2)) - No OH logs submitted (hardcopy nor digital data) (as per 20 AAC 25.071 (6)) - No core chip samples submitted(as per 20 AAC 25.071 (4) ) - No core analysis submitted(as per 20 AAC 25.071 (3)) - No core description submitted(as per 20 AAC 25.071 (3)) - Density and porosity data missing from submitted digital data. (407 states that those types of logs were run.) (as per 20 AAC 25.071 (6)) Within 40 days of the date of this letter, the AOGCC requests USGS provide written verification that the violations listed above have been rectified and that all Wainwright g operations are being conducted in compliance with AOGCC regulations. Upon receipt of p such verification, the AOGCC will consider this matter closed. Should the USGS fail to submit the required information the AOGCC will notice a public hearing on the Wainwright violations to determine, among other things, the reasons for noncompliance and whether non - compliance poses any threat to human health or the environment. If you have any questions regarding this request for information, please contact Guy Schwartz at 907 - 793 -1226 or guy.schwartz @alaska.gov. Sincerely, Daniel T. Seamount, Jr. Chair Encl. cc: Greg Noble, BLM 411* 1 F G t ; � - E i � � r � 1 i s� i )e ` � `\ r ` i i r / SEAN PARNELL, GOVERNOR _ - i i � r l . 2 t ,.j � [ ( `mo t � 4 i 1 t t \v � 1 ` f 1, ` ALASKA. S 1. K . OIL AND GA 333 W. 7th AVENUE, SUITE 100 CONSERVATION. COMMISSION � / PHONE E A A S 1 433 99501 -3539 FAX (907) 276 -7542 September 9, 2009 Art Clark, Supervisory Physical Scientist Gary Reimer, District Manager USGS CR RM WRD USGS, Anchorage District Office Box 25046, Denver Federal Center Mail Stop 939 4700 BLM Road Denver, CO 80225 -0046 Anchorage, AK 99507 Dear Mr. Messrs: The U.S. Geological Survey (USGS) has again failed to meet the Alaska Oil and Gas Conservation Commission's (Commission) regulatory requirements for exploratory coal bed methane wells drilled near Wainwright, Alaska. During the current drilling season, the USGS failed to file Sundry permit applications — required by 20 AAC 20.015, 20 AAC 25.280 and 20 AAC 25.110 — for the following operations: 1. repairing of monitor well Wainwright 6, 2. plugging and abandoning of well Wainwright 9, and 3. plugging and abandoning of well Wainwright 10. The USGS also failed to file, in a timely manner, weekly operations summaries for the current Wainwright exploratory drilling program. These summaries are authorized under 20 AAC 25.300. Alaska Statute 31.05.027 and Regulation 20 AAC 25.515 require Federal agencies to conform to the Commission's permitting and reporting requirements. Without permit applications in advance of well operations, it is not possible for the Commission to review proposed operations to ensure that they meet Alaska's statutory requirements to prevent waste, protect correlative rights, and improve ultimate recovery while protecting underground freshwater, health, safety and the environment. Without weekly operations summaries, the Commission cannot, in a timely manner, review actual well operations to ensure conformance with our requirements. The current failures reflect a continuing pattern of poor compliance by the USGS and the Bureau of Land Management (BLM) over the past five years. On May 23, 2008, the Commission issued Conservation Order No. 600 (CO 600), which found that the BLM had drilled the Wainwright No. 2 exploratory coal bed methane well before the Commission received or approved a Permit to Drill application for the well. This inaction drew the BLM and the USGS, the operator for the well, a rebuke from the Commission. CO 600 also concluded that the BLM and the USGS had not submitted all information required for the Wainwright No. 1 and No. 2 exploratory wells. CO 600 ordered BLM and the USGS to submit, by June 23, 2008, the reports and information required by 20 AAC 25.070 and 20 AAC 25.071. Attachment 1 presents the continued reporting deficiencies for Wainwright No. 1 and Wainwright No. 2 along with reporting deficiencies for the Franklin Bluffs No. 1 and DOI -04 No. 1A exploratory wells that were drilled about five years ago. eip U.S. Geological Survey September 9, 2009 Page 2 of 3 If the USGS and BLM continue to fail to meet Alaska's statutory and regulatory requirements, the Commission will issue notice and convene a public hearing to address these matters further. OV Daniel T. Seamount, Jr. Chair Leslie Holland- Bartels, Regional Executive - Alaska Area USGS WR AA DO 4210 University Drive Anchorage, AK 99508 -4626 Anne Kinsinger, Western Regional Director USGS WR -- DO 909 1st Avenue, Suite 704, 7th Floor Seattle, WA 98104 -1055 Peter Lyttle, Acting Associate Director for Geology USGS HQ -- GD 12201 Sunrise Valley Drive, Mail Stop 911 Reston, VA 20192 -0002 Thomas P. Lonnie, State Director Bureau of Land Management Alaska State Office 222 W 7th Avenue #13 Anchorage, Alaska 99513 Public Room: 907 -271 -5960 Bob Abbey, Director BLM Washington Office 1849 C Street NW, Rm. 5665 Washington DC 20240 410 U.S. Geological Survey September 9, 2009 Page 3 of 3 Attachment 1 Continued Reporting Deficiencies for BLM and USGS Wells Wainwright I No hardcopies of open hole logs were submitted (PTD 207 -065) No core chip samples submitted No core description submitted No core analysis submitted No header information on the .pdf digital graphics files submitted on dataset number T14024. Wainwright 2 No washed and dried samples submitted (PTD 207 -106) No lithology / sample log submitted (hard copy nor digital) No core chips submitted No core description submitted No core analysis submitted No header information on the .pdf digital graphics files submitted on dataset number T14024 No directional survey submitted (hardcopy nor digital) Franklin Bluffs 1 No mud logs submitted (hardcopy nor digital data) (PTD 205 -105) No dry samples submitted No as -built submitted Core cut and was apparently directly sent to Alaska Geological Materials Center No core analysis submitted No core description submitted No open hole logs submitted (hardcopy nor digital) D0I -04 IA No mud logs submitted (hardcopy nor digital data) (PTD 204 -083) No dry samples submitted No open hole logs submitted (hardcopy nor digital data) No core chip samples submitted No core analysis submitted No core description submitted Density and porosity data missing from submitted digital data. (407 states that those types of logs were run.) DOI -041A Well Decommission Daily Logs Saturday May 7, 2005: Drill personnel fly from Fairbanks to Fort Yukon. Plug in heat trace to thaw well. Remove pressure transducers. Position drill rig over well. Sunday 5/8/05: Call AOGCC and give well closure 24 hour notice. Run temperature log in well and collect water samples. Monday 5/9/05: John Spaulding from AOGCC arrives. Bail water from well and abandon well using bentonite pellets and neat cement per Spaulding's guidance. Tuesday 5/10/05: Cut surface casing below land surface and weld information cap onto casing per Spaulding W `ari.. p t a off n l 1 „ + natural 1 h:, �a ., l' ►:,�.,� and s� signs off on - well. Fill have with ra�..r. -1 material and conduct final reclamation. Pack equipment and return to Fairbanks. RECEIVED DEL 1 1 2007 Alaska Cis& Gas Cons. Commission final ahem RECEIVED • , ...?9 ,, ...?9 , 07 STATE OF ALASKA ,. ..?9 ,07 7 ALASKA OIL AND GAS CONSERVATION COMM 'SION OCT 2 5 2007 WELL COMPLETION OR RECOMPLETION REPORT Commission 1a. Well Status: Oil ❑ Gas ❑ Plugged 0 Abandoned 0 Suspended El 1b. Well Class: Anr 20AAC 25.105 20AAC 25110 Development ❑ xp o tory 0 GINJ ❑ WINJ ❑ WDSPL WAG ❑ Other❑ No. of Completions: 0 Service ❑ Stratigraphic Test III 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Numb Dept. of the Interior - BLM Aband.: 5/9/2005 204083 3. Address: 6. Date Spudded: 13. API Number: 6881 Abbott Loop Rd 8/22/2004 50- 091 -20001 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: Fairbanks Meridian, T2ON R12E Sec 16 SW, NW September 3, 2004 DOI -04 -1A Top of Productive Horizon: 8. KB (ft above MSL): 31 15. Field /Pool(s): Horizons not formally named. Tertiary coal. Ground (ft MSL): N/A Total Depth: 9. Plug Back Depth(MD +TVD): 2287 Feet 2287 - 1314' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: , Surface: x- 615649 y- 4591281 Zone- 3 2287 Feet Air Force, Fort Yukon TPI: x- y- Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 615649 y- 4591281 Zone- 3 N/A FG5020- 04170 -0511 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 300 Feet 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Density, Resistivity, Sonic, Porosity, gamma 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 8 5/8 24.7 Surface 93 Feet 10 3/4" 23. Open to production or injection? Yes ❑ No ❑ If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 6 3/4 " open hole from 1270' - 1314'. 2.5" PVC 1270' 1265' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 27. CORE DATA Conventional Core(s) Acquired? Yes 0 No ❑ Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 0 - 93' Gravel, cobble, boulders; 93' - 925' clay, silt, sand interbeds; 925' - 1253: sand, soft, fluidized; 1253' - 1325' coal; 1325: - 1900' sand, clay interbeds; 1900' - 1925' coal; 1925' - 2273' sand, clay, silt, conglomerate interbeds.OMi'LF7(ONT1 ' 1 ;1.. BR APR `. II 2004 , mo o Form 10 -407 Revised 2/2007 0 R 1 G 1 N A1 ON REVERSE 41f t-°S �j • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD _ Well tested? Yes ', No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top: 0 Feet 0 Feet and submit detailed test information per 20 AAC 25.071. Permafrost - Base: 300 Feet 300 Feet Horizons not formally named. Clay, silt, sand interbeds 93 Feet 93 Feet Sand 925 Feet 925 Feet Tertiary Coal 1253 Feet 1253 Feet Sand, Clay Interbeds 1325 Feet 1325 Feet Coal 1900 Feet 1900 Feet Sand, Clay, Silt, Conglomerate interb 1925 Feet 1925 Feet Formation at total depth: 2287 Feet 2287 Feet Horizons not formally named. Conglomerate. 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Elizabeth Maclean Title: Geologist —Iiiii , Signature: T t OPhone: 907 - 271 -1985 Date: 10/24/2007 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for,separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the • producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • • Saturday May 7, 2005: Drill personnel fly from Fairbanks to Fort Yukon. Plug in heat trace to thaw well. Remove pressure transducers. Position drill rig over well. Sunday 5/8/05: Call AOGCC and give well closure 24 hour notice. Run temperature log in well and collect water samples. Monday 5/9/05: John Spaulding from AOGCC arrives. Bail water from well and abandon well using bentonite pellets and neat cement per Spaulding's guidance. Tuesday 5/10/05: Cut surface casing below land surface and weld information cap onto casing per Spaulding who takes photos and signs off on well. Fill hole with natural material and conduct final reclamation. Pack equipment and return to Fairbanks. uc� uniy 2 -51.11 50-86-0226 482 USS 7161 N/A Cert USS 7161 ,' USS 7161 D/C 21 -5.92 I l / 9 -54.37 USS 7161 - 6- 159.98 8 -39.99 SSE Only 3 -5.60 uss 7161 EE SUPPLEMENTAL PLAT 50- 2007 -0574 ` 7 -49.98 50 -86 -0249 / 079 0 1 50- 2007 -0573 50 -87 -0183 1 -4 83 F93344 —FY N/A Cert R/A Cert SSE Esmt N/A Cert Reg /E /ec o/c oG — D/C 06 OG Only 352.67 F93344 —FY 4-376.11 Reg/E1ec 7 8 USS 7161 9 10 OG Only 17 -51.34 USS 7161 SEE SUPPLEMENTAL PLAT F93344 —FY 11- 160.00 Reg N 0 2 /E/ec OG Only 50 -86 -0560 r 50-94-0021 N/A Cert r N/A Cert D/C OG D/C OG USS 7 1- 470.58 2- 489.60 � 1 -63.57 12 -15' USS 7161 r FFIJ f E SUPPLEMENTAL PLAT SE PLAT / ` r r �r�r 27 -94.48 I r / �J I ?, 1 .. l • - • PLO 1396 ' I' i- V I< l6 / i pjor / USS 7161 Wd/ AO Purp 18 17 25 -7544 t • 16 15 -r r r r • . ``eIf 11 FF94599 pp 3 -0.31 4 6� -..� tp � � OCD from USAF �/ t' � d/= s .0 /' r' .� r Fl ,. f ., Lam! SSE Only i ` : vve j , c ein J ,. , l � _ 50- 2007 -0 ,yr' ° 2 ___ 5.0 - 2607 - 0573 0 T 1 1 ' S 41 , r ` 21.99 L SSE Esmt '..r r 1- 130.72 r r r j 552.62 442 I I ' I -, J _ .1 _r r r rf SSE Only f r _r r r r _rsr 50- 2007 -0574 r r r 1 - 50-2007-0573 SEE SUPPLEMENTAL PLAT SEE SUPPLEMENTAL PLAT r SSE Esrnt NO 5 NO 5 r r ,...r ,.. DATA SUBMITTAL CON PLUANCE REPORT wimair Permit to Drill 2040830 Well Name/No. D01-04 1A Operator U S DEPT OF INTERIOR API No. 50 -091- 20001 -00 -00 I MD TVD Completion Date Completion Status Current Status PEND UIC N REQUIRED INFORMATION Mud Log Yes Samples —We v Q, ; Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval 011 / lir Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED Las 12965 Gamma Ray 372 2092 Open 3/8/2005 GR Caliper ED Las 12966 Induction /Resistivity 3 2288 Open 3/8/2005 GR, Temp, Res(16N), Res(64N), Del Temp, Res Lateral Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cores and /or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 6/1/2004. ADDITIONAL INFORMATION ` �, y c (� r bt.joju -- Well Cored? 0Y N Daily History Received? Chips Received? Y C. Formation Tops 6 N Analysis Y t IIII Received? — c UV a.. �v ka-vi. A -Q (GC- L,1tra4-1.e °s 0 Comments: Air s K oL. / u 7 /i v i t Lv 2 c i, .-, ,,. 4 , ‘ , 3 4 .ti. 0 AktV) . _ ► . _ _ Compliance Reviewed Date: Ah a, ., ) ,�� A I C l��.., I v r 4 Rt jd'kC.a ctarvi L. j 4 k 3 C ✓ f,...+. r ) :' 1,i ON Sy f a 1 Subject: Well Completion Report Needed for Well DOI -04 1A From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Thu, 09 Nov 2006 14:40:38 -0900 To: Beth.Maclean@mms.gov CC: Bob.Fisk@mms.gov Beth and Bob, During review of the well history file for DOI -04 1A, I noticed that a final Well Completion Report ( AOGCC form 10 -407) has not been filed for this well. The Application for Sundry Approval to plug and abandon the well was approved by AOGCC on May 5, 2005. The "Conditions of approval" section on this application notes that a 10 -407 form is required. Please also provide a history of operations for the plugging and abandonment of the well along with a final well completion diagram. Thanks for your help, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission 907 - 793 -1224 Steve Davies RE: Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 1 Subject: RE: Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 From: "Shearer, Gerald" <Gerald.Shearer @mms.gov> Date: Thu, 09 Feb 2006 12:52:09 -0700 To: Stephen Davies < steve_davies @admin.state.ak.us> CC: "Maclean, Beth" <Beth.Maclean@mms.gov >, "Fisk, Bob" <Bob.Fisk@mms.gov> Steve, In response to your question, below, concerning samples and geologic descriptions I have compiled the following progress report. Jim Clough and others are compiling and interpreting information on the Fort Yukon Well. I asked Jim to summarize the current status and projected completion. That summary follows. Art Banet and I, along with Jesse White, (a DGGS intern) described the core from the 2004 slim -hole coring conducted at Fort Yukon by the U.S. Geological Survey, U.S. Bureau of Land Management - Alaska and Division of Geological & Geophysical Surveys. At the time of our description of the core it was stored at the U.S. Geological Survey's storage warehouse in Anchorage, Alaska. There is about 650 feet of core that was retrieved from the 2004 core drilling. Additionally, cuttings were collected from about 330 feet of non - coring rotary drilling. We described the core and took some photographs of intervals that were of interest geologically. There is also a set of photographs of most (or all) of the entire core boxes that can be provided. Most core box photos were taken on site after the core was retrieved and the core is still wet and covered with drilling mud. Our descriptions were compiled into an Excel spreadsheet and some thin sections were also cut from samples that were collected from the core. These include some grain mounts from cuttings. We are working on a final paper that will provide lithologic description and depositional setting for the 2004 core. The spreadsheet descriptions, the photographs and the thin sections will be part of the permanent record to accompany the core. please call me if you have any questions. Regards, Jim Clough The cores for the Fort Yukon well are still stored at the USGS storage warehouse in Anchorage. The instructions are to turn them over in their entirety to the State materials facility in Eagle River 2 years after the completion of the well. I talked to Beth Maclean with BLM and she said that if you prefer, we could transport the core to the Eagle River facility at an earlier data with the provision that it be held proprietary until the 2 years expire. As for the Franklin Bluffs Well, the cores are currently stored at the State materials center in Eagle River, to be made available to the public 2 years after completion. Beth Maclean is asking the USGS what type of studies and description will be performed on materials from the Franklin Bluffs Well. When we receive a response, I will forward that on to you. With this email in each of your well files, a reader would know know about the disposition of the cores and who to contact to acquire any preliminary geologic information before the final reports are published. Does this approach adequately satisfy AOGCC's regulatory requirements? Thanks for your assistance. Gerald Shearer From: Stephen Davies E mailto: steve_davies ©admin.state.ak.us] Sent: Thursday, January 19, 2006 8:10 AM To: Shearer, Gerald Subject: Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 /( �rrtiGG KeIJ more. 1 of 2 7/10/2006 9:07 AM i•/0.0‘. RE: Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 Gerry, • • In addition to the location information discussed in the attached email, I also noticed that core chips have not been submitted for Franklin Bluffs #1 or DOI - 04 #1A (in the Yukon Flats Basin). State regulation 20 AAC 25.071 (available on AOGCC's web site at www.aogcc.alaska.gov) requires a chip of either one cubic inch volume or two ounces weight taken from, and representative of, each foot of recovered conventional core. These chips must be provided in paper sample envelopes that are clearly marked with well name and footage. Along with the chips, the Commission also requires a lithologic description, results of laboratory analysis and, if available, photographs of each core. The descriptions must include apparent textural, fluid and lithologic variations (such as rock type, porosity, fractures, bedding plane attributes, sedimentary structures, grain size and the presence of hydrocarbons). 2 of 2 7/10/2006 9:07 AM Additional Information Needed: Franklin Bluffs 1 and D0I -04 #1 (r _ 663 Subject: Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 From: Stephen Davies < steve_davies @admin.state.ak.us> Date: Thu, 19 Jan 2006 08:10:20 -0900 To: Gerald.Shearer @mms.gov Gerry, In addition to the location information discussed in the attached email, I also noticed that core chips have not been submitted for Franklin Bluffs #1 or DOI -04 #1A (in the Yukon Flats Basin). State regulation 20 AAC 25.071 (available on AOGCC's web site at www.aogcc.alaska.gov) requires a chip of either one cubic inch volume or two ounces weight taken from, and representative of, each foot of recovered conventional core. These chips must be provided in paper sample envelopes that are clearly marked with well name and footage. Along with the chips, the Commission also requires a lithologic description, results of laboratory analysis and, if available, photographs of each core. The descriptions must include apparent textural, fluid and lithologic variations (such as rock type, porosity, fractures, bedding plane attributes, sedimentary structures, grain size and the presence of hydrocarbons). Can you provide these or would Bob Fisk be a better point of contact? Thanks, Steve Davies AOGCC Original Message Subject:Re: [Fwd: Re: Franklin Bluffs - 1 Information] Date:Wed, 18 Jan 2006 12:24:38 -0900 From:Stephen Davies <steve davies@admin.state.ak.us> Organization:State of Alaska To:Shearer, Gerald <Gerald.Shearer@mms.gov> References: <E86649C48448E845A 1 C 15D35B2C75B6AAAEE3E@ IMSDEXPRI01 .service.agency.mms.pri> Gerry, In reviewing the Franklin Bluffs 1 well history file, I'm still confused by the different coordinates listed for this well. Could you help me resolve this? I noticed again that the surface location of the well on the latest Well Completion Report that you submitted on November 30, 2005 is 1,777' FNL and 1,362' FEL, Section 9, T4N, R14E, Umiat Meridian. On the approved permit to drill issued by the Commission, the surface location coordinates are listed as 2,012' FNL and 1,694' FEL, Section 9, T4N, R14E, Umiat Meridian. I need to ensure the Commission's records are accurate. We need the final footage coordinates for the surface and bottom hole location of the well measured from section corners for the surface location along with corresponding coordinates in Alaska State Base Plane, Zone 4, NAD 27. If the actual surface location of the well is different from that permitted by the Commission, I will also need letter of explanation because, under current regulations, any change is surface location from that permitted requires a new application for a permit to drill. Thanks for helping us clear this up. Steve Davies AOGCC 793 -1224 1 of 2 1/30/2006 8:13 AM Additional Information Needed: Franklin Bluffs 1 and DOI -04 #1 Shearer, Gerald wrote: I dropped of f a new packet with your secretary which contained the changes and information you requested. However, in getting the necessary signatures and getting it all put together the most important part of the package was left out — the final well diagram. I am going to drop it off at your office now, but I thought I would send you a digital copy also. 2 of 2 1/30/2006 8:13 AM • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6 0 DATE: May 10, 2005 P. I. Supervisor FROM: John Spaulding, SUBJECT: Plug & Abandonment Petroleum Inspector DOI -04 -1A Ft. Yukon, AK PTD: 204 -083 May 10, 2005: I traveled to Ft. Yukon via Fairbanks to witness the Plug and ✓ Abandonment on the USGS coal bed methane appraisal well. The original wellbore was drilled in 1994. The well was reentered in 2004 and deepened to 2287' tvd. Several layers of coal were encountered none of which showed any possibilities of production. Please note the enclosed well completion diagram for down hole P &A. Cement was pumped into the 2.5" pvc pipe from TD to surface. The casing was then cut 3' below grade and capped with a steel plate with the well nomenclature bead welded in place. The well was then covered and the US Air Force noted that the area will reseed with native grasses later summer. Attachments: well completion diagram and photos NON - CONFIDENTIAL • • DOI -04 -1 (USGS) Surface Aban donment Inspection Photos from John Spaulding, AOGCC May 10, 2005 T i i i USGS rig used • � shallow CBM drilling .„: f't , . . § . Casing c ut; benton .,_,..,,.,..: _ ,„ . ,,,.„,... :.- lipo e4 ' .,„ - ,,,- T - -;,. - 0-, - 1 r. -- .0 oft � a� hips in annulus pellets /c -, -,-,f.,,, '--, - - ix ,,,.., _ c. ��•�{ for abandonment plug A . 4 xa 6 ° 11.111PWIMMIPMPRIllir 0 �— Mixing cement for - surface plug a 2005 -0510 P8�A _D01-04 -1A Ft Yukon.doc 2 M 4 N C�/7 O cci 0 cA M O O cd tO N E 0 0 C • O 7 I 3 v fi �" 4 ti t em 7a � a 1 ., r F m ' a "'1,,,,.. cu ��, i • ,3 a p °..,, " � a + 0 r a r s r t r art �' f . w , s .r +� cA x . :, ' t , of v + ` X s.� Csi • ,«. 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OIL AND GAS 333 W. 7"' AVENUE, SUITE 100 CONSERVATION COMMISSION 1 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Elizabeth Maclean Geologist Department of Interior, BLM 6881 Abbott Loop Road Anchorage, Alaska Re: DOI-041A Sundry Number: 305 -113 Dear Ms. Maclean: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty -four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd ■ - following the date of this letter, or the next working day if the 23rd day falls on . olid. y or weekend. A person may not appeal a Commission decision to Superio • Court less rehearing has been requested. 1 0. .c- Ch.'is DATED this‘day of May, 2005 Encl. STATE OF ALASKA Cf3' S -c" —DC ALGA OIL AND GAS CONSERVATION COM IORECEIVEDPT APPLICATION FOR SUNDRY APP VAL _5' 20 AAC 25.280 APR 2 9 2005 S 1. Type'of Request: Abandon • Suspend U Operational shutdown L] Perforate U (n�'''' �jaaS� Waiver I Other U+ Alter casing ❑ Repair well ❑ Plug Perforations ❑ StimuI t 0 r gAi n° 0fi1ti11SSI0P ee nrC�hh LI Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Susp2rlg88 Went] 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Dept. of the Interior, BLM Development ❑ Exploratory ❑ 204 -083 3. Address: Stratigraphic Ei / Service ❑ 6. API Number: 6881 Abbott Loop Road 50- 091 -20001 V 7. KB Elevation (ft): 9. Well Name and Number: 31' DOI -04 -1A / 8. Property Designation: 10. Field /Pools(s): Air Force, Fort Yukon, Alaska. N/A 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 'Total Depth TVD (ft): 'Effective Depth MD (ft): 'Effective Depth TVD (ft): 'Plugs (measured): 'Junk (measured): 2287 12287 1 12287 12287 'NONE I NON E Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 93 Feet 8 5/8 93 Feet 93 Feet N/A N/A Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6 3/4" open hole from 12( V3 6 3/4" open hole from 1270'-131z 2.5" PVC N/A 1270' Packers and SSSV Type: / 2.5" x 6 3/4" formation packer. Packers and SSSV MD (ft): 1265' I r 12. Attachments: Description Summary of Proposal U 13. Well Class afte r proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: / Commencing Operations: 5/10/2005 Oil ❑ Gas ❑ Plugged 0 Abandoned Ei 16. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact BLM Printed Name Elizabeth Maclean Title Geoiogist Signature — ignature titiOgrItU Phone 907- 267 -1448 Date 4/28/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305 a 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance M Other: Pe 7A A-A L 25.112-(1 i &j f e.,. - e_ w- t 1 p,u 7 r u . A r tip: e LA t,.t 1 S ) P ( 1 . .e cl . RBDMS BFI MAY 0 9 200 Subsequent F. :equir-c/ 4 0 ' APPROVED BY /� �� „-- Approve.: � ` /� ' COMMISSIONER THE COMMISSION Date: %. Form 10-403 Revised 11/2004 ORIGINAL Submit in Duplicate • Description Summary of Well Closure Proposal At the completion of drilling and coring operations in September 2004, well DOI -04 -1A was sealed through all hydrocarbon and water - bearing zones, using high- solids abandonment bentonite grout, specifically designed for this purpose, using the displacement method by pumping the slurry from the bottom of the borehole through 3.5" diameter core rods. The only exception is a ten -foot zone, from 1295' -1305' below land surface (bls), in the upper lignite (1257' -1315' bls) that has been isolated using bentonite grout, bentonite pellets, and rubber formation packers, gravel- packed with washed and sorted Yukon River gravel, monitored through a 2.5" schedule 80 PVC well set to collect hydraulic conductivity /transmissivity and water - quality data, and instrumented with a pressure transducer to test formation pressure fluctuations during the winter months (see attached diagram #1). In May 2005, two heat traces that were placed in the upper 350' of the monitor well will be plugged in and used to thaw ice that has formed in the permafrost zone (approximately 0' -300' bls), the pressure transducer removed, a temperature log run, and a water sample taken. At that point, a combination of bentonite pellets and bentonite chip will be tremied into the monitor well using 1.5" diameter pipe from the top of the gravel pack (1295' bls) to 150' bls. A cement plug will be place in the top 150' of the monitor well and all PVC and steel pipe cut to 3' bls (see attached diagram #2). A steel marker plate will be welded onto to the cut pipe and the whole thing buried and reclaimed. Sundry for DOI -04 -1 A • Subject Sundry for D01-04-1A From: Beth Macleana ak.blm,gov Date: Thu, 05 May 2005 11:58:47 -080(} To: Winton Aubert <viiintori aub aateJ CC: Robert P Crandall ob �4dI a hate us A s � - n seal a � gin? � . .... fi HowardD Okland <howard oktand ^ .te.ak u , lama gg u °ryB Re re a . aclark us v bark ry. , " Bob Fisk _ � v : i r�a,, Pie %`vzs : g Winton, Here is the revised Fort Yukon Well Completion document with the corrections that we talked about earlier this week. I've also included the Sundry and the well diagram again. I talked to John Spalding today about going up to witness the plugging. I called Art Clark and left a message that included John's contact numbers so Art can give John enough advance notice before going up to Fort Yukon. Beth (See attached file: DOI -04 -1A 10- 403.xls)(See attached file: Ft Yukon well completion.doc)(See attached file: Ft Yukon completion.ppt) ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 -1304 Content - Type: application/msexcel DOI -04 -1A 10- 403.xls Content- Encoding: base64 Content - Type: application/msword Ft Yukon well completion.doc Content - Encoding: base64 Content - Type: application/vnd.ms - powerpoint Ft Yukon completion.ppt Content - Encoding: base64 DOI -04 -A1 11P Subject: 001-04-Al From: Winton Aubert <winton aubert admin ,.state.ak.us> Date: Tue, 26 Apr 2005 14:21:31 -0800 . .... .. .:= :.:::.:arm <:,�, z k'A;x' §:. -.F -K•.. f.r :; s3 :, =i; .a:: ,.,.`u. T+. Del I�Ilcla a �� .:. . _'ifs: . ; .. v # .�. q .. CC: Ja B'Ft -< im °�r irt, tel< �ki ,gObert• : ra ral i ,* .: _ bQ crandaliCgadmin: its akt ; Howaird D •O a nd ,.>r :• ed_�. min. `ik is ;m thn : �, f Searncurlit " G � n4 s i # a W °S:X -. k , . r .. - Beth, Alaska wells must be abandoned per 20 AAC 25 Article 2. An Application for Sundry Approvals (Form 10 -403) must be submitted to and approved by the AOGCC prior to beginning well abandonment. Details of proposed abandonment procedure must be included as support documentation for Form 10 -403. AOGCC forms, regulations, and other information are available at www.aoqcc.alaska.gov. Thank you for your attention to this matter. Winton Aubert AOGCC 907 793 -1231 Well Diagram - DOI -04 -A1 S Subject: Well Diagram - DOI -04 -A I From: Beth Maclean@ak.blm.gov Date: Tue, 26 Apr 2005 13:40:04 -0800 To: howard oldand@u admin.state.ak,us Howard, Attached is the well diagram for both it's current state and it's plugged state. I just heard from Art Clark today that he is planning on doing the plugging May 10 -11. Please let me know if you will be sending someone up to Fort Yukon to witness this as they may need permission to be on the Air Force Site. Beth (See attached file: Ft Yukon completion.ppt) ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907- 267 -1448 Fax: 907 - 267 -1304 Content -Type: application/vnd.ms- powerpoint Ft Yukon completion.ppt Content - Encoding: base64 Re: Well Bore diagram Of DOI -04 -1A • i Subject: Re: Well Bore diagram Of DOT -04 -1A From: Betb_Maelean@ak.blm.gov Date: Thu, 14 Apr 2005 09:50:33 -0800 To: Howard Okland <howard_okland a t n.state.ak.us Howard, I'm working with Art Clark to get not only the Well Bore Diagram but a firm date for abandoning the well. I will let you know as soon as I get that date so AOGCC has enough time to make travel plans to Fort Yukon. Jim Clough with AK DGGS is going to do the core description and take samples. I'll contact him for an update. Beth ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 - 1304 Howard Okland <howard_okland @ad min.state.ak.us> To Beth Maclean @ak.blm.gov 04/14/2005 08:17 cc AM Subject Well Bore diagram Of DOI -04 -1A Beth, Had your coffee yet? Have received the Completion report. TNX. We are still missing a "wellbore diagram" indicating the configuration of the well as of the date of the completion report. How is the core analysis going? Please inform the Commission when you have "firmed up" the plans for abandoning the well as one of our inspectors will need to witness it. Once the well is abandoned, we will need a Completion report of that event as well as a Borehole diagram of the abandoned well. TNX Howard STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMIS. RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG g 2005 la. Well Status: Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended ❑ WAG ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development Alaska OIIEoaploo3toxy'! . :OIY missI0r1 GINJ❑ WINJ❑ WDSPL❑ No. of Completions Other Observation Service ❑ StratigrapAin 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Dept. of the Interior, BLM Aband.: 204 -083 3. Address: 6. Date Spudded: 13. API Number: 6881 Abbott Loop Road August 22, 2004 50- 091 -20001 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: Fairbanks Meridian, T2ON R12E Sec 16 SW, NW September 3, 2004 DOI -04 -1A Top of Productive Horizon: 8. KB Elevation (ft): 15. Field /Pool(s): Horizons not formally named. Tertiary coal. 31 N/A Total Depth: 9. Plug Back Depth(MD +TVD): 2287 Feet 2287' - 1314' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 615649 y- 4591281 Zone- 3 2287' Air Force, Fort Yukon TPI: x- y- Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 615649 y- 4591281 Zone- 3 FG5020- 04170 -0511 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 300 Feet 21. Logs Run: Gamma, Caliper, Resistivity. Tried to run Density but the data was garbled and non - reproducible. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 8 5/8 24.7 Surface 93 Feet 10 3/4 " 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) 6 3/4 " open hole from 1270' - 1314'. 2.5" PVC 1270' 1265' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period .O Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate — 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none ". 0 - 93' Gravel, cobble, boulders; 93' - 925' silt, clay, sand interbeds; 925' - 1253' sand, soft, fluidized; 1253' - 1325' coal; 1325' - 1900' sand, clay interbeds; 1900' - 1925' coal; 1925' - 2273' sand, clay, silt, conglomerate interbeds. UVO6INAL Form 10 -407 Revised 12/2003 CONTINUED ON REVERSE C 28. GEOLOGIC MARKER 29. FORMATION TESTS NAME M TVD Include and briefly sui ze test results. List intervals tested, and attach detailed supporting dat as necessary. If no tests were conducted, state "None ". NONE 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: i t �� Title: �� j T' - r Signature: -- a:kt Phone: 2_(0 - (Lt ik Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: If no cores taken, indicate "none ". Item 29: List all test information. If none, state "None ". Form 10 -407 Revised 12/2003 001 - 04 - 1A Well Completion Diagram, Fort Yukon, Alaska 10 3 /4" casing to 63' ► cement bentonite abandonment grout 8 5/8" casing to 93' ■ bentonite pellets /chip 410 gravel pack 2.5" PVC water monitor casing ■ lignite € € € € € € € € €? iii?i€ iii': i`: €iiisi • €isisi ' : • s € € € € €;; € ii 2.5 x 6 3/4 formation packers € :1257 1315 ravel ack from 1295 1305' €€ Lignite g p 6 3 /4" drill hole diameter ■ ••••••••••........... •::::::::::::::::::::*- - - - - - - -::""•"•,".E.E.:• 11 '- : : x :::::: .' :::::::::::::''''''':::' ::::::::::::: :: :: :.:::::::::::: -1920 ................:.:.:.:.:.:.:.:.:.:.:.:.:::.:.:.:.:.:.:.:::............:::::.:.:.: :.: .:.:::.:.:.:.:.:.:.::::::::: ,..- Li Hite. 1900 T.D. 2287' DOI -04 -A 1 • Subject: DOI-04AI From: Beth_Maclean ak.b1m.gov Date: Tue, 05 Apr 2005 12:55:15 -0800 To: :haward n.state.ak.us CC: aclarkkusgs.gov; barker@usgs.gov Howard, I received your voice mail today, I am in training all week. I emailed Art Clark about the Density logs and the the formation testing. I found out that we attempted to run a density log but that we got garbled, non - reproduceable data and therefore no log is available. We didn't test the formation due to borehole well seal failure. I will make those corrections to the 10 -407, sign it and fax it over to you today. I will also send a hard copy in the mail. Beth ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 -1304 I I II APR -05 -2005 TUE 02:29 PM P.NERGY & MINERALS FAX N0. 9067 1304 P. 01 "`"" ' United States Department of the Interior i . z"` f $ BUREAU OF LAND MANAGEMENT d BRANCH OF ENERGY 6881 ABBOTT LOOP ROAD RECEIVED ANCHORAGE, ALASKA 99507 -2599 APR - 5 2005 FAX from AlilisOiltGatOsiGsvishil Anchoillit DIVISION OF ENERGY AND SOLID MINERALS BRANCH OF ENERGY Telephone Number: (907) 267 -1246 MAIN FAX Number: (907) 267 -1304 DATE: 4/5/05 TO: Howard Okland FAX 276 -7542 SUBJECT: DOI -04 -A1 Form 10-407 FROM: Beth Maclean COMMENTS: — Number of Pages (including cover page): 3 ORIGINAL DOCUMENT TO FOLLOW IN THE MAIL: X YES NO If you have any questions or if this FAX is received incomplete, please call 907 - 267 -1448. t APR -05 -2005 TUE 02:29 PM B NERGY & MINERALS FAX NO. 907 7 1304 * , STATE OF ALASKA +b./ ALASKA OIL AND GAS CONSERVATION COMMISSION 14Pir v . WELL COMPLETION OR RECOMPLETION REPORT A • 4 y �' 1a. Well Status: Oil • Gas • Plugged • Abandoned • Suspended • WAG • 1 b. Well Class: r-, 20AAC 25.105 20AAC 25.110 Development ❑ Explo 4 'j GINJ ❑ WINJ ❑ WDSPL❑ No. of Completions Other Observation Service © Stratigraphic Test r 2. Operator Name: 5. Date Comp„ Susp., or 12. Permit to Drill Number: Dept. of the Interior, BLM Abend.: 204 -083 . 3. Address: 5. Date Spudded: 13, API Number: 6881 Abbott Loop Road August 22, 2004 50-091 -20001 4a. Location of Well (Governmental Section): 7, Date TD Reached: 14. Well Name and Number: Surface: Fairbanks Meridian, T2ON R12E Sec 16 SW, NW September 3, 2004 DOI -04 -1A Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): horizons riot formally named. Tertiary coal. 31 N/A Total Depth: 9. Plug Back Depth(MD +TVD): 2287 Feet 2287' -1314' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 615649 y- 4591281 Zone• 3 2287' Air Force, Fort Yukon TPI: X- y Zone- 11. Depth Where SSSV Set 17. Land Use Permit: Total Depth: x- 615649 y 4591281 Zone- 3 FG5020- 04170.0511 18. Directional Survey: Yes ❑ No Q 19. Water Depth, If Offshore: 20. Thickness of Permafrost: N/A feet MSL 300 Feet 21, Logs Run: Gamma, Caliper, Resistivity. Tried to run Density but the data was garbled and non- reproducible. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING F) GRADE TOP BOTTOM - TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 8 5/8 24.7 Surface 93 Feet 10 3/4 ° 23. Perforations open to Production (MD + TVD of Top and Bottom 24, TUBING RECORD Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) 63/4 " open hole from 1270' - 1314'. 2.5" PVC 1270' 1265' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26, PRODUCTION TEST Date First Production; ' Method of Operation (Flowing, gas lift, etc.); N/A Date of Test: Hours Tested: Production for ' 011d3b1: - Gas•MCF: - Water -Bbl: Choke Size: Gas-0111140: Test Period .,} . Flow Tubing Casing Press: Calculated Oil -Bbl Gas -MCF: Water-Bbl: Oil Gravity • API (corr): Press. 24 -Hour Rate .-41- 27. CORE DATA - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, H necessary). Submit core chips; if none, state "none ". 0 - 93' Gravel, cobble, boulders; 93' - 925' silt, clay, sand interbeds; 925' - 1253' sand, soft, fluidized; 1253' • 1325' coal; 1325' - 1900' sand, clay interbeds; 1900' - 1925' coal; 1925' - 2273' sand, clay, silt, conglomerate interbeds. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE APR -05 -2005 TUE 02:29 PM NERGY & MINERALS FAX NO. 907 67 1304 P, 03 28. GEOLOGIC MARKERS 29. ORMATION TESTS ---� NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None ". NONE 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: FRAL R ,Qi3_Jk. Title: C 5 Signature: ,� 1. J f Phone: Date: 4 5 b INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10.407 well completion report and 10-404 well sundry report when the downhale well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion, Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex, 50-029-20123-00-00). Item 20: True vertical thickness. 11em 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool, Item 23: if this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible. Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: If no cores taken, indicate "none ". Item 29: Ust all test information. If none, state "None ". Form 10 -407 Revised 12/2003 STATE OF ALASKA ALASKAOAND GAS CONSERVATION COMMIS WELL COMPLETION OR RECOMPLETION REPORT ANCRkgEIVED 1a. Well Status: Oil Gas ❑ Plugged ❑ Abandoned ❑ Suspended ❑ WAG ❑ 1 b. Well Class: MART 5 a c 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory � Lj GINJ❑ WINJ❑ WDSPL❑ No. of Completions Other Observation Service ❑ AIaSIatet16143TJC01Ymission 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Anchorage Dept. of the Interior, BLM Aband.: 204 -083 3. Address: 6. Date Spudded: 13. API Number: 6881 Abbott Loop Road August 22, 2004 50- 091 -20001 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: Fairbanks Meridian, T2ON R12E Sec 16 SW, NW September 3, 2004 DOI -04 -1A Top of Productive Horizon: 8. KB Elevation (ft): 15. Field /Pool(s): 31 Total Depth: 9. Plug Back Depth(MD +TVD): 2287 Feet 2287' - 1314' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- y- Zone- 2287' Air Force, Fort Yukon TPI: x- y- Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- y- Zone- FG5020- 04170 -0511 18. Directional Survey: Yes ❑ No 111 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 300 Feet 21. Logs Run: Gamma, Caliper, Resistivity, Density. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 8 5/8 24.7 Surface 93 Feet 10 3/4 " 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) 6 3/4 " open hole from 1270' - 1314'. 2.5" PVC 1270' 1265' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period ., Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none ". 0 - 93' Gravel, cobble, boulders; 93' - 925' silt, clay, sand interbeds; 925' - 1253' sand, soft, fluidized; 1253' - 1325' coal; 1325' - 1900' sand, clay interbeds; 1900' 1925' coal; 1925' - 2273' sand, clay, silt, conglomerate int gliq e s� ,, oli ‘4,1 ,--AL Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. GEOLOGIC MARKER$ 29. FORMATION TESTS NAME M TVD Include and briefly sun a test results. List intervals tested, and atta detailed supporting dat necessary. If no tests were conducted, state "None ". 30. List of Attachments: 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Title: Signature: Phone: Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each po completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing too Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: If no cores taken, indicate "none ". Item 29: List all test information. If none, state "None ". Form 10 -407 Revised 12/2003 DOI -04 -1A Well Completion Diagram, Fort Yukon, Alaska 10 3 /4 " casing to 63' - 4 • cement : I bentonite abandonment grout 8 5/8" casing to 93' • bentonite pellets o gravel pack 2.5" PVC water monitor casing ■ lignite i 2.5" x 6 3/4" formation packers = "� • °.'�=,� : :.:.::::::::. gravel pack from 1295' -1305' Lignite: 1257' -1315' 6 3 /4 " drill hole diameter ==` - - __-__ - __ ___= __ _:- 190(Y-1920' :.::::::::::::::::::::::.::::::::::::::::::::€:::;:::€::::::::;::: ::;::::::::::::::::::::::::::� -- ::::: = = =- :::::::::::::::::::::::::::::::::::::::::::::::€::::::::::::::::::::::::::;:::::::::: :::::::::::::::::::::::::::: Li Hite: • • g T.D. 2287 ' : = : =:= _: = == :=:= _: -: -: August 19, 2004 Fly from Denver to Fort Yukon (Clark, Eman, Grant, Schulz, Bird) leaving Denver on Delta at 08:20, through SLC, Anchorage, AK Airlines to Fairbanks, Frontier Flying Service to Fort Yukon, arriving at Radar Site at 20:00. Met by Jim Clough (flew up earlier today) at airstrip. Checked everyone in to Radar Site (Clough staying at River Lodge), watched mandatory video, and got somewhat situated. August 20: Spend all day moving, unpacking and setting up drilling equipment. Dig cement out of old surface casing, weld on connector piece and install diverter. Get rig moved over hole, set up, install 5000' of wireline cable. Move shaker in place, have pit dug, install liner, have forklift move wireline steel to site, unload timbers from water truck, get rig leveled, get water from pit etc. Steve Roberts arrives at 19:15. August 21: Continue getting arranged at site. Finish getting drilling equipment set up, mix mud, drill through cement (30') and abandonment mud in 8" steel casing to 93' (bottom of casing). Wright Air Service delivers shipment from Denver (32 pieces), arriving at 11:00. Move everything to site, set up three Weatherport tents and begin organizing desorption, logging, and hydro- testing equipment. David Ogbe and Amy Rodman (UAF) arrive in morning. August 22: Rotary drill to 335'- dark, sticky clay all day – seem to be drilling a new hole below the steel casing. Assemble and pressure -check desorption canisters, build saw horses, assemble core boxes, organize tents. Discover that latching sub at top of core barrels has an HQ thread rather than an HT thread and we have no adapters for that thread. Get hold of Greg Kerr at Christensen who says that they screwed up, they have the right adapters in SLC and that he'll get two of them shipped tomorrow "free of charge" to Fairbanks where Jim C. can pick them up and send them on to us. Hopefully they'll arrive by tomorrow night. Karen Clautice (ADDGS) arrives at 11:00, Jim Clough departs at 15:00. Hunley, Williams and Ratliff arrive at 21:00 along with Steve Harris (microbiologist). Congressman Don Young stops by in afternoon for an informal visit – talk to him and his wife for about 45 minutes, explain the project and the equipment – he seems very interested in what we're doing and says he'd like to see us continue this at other villages in the future. He stays and has lunch with us at the Radar site. August 23: Begin bringing up jelly -like chunks of old drill mud from the 1994 well at about 350'. We probably drilled into a large washed -out zone that occurred in the soft - sand section of the hole – 1994 lithology log shows several thick sandy intervals between 400' and 800'. We bring up dark, sticky clay cuttings in the finer- grained sections although it's so soft that the rig blows right though it —can't even tell you're drilling through anything. Continue organizing around the site and in the tents. Beth MacClean arrives at 15:00. Charley Barker arrives at 19:15. Have an informal meeting (Clark, Roberts, MacClean, Rodman, Barker) to discuss how we're going to handle core, desorption, schedules etc It's pretty smoky when the wind stops blowing. However, the wind kicks up around midday and blows it all out —it does get pretty darn cold at night though. Hole depth is at 800' as of 23:30. Clautice leaves at 10:00 a.m. 411 4 10 August 24: Rotary to 1205', and trip rotary bit from hole. Spend a few hours at end of day jacking rig up higher to allow for inserting the diverter system. Seem to be drilling new hole as we're bring up lots of sticky clay cuttings although there's never any real resistance at bottom of hole; maybe we're still in the 1994 hole? Wind continues through day and it stays cool — almost no smoke in the immediate vicinity although you can see plumes not far off in the distance. August 25: 860' of drill steel and core barrel are dropped down the hole when hoist bail comes unthreaded while tripping core barrel into hole. Spend the rest of the day attempting to fish it out, assuming that the top of the steel is at 332' (assuming bottom of hole at 1205'). Try spear, overshot, and overshot fashioned with hook without success. Pipe drops by the target zone and freefalls below — assume that we're in the washed out sand section and that the pipe is leaning against the sidewall. Decide to put on the 6 3/4" rotary bit (PDC) again and see if we can deflect off and redrill to core point. Rotary down to 404' and hit the top of the steel. Apparently, the steel fell to the bottom of the 1994 drill hole with the bottom at 1281' rather than at 1205'— we must have been more or less in the old hole the entire time. Pull the rotary bit and try fishing again with the overshot/hook tool. Latch onto pipe and begin pulling it from hole (very wet and dirty trip) -- about halfway out by midnight. Have visit today, while we're fishing, from BLM, DOE, DOI, AK State and BP folks to check out the equipment and operation — great timing! August 26: Finish pulling pipe from hole; core barrel, bit, and all steel appear to be in good shape. Also have about one foot of fresh lignite sample jammed inside the core bit — Jr this is one hell of a way to take a core! Trip in with the 6 3 /4" rotary bit and ream to S� 1280'. Pull rotary bit, install core barrel and begin coring operations at 1280'. Hit lignite right off the bat. Steve and Art handle site geology (canisters, boxing etc.) with everyone else up with the desorption equipment. Charley and Karen go to bed once things get running smoothly there. Depth of hole at midnight is approximately 1300'. August 27: Continue coring lignite to approximately 1325' (07:00). Art and Steve stay up all night working at site. Core recovery in lignite is excellent although the new style of lifter retaining ring that Christensen sold us doesn't work — one piece of core slid out the bottom due to the fact that the lifter and the ring ended up halfway up the core. Spent the next few runs fishing the fallen core out from inside the bit. We're able to fabricate a workable retaining ring from another style of ring that wasn't made for the shoe and lifter we're using. Coring though siltstone below the lignite and then into very soft sand. Decide to make multiple 10' runs before pulling core when in the sand. Drill from 1445'- 1490' in one shot before hitting more siltstone at that point. Depth in hole is 1485' at midnight. Finally get a decent core water sample in some of the silty sand by pressing it over a span of about five hours. August 28: Continue coring to 1675' as of midnight. Core becomes more competent and begin having to pull the inner -tube after each 10' run. Still primarily silty sand, some relatively dense clay, and sand. No lignite found at the second seismic horizon. A few very thin (1 " -2 ") lignitic zones noted but none worth sampling. Minor gas bubbles are noted coming from several of the sand and silt cores. August 29: Begin to have troubles getting clay cores to break off bottom and therefore are wasting a lot of time making cleanup runs. Finally decide to make all core runs greater than 10' so that the core will have to break off at the bottom. This works but it becomes difficult to extract the core from the tubes at times and the tubes are becoming increasingly difficult to pull from the barrel. Core depth is about 1805' as of midnight. August 30: Overshot latches onto inner -tube at the end of the 1835' core run but will not pull tube from barrel. For some reason the quad -latch also will not release. After about two hours of screwing with it the wireline cable is cut and the core steel and barrel are removed from the hole. Decision made to reinstall 6 3 /4" PDC rotary bit, ream from 1280' to 1835' and begin open hole drilling from there. Pull steel, install bit, and trip to 1280' stopping and circulating several times along the way. Decide to catch lignite cuttings from 1280' through 1325' to desorb and compare to the core desorption for future reference. Catch, wash, and mix cuttings in 5' or 10' increments (1284' - 1294', 1294' - 1304', 1304'- 1314', 1314'- 1324', 1340' - 1345', 1345'- 1350') and begin desorption. Reaming continues and is at approximately 1380' as of midnight. August 31: Finish reaming hole to 1835' and begin open -hole rotary drilling below that point. Hit another lignite bed at about 1907'. Stop at 1915', circulate to clean hole, drill ahead five feet (1920'), and catch cuttings for desorption. Decide to pull rotary bit and core this zone. Pulling steel at midnight. Steve Roberts heads home on morning Frontier flight. Geophysical logging winch arrives. C Sept 1: Steel pulls tight in two spots and have to drill out of clay boots. Finish pulling, install core barrel and trip to bottom. Core from 1920' - 1965', lignite from 1920'- 1930', total bed thickness of approximately 23', clay and sand below. Decide that since we're more interested in depth than in core (with the exception of the lignite beds) and since we can collect excellent cuttings for desorption when lignite is encountered, and A-- J Q _ since the desorption of the cuttings seems to be giving us at least a general idea of how6 c much gas is in each bed, that we'll end coring operations at 1965', pull steel, install rotary bit and drill to as great a depth as possible in the next two days, collecting cuttings and desorbing lignite cuttings when thick beds are encountered. Trip steel from hole, change over to rotary drilling, and tripping to bottom at midnight. Sept 2: Finish tripping steel to bottom; have to ream cuttings/boots from the bottom 100'. Begin rotary drilling at 9:00 a.m. Clark collects and bags cuttings all day looking for lignite beds. Drill through several thin beds ( <1' thick) but encounter no significant beds. Primarily drilling though silt and sand beds with occasional clay beds between 5' and 10' in thickness. Drilling depth is approximately 2150' at midnight. Sept 3: Drill into quartz- pebble conglomeratic unit at abut 2165' with the top 20'- 30' being relatively loose and becoming more indurated as depth increases. Drilling becomes very slow (5' penetration per hour) at about 2235' -2250' and begins speeding 4 10 up again at that point. Appear to break out of the conglomerate at about 2275' and into a sticky clay. Having problems drilling through the clay with the mudpump building back pressure and the drill rotation increasing in pressure. With penetration rate slowed to almost a complete stop, decide to T.D. the hole at 2287' (20:30) and spend the next 12 -18 hours cleaning up the hole prior to logging. Spend about 2 hours rebuilding the fluid end of the 5X6 mudpump; one piston had completely trashed and several valve seats were badly washed. Ed Weeks and Barbara Corland arrive at 19:00. Sept 4: Crew trips steel (very tight through conglomeratic section) to approximately 1600' and begins reaming to bottom. Finish reaming to TD at 9:00. Circulate and trip steel from hole. Set up and begin logging at 15:00. Run caliper first and .//' , only get it down to 2000'. Run multi -probe next (gamma, resistivity, temperature) and get it to dead bottom: excellent logs). Discover that Mt. Sopris software is not correlated to � � � � � � s new logging winch and that the footages down hole are way out of whack. Spend the next 0' si 44 a3 1 two hours changing numbers and measuring lengths of cable to get everything working t-'v" " correctly. Run density tool down hole, get it to bottom, log up and depth meter is still reading 510' bls when we get to surface. Check settings, run quick 10' field check (comes out correct) and decide to go ahead and run sonic log. Get probe to bottom and begin logging at 10' per minute. Determine that footage is off on this log as well and, sure enough, meter reads 300' bls when tool is at surface. Hopefully data can be correlated to correct depths using Welcad. Finish logging at 03:00 on Sept. 5. Sept 5: Finish logging at 03:00. Crew trip steel, without bit, to bottom to begin abandoning the bottom of hole (decide to hydro -test 1250' -1325' lignite). Trip to bottom and abandon with Volclay abandonment bentonite mixed with thick drilling mud. Mix nine tanks and cut from 1340'. Circulate and tremie four buckets of pellets from 1320'. Tag at 1334', tremie 7 bags chip and tag at 1314', tremie 4 buckets gravel and tag at 1307' (lower testing point in lignite). Pull drill steel from hole and begin tripping in 2.5" PVC pipe with 2, 8" and 5, 6" shale baskets on 2" stainless pipe coupled to bottom of 2.5" pipe. Great Northern Lights starting at 23:00. Sept 6: PVC pipe hangs in hole at 340'. Rather than try and pull pipe with formation baskets on, trip in 1.5" stainless tremie and attempt to wash through tight spot — no luck. Pull pipe with wireline hoist without a problem — both of the 8" baskets and two of the 6" baskets have folded over but everything is in good shape. Remove the 8" baskets and trip 2.5" pipe with 6" baskets to 1265' without a problem. Circulate fluid and tremie ten buckets bentonite pellets on top of baskets. Mix and pump approximately 2000 gallons of Volclay grout to surface. Sept 7: Trip tremie inside well to 1302' and circulate fresh water, flushing drill mud from well. Pull pipe back to 200' and begin air development. Air develop from 200', 300', 400' and 500'. Water recovery is slow; take measurement with e -tape and seems to be recovering approximately 1' per minute at 300', but seems to be increasing as we deepen the development depth. At 500', PVC casing slips though clamp, shears off glued coupling at top, and drops 35', apparently stopping where it hits tremied gravel layer at r about 1305' — so much for openhole well development; next time consider treming sand or gravel into the bottom of the well after flushing the mud out. It would go in like gangbusters, would filter coal fines from coming up the hole, and keep something like this from happening again. Regardless, we can look down the hole with a mirror and see the top of the casing. Decide to attach another length of 2.5" PVC with a slip - coupler on to the original piece and continue air development in the hopes that the 7' -10' section of lignite that is graveled will make enough water to get decent information. Other option would be to attempt to spear casing and pull back to surface but I think that the possibility of breaking the casing and losing all possible data, including the overwinter data, is too great. Attach to PVC and pull development pipe back to 200' and develop there. Continue to develop and drop to 300', 400', 500', 600', 700', and 800'. Well is now making a very small amount of water; check recovery with e -tape at 500' and it seems to be recovering about 1' per 3 ' /2 minutes. After developing for about an hour at 800', decide to install programmable transducer to monitor overnight recovery rate: will take that information and decide if the well will produce useable data. Attach transducer to wireline cable and run down tremie pipe to 780'. Night crew drains, cleans, and packs equipment. Shut down at about 21:00 for the night. Verify in the morning that the Hermit data recorder has a blown circuit board making the real -time transducer that we planned to use for recovery and pump testing non - useable. Will send it back to In -Situ for repair. Sept 8: Pull transducer at 08:00 and download data. Had a good recovery test going until 01:00 when there was a 10' oscillation in recovery, both up and down: what happened? Formation collapse? The well continued to recover after that for another hour or so and then flat - lined. Drop tremie to 900' and then 1000' to air develop — going any deeper will collapse the well. Attach transducer to wireline cable, run to 1020', and gather data for two hours while the crews shuttle equipment and core to the airport to meet the Wright Air charter. Pull transducer after two hours; the well has recovered less than two feet during that time. Decide to wash tremie to bottom and attempt to clean the bottom of the hole. Hit bridge at 1100' and wash down; begin bringing up lots of coal chips. Wash through bridge after about 40' and then have pretty much open hole to about 1250'. Start washing down again, bringing up coal chips and small gravel. Discover that tremie pipe is cut at slightly random lengths so that we really don't know exactly where we are in the hole. Feels very gravelly and tight at bottom and pump pressure suddenly spikes at a certain depth. If the tremie averages 19.5' per two joints rather than 19.25' as calculated, we would be in the "open" portion of the hole and washing down to the bentonite chip plug. Wash for about an hour, pull tremie back to 200' and air develop. Making very little water so drop to 300' and blow some more. Decide to pull all tremie from hole and run transducer to 400' to collect overnight data. Crew digs and cements in 8" surface casing and digs in ditch and sump for gravel hole attempt. Sept 9: Pull transducer at 08:00 and download data. Transducer shows that water came up hole a total of about 8' overnight; better than at end of the previous night but not as good as the beginning of the previous night, prior to the "event" that caused the water oscillation/spike and subsequent plug. Nothing more that we can do at this point other than to collect data over the winter. Move rig over to new spot on other side of pit (44' from drilled well) to attempt to case off gravel with 6" casing. Spend all morning moving, thawing, and getting chuck and jaw systems switched over for 4.5" drill steel. Get two lines of heat tape (275', 350') wired and set into DOI -04 -1A along with transducer to 600'. Rig begins drilling on gravel hole at about 16:00. Drill through 20' of overburden, then gravel; at about 35' at midnight. Art and Ed fly to Fairbank;, on to Denver on 9/10. Sept 10: Crew spends all day drilling through gravel. Very loose, coarse, and wet. By keeping mud extremely thick, running pumps slow, and slowing working through, continue to make progress. Drilling at 85' at midnight. Sept 11: Break out of gravel and into sticky gray clay at 93'. Drill to 105' to have sump for gravel to fall into. Hole continues to bring up gravel as it is still very unstable. Pull steel from hole: getting out of the clay is very tight, the rest pulls easily; weld and set 6 5/8" O.D. steel casing to 96' where it hits gravel that has fallen into bottom of hole. Pump water through and around casing — appears to be wide open. Mix tank of Portland cement and begin pumping. Pump approximately 100 gallons beyond what it takes to fill casing and mudpump pressure builds to over 500 psi. Close valves and shut in to cure. Begin cleaning up at site. Sept 12: Cleanup site, winterize equipment, remove batteries for storage at GZ generator building, make dump runs, dig out liner, fill and reclaim pit, remove valves from cemented hole and cut casing approximately 6" below ground surface, reclaim site, park equipment,. Drill crews leave Ft. Yukon at 19:30. Sept 13: Drill crews fly back to Denver from Fairbanks arriving at 18:30. End of project. [Fwd: Re: DOI well completion report] 4► t► Subject: [Fwd: Re: DOI well completion report] From: Robert Crandall <bob erandall a@admin.state.ak.us> Dote: Mon, 14 Mar 2005 08:37 :47 -0900 " Okland, Howard" <howard okland@a.€ min.state.ak.us= : . Original Message Subject: Re: DOI well completion report Date: Fri, 11 Mar 2005 14:04:31 -0900 From: Robert Crandall <bob crandall;vadmin.state.ak.us> Organization: State of Alaska To: Arthur C Clark <aclark @usgs.gov> References: < OFFC725C50. DD886AEO- ON87256FC1. 005F4DAA- 87256FC1.0060F176 @usgs.gov> Art; I understand your comments here and if I remember correctly we had some very similar discussions regarding your permit to drill last summer. Basically we have the responsibility to regulate all subsurface oil and gas activity i Alaska. You have drilled a well to evaluate the CBM potential in the Fort Yukon area. You have taken a cores and don desorbtion analysis on a lignite (why lignite ?). As predictable as these results are, you are still required to file the appropriate information and materials (see Howards e -mail) such as core chips, analysis and ect. Do the best you can with that form, it will become part of Alaskan history. Let me know if I can help. BC Arthur C Clark wrote: Hi Bob, While meeting with Beth Maclean yesterday in Denver, she gave me a copy of Form 10 -407 that Howard Okland had given her to fill out as a completion record for the CBM test hole that we drilled in Fort Yukon last summer. After looking over the form, it strikes me that this is an oil and gas well completion form and is really not appropriate for the work we did at Fort Yukon or for similar future work that we'll be conducting in other locations. DOI -04 -1A was completed as a water observation well in an isolated coal interval and will be abandoned this spring. Is this form really the appropriate or best available form for providing you with that information? If so, I'll fill out what I can but the bulk of the boxes will be filled with an N/A since the vast majority of the questions are not applicable to our work. We certainly want to provide AOGCC with all necessary information but isn't there some way to differentiate our work from commercial oil and gas drilling? Again, I'm happy to fill out the form as much as possible if that's what the AOGCC needs but it seems to me that its not going to provide you with much in the way of beneficial information. - Art Art Clark Supervisory Geologist Central Region Research Drilling Project U.S. Geological Survey Denver, CO 80225 phone: 303 - 445 -4608 fax: 303 - 445 -4657 aclark@usgs.gov • Re: DOI -04 -1A • • Subject: Re: DOI-04-IA From: Beth Maclean@akblm.gov Date: Tue, 08 Mar 2005 11:03 :23 -0900 To: Howard Okland <homiard okland@a admin.state.ak.us? Howard, Here are LAS files of the gamma /resistivity and gamma /caliper logs for the DOI -04 -1A well in Fort Yukon. (See attached file: DOI- 04- 1A_ 09- 04- 04_ 17- 13_ 9074C _.10_372.70_2092.10_PROC.LAS) (See attached file: DOI- 04- 1A_ 09- 04- 04_ 19- 18_ 8044C _.10_3.20_2288.10_PROC.LAS) ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 -1304 DOI- 04- 1A_09 -04 -04 — 17 -13 — 9074C — .10 — 372.70 — 2092.10 — PROC.LAS Content -Type: application /octet - stream �) Content- Encoding: base64 1 — — — — — Content -Type: application /octet - stream DO -04 -1A 09 -04 -04 19 -18 8044C_.10_3.20 2288.10 PROC.LAS Content- Encoding: base64 Lat -Long of D01-04-la • • Subject: Lat -Long ofDOI -04-la From: Charles E Barker <barker @us Date: Wed, 02 Mar 2005 08:42 :44 -0700 t5 r t i (j,(t,[.t Sq j "#H k F €1 "1tE #'�# , ° s? ^#`�@.• e a•?', .£\'�'a..P ' .., '.S.,Z �',� .• '3 c .. & E' 1f% �+q s Y h.: ,k._ Q ,a. •F+y 3 tl :. . , .✓ _ :.. }. • F , •. w � e , " g F £ . 1£ ' iz. z �. .. i N 66.55949 (in decimal degrees) / 6vov Q,vl,o "‘ 7,1 W145.20616 lJ I (�20 ate( 31' - 1,z.,2..-.S`z-19 3I Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 USA Voice (303) 236 -5797 FAX (303) 236 -3202 III D01-04-1A • • Subject; DOI -04 -1A From: Howard Okland < howard okland @admin.state.ak us> Date: Mon, 28 Feb 2005 13:52:48 0900 _ •�� „ # i�:x ,1 i t t t om: EAYLt1� . -i 4i1X3 -: -... � ( °• ` " x , . z .. r_. ,i. :. i . .. ''t�' ....� £ ik.- i.yg.. Beth, TNX for the Daily Drilling History. I have it printed and in our well history folder for DOI- 04 -1A.. To recap what we need from the Coring operation: 1) Need chip samples (approx 1 cubic inch representative sample for each foot) 2) Core description (Lithology, structural features, etc ) 3) Core Analysis Report For the Logs: (Drilling history indicates GR, RES, & Temp logs run). 1) Blue line copy of each log. 2) Reproduceable (either sepia or digital graphics file .pdf or .pds preferred) 3) Digital file of the logging data (L.I.S., D.L.I.S., or L.A.S. formats are acceptable). A wellbore diagram is required. A Completion Report, form 10 -407, is required. A Mud Log is required (Blue line and reproduceable). Washed and dried cuttings are required. Reporting requirements are specified in our regulations: 20 AAC 25.070 & 20 AAC 25.071 Please e mail or call if you have any questions. Howard 7931235 Bob adds Beth; Due to the late stage of these compliance issues (these materials are due 30 days after the well is drilled) please advise us as to when these materials should be expected. Thanks BC II DOI -04 -1A PTD 204 -083 • i Subject: D01-04-1A PTD 204 -083 From: Howard Okland <howard okland @admin.state,ak.us> Date: Mon, 07 Feb 2005 11:20:21 -0900 i`i:1t P Gr . x andall <bAh �radall(a�.st,akt-�a �- ::. -::� =� x:t�.. Bob, got in contact with Beth Maclean (267 1448) of the U.S. Bureau of Land Management and asked her about the status of the DOI -04 -1A well. She told me that they would be heading back on site to plug and abandon the well this May. I asked her to call Jim Regg when they were planning to go up there for abandonment, so an inspector could be on -site for the operations. She asked about the reports required to be submitted. She was aware that the Regulations are available on the website. I told her that the reporting requirements are "spelled" out in the Regs. I summarized the required paperwork for her. I also mentioned that she can get the AOGCC forms off the website. Howard } 1[1' A 1 : 1 EL- [F _ f ! FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS / 333 W. 7Th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 r£ PHONE (907) 279 -1433 FAX (907) 276 -7542 August 26, 2004 Beth Maclean, Geologist US Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Re: DOI -04 -1A US Bureau of Land Management Permit No.: 204 -083 Dear Ms. Maclean: The period for notice and public comment on the Alaska Oil and Gas Conservation Commission's ( "AOGCC ") proposal to waive the bonding requirement of 20 AAC 25.025 for the subject well has expired. AOGCC received no comments on this waiver proposal. Waiver of the bonding requirement for DOI-04-1A is final. Sincer- .;( � TK. o an airman ' • • i fit co ri"; (6) IF I t7i n rk: ( -(2i) [ /-i- „,, ,, ,„ k ; : : ( , , ! , = ,. r , i: , , , , ” , , Cu,i () 11 Li in L „i Li A3 t z ti (.� i `. FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS 333 W. 7"' AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 June 10, 2004 Arthur Clark Supervisory Geologist US Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Re: DOI-04-1A US Bureau of Land Management Permit No: 204 -083 Dear Mr. Clark: Under my signature I transmitted the Alaska Oil and Gas Conservation Commission ( "AOGCC ") approval of the above referenced permit. Ordinarily issuance of a permit to drill requires a bond to be posted by the operator, in this instance, the Bureau of Land Management. As you know, given the identity of the operator, the AOGCC proposes waiving the bonding requirement of 20 AAC 25.025 for this well. To waive the bonding requirement we are required under statute to publish notice, which we have done. Upon completion of the period for notice and public comment we will notify you when the waiver is final. i•.- .No an Ihai STATE OF ALASKA i NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVO�fv1UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER ("CERTIFIED /� O_02414041 + AFFIDAVIT OF PUBLICATION (PART OF THIS FORM) WITH ATTACHED COPY OF A ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE 1 ADDRESS • F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 Jody Colombie June 1, 2004 ° Anchorage, AK 99501 PHONE PCN M _ (907) 793 —1221 DATES ADVERTISEMENT REQUIRED: Anchorage Daily News June 2, 2004 P 0 Box 149001 Anchorage, AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e- mailed Type of Advertisement X Legal ❑ Display ❑ Classified ❑Other (Specify) SEE ATTACHED $END � AOGCC, 333 W. 7th Ave., Suite 100 PAGE 1 OF TOTAL OF ` . � �� - �I�Y ^• � � . Anchorage, AK 99501 2 PAGES ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LIO 1 04 02140100 73540 2 3 4 REQUISITION BY: / DIVISION APPROVAL: 02 -902 (Rev. 3/94) Publisher /Original Copies: Department Fiscal, Department, Receiving AO.FRM • • Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pursuant to 20 AAC 25.505, the Alaska Oil and Gas Conservation Commission ( "Commission ") proposes to issue an order granting to the United States Geological Survey ( "USGS "), a bureau within the Department of the Interior, an exception from the bonding requirements of 20 AAC 25.025. The USGS has applied to drill a coalbed methane exploratory well in the vicinity of Fort Yukon. The surface and subsurface locations of the well are entirely on federally owned land. If the proposed exception is granted, this operation will be exempt from the requirement of 20 AAC 25.025 to file a bond or security. The Commission has tentatively scheduled a public hearing on this application for July 13, 2004 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7 Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on June 18, 2004. If a request for a hearing is not timely filed, the Commission may consider issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793 -1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7 Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on July 2, 2004 except that if the Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the hearing. If you are a person with a disability o - need a special accomodations in order to comment or to attend the • 4 ;' ing ease contact Jody Colombie at 793 -1221 before June 21, 2004. N1. an, air . issioner Published Date: June 2, 2004 ADN AO# 02414041 Anchorage Daily News 6 /8/2004 Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD # DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 182526 06/02/2004 02414041 STOF0330 8163.52 $163.52 $0.00 $0.00 $0.00 $0.00 $0.00 $163.52 STATE OF ALASKA Notice of Public Hearing . THIRD JUDICIAL DISTRICT - .- STATE. 0F. ALASKA , Alaska Oil and.Gas Commission Kimberly Kirby, being first duly sworn on oath deposes and says Re .Pursuant10 20 AAC 25<sos, Alaska Oil' and that she is an advertising representative of the Anchorage Gas Conservation Commission -( "Commission ") Daily News, a daily proposes to issue an order granting to -the United 1 } y news P a P er. States Geological Survey ( "USGS "), a bureau within the Department of the Interior, an excep- tion. from the bonding requirements of 20 AAC That said newspaper has been approved by the Third Judicial 25:025. Court, Anchorage, Alaska, and it now and has been published in The t1SGS has appred to driu a roa,bee. m ethane the English language continually as a daily newspaper in exploratory well in the vicinity of Fort Yukon. The Anchorage, Alaska, and it is now and during all said time was surface and subsurface locations-of the Well are i g g entirely on federally owned land: -If the proposed printed in an office maintained at the aforesaid place of exception is granted, this operation willbe a . ublication of said news a er. That the annexed is a copy of an from The requirement of 20 AAC 25,025 to file a p p p py bond or security. • advertisement as it was published in regular issues (and not in The Commission has tentatively scheduled a pub- ' supplemental form) of said newspaper on the above dates and lic hearing on this application .for July -13, - 2004 at that such newspaper was regularly distributed to its subscribers 9:00 -a v the of s of the Alaska Oil 'and Gas d p p g y Conservation Commission aT.383 West 7th Avenue, during all of said period. That the full amount of the fee charged Suite 100; Alaska 99501. A.person may request the tentatively scheduled hearing be • ; for the foregoing publication is not in excess of the rate charged held by filing a written request with the Commis -- - private individuals. sion no later than 4:30 pm on June 18, 2004. r If a request for a hearing is -not timely filed, -the- ' j Commission may consider - issuance of an order - ! without a hearing. To learn if.the"Commission will 1 t ; hold the public- hearing, please call - 793- 1221 . / 1 1 • / .? r ' . I In addition, a person may submit written cam- Signed - 'a ( t , j2„,1 , I- ! -, 'i / f / r '' ) (',.t .11;!,,/ and Gas Conservation Commission at 333 Alaska est i- / Avenue, Suite 100, Anchorage, Alaska 99501. Writ - Jr/ ten comments must,be received no later than 4:30 ,,- / pm on July 2, 2004 except that if -the Commission decides-to hold a public hearing, written protest or Subscribed and sworn to me before t date: comments mutt be received no later than the con - .r, elusion of the hearing. � r / �y / If you are ccom with - a - disability who may need U a Specigl . accommodations in o rder to comment or to atterifithe public hearing, please contact Jody Colombieat - 1221 before June 21, 2004. John K. Norman, Chair Notary Public in and for the State of Alaska. •. Commissioner . Third Division. Anchorage, Alaska P°ti,i AO Jun 414041 4 MY CO 4 ON EXPI S: , CI 't =" "'z %li /i / . STATE OF ALASKA • NOTICE TO PUBLISHER • ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED p ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF A0- 02414041 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7 Avenue, Suite 100 Jody Colombie June 1, 2004 ° Anchorage, AK 99501 PHONE PCN M 907 - 793 -1221 (907) 793 -1221 DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News June 2, 2004 P O Box 149001 Anchorage, AK 99514 ENTIRETY RI THE BETWEEN ES SHE DOUBLE LINES MUST BE PRINTED IN ITS SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he /she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This day of 2004, Notary public for state of My commission expires 02 -901 (Rev. 3/94) AO.FRM Page 2 PUBLISHER RE: Legal Notice 1 1, 41 111/ Subject: RE: Legal Notice From: Group - legalads <legalads @adn.com> Date: Tue, 01 Jun 2004 17:14:06 -0800 To: Jody Colorable <jody colombie @admin.state.ak.us> Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 182526 Publication Date(s): June 2, 2004 Your Reference or PO #: 02414041 Cost of Legal Notice: $163.52 Additional Charges Web Link: E -Mail Link: Bolding: Total Cost to Place Legal Notice: $163.52 Ad Will Appear on the web, www.adn.com: XXXX Ad Will Not Appear on the web, www.adn.com: Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E -Mail: legalads @adn.com Phone: (907) 257 -4296 Fax: (907) 279 -8170 From: Jody Colombie Sent: Tuesday, June 1, 2004 1:38 PM To: Group - legalads Subject: Legal Notice «File: Ad Order form.doc» «File: Bonding Exception.doc» Please publish on 6/2/04. Jody 1 of 1 6/2/2004 2:56 PM Notice • Subject: Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Tue, 01 Jun 2004 13:40:22 -0800 To: undisclosed-recipients:; BCC: Robert E Mintz <robert mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw®trustees.org>, roseragsdale <roseragsdale®gci.net>, trmjrl <trmjrl ®aol.com>, jbriddle <jbriddle@marathonoil.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington®forestoil.com>, nelson <nelson@gci.net>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrine.com>, Shannon Donnelly <sharmon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, "Jerry C. Dethlefs" <jetTy.c.dethlefs@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles °Donnell <charles.o'donnell®veco.c,om>, "Randy L. Skillern" <SkilleRL@BP.com>, "Jeanne H. Dickey" <Dickey.TH@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg®BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, "Joseph F. Kirchner" <KirchnJF@BP.com>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.eom>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JaeobsRM@BP.com>, ddonkel <ddonkel@efl.rteom>, Collins Mount <collins mount@revenue.state.alcus>, mekay <rnekay@gei.net>, Barbara F Fullmer <barbara.f.fulliner@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug schultze <doug schultze®xtoenergy.com>, Hank Alford <hank.alford®exxonmobil.com>, Mark Kovac <yesnol ®gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rerotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-titemet>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, Kurt E Olson <kurt_olson@legis.state.ak.u.s>, buonoje <buonoje@bp.com>, Mark Hanley <mark hanley@anadarko.com>, loren Jeman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle®dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh®drmstate.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White limwhite@satx.mcom>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <maclean@pobox.alaska.net>, James Schen <james.scherr@mms.gov>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaaalaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TD1JRKEE@KMG.com>, Gary Schultz <gary schultz©dnr.state.ak.us>, Wayne Rancier <RANCIER®petro-canada.ca>, Bill Miller <Bill Miller@xtoalaska.com> ,Bonding_Exception.doe Content-Type: application/msword 1 of 2 6/1/2004 1:40 PM Notice • • Content - Encoding: base64 2 of 2 6/1/2004 1:40 PM Notice • Subject: Notice From: Jody Colombie < jody _colombie @admin.state.ak.us> Date: Tue, 01 Jun 2004 13:39:45 -0800 To: undisclosed- recipients :; BCC: Cynthia. B Mciver <bren mciver admin.state.a .us>, Angela Webb <angie webby admin.state.ak.us> Please post on -line. Jody Content -Type: application/msword Bonding_Exception.doc Content-Encoding base64 .... ......................._....._� 1 of 1 6/1/2004 1:40 PM Legal Notice • • Subject: Legal Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Tue, 01 Jun 2004 13:38:44 -0800 To: Legal. Ads Anchorage Daily News <legalads@adn.com> Please publish on 6/2/04. Jody Content application/msword Ad Order form.doc Content-Encoding: base64 Content application/msword Bonding_Exception.doc Content-Encoding: base64 1 of 1 6/1/2004 1:40 PM • Citgo Petroleum Corporation Mary Jones David McCaleb 9 P rY PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201 -3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401 -2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045 -0738 Portland, OR 97201 Seattle, WA 98119 -3960 Mark Wedman Schlumberger Baker Oil Tools Halliburton Drilling and Measurements 4730 Business Park Blvd., #44 6900 Arctic Blvd. 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Jill Schneider Gordon Severson Land Department US Geological Survey 3201 Westmar Cr. PO Box 93330 4200 University Dr. Anchorage, AK 99508 -4336 Anchorage, AK 99503 Anchorage, AK 99508 David Cusato Jack Hakkila Darwin Waldsmith 600 West 76th Ave., #508 PO Box 190083 PO Box 39309 Anchorage, AK 99518 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669 -7714 Soldotna, AK 99669 -2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K &K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 7/e/ 67771--/ • S F 't . � .. i " ' 6 ° 1 I ttt ± _ 4 S l- (1 Li WO Li 4 k j L L r :,: • < FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS 333 W. TH AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 10, 2004 Arthur Clark Supervisory Geologist US Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Re: DOI -04 -1A US Bureau of Land Management Permit No: 204 - 083 Dear Mr. Clark: Under my signature I transmitted the Alaska Oil and Gas Conservation Commission ( "AOGCC ") approval of the above referenced permit. Ordinarily issuance of a permit to drill requires a bond to be posted by the operator, in this instance, the Bureau of Land Management. As you know, given the identity of the operator, the AOGCC proposes waiving the bonding requirement of 20 AAC 25.025 for this well. To waive the bonding requirement we are required under statute to publish notice, which we have done. Upon completion of the period for notice and public comment we will notify you when the waiver is final. -re .No an thai \ � F ` $ rm t _ i E t. J lr 1 L , £[ is t iC.q 4 FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS 333 W. 7`" AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Arthur Clark Supervisory Geologist US Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Re: DOI -04 -1A US Bureau of Land Management Permit No: 204 -083 Surface Location: T2ON, R12E, Sec. 16, SW, NW Fairbanks, Meridian Bottomhole Location: T2ON, R12E, Sec. 16, SW, NW Fairbanks, Meridian Dear Mr. Clark: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty -four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 6 ' 607 (pager). gi g o an r BY ORDER OF COM ► ISSION ! DATED this day of ■ . y, 2004 I cc: Department of ish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. WA- S f 21(ZOO4. II STATE OF ALASKA el RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 4 2004 i,44414- PERMIT TO DRILL 20 AAC 25.005 .Alaska Oil & Gas Cons. Commission 1a. Type of Work: Dri edrill ❑ 1b. Current Well Class: Exploratory DeveloprTAtibR8ra Multiple Zone III Re -entry Stratigraphic Test IV Service 0 Development Gas Single Zone ❑ 2. Operator Name: 13(..... 5. Bond: Blank 7(06t El Single Well ❑ 11. Well Name and �` J d Nu be : / V. S G--e�1.0 C c.- rr Bond No. i` 1,46k U O 3. Address: g ( 0 (...-02) (...-02) - o V2-.k � 6. Proposed Depth: 300p 000 12. Field /Pool(s): Ark-- C t 5 0 MD: -- 1�Z7 T TVD: 4a. Location of Well ( Gover ente Section): 7. P operty Designation: Surface: _ -- Alf cU 'rCQ- VA - "l.J Top of Productive Horizon: k 2-0 0 8. Land Use Permit: � AQ t �� 0 13. Apprroxi ate S ud Date: Total Depth: Oka %61(. t'- 9, , 9 Acres in Pr perty: 14. Distance to /�V { earest 5 -c.- , - W / t w 0 Y Property: 1.1 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation ' ? .3° 15. Distance to Nearest ell Surface:x- y- Zone- (Height above GL): r�(keet Within Pool: (`.� it 16. Deviated ells: Kickoff depth: feet 17. Maximum Anticii - Pressures in psig (see 20 AAC 25.035) 1)(tk Maximum Hole Angle: degrees Downhole: (�o Surface: Q 18. Casing P ogram: etting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re - -Entt Operations) ., Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Y " i - Surface Intermediate 1 M Production Liner th Perforation Depth MD (ft): J ( Perforation Depth TVD (ft): tO i' 20. Attachments: Filing Fee Lf BOP Sketch__ Drilling Progra 11 Time v. Depth Plot _ Shallow Hazard Analysis Lf Property Plat 0 Diverter Sk: FP Seabed Report _ Drilling Fluid Progr: 0 • 0 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: ' - 22. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ,` f o.......,(cl_ Title �, 1 Jl,0 T Signature Phone 303 - L44 S - (Q0 IS Date 'S /..{ / tA Commission Use Only (� r Permit to Drill API Number: Permit Approval See cover letter for other Q u - Q ?3 f ,, /1 1� 1„t requirements. Number: 50- Q 9f / Date: `{' ) Conditions of approval : Samples -quired Yes ■■ No ❑ Mud log required Yes X No 0 Hydros -n • ulfide measures Yes /+ r�� No 0 Directional survey required Yes No �i Other: Re ,. cc, ■ . e d o..ck .k'(/N C S 0 alp VO ti a , BY ORDER OF Approve / THE COMMISSION Date: 65/ F 1 R vise. 12/2_0033 ORIGINAL Submit inDuplicate • • Conditions of Approval U.S. Bureau of Land Management DOI -04 1A (PTD 204 -083) I 1. Per 20 AAC 25.030 (g), the formation integrity test requirement is waived. 2. Per 20 AAC 25.035 (h) (1) and (2), alternate BOPE and diverter are ap- proved. 3. Per 20 AAC 25.050 (h), well bore directional survey requirement is waived. 4. Abandonment plug cement volumes may be adjusted dependent upon actual subsurface conditions. b b(IIf 1 • Drilling Plan for Alaska Rural Energy Project CBM Drilling, Fort Yukon, AK Summer 2004 1. Set up equipment over existing conductor casing from 1994 Climate Studies drill hole 2. Reenter casing (8" ID to 100') and open hole drill (6 3 4 ") to top of upper coal (1250'). Assume that drill hole will deflect from 1994 hole (abandoned with bentonite grout) in fluidized sand zones. 3. Continuous core (HT, 4.25" core bit) from top of upper coal to basement rock (approximately 2200'). 4. Ream hole to 6 3 /a" diameter 5. Core approximately 200' into basement rock (2400' TD). 6. Run geophysical logs (gamma, resistivity, density, caliper, sonic, acoustic televiewer). 7. Backfill hole with abandonment bentonite to selected primary coal of interest. 8. Set 2.5 ", schedule 80 PVC casing with rubber formation packers in coal seam, open completion in coal. Casing will be instrumented with pressure transducers for testing coal permeability and formation pressure. 9. Set solid bentonite plug above formation packers and abandonment grout above solid plug into 8" conductor casing. 10. Set cement plug above abandonment grout in conductor casing. l • Drilling Fluid Plan for Alaska Rural Energy Project CBM Drilling, Fort Yukon, AK Summer 2004 Hole will be drilled using standard fresh water - bentonite drilling fluids. Additives to be used include (all listed products are NL Baroid trade names): • Quick -gel high yield bentonite (hole stability, circulation control, clay -shale control) • Aqua -gel bentonite (hole stability, circulation control, mud weight) • Pac -L powdered cellulose polymer (clay -shale control) • EZ mud liquid polymer (clay -shale control) • Pennetrol liquid detergent (to prevent clay balling around drill bit) Drilling fluids will have drill cuttings removed and fluids recirculated via a 1000 gallon / trailer - mounted shaker system. Core drilling will be conducted using a Bean 35 gpm triplex pump Rotary drilling and reaming operations will be conducted using a Gardner- Denver 5 "x6" 200 gpm duplex pump. • • Drill Cuttings and Fluid Disposal Plan for Alaska Rural Energy Project CBM Drilling, Fort Yukon, AK: Summer 2004 Drilling fluids will be cleaned and recirculated using a 1000 gallon capacity shaker trailer. Cuttings from the shaker screens will be temporarily contained in a shallow, onsite dug pit capable of holding approximately 350 cubic feet (2600 gallons) of material. Cuttings and fluids will be transported and dumped in an unlined off -site dug disposal pit using a vacuum suction truck. The pit will be approximately 30' long x 10' wide x 8' deep and capable of holding 2400 cubic feet if material (18,000 gallons). Upon completion of the drilling project, the liquid fraction of the waste will be mixed with Portland cement using a duplex fluid pump and turned into a solid. The pit will then be backfilled and covered. 0 - ence drilling operations t ill out bentonite plug in existing casing -200 -400 • /en hole drill to first coal -600 -800 • V, -1000 Wm -1200 .1•••• MAO' tagngiarglirEPEbal -to ivf C- c " core to second coal 4.1 -1400 0 . -1600 tukAo tart core second coal Set PVC casing e.NA 04.4-zt—e .+b C=' end core second coal / • • -1800 coaA continue coring to basement Hydrotest well End of drilling • -2000 -2200 core basement 1 :( -2400 backfill hole to 1700 ft, set plug , End core basement; ream hole; Log -2600 11 illiii1111111 ii 0 10 20 30 Time (days) '------0 k \.) Art_ LiI__-. 0 -7) ---...(Ac_ I 4 1 VAJ ' (il =) , _ 0 _ -;1. 0 - ' - "coo &-c4t SC'j f -VS ` cti ' U3 ASLV- - 100 t� i .c.., 4 co.) k BE . _I k _-------" 1 &---- &q Om ' ----- L1 (J " jfr Doctit_ it t,. Ste" L-9---- 6,16A). , tivvk `-Q is( - ' c— tia (6.1/4.J— r / a oif -vor ‘.. -6 - -Cv k%-, 4 ,b --C--N-0-e-- ; ,-k„ s s I. s ,,,,I tc, ,-k--/ sue -t/' vt- ,G.-c.fjy • SURVEYED TOWNSHIP 20 NORTH RANGE 12 EAST OF THE FAIRBANKS MERIDIAN, ALASKA STATUS OF PUBLIC DOMAIN en e Ca ids WA 91 M ►l� 5.70 ' -I.aJ I LAND AND MINERAL TITLES v � DIIDt "" "" oRgN 2 :83.60 ' ++5] ,,� 4lf I1-470.011 701-470.011 1.93.01 IIII x_man 1 rff „r, Y, N a S r K ' `".. °R K 6u al C u N u dm h M TP . -zrad� �-- S I -43136 . oG OxM y y , a � Yad:d 6 5 .59 7161 ; 4 i 3 A .., e .� ' u ^ 1_3.9x 2 FOR ORDERS LANDS NDS EfFECBNC 0/SPo MUSE CA UN- d /xN.I n wa s; Ji Y U99 7NI :r - '\. yg �, q - I ILMNAMO LANDS eIINOBAMW FOR CLASS/MASON wS/MASON " mrl � , aw nsxl F7 K !o - a/ bd00 � on ]WI R2aNr / \• K / dP W ~^ \ /f MINERALS WATER AND/O? 00/FR P" /BL /C PURPOSES !v + F p0, me AaY NA Cxl I0-102.21 T W \ � SSE Cool I K6 REFER ro6VOEX MISCELLANEOUS OOCUMENrs ant On I 3.v � 4" mN wN t' "" /c a 713 n Cr,"" e ' . -, ... � i A ssF e mr 1 m vII -.r 0,,,c ��--- u 1 \` r _ _ 1 P -144.93 l �� PL W !11837. n4857-4 n41157-8 4n41157-8 -B / ' -' -f u� x- 134.13 � a-OAO er 7 SO-OS Ore: u sa 7181 +eeea r n , , e -Le4 1 -4x0] PLO 5784 NW L7 affects Le Len : /a not convened 3-5.50 II-meat 7114 .ar aW %c n 9.33] II-meat -meat \ E „ ao a -en 1 L4on Flats NM Fe SEE SUPPLEMENTAL PLAT K6# , ` � stt Fwtl �� I -1.03 +68004 , 4 , J . \ ✓ 1 S0. 1 / so ex 1 MINI - n 4 PL 96 - 487 OW I 1S•19 4 fu r mrr �l p.u/xno I \ IC II)0 sweets K 1017 o3. to E l Res only OO ` a K tar 7 43x95 53x.43 26 r/the 6 usa x161 9 S ia" Only 10 Only II w ' o n t 12 ue l- j .M SO-N-6 K 6J NA l V r/a' WK, a r 11 w SEE SUPPLEMENTAL PLAT R NO. 2 /y Fvn/ 1 do -sr-ono NA- oaf / Oe NA OC NA n ua ne AIT038 2 I 1e 843.67 R+ ' +] 498 a o 673.39 MINI Onl OG SEE SUPPLEMENTAL U PPLEMENTAL PLAT SEE SUPPLEMENTAL PLAT I '55 9tle 1i e i i TOOT -e3d NO. 3 04/ 23-75 1 4; 18 1? 16 15 \ 14 13 �s SSC COO x 8A roaoo o11 dsF PL99 S Fn^r NM /On U E / 1.131 0.y 6C 552.92 •40,54 060., 1_544.62 I sbCf OFM ' 0/C aB \.. 3.v 'Off NO SUPPLEMENTAL PLAT SEE SUPPLEMENTAL PLAT / NO. 5 V88 x810 TORT T6ON EMT 999E RAW -90.00 19 fe:m 20 21 22 2 3 '1 24 6 a - a 007: 50 0MF I I 9, 06' - tr3.p 11 2-30592 ✓ / US$ 7160 J K e u y 5 -169.71 n Emile 1 j K ( _ a. oNy SA F>n/ I - -O AM., 88 ] RO I -0eO,N 90-89 -per LOke l -54133 2-011 a � Y IN31 ma Col I_4A9 o/C a8 01 /c os ow y SEE SUPPLEMENTAL PLAT SEE SUPPLEMENTAL PLAT t la 601 0� NO.6 NO I- 468. 3.r am/ i 'It 30 'z \ v�i' �- 29 28 Ms 6-13.97 8 27 �\ 26 25 ----' \ ('� a -0.16 SS( Ocly K 65/ d6da -09x4 K n/ As.... Stt [sm/ 1 5 -L6o 606 6 .93 A Six 33F[ I 7 \ Mile �^ � 1 3 -OAP' � 4]9.60 • S3. 3 -315.71 V \ �mr C�� u SEE SUPPLEMENTAL PLAT 11 �� S0 N0.6 SEE SUPPLEMENTAL PLAT f� ' � ), Ud4 7004 nI...'" NO.6 1 3.Y aey `. '. 78.96 y 86].05 V43 ]I . ' 3 .4 " (.,L • + _ y 5 071E 5 , , ,,, P 3;8000 N war 31 \ e 'y xas2 \ 7-77190 oi ac r 32 33 34 \ 7-75.9 35 36 so -n -emm 044' r 3 0.03 J NNA CAn � � se- aN \ % an '' XeV K 651 ( 5 t 1 nQ 551 Font SSC Cowl I 3.3E Only K 69 e '6 651 / Lot 6010'33.2" Long 105 '03'45 35 "W SCALE in c00ina CURRENT TO FWS. UT2, Pbx Mer la 0 ' 1 0 ,_ p 0 O P 2 x 05 90,20:. 3..96 el nut an/ Oa. In Road T 20 N I ay 20.no es 1 - 6 - 2003 > 12 E L • SURVEYED TOWNSHIP 20 NORTH RANGE 12 EAST OF THE FAIRBANKS MERIDIAN, ALASKA • STATUS OF PUBLIC DOMAIN LAND AND MINERAL TITLES LISS , M ;sg TP "' A,� 24-22 19 SUPPL SEC 17 VI! , NO 3 FOR ORDERS EFFECIINC DISPOSAL OR USE OF UN- IL 7Z,„, /DE LANDS IMINORARN FOR CLASS/FICA ZION MINERALS WATER AND /OR OTHER PUBLIC PURPOSES REFER TO INDEX LY MISCELLANEOUS DOCUMENTS PL 92-203 OH/ F14857 Las Wy1 FI4857 - -A, F14857 -8 USS 7596 3 -e 01 PLO 5184 OW C/ affects LOs/lnterests not corznejecl s 20 5 PL 96 -487 OW Yukon Rots NOR entire Tp 5000 ''e SW 0 .� �{ NC 1170 corrects /C 1012 as to E t Res only Lam/ � ..w, �o.sfs .a n _ ] -s.2. Nk Cr, TA , -, 13-3,5 sl -s�ieT OM TIM I 1162102 F010669 /( , 7 _rorF ss a 7008 It i 5.0 CNy USS 7006 NA "e r —. - _— — .._ _ 'C cs c av F ssr awy i; _—� �_--- m___� ses- - >r� aaa 111101,614114 ,,,r r 5-293 99 ' ex 126-1536 25-75 44 4-4 50 S. Orrry 5 0 �_` 70 17 \ \\ \ ' � ri NN F r4 � 0 N \�� • L A \_ KB5Y IC 651 S. fang NO .0 SCALE In chains CURRENT TO FWS, UYZ, Ft. Mel _ 7 20 N 1 1 1 1 1 1 eio'ertn.'.4M N U'io. n 41 - 1 -e -2003 N 12 E 0 - • Re: well log and seismic section for USGS well reentry i • Subject: Re: well log and seismic section for USGS well reentry From: Robert Crandall <bob crandall a admin.state.ak.us> Date; Wed, 12 May 2004 12 :10:21 -0800 y �sy w5 a "�K;"'F` F, >' _. 3 - '/ ' ": • . fix �z' t'n'a ;s ^:, a• � E k• ." • "IB 41 4. :tr ia �€�'� . 1 49, +'x ,"'" ;, In?, ro ic..i 4 d f 1 NO 1i • $ f) 11 d 'Wit ..4$I N y a x �', 3 a..k �$ .,t,. It • 9 Thanks Charlie, we agree that your basement pick could be an uncomformity and that regional geology indicates it's an event within the non - marine Tertiary section. Based on your previous shallower core holes, the seismic line you shared with us, and geologic reports from the area there are two prognosis for what this well will encounter; 1) nonmarine thermally immature (lignite bearing) Tertiary to 2200' TVD and thermally overmature Angayucham - Tozitna Terrane from 2200 -2500' TVD or 2) nonmarine thermally immature (lignite bearing) Tertiary to 2200' TVD and Teriary nonmarine sediments of unkown maturity from 2200 -2500' TVD . The occurence of flowable oil in either case is unlikely. The exploratory nature of this well will require monitoring the section for any evidence of hydrocarbons. A continous gas chormatograph log will be required for the well. The AOGCC has other gas monitoring requirements for H2S detectors, Winton Aubert can discuss this with you. Based on the probable nature of the lithologies anticipated for this well, the requirements for an oil spill contingency plan can be waived.. Bob Crandall Charles E Barker wrote: If basement below the Yukon Flats Tertiary basin is the Angayucham - Tozitna Terrane that the aeromagnetic signature suggests it is, then the basement would range from supermature igneous - Mesozoic metasediment complex to supermature Paleozoic sediments (Ro = 4 -5 %) according to data in Johnsson and others, 1999, (USGS DDS -54, Thermal maturity of sedimentary rocks in Alaska: Digital resources). On the other hand, Rick Stanley says that recent gravity modelling by the USGS indicates a basement is several km below Frot Yukon and we will not hit true basement at all in the 2500 ft well we are proposing. We talked with Rick Miller, the geophysicist who ran the seismic data, and what he is calling "basement" is actually just a seismic discontinuity. This discontinuity could be just older Tertiary rocks that are more lithified than above, perhaps another coal zone or a regional flooding surface that some interpretations indicate underlies much of the basin. In the deepest part of the basin to the SW of Fort Yukon, these older Tertiary Rocks may be mature according to burial history modelling. The deepest portion of the basin has not been drilled so it is speculative as to thermal maturity or the oil or gas generation capacity of any source rocks there. Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 Voice (303) 236 -5797; FAX (303) 2363202 USGS Field Cell Phone: (303) 589 -1137 1 of 2 5/12/2004 12:10 PM Re: well log and seismic section for USGS well reentry • Subject: Re: well log and seismic section for USGS well reentry From: Charles E Barker <barker @usgs.gov> Date: Wed, 12 May 2004 13:32:37 -O6O0 If basement below the Yukon Flats Tertiary basin is the Angayucham - Tozitna Terrane that the aeromagnetic signature suggests it is, then the basement would range from supermature igneous - Mesozoic metasediment complex to supermature Paleozoic sediments (Ro = 4 -5 %) according to data in Johnsson and others, 1999, (USGS DDS -54, Thermal maturity of sedimentary rocks in Alaska: Digital resources). On the other hand, Rick Stanley says that recent gravity modelling by the USGS indicates a basement is several km below Frot Yukon and we will not hit true basement at all in the 2500 ft well we are proposing. We talked with Rick Miller, the geophysicist who ran the seismic data, and what he is calling "basement" is actually just a seismic discontinuity. This discontinuity could be just older Tertiary rocks that are more lithified than above, perhaps another coal zone or a regional flooding surface that some interpretations indicate underlies much of the basin. In the deepest part of the basin to the SW of Fort Yukon, these older Tertiary Rocks may be mature according to burial history modelling. The deepest portion of the basin has not been drilled so it is speculative as to thermal maturity or the oil or gas generation capacity of any source rocks there. Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 Voice (303) 236 -5797; FAX (303) 2363202 USGS Field Cell Phone: (303) 589 -1137 1 of 1 5/12/2004 11:46 AM well log and seismic section for USGS well reentry • • Subject; well iog and seismic section for USGS well reentry From: Charles E Barker <barker®a usgs.gov> Date: Wed, 05 May 2004 18:06:25 -0600 e � ; Y ,. : � .,..:.< ..' , $s.a.s:...:w .._.. " ,.G x;N >>`:o-. �=.�K >.a >,. "`eu; :ct ; °.,,;' .s; ".e"` ° ; " : ".._ ,y €.• .• •l sss �l� ,. ` i�"'4 #`d� ;� N. ��.11 �t i`� .t��p 71f . �. .a,<... �_ F' �'�'� fi• . ,' .w ', .i... .<T. •.. F. ",ry;,, 2+.2 n.4 a... < T.;?rx. 'CHI :,3 Hi Bob, I'm sending this powerpoint file to supplement the application for permit to drill for DOI -04 -1A that Art Clark Dropped off the other day. Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 Voice (303) 236 -5797; FAX (303) 2363202 USGS Field Cell Phone: (303) 589 -1137 Content -Type: application/vnd.ms- powerpoint USGS 1994 Well log.ppt Content- Encoding: base64 1 of 1 5/12/2004 12:11 PM Depth Fort Ytikrri Core 1 994` - Feet USGS 1994 0 �, Late Pleist / Holocene Water wells on r• Plei�t° " } - VVeI I Log 100 �' = . � ` . p � -� — Latest P Iiocenel Earliest Pleist.? Mud 230 ft thick 00 " c a.. 4 3 Ma_ (Mid-Pliocene) � 300 = =, -- bass of permafrost • Zan m -_- _ ca. 5.2 Ma (Miocene - Pliocene ,. =:;.r; :. .� Boundary} 400 :4::;.. . 'we % '. 504'1 ; :` =< Latest Miocene Mud 25 ft thick 600 �_:...,$. Mud 20 ft thick `a4 m r., Late Miocene Mud 30 ft thick 700 r m r � . 800 r; ..,:r'.+r:: Wud 160 ft thick seas - _ Early Late Miocene 300 itt - -- _ 1000 w`= ..r:; ____ 11 Ma _.® Mud 200 ft thick 1 - - . -" . 4- Early Middle Miocene Shale 20 ft thick 1281 t Lignite ca. 15 Ma 1240 ft First Coal 1 .... . Fort Yukon Seismic Line Across USGS Core Hole 2025 2050 2075 2100 2125 0 4 44444' _ ___ �_____ __ ___ ____ __ ______ ____ __ ____ ,111 = = = = = ___ ___ ___ __ ___ =111 . To of first coal at 1240 ft from core t o 1 a4a 4414111 1a 111 1 1 1 111 i 11 i U11 1 11111 44 _ 44 1 444 1 1 = 111 1 p g ■ ■ ■■ 4 _ =4 1, 1 11 11 111111 }111 1111111 1 11 11!11= = 4 _, 1 11 .4„,„6911 ,1131111111RIR111ti1111111 1 11 Illlll 111111 11 !/1 RRi {1]Y 7 z . 1 } : � ; S �ISRR�� ej� rll. a 1� 1 )!. #t �� j4 it 1 a�a�zt • •1 � f � 1 2 1 .1(; P , 1�t+ li+ }7 �� •�1l .J 7PS.l 1'� f i , • z _��`� �� ,�a =»ILLL < <� +f +JJJ �1��5 t�1 = =j To of second coal at 1640 ft from seismic {{ 1� yis s1 <s��t� , ��''� �� '�1 �, 1 13'i�Sir��l } < { e�1 <� r �<; • p . «10 :3 1 <s�rz..�7> . ,z�r: &a s :u m itt l tk«+l Alai � .2c�<F1 „5 �u �}nu_ • 10 ff{ f/fft! aii i t ra; 1f }� 2i i{SSY } }77 l 5 ifY `ii g/ )» SX < 1171 I 1S G 5 SS r, J 7J7 �� d� 7 ] } 2 27 � r A1 { iT {� Z� <jFE � it}5 T i� fSt2r7 i5 j 1 �� S j11 ri1311 :` 2 I *) L! u �7 rrp, k } 7 «f �y (Z�t/((<+ i t l7 LrfJ 4 C y 17 4ji 1 f'1�,� } j] { t 5 111131223 ii 01 ?J 77! /� f`+J, , _ a A li, t ii < l1 it i� 2 1 1i } }7 ±'Sf pi 31 < 1 1 w f 1< i S ! 5 • • /�f $ } 1� y l,s> „1�1;1;,�1; t I f 1 ft l l } ,�� » ,12r t1 1 11 Seismic su eats ne coa o 50 �a 2 a. r z ' z zz t <SSS ! -�4 a�� 1-I nnu, }n, ,,, , 99 200 7 in i !F-, 4 ,1 34611163 W aVOTOSMIMMAP v 1 1515 5 » > ?AAA } s� � } 100 4 corin cut 28 ft of gassy coal c# « <<« <1 �5� » �r�n n uul, g . , J t c < r t «I it r r 1 t} ,u « 1 111 « u t t r //a 1 » / 1 1111 i I 1141 1111 1 1 11,1 1 1« ll llt tli, 1 11 , , MRam ,tl ,,,,,,,,r rtt III}} II1 � il tl j l� ' ti iE�!! !t!! !l1� ��1�� I111E 11 f i y�93 , � r ` .4 i(U1 II 1' I i il J 0 • ■ t / l rr I , 411141 } 'I w . j 5.ifiti ;1 11 C t t < t l I .S } ) P)»II ' I ' (rrr( J rr (R « L'Rf g .\ '� • < 1 , ` l ` . l t l ( l) 1 1, ,,, • Immature thermal maturity at 0.3% vitrinite j) flS , t #1, 1111! « I! (1 ��1��1 �� `J �SWIIllitt << 2 � f,121� ,, <,« ■ ( �� a z< � � g }g{.... reflectance [Lignite rank] 400 Ab j H ( / k � i ( / !! ( ! ( ! /; K K<< C! Ctt : �1 5'' ` 11111 , ,})• � 31i � �Sl /} 7 1, •4•S, ]l 1 9t5 � a 4V 11�) } 1 7 }1 11! llll� ,�� I N; IglUt 4 t ( 1l 7/ � , 1 11 1 1 1 1 11 j t r , r Il l]l�l 11 iI i if i } !r( ii ll « gi 111 hail li 1 ti�lilll� 1 1 111 1 11 » } } } 1 i } O 111 l i r rlli i a r t f�CC } A t l <i iii 1 s ii 5i tttn} i i l i ii i n l . ' . PM Pi1 t( 1, I 5 j iil %IJ 1 �i 3 s f�I C(i (< <( 1S, umit 4I I1dIlo,JI I t.1'. . . C 1 t`l I J J. 1 , it l l , 1 SI f I{ c 11 i stil 1 11111 °I t« Detrital coal vitrinite -rich 500 11 11111 " 1Si1 � 21, 11 1: 1911 11� 1� �J �lJ3f hii�d9iumn` L 1�S3�1 ;� i S �«1 " „K „� „ �� } �2t�a.- • f« asa ,, I,l. 1 1 :. , 1 }7 m, m , tut ,,, I uav !d � umua,ua 9' Pa ..) d2d�Qlit rrt1 .d11d�11�JZj 7P�lrin2lEll7nn,S „ 2• ;1 � _ 9 �5 „ ; }) (4. / , . g , z % v � 2 _ ■ very low ash < 0.5 wt. -/ t....i ►� 111l�3l)R Etj X1 � f igid?'S� » >S �1 g 600 , , .... :,:�� s��` �,� / // A 1 }, ; , liTh i_ � _ i ,,, j l =;, : .l �� (;�(1�(( , , << �, ;; - egligible sulfur 4110 I 1y <�,� 1 1 � 1 �� 1, �'1'1�"1,71111i 114 11 t { 111u, 1111a'l�L�`I��ll(l z , : S1 ..� -) 114 „. � f /[ 1(StSI ffl r c « <r! ! !<�c�<c « <li l,l r_ N N\ a j , \\ l�l {�1 /1J , /i11�N... « j ll % . troommogot IJ � ;� �� €,1 11 rili "tat ` �;��' • I ;. , ; 1 1 A 11,1 11 111 lft t Adsorption isotherm indicates coal storage 700 4 4� 1 4 44 114 Sr t Ill) 7 ?7 ]d z 1 U<JI Id ..4 ( 7 111 TIM) \ t to 119p1191319/1111111111 )` 4 11 <G i1 a�� i ii z r r 7771 I M1 j'11 '1 1 t 1 f 1 1 , 111 l l l ! iN a i , ; cle w,1. ?1 1 l lire � ; ? 41 «� III MI! r . I att1� ( .. a) �I ca acit of about 40 scf /ton [a. r. basis] ti l J 1f1 1 ,1 J l l ,,, ,,.,,f, /,1111 p Y .la.: ( : 1' , ... ✓ { t ,1,1, „3.) /1,��f/Jlo'14�1 <tCf<f 1 II I I 4 7 i �I ( l_ iil ilii Ii ili il �i < mn i mi t li , '7 7 iii l il » 11111131}1 \�� f Ii� ar �iiita aoo $ �� s�� . %t ( I I . ( { j l♦ i .J ll.AAIs ; ;IIIIJ.J ,J( I IIS N I 7 1 / 4 ==tfl41}SS IJfi1 11 tSV. 1 14 1 t 4 11!} i 1;�C /!,y)��!'.�/��, l rC«(fl10 f l(t1 l i d , 1,�} • Depth to seismic anomaly interpreted to be 111 5 117)]"" •ill I 1 ,11 11 11111M 1 11 1n ' ;% 11111 7 111 niJiJi I JJJ 4 +1 , i l <i« u i o f in iic � �iti l � aaaaa. 5141..; ��a111� 1 9°C) 1� � )4 �4a g 01111 s � , 1Ps b<� ; � U tS ;,�t;;1 S <,' ] 4SSS S'SSS7411 5 1P 55 3014 415 949 „1, �i f,iillaiS,,,1}I2 basement at 2200 ft 11 «., „ \7511 {{,1 1M15N11011 « 1ma ti 1t «tll ««,,1 ! . ! 1 Il f ((K «< (c(( 7 ff ((< IIIN114 11 11 ) 1! 1 111 Il rim- i r l ��'t lli'S� -`� �� - -5" < t 0 114�i 111101 u 1 11 » i li} � }9} �l Miami {{� �{ 1 } r ! 111 . t [ t « «r «ti( ■!'!$ r' 'lt4tSS(f4lf!!�!t'1! °1 ")`J , .)..:J::�;d�d 9;;1! "�d:.;.:ddd "" Basement conjectured to be Mesozoic like seen at margin of Yukon Flats Basin Re: well log and seismic section for USGS well reentry • • Subject: Re: well log and seismic section for USGS well reentry From: Robert Crandall <bob crandall @admin..state.ak.us> Date: Wed, May 2004 12:33:26 -0800 ±+ a x„ & a. L; . .£ , Charles; We need $100.00 to process your permit to drill. BC Charles E Barker wrote: If basement below the Yukon Flats Tertiary basin is the Angayucham- Tozitna Terrane that the aeromagnetic signature suggests it is, then the basement would range from supermature igneous - Mesozoic metasediment complex to supermature Paleozoic sediments (Ro = 4 -5 %) according to data in Johnsson and others, 1999, (USGS DDS -54, Thermal maturity of sedimentary rocks in Alaska: Digital resources). On the other hand, Rick Stanley says that recent gravity modelling by the USGS indicates a basement is several km below Frot Yukon and we will not hit true basement at all in the 2500 ft well we are proposing. We talked with Rick Miller, the geophysicist who ran the seismic data, and what he is calling "basement" is actually just a seismic discontinuity. This discontinuity could be just older Tertiary rocks that are more lithified than above, perhaps another coal zone or a regional flooding surface that some interpretations indicate underlies much of the basin. In the deepest part of the basin to the SW of Fort Yukon, these older Tertiary Rocks may be mature according to burial history modelling. The deepest portion of the basin has not been drilled so it is speculative as to thermal maturity or the oil or gas generation capacity of any source rocks there. Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 Voice (303) 236 -5797; FAX (303) 2363202 USGS Field Cell Phone: (303) 589 -1137 1 of 1 5/12/2004 12:33 PM MAY -24 -2004 MON 04:05 PM BLM ENERGY & MINERALS FAX NO. 907 267 1304 P. 02 IIAY -21-04 FRI 1024 AN fA GEOLOGICAL SURVEY FAX NO° 451 P. 02 4, MAY-12 WED 09:38 API 611 ASUS FAX N0. 1907 19706 P. 02 (,,\- =,` °� DEPARTMENT OF THE AIR FORCE ‘4 i:7,,,,,or,.. PACIFIC MRFORCIS MAY 52 4 Colonel Steven,. Mods 611 ASO /CD 1047120th St Ste 361 Btroendorf Af AK 995M-2200 Mx. Jim Clough Depatintem of Natural Resources Division of Geological & Geophysical SutileYe 3354 College Rd • Fairbanks AK 99709.3703 Dear Mr, Clough We rt celved yOUT letter Tequastias support at port Yam Long Range Radar site. We Initially support, your request to access the site with the below stwalstions regarding your additional requests. However, a holonsaranthun of A.greeanet t needs to be completed before work eau begin. is Due to lack of lodging in the community, you may stay at the radar d mission site Mr Force avaxlablo and do tot dictates otherwise. You must for your lodging and meals of a rate of $106 per day, p p � person. We will need to know w the Please number ol"inc4ividc,als staying per night, so arrangemattt,a on 1 rat t;areitngly, contact Mr. Nick Hilton at (907) 552.4400 for reservations and payment A short- t'erni work ape of approximately 10° X to' for your desorption tanks storage will he provided during exploration through the summer months, but must be removed prior to winter, You will need to obtain an aut grant from the Air Voter; for the temporary use of this space as well as for spy needed for any equipment left, of the sib through the winter. Me_ Maly Adams at (907) 552 -5226 will assist you with this prooes,t. We roust decline your roquoet for equipment use and waste materials s (b nite, polymer and borehole cuttings) di oat to the radar site's landfill. We soggiest te g equipment the local cos n wity and using the local lsndtilL MAY -24 -2004 MON 04:05 PM BLM ENERGY & MINERALS FAX NO, 907 267 1304 P. 03 MAY -21-04 FRI 10 :24 AID OKA GEOLOGICAL SURVEY FAX NO. 451 P. Q MAY -12 -2004 WED 09:36 AN 611 ASS FAX NO. 1907 9706 P. 03 z your o' ocT• Ply coritirtuc welting with Mr- Hilton 1br any c bast on 4 pr J Wo wish you � y &lure ao»coTns ox i Sint/ rely STEVR t J MOBS, Colony'. Ulm Deputy t aridel 611 CZS /CBCR • • NOTE TO FILE DOI -04 -1A These maps show the proposed location for the DOI -04 -1A well; SW,NW Section 16 T20N R12E Fairbanks Meridian is on Air Force controlled land. As of 5/18 I have requested more current documentation of the current land status from BLM. Due to the stratigraphic test designation for this well, correlative rights and spacing concerns do not apply to this application. S /.2. f ir A w ,../ A rt re2401 t� direeed,ef-04 1 4- +h./ .1 '/- $ 7/s" 640 Ad 0) 4e41"'ed-r. .14:4•GireP / .11j4m4111 ,f 7117 i G ill ! �o i G . y \ U �U o O ---' v \ z j D v v ;r_ ' C` . ; o a o o ► �. - Q { C a Cabin < f � , � I' fit' - 0 1 c o 00 ,L._ 0, o co . . o o • 0 0 0 L-4 o o , ° p i g S' Kti'' ( 0 i� —,, ° �' � � � � �F:c =� entee , . : .= o� `i, Q co) C c, ° t fflfl JJ dh 1c , L 2_( . R 16 J ` � oco . o o ° � E �;� ' t' . 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V j ki4D — � / . .L .. b n 'd) .,,\., p r � � �D D J� 528 j : �* -,.'1 _ 4 A • �� '.� t l �-� f �` � p's) � ti _ Paz I 1 "" �o ti� (. , _ 1 l\ / r�, �t? l ` . _ 1 j'; , ( 41,7770. Via^ . \161 C ■ .n nU _ /" r �© C , »"_. 1 l i 1 I \ / • - - --- , '...,..., . 11 I I '; . • . 11 "I r • . fi ------------- ' 11 1 ` "\ CAW R - . . . • . . . . . . . . . . 11\ 4 . . . . . • „ . . . - -- 4 ' - - - 17 . . ,___ _- 4 / it 1 . . . , __.4- . - - - -- I , _ - i HOS MT A L LA K E I -....-....,,t , i ) i CM 853 , 1 _ __ _ • i ?., ILIVI A 1 A 02.. 75946 I , 1 l i ; .*;," 1 .9 S o' ED 8 , - 1 1 \ ..... • , ...• -. • • . ....,..• .• ... ...• .,........... ' te I li HOSPITA L LA • FO RI '(1.114h1 il:1Ni GIPP. L A IR IVT I . \ h i" .,, OSL st.Mi 051_,,85.3 - ..-,... 4., ..... I ...,,,. , ' , , , 1 1.:1,1NO_N-ILISAF:SHORAW-Taym7R-4—/ - : . - --'-- ' FORT YUKON 'Y'Y' B.A SE _ _ 1 - i i : --- 0_ ( - - -- 1 3/4 , - C7 L '=. , 6? -.---- '1, 2 - 1_94 Aet • * 103-0 ..."; iC-k* c. a 4==.- . • o ss 7 16.1 j \ . . ‘ - CO.i 4 _ , ISL-4 7-7 .41P"- - 0 1 I - - --sz.."''' ' ■1 =._.„7. - • I - ----- . . . . .... . . . . . . . • . . 18 .., '. 1 ' 1 ,r:.7 Of 1 Screenshot from LASMapper for FO2ONO12E , . „...! - i 7 Lse,- i's' Note image from Federal Master Title Plat super-imposed ,_ ....„ , for Section 16. Federal land status does not show on plat in I, ) ) i8 May 2004 \'-- - areas with no state interest. Neither does private land that '‘I 1. by: S. M. Weens is not conveyed through the state. lira. ' --- ONR/LRIS/GIS, 1 16 ' :; \ T]ON }I ,..1:!, `II 1 5 T I 1 . 4 °n.f iP t �. - -- ASBESTOS CELL ( I ( .: _ .. tEAl1.iG r OISSTANC[ ' • 4NT' - A to B COURSE r BN ] Al 53 E ( 20.00' B., ) . A ' aA .. iNM R -444.44444" i I � �� ', 1,w D to A yN .' 2a ` ' w � , 1 K ' I JOSEPH C. BURGH I r F � '1 24 j/ I//I n ', , , } REGSTRATON No. 2237 -S r v p•,, � • T - . ,'...% DATE .Irr2 ._ .......... _ II I USES FORT YUKON (C -J). 1971 SCALE: 1' 4 1 114Ej I VICINITY MAP 44 7.- 07 = _ _- 31 • W` -3 1 y 17.3...;* 1I 9!a$( 17.3...;* LANDFILL 1 X L C -1 440 tj ` 4 l' Q C NOTES 5TA 'f1 YUKON sr AY � ASBESTOS CELL LOT 69' 33' 3409048 N Y• I,� D 1. 045 SURVEY DOES NOT CONSTITUTE A SUBDIN5IGN AS DEFINED LONG 143' It 44.31824' W 4 1 BY A.S. 4015.190(2). (400 83) C -3 872. 2. THIS SURVEY IDENTIFIES THE LOCATON Of A SOLD WASTE LANDFILL �1 N n' If' T1. `C -N AUTHORIZED BY ALASKA DEPARTMENT OF ENNRONIIENTAL CORISERVATON ® '1 _ - L. W Z PERMIT NUMBER 8631 - 80008. 6,. L C -1. L - 3. UNLESS OTHER'MSE NAIAD, ACCESSORIES FOR ALL MONUMENTS RECOVERED N 99' 19' D9.W W 11449J(Y) :, 8 -7 B 1!751' W UNLESS ARE AS DESCRIBED IN TIE ORIGINAL HELD NOTE RECORDS OR PLATS. 0. 4. THE BASS Of COORDINATES IS A LOCAL ORM ESTABLISHED BY THE CORPS £ OF ENGINEERS ON STA 'FT YUKON WS AZ'. 100,000 N AND 100,000 E. 5. THE BASIS OF BEARING IS TIE CORPS OF ENGINEERS LOCAL SKID BEARING \ \ _ BETWEEN 5TA TT YUKON WO AZ' AND 'FT YUKON W OF N 73' 09' 37.9' W. • EA oC018T ' DEL • 0 I1 OSB . Le.L e By DATE E SK SURVEY. E AND .0 Ap LEGEND • 4 4A1 21 1094 ON INS C OPERA lOSS SQUADRON —_ Ending 9 1941 FL ME"DORF AFB, AK 99509 -4420 ® USC&GS MONUMENT RECOVERED e SET 2' ALCAP ON 5/9" K 30' DRIVER00 ,\ E. CAUTION RECORD OF SURVEY • ASBESTOS CELL MARKER (CORNERS ME 204 POSTS 16/5I010 ASBESTOS WASTE DISPOSAL SITE BE AOEC PEW! N. •W -BMM. LOCATED 010(05 — — LANDFILL LIMITS DO NOT CREATE DUST SW1 /4 NW1 /4 — ASBESTOS FILL LIMITS Cl CO NOT DIG IN THIS AREA I (PROTRACTED) SECTION 16 BREATHING ASBESTOS MAY BE TOWNSHIP 20 NORTH, RANGE 12 EAST, (M) - MEASURED (c> - COMPUTED 7993 HAZARDOUS TO YOUR HEALTH FAIRBANKS MERIDIAN, ALASKA (REC) - RECORD FAIRBANKS RECORDING DISTRICT J, TYPICAL TYPICAL I BY SCA LE C HECKED BY 1 FILE M0. I MONUMENT MARKING ASBESTOS SIGN l DRAWN Ra 1 AUG 03 1 30' I J Fairbo..drs .26,0i -vs Re: Section 16 • Subject: Re: Section 16 From: Beth _ Maclean ak.blm.gov Date: Fri, 21 May 2004 12 :22 :41 -0800 To: Robert Crandall <bob c adall @adinin.state.ak.us I have the the records that state that the subsurface in the military withdrawl remains under the jurisdiction of the Department of the Interior, as well as the Interim Conveyance of the rest of Section 16 to Doyon (subsurface) and Gwitchyaazhee (surface). What is your fax number? I don't have electronic copies. Beth ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Beth Maclean Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 -1304 Robert Crandall <bob crandal lx%admin . s To: Be i Maclean@ak.blm.gov tate.ak.us> cc: Subject: Re: Section 16 05/21/2004 09:16 AM Beth; Anything to report on this? We'd like to move the drilling application on. Thanks Bob C Beth Maclean@ak.blm.gov wrote: If I may add, the split with USS 7161 is the contraction of the old US Air Force Due Line radar site. The outside line is the old boundary. The inside line is the new boundary. The difference between the two has been or is in the process of being conveyed to the village of Ft. Yukon. We have had meetings with the Village, as well as Doyon and they are in support of this project. ***** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** 1 of 3 5/21/2004 1:45 PM Re: Section 16 Beth Maclean • • Geologist Bureau of Land Management Energy Minerals Branch 6881 Abbott Loop Road Anchorage, AK 99507 907 - 267 -1448 Fax: 907 - 267 -1304 "Charles E Barker" To: Robert Crandall <bob crandall@admin.state.ak.us> <barker@us9s.gov> _gov> cc : acl.ark@u.sgs_gov, karen clautice @dnr.state.ak.us, "Jim Clough" <jim@dnr.state.ak.us>, Bob Fisk@ak.blm.gov, Beth Maclean @ak.blm.gov 05/19/2004 06:22 Subject: Re: Section 16 AM Its a part of an old Dew Line radar station and it still is a US Air Force owned section. We have permission to drill from them. Charles E. Barker, Ph.D. U.S. Geological Survey Denver Federal Center Building 20, MS 977 Sixth Ave. and Kipling St. Denver, CO 80225 Voice (303) 236 -5797; FAX (303) 2363202 USGS Field Cell Phone: (303) 589 -1137 Robert Crandall <bob crandall@admin.s To: Charles E Barker <barker@usgs.gov> tate.ak.us> cc: Subject: Section 16 05/18/2004 06:29 PM Charlie; 2 of 3 5/21/2004 1:45 PM Re: Section 16 Our records show section 16 is divided into two ro ertie• USS 7161 A A includes where you want to drill. Who owns 7161? Who owns the rest of the section? Let me know soon, I'd like to pass this application on. Thanks Bob C 3 of 3 5/21/2004 1:45 PM MAY -21 -2004 FRI 02:55 PM BLM ENERGY & MINERALS FAX NO. 907 267 1304 P. 01 • • United States Department of the Interior • BUREAU OF LAND MANAGEMENT q BRANCH OF ENERGY CH 3 6881 ABBOTT LOOP ROAD ANCHORAGE, ALASKA 99507 -2599 FAX from DIVISION OF ENERGY AND SOLID MINERALS BRANCH OF ENERGY Telephone Number: (907) 267 -1246 MAIN FAX Number: (907) 267 -1304 DATE: 5/21/04 TO: Bob Crandall FAX 907 - 276 -7542 SUBJECT: I Section 16 FROM: Beth Maclean COMMENTS: If you have any questions about the information please call Melissa Ainsworth, Land Law Examiner at 267 -1212. Number of Pages (including cover page): 15 ORIGINAL DOCUMENT TO FOLLOW IN THE MAIL: YES X NO If you have any questions or if this FAX is received incomplete, please call 907- 267 -1448. MAY -21 -2004 FRI 02:55 PM BLM ENERGY & MINERALS FAX NO 907 267 1304 P. 02 SL �' /J tf ' ? ftx1/41 e 3 o f - � ) A°, - 4 l / , 04;; i , ,� Al ' p co r44_ Pig F-Ks - diva ki0, a. :( 487/04, 4 ',rc> r " ..1 , 1,: 1638 , 71. even* A f. nr 4,,M/ /. / �' � , , -i� i Order NO. 10355 of May 26, 1052, !t Ls r f tv` 'BI I ; Ordered as follows: ''s r '"T Subject to valid existing rights, the '"Ie'I following- described public lands in Alas- ;0 Af.ASK Y f1T 7 : t,t, A ka are hereby withdrawn from all for s ,i f .1`,¢'i � nonce 07' PROPOSMD wrrfiDRAwAL AND of appropriation under the public land , i },> { I linivATION Or LANDS laws. including the mining and the rain- I q .YANITARY 2S, 1855. era!- leasing laws, and reserved for use 6 ' of the Department of the Air Force for s5 An application, serial number Anchor- military purposes; 'y , l i 1 age 012027, for the lthdrawa ' from all ,, a;:: fortes of appropriation under he publla PA■ No. 1 Oo„ �f Beginning at a point on the bank of an r ,, ,L, • s land laws, including the • loin; and unearned slough of the Yukoe River. w.lu . � '�`•ktt ' .; Mineral leasing laws of th lands de - point being B. '7E30' W., 1540 feet from Port ,; ' i , , scribed below was }fled on r .comber 30, Yukon West Base Azimuth Mark. $ltUf.Wd M. W, 1954. by Department of t • e. Air Force Latitude 88 30.313" Nort an Longitude fa � ': , ,i pr posed with- 11b" 17'34.977" went; thence North 700 fort: The purposes of the Y ' . � it F1d • drawaI: Classifi multa • purposes. t hence Ewa 1640 feet; thence North 800 fret; , , For a period of 60 day from the date thence East 268o feet; thence South 2b00 ' d Of publication of this otice, persons ° having cause to Object o the proposed feet: thence Went 2.4O feat more or Leas, to i�, ;� 4 the right bank of the aforesaid slough: i tt r ,tl.rr ' ;., thence northwesterly along the sight banbank �i !r withdrawal may presen their obiectlons or the slough to the i Jn writing to the lteglo , al Administrator, point of beginning, The are described contalne approxi- , 7 of Area 4, Bureau of nd Management, z'u a 1 ° , v, Department of the I rior, at Anchor- mately 190 acres. '� c � ' age. Alaska. In ea any objection Is � ' f;(° '' PA RCEL No 2 r , r`,,,, flied and the nature of the opposition i9 F, Inls 7 snag. Block 14, and Lot 1. Block 2b, 1 s . such as to warrant t a public hearing :-'1 the Fort Yukon, T and e, U. B. Burney ° t ti w be held at a onvenicnt time and No. 27e t; ,, : . ill place, which will , announced, where - i ' ' � opponents to the •rder may state their ( The area described contains 0.86 acre. a i1r i r / ..i ' can explain its p rpose, views and where oponents of the order r � withdrawn minerals in the lands shall remain under the jurisdiction of the De- , '' .1 It is the intent of this order that the '`' ■ � .� The determine ion of the Secretary on 3 ac C ti ''t � the application 111 be published in the "1 partment of the Interior and no disposi- , I ■ FED[AAL RgG18T' , either 1n the form of 0, ,6-, lion shall be made of such minerals , `' Lp, except under the applicable public land , '" public land or er or In the form of a is.: i .� mining and Mineral-leasing Saws, and Notice of bete !nation If the applies.» r � rM "�:` lion la rejecte.. In ei ther case, a sem- mil' then only after such modification of the / r Previsions of this order as may be neees� rt';, fi , rate notice wll be sent to each interested Bury to permit such disposition. . ,6 party of ret~o - 1� The lands volved in the application ,- } IATrrel,p CHIL$OH, ` a1i l Assistant Secretary of the Interior. � . Parcel No 1 Beginning at R point nn the MARCH l; 1DJ ly, is bank of an named 'slough of the Yukon , f 'I R jF . R. Doc. 67 - 1911: Filed. ]liar. 13, 196 ' it River said po It being 8. 70' 90' W. 1,640 foot 0:40 a. in .1 I ., 1 . front Port Y kon West ruse Azimuth Mark, ` situated at tltude 66° 33' 3U,:1I3" Norm A " _';'' and Longlt a 146' 12' 34.027" Went; thence w. , 'I North Teo f .t; thence FAA 1,840 tent; thence ' r4i #. ?,'+� North 800 f et; thence Ewa 2,580 feet; thence +. {1 ' , ' booth 2. feet; thence West 2,840 foot more 4 °, . ,141 , ,i r ` or lees, to the right bank of the afrrrensid "4 • slough: t .nce northwesterly etyma the right � "" bank of t e slough to the point of beginning, L lr i ,:'s: i 'The are described Dont /dos 00 acres, mor am V ti � or l, '' Faroe No. 2, All of the plotted f undo- ' ( t d ' rein; Lets and 6. Block 17, and l.nt 1, r o it � / t, l...� } D iwlt ' , of the Fort Yukon Tfnse. 17. a. " ` °' e , Burro No . 7700, The a rea contain,► 0.06 acre. ;k pl' " " ;i r •, X435'' If %ROr,p T. JORarbsoff, , '; • Acting Area Administrator. ` � r • N'. A. PM 50-046; Fllao, i"Eb. 1. f966; T k S, 11:46 R, m. j � ` tl iav�y'- , + P S ,f ' ' > + pl r ti , t : n " -� , 4 c 4 F , i , � s n+ s , � a y�,. .. ,.... ..r. i , . ,, .., P i , r ,c,� i J l „ 1I',�t, �- a.: 'I ''' ., � ft , A.xm,.0 r. „0 . .r MAY-21-2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO. 907 267 1304 P. 03 • I • • F- 14857 -A • F- 14857 -8 • INTERIM CONVEYANCE • WHEREAS - Doyon, Limited is entitled to a conveyance pursuant to Seca, 14(f) and 22(i) of - the Alaska Native Claims Settlement Act of December 18, 197'1 (43 U.S.C. 1601, 1613(f), 1621(j)), as amended, of the subsurface estate reserved to the United States, in the hereinbelow identified interim Conveyance of the surface estate in the following described lands: . Interim Conveyance No. J • Fairbanks Meridian, Alaska (Unsurve� red) • T. 20 N„ R. 9 E. Seca. 1 to 12, inclusive; ' Sees. 13 and 14, excluding Native allotment F- 13401; Seca. 15 and 16; Secs. 17 and 18, excluding Native allotment F- 025732 Parcel Al - 5ec. 19; Sec. 20, excluding Native allotment F- 025732 Parcel A; Secs. 21 and 22; Sec. 23, excluding Native allotment F- 13401; . . Sec. 24 excluding Native allotments F -13401 and F- 031966; . Secs. 25 to 36, inclusive, Containing approximately 19,363 acres, - T. 22 N. R. 9 E. Seca. U.S. Survey No. 5220; • Seca. 34, 35, and 36,,excluding U.S. Survey No. 5220. . Containing approximately 1,041 acres. • T. 19 N., R. 10 E. Secs. 1 to 6, inclusive; Sec. 23; Sec. 24, excluding Native allotment F -14045 Parcel A; Sec. 25, excluding U.S. Survey No. 6992 and Native allotments F -14045 Parcel A and F -13738 Parcels A and S; Sec. 26; • Sec. 36 excluding U.S. Survey No. 6992 end Native all F -13738 Parcel A. • Containing approximately 6,722 acres. T. 21 N., R. 10 E. . es, and 2; • Sec. 3, excluding Native allotment F -14043 Parcel A; Sec. 4, excluding Native allotments F -14043 Parcel A • and F- 025733 Parcel 8;' Secs. 5, 6, and 7; Sec. 8 excluding Native allotment F -14049 Parcel S; Seca. 9 to 15, inclusive; Sec. 16. excluding Native allotment F- 13446; • Sec. 17, excluding Native allotment F -14043 Pareel•S; Secs. 18 to 23, inclusive; • Sec. 24, excluding Native allotment F- 13700; . • Interim Conve enae No. - 65 2 Date MAC 241983 MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO, 907 267 1304 P. 04 IC_0652_002.djvu • • F- 14857 -A F- 14857 -8 . Secs. 25 to 29, inclusive; Sec, 30, excluding Native allotments F-14722 and•F -14723 Parcel B; Secs. 31, 32, and 33; Sec. 34, excluding.Native allotment F -14776 Parcel 0; • Sec. 35, excluding Native allotment F- 17760; Sec. 36. Containing approximately 21,103 acres. T.20 N. N. 11 E. • e , etc u ng ative allotments F -14712 Parcel A and F- 025741 Parcels B and C; Secs. 2, 3, and 4; Secs. 5 end 6, excluding Native allotment F- 025731; Secs, 7, 8, and 9; See. 10, excluding Native allotment F- 136931 Sec. 13, excluding Native allotment F- 025733 Parcel A; Sec. 14; Sec. 15 excluding Native allotment F- 13693; • Secs. 16 and 17; Sec, 18, excluding Native allotment F.17789 Parcel B; Secs, 19, 20, and 21; Sec: 22, excluding Native allotments F -14045 Parcel B and F-13448 Parcel s; Sec. 23, excluding Native allotment F -13448 Parcel B; Sec. 24, excluding Native allotment F -14712 Parcel B; Sec. 25, excluding Native allotments F -13540 and F -14712 Parcel B; . Sec. 26, excluding Native allotment F -13448 Parcel 8; • Secs. 27 to 35, inclusive; Sec. 36, excluding Native allotment F- 14710. Containing approximately 15,280,acres. T. 19 N. F, 12 E. • es c. 1.excluding Native allotment F- 13695; Sec. 2, excluding Native allotments F -13695 and F- 13740; Secs. 3 to 10, inclusive; Sec. 11, excluding Native allotments F -13740 and F- 13695; Sec. 12, excluding Native allotment F -13695 and those Lands formerly within Native allotment F -17789 Parcel A; Secs. 13, 14, and 15; Sec, 16, excluding Native allotment F -17789 Parcels A -1 and A -2; Secs. 17 to 33, inclusive; Sec. 34, excluding Native allotment F- 13702; Sec. 35, excluding Native allotments F -15501 Parcel b and F- 13702; See. 36, excluding Native allotment F -13701 Parcel. B and those lands formerly within Native allotment F- 13702. Containing approximately 27,558 acres. T. 20 N., R. 12 E. Sec. 1; Sec 4, excluding Native allotments F -13699 and F -13520 Parcel A; interim conveyance No. 652 Date MAY 2 4 1883 2 MAY -21 -2004 FRI 02:56 PM ELM ENERGY & MINERALS FAX NO. 907 267 1304 P. 05 Iii1 4111 IC_R652._,,.003 . djvu F- 14857 -A F- 14857 -8 R • Sec. 5, excluding Alaska Native Claims Settlement Act Sea, 3(e) application F -73257 and Native allotment F- 13531; Sec. 6, excluding Native allotments F -13531 and F -14712 Parcel A; Sec, 8, excluding the following described lands: U.S. Survey No 2760A and 8, U,S. Survey No. 3191, U.S. Survey No. 4999, Alaska Native Claims Settlement Act Sec. 3(e) applications F -79257 and F- 73259, and Native allotment F -13542 Parcel 8; Sec. 9, excluding Alaska Native Claims Settlement Act Sec. 3(e) application F -73237 and Native allotments F. 13699, F- 13547, and F -13520 Parcel A; • Sec. 14, excluding Native allotments F -13741 and F- 17157; Sec. • exclu ing the o wing a cribed lands: U.S. Survey No. 2760A and 8, U.S. Survey No. 3639, U.S. Survey No. 4310, U.S. Survey No, 4387, U,S. Survey No. 4396 (Native allotment F- 010702 Parcel 1), Public Land Order 1396, Public Land order 1996, Alaska Native'Claims Settlement Act Sec. 3(e) • applications F -35322 and F- 73257, and Native allotment F- 035317; Sec. 18, excluding the following described lands: U.S. Survey No. 1251, U.S. Survey No. 2122, • U.S, Survey No. 2263, U.S. Survey No. 2641, U.S. Survey No. 2760A and B, U.S. Survey No. 4073, Public Land Order 1396, and Alaska Native Claims Settlement Act Sec. 3(e) application* F- 74051 and F- 73258; Sec. 19, excluding Native allotment F -14770 Parcel A; • Sec. 20, excluding Native allotment F- 14724 Parcel A; Sec. 21; sec. 22, excluding Native allotment F- 14732; Sec. 23, excluding Native allotments F -14732 and F- 13741; Sec. 24. excluding Native allotment F- 13741; Secs. 25 and 26; Sec. 27, excluding Native allotments F- 14732, F- 14777, and F- 029786 Parcel S; Sec. 28, excluding Native allotments F -14777 and F -14811 • Parcel A: sec. 29, excluding Native el1otments•F -14724 Parcel A and F- 14718, and those lands formerly within Native allotment F- 029786 Parcel A; Sec, 30, excluding Native allotment F -14718 and those lands formerly within Native allotment F- 029786 Parcel A; • Sec. 31, excluding Native allotment F•14710; Secs. 32 and 33; sec. 34, excluding Native allotments F -14777 and F- 029786 Parcels A and 8; • Interim Conveyance No. 652 - • Date MAY 24 1983 • 3 MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO. 907 267 1304 P. 06 IC.- 0652_004 . djvu F- 14857 -A F- 14857 -B • • S. 35, excluding Native allotment F- 029786 Parcels A and 8; Sec, 36. Containing approximately 12,504 acres. T. 21 N. R. 12 E. .Secs. r Co 7, inclusive; Sec, 8, excluding Native allotments F -16245 and F- 022797; - Sec. 9 excluding Native allotment F- 022797; Secs. f 0 to 15, inclusive; Secs. 16 and 17, excluding Native allotment '- 022797; Sec. 18; Seca. 19 and 20, excluding Native allotment F- 14787; Secs. 21 and 22, excluding Native allotment F- 14735; Sec. 23 excluding Native allotment F- 14731; Secs. 24, 25, and 26; Sec. 27, excluding Native allotment F- 14735; Sec. 28; excluding U.S. Survey No. 6977 and Native allotment F- 14735; Sec,"29, excluding ,S. Survey No. 4301. U.S. Survey No, 6977, and Native allotments F- 13537 and F- 13528; Sec. 30, excluding Native allotments F -13259 and F- 16290; Sec'. 33, excluding U.S. Survey No. 6977 and Native allotment F- 13734; • Sec. 34; Secs. 35 and S6, excluding Native allotment r-13539, • Containing approximately 18,738 acres. T. 18 N., R. 13 E. Secs. 1 to 6, inclusive; Seca. 7 and 8, excluding Native allotment F- 14815; Secs. 9 to 27, inclusive; Sec. 28. excluding Native allotment F -13701 Parcel C; Seca. 29 to 36, inclusive. Containing approximately 17,197 acres. T. 20 N., R. 1$ ud Sec. i, eo. ng'Native allotment F- 025741 Parcel E; Secs. 2 and 3; Sec. 4, excluding Native allotments F- 025741 Parcel D and F- 025740; See. 5, excluding Native allotment F- 025741 Parcel A; Secs. 6 to 11, inclusive; secs_ 17 to 20, inclusive; stc. 29, excluding Native allotment F- 14719; Secs. 30 and 31. • • Containing approximately 10,878 acres. • T. 22 N. R. 13 E. re and 36. • Containing approximately 2,380 acres, Aggregating approximately 142,764 acres. • Excluded from the above - described lands herein conveyed are the submerged lands, up to the ordinary high rater mark, beneath Interim Conveyance No. 65 2 Date MAY 24 1983 • 4 MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO 907 267 1304 P, 07 IC„0652_005.djvu • F- 14857 -A F- 14857 -B a all water bodies determined by the Bureau of Land Management to be navigable because they have been or could be used in connection with travel, trade and commerce, Those water bodies are identified on the attached navigability mays, the original of which will be found in easement case file F- 14857 -EE. NOW KNOW YE, that there is, therefore. granted by the UNITED STATES OF AMERICA, unto the above -named corporation the subsurface estate in the lands above described; TO RAVE AND TO HOLD the said estate with all the tights, privileges, immunities, and appurtenances, of whatsoever nature, thereunto belonging, unto'the said corporation, it$ Successors and assigns, forever, THE GRANT OF THE ABOVE - DESCRIBED LANDS I5 SUBJECT TO all the easements and rights -of -way reserved in the aforementioned conveyance of the surface estate, and to valid existing rights therein, if any in the said subsurface estate, including but not limited to those created by any lease (including a 1eaae issued under Sec. 6(g) of the Alaska Statehood Act of ,Inly 7, 1958 (48 U.S.C. Ch. 2, Sec. 6(g))), contract, permit, right -of -way, or easement, and the • right of the lessee, contractee, petmittee, or grantee to the complete enjoyment of all rights, privileges, and benefits thereby granted to him. IN .WITNESS WHEREOF, the undersigned authorized officer of the Bureau of Land Management has, in the name of the United States, set his hand and caused the seal of the Bureau to be hereunto affixed on thin 24th of May, 1983, in Anchorage, Alaska. • UNITED STATES OF AMERICA \i; 4 ;:t9" . Acting Assistant to the State Director for Conveyance Management • Interim Conveyance No. 652 Date • NAY 2 4 1283 • 5 • MAY -21 -2004 FRI 02:56 PM BLLN ENERGY & MINERALS FAX NO. 90 267 1304 P. 08 IC_0651_001.c1jvu • • • • F- 14857 -A , ' , F- 14857 -8 • • INTERIM CONVEYANCE • • WHEREAS Gwitchyaazbee Corporation • is entitled to a conveyance pursuant to Secs. 14(a) and 22(j) of the Alaska Native Claims Settlement Act of December 18, 1971 • (43 U.S.C. 1601, 1613(a), 1621(j)), as amended, of the surface estate in the following described lands: Fairbanks Meridian, Alaska (Unsurve�edl • T. 20 N, R. 9 E. Secs. 1 to 12, inclusive; • Secs. 13 and 14, excluding Native allotment F- 13401; Secs. 15 and 16; • Secs. 17 and 18, excluding Native allotment F- 025732 Parcel A; • Sec. 19;. Sec. 20, excluding Native allotment F- 025732 Parcel A; Secs. 21 and 22; Sec. 23, excluding Native allotment F- 13401• Sc e. 24, excluding Native allotments F -13401 and F- 031966; Secs. 25 to 36, inclusive. • Containing approximately 19,363 acres. T. 22 N. • e 5 and 26, excluding .S. Survey No, 5220; Secs. 34, 35, and 36, excluding U.S. Survey No. 5220. • Containing approximately 1,041 acres. • T. 19N R . 10E s to nc u$ ive; • Sec. 23; Sec. 24, excluding Native allotment F -14045 Parcel A; • Sec. 25. excluding U.S. Survey No 6992 and Native allotments F -14045 Parcel A and F -13738 Parcels A • and 8; Sec. 26; Sec. 36, excluding U,S. Survey No. 6992 and Native • allotment.F -13738 Parcel A. Containing approximately 6,722 acres. T. 21 N., R. 10 E. • Secs, 1 and 2; Sec. 3, excluding Native allotment F -14043 Parcel A: • • Sec. 4, excluding Native allotments F -14043 Parcel A and F- 025733 Parcel B; Secs. 5, 6, and 7; • Sec. 8 excluding Native allotment F -14043 Parcel B; • Secs. 9 to 15, inclusive; See..16, excluding Native allotment F- 13446; Sec. 17 excluding Native allotment F -14043 Parcel 8; Secs. 18 to 23, inclusive; Sec. 24, excluding Native allotment F- 13700; Seca. 25 to 29, inclusive; Sec. 30, excluding Native allotments F -14722 and F -14723 • Parcel 8; Secs. 31. 32, and 99; • interim Conveyance No. 651 Date MAY 241883 MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO. 907 267 1304 P. 09 111, IC_ • • • F- 14857 -A F- 14857 -8 • • Sec. 34, excluding Native allotment F -14776 Parcel D; • Sec. 35, excluding Native allotment F- 17760; Sec. 36. Containing approximately 21,103 acres. T. 20 N_, R. 11 E. 3e77 excluding - Native allotments F -14712 Parcel A and F- 025741 Parcels B and C; Seam, 2, 3 and 4; Secs. 5 an d 6, excluding Native allotment F- 025731; Secs. 7, 8, and 9; Sec. 10, excluding Native allotment F- 13693• Sec. 13, excluding Native allotment F-025733 Parcel A; Sec. 14; Sac. 15, excluding Native allotment F- 13693; Secs. 16 and 17; Sec. 18 excluding Native allotment F -17789 Parcel B; Secs. 19, 20, and 21; • Sec. 22, excluding Native allotments F -14045 Parcel B and F- 13448.Parcel B; Sec. 23, excluding Native allotment F -13448 Parcel 8; Sec. 24, excluding Native allotment F -14712 Parcel B; Sec. 25, excluding Native allotments F -13540 and F -14712 Parcel B; Sec. 26, excluding Native allotment F -13448 Parcel 8; Secs. 27 to 35, inclusive; Sec. 36, excluding Native allotment F- 14710. • Containing approximately 15,280 acres. • • • T. 19 N., R. 12 E. • Sec. 1, excluding Native allotment F- 13695; • Sec. 2, excluding Native allotments F- 13695 and F- 13740; Secs. 3 to 10, inclusive; • Sec. 11, excluding Native allotments F -13740 and F- 13695; Sec. 12, excluding Native allotment F -13695 and those lands formerly within Native allotment F -17789 Parcel A; • Secs. 13, 14, and 15: Sec. 16, excluding Native allotment P -17789 Parcels A -1 and A -2• Secs. 17 to 33 inclusive; Sec, 34, excluding Native allotment F- 13702; • Sec. 35, excluding Native allotments F -15501 Parcel D • and F- 13702; Sec. 36, excluding Native allotment F -13701 Parcel 8 and those lands formerly within Native allotment F- 13702. • Containing approximately 17,558 acres. • T. 20 N•., R. 12 E. Sac. 1; Sec. 4, excluding Nativ "e allotments F -13699 and F -13520 • Parcel A• Sec. 5, excluding Alaska Native Claims Settlement Act Sec. 3(e) application F -73257 and Native allotment Sec, F.13531; , ding Native allotments F -13531 and F »14712 • Parcel A; /" • • • • • interim conveyance No. 651 • nate MAY 24 19B3 • 2 • • MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO. 90 1304 P. 10 • IC,_0651_003.djvu F- 14857 -A F- 14857 -5 Sec. 8, excluding the following described lands: • U.S. Survey No. 2760A and B, U.S. Survey N. 3191, U.S. Survey No. 4399, • Alaska Native Claims Settlement Act Sec. 3(e) applications F -73257 and F- 73259, and Native allotment F -13542 Parcel B; See. 9, excluding Alaska Native Claims Settlement Act Sec. 3(e) a 9lication F -73257 and Native allotments F- 13699, F- 13547, and F -13520 Parcel A; • Sec. 14, excluding Native allotments F -13741 and F- 17157; Sec. 15; Ste. 16, excluding -$a i,c Land Order 1996; Sec. 17, excluding the following described lands; U.S. Survey No. 2760A and B, U.S, Survey No. 3639, U.S• Survey No. 4310, U.S. Survey No. 4387, U.S. Survey No. 4396 (Native allotment F- 010702 Parcel 1), Public Land Order 1396, Public Land Order 1996, Alaska Native Claims Settlement Act Sec. 3(e) applications F -35322 and F- 73257, and Native allotment F- 035317; Sec. 18, excluding the following described lands: U.S. Survey No. 1251, U.S. Survey No. 2122, U.S. Survey No. 2263, U.S. Survey No. 2641, U.S- Survey No. 2760A and B, U.S. Survey No. 4073, Public Land Order 1396, and Alaska Native Claims Settlement At Sec. 3(e) applications F -74051 and F- 73258; S. 19, excluding Native allotment F -14770 Parcel A; Sec, 20, excluding Native allotment F -14724 Parcel A; Sec. 21; Sec. 22, excluding Native allotment F- 14732• Sec, 23, excluding Native allotments F -14732 and F- 13741; Sec. 24, excluding Native allotment F- 13741; Secs, 25 and 26; Sec. 27, excluding Native allotments F- 14732, F- 14777, and F- 029786 Parcel 8. Sec. 28,•exc.luding Native allotments F -14777 and F -14811 Parcel A; Sec. 29, excluding Native allotments F -14724 Parcel A and F- 14718, and those lands formerly within Native allotment F- 029786 Parcel A; Sec. 30, excluding Native allotment F -14718 and those lands formerly within Native allotment F- 029786 Parcel A; Sec. 31 excluding Native allotment F- 14710; Secs, 32 and 33; Sec. 34, excluding Native allotments F -14777 and F- 029786 Parcels A and 8; Sec. 35 excluding Native allotment F- 029786 Parcels A and B; 'Sec. 36. Containing approximately 12,504 acres. Interim Conveyance No. 65 1 Date MAY 2 3 MAY -21 -2004 FRI 02:56 PM BLM ENERGY & MINERALS FAX NO. 90 267 1304 P. 11 IC_0651•,_004 _ djvu • • • • • F-14857.A F- 14857 -8 • T. 21 N., R. 12 E. Secs. 1 to 7, 72Iusive; sec. 8, excluding Native allotments F -16245 and F- 022797; Sec. 9, excluding Native allotment F- 022797; Secs. 10 to 15, inclusive; Seca. 16 and 17, excluding Native allotment F- 022797; Sec. 18; Secs, 19 and 20, excluding Native allotment F- 14787; Secs. 21 and 22, excluding Native allotment F- 14735; • Sec. 23 excluding Native allotment F- 14731; secs. 24, 25. and 26; Sec. 27. excluding Native allotment F.14735; Sec, 28. excluding U.S. Survey No. 6977, and Native d11ftment F- 14735;' Sec. 29, excluding U.S, Survey No. 4301 U.S. Survey No. 6977, and Native allotments F -13537 and F- 13528; Sec. 30, excluding Native allotments F -13259 and F- 16290; Sec. 33 excluding U.S. Survey No. 6977 and Native allotment F- 13734; Sec. 34' Seca. 35 and 36, excluding Native allotment F- 13539. Containing approximately 18,738 acres. T. 18 N., R. 13 E. Secs. 1 to 6 inclusive; Secs, 7 and 8, excluding Native allotment F- 14815; Sees. 9 to 27, inclusive; Sec. 28, excluding Native allotment F -13701 Parcel C; secs. 29 to 36, inclusive. • Containing approximately 17,197 acres. T. 20 N. , R. 13 E, Sec. 1, excluding Native allotment F- 025741 Parcel E; Secs. 2 and 3; Sec. 4, excluding Native allotments F- 025741 Parcel D • and F- 025740; Sec. 5 excluding Native allotment F- 025741 Parcel A; Secs, 6 to 11 inclusive; Secp, 17 to 20, inclusive; Sec. 29. excluding Native allotment F- 14719; Secs. 30 and 31. Containing approximately 10.878 acres. T. 22 N R 13 2. S . e cs. 26357 and 36. Containing approximately 2,380 acre*. -� • Aggregating approximately 142,764 acres. • Excluded from the above described lands herein conveyed are the submerged lands, up to the ordinary high water mark, beneath all water bodies determined by the Bureau of Land Management to be navigable because they have been or could be used in connection .with travel, trade and commerce. Those water bodied are identified 'on the attached navigability maps, the original of which will be found in easement case file F- 14857 -EE. Interim Conveyance No. _65 1 • • Date MAY 24 1983 - • 4 • MAY -21 -2004 FRI 02:57 PM BLM ENERGY & MINERALS FAX N0. 907 267 1304 P. 12 • IC_0651_005.djvu • F- 14857 -A F- 14857 -B • • • NOW KNOW YE, that there is, therefore, granted by the UNITED • STATES OF AMERICA, unto the above -named corporation the surface estate in the lands above described; TO HAVE AND TO HOLD the said • estate with all the rights,' privileges, immunities, and appurtenances, • of whatsoever nature, thereunto belonging, unto the said corporation, its successors and assigns, forever: EXCEPTING AND RESERVING TO THE UNITED STATES from the lands • ..so granted: 1. The subsurface estate therein, and all rights, privileges, immunities, and appurtenances, of whatsoever nature, accruing unto said estate pursuant to the Alaska Native Claims Settlement Act of December 18, 1971 (43 U.S.C. 1601, 1613(f)), as amended; and • • 2. Pursuant to Sec. 17(b) of the Alaska Native Claims Settlement Act of December 18, 1971 (43 J.S.C. 1601, 1616(b)), as amended, the following public easements referenced by easement identification number (EIN) on the easement maps attached to this document. Copies of which will be found in cage file F- 14857 -EE, are reserved to the United States. All easements are subject to applicable Federal. State, or Municipal corporation regulation. The following is a listing of uses allowed for each type of easement. Any uaee which are not • specifically listed are prohibited. 25 Foot Trail - The uses allowed on 4 twenty- . five ( foot wide trail easement are: • travel by foot. dogsled, animals, snowmobiles, two- and three -wheel vehicles, and small • all- terrain vehicles (less than 3,000 lbs. Gross Vehicle Weight (GVW)). 60 Foot Road - The uses allowed on a sixty (60 foot wide road easement are: travel by foot, dogsled, animals, snowmobiles, Uwe- and • three -wheel vehicles, small and large all- . terrain vehicles, track vehicles, four -wheel • drive vehicles, automobiles, and trucks. • One Acre Site - The uses allowed for a site easement are; vehicle parking (e.g., aircraft, boats, ATV +s, Snowmobiles, cars, tracks). temporary camping, and loading or unloading. Temporary camping, loading or unloading shall ' be limited to 24 hours. • a. (EIN 1 C3, C5, D4, D9) Art easement for an existingl, access trail twenty -five (25) feet in width from Fort Yukon in Sec. 7, T. 20 N., R. 12 E., Fairbanks Meridian, northerly to public lands. The uses allowed are those listed above for a twenty -five (25) foot wide trail easement. • . b. (EIN 2 C3, C5, D1) An easement for an existing access trail twenty -five (25) feet in width from • Fort Yukon in Sec. 18, T. 20 N., R. 12 E., Fairbanks Meridian, southeasterly to public lands and the • Interim Conveyance No. 65 1 Date MAY E 4 1983 5 MAY -21 -2004 FRI 02:57 PM jENERGY & MINERALS FAX NO. 9 267 1304 P. 13 IC„.0651_006 . djvu • • F- 14857 -A F•14857 -5 • village of Circle. The uses allowed are those listed above for a twenty -five (25) foot wide trail easement. • c. (EIN 3 C3, C5, 01, D9) An easement for an existing access trail twenty -five (25) feet in width from trail EIN 2 C3, C5, D1 in Sec. 29, T. 20 N., • R. 12 E. Fairbanks Meridian, svut'hwesterly to Public land and the village of Birch Creek. The uses allowed are those listed above for a twenty- . five (25) foot wide trail easement. d. (EIN 4 c3,.C5, Dl, L) An easement sixty (60) feet in width for an existing road from the Federal Aviation Administration (FAA) Remote Communication Outlet (RCO) site in Sec. 8, T. 20 N., R. 12 E., Fairbanks meridian, creasing EIN Sb C5, thence northerly to the Porcupine River, The uses allowed • are those listed above for a sixty (60) foot wide road easement. • e. • (EIN 4b C4) An easement sixty (60) feet in width for an existing access road from EIN 4 C3, c5, D1, • L in Sac, 8, T. 20 N. R. 12 E., Fairbanks Meridian, southeasterly to the FAA's Remote Center Air /Ground • Communication Facility (RCAG). The uses allowed are those listed above for a sixty (60) foot wide road easement. f. (EIN 5a C3, C5 A1) An easement twenty -six (26) feet in width �or an existing road from road . easement E1N 4 C3, C5, D1, L in Sec. 8, T, 20 N., • R. 12 E., Fairbanks Meridian, easterly to the Sucker River. The uses allowed are .those listed above for a sixty (60) foot wide road easement. • g. (EIN 5b C5) An easement sixty (60) feet in width far en existing road from the Fort Yukon airport in See. 8, T, 20 N. R. 12 E., Fairbanks Meridian, southeasterly to raid easement EIN 30 c4, K. The uses allowed are those listed above for a sixty (60) foot wide road easement. • h. (EIN 7 C5, D1) An easement for an existing access trail twenty -five (25) feet in width from trail easement EIN 1 C3, C5, D4, D9 in Sec. 7, T. 20 N., R. 12 E., Fairbanks Meridian, westerly to Venetie Landing and public lands. The uses allowed are those listed above fora twenty -five (25.) foot wide trail easement, • (EIN 9 C5, L) An easement for an existing access trail twenty -five (25) feet in width from the east terminus of road easement E1N Sa C3, CS, D1 in • Sec.. 2, T. 20 N., R. 12 E., Fairbanks Meridian, • northeasterly to public lands and the village of Chalkyitsik. The uses allowed are those listed • • above for a twenty-five (25) foot wide trail easement. • Interim Capveyauce No. 65 1 1 Gate NAY 24 1983 6 MAY -21 -2004 FRI 02:57 PM BLM ENERGY & MINERALS FAX NO. 90 267 1304 P. 14 • Ic_0651_OO7.djvu • • • F- 14857 -A • F- 14857 -8 • • • J. (EIN 15 C1) A one (1) acre site easement upland of the ordinary high water mark in Sec. 18, T. 20 N., R. 12 E., Fairbanks Meridian, on an island in the Yukon River. The uses allowed are those listed above for a one (1) acre site. k. (EIN 26a C4) An easement for a proposed access • trail twenty -five (25) feet in width from the east terminus of road easement EIN 5a C3, C5, D1 in • Sec. 2, T. 20 N., R. 12 E.. Fairbanks Meridian, southeasterly to public lands. The use allowed are those listed above for a twenty -five (25) foot wide trail easement, 1. (EIN 27a C4) An easement for a proposed access • trail twenty -five (25) feet in width from the • Yukon River in Sec. 12, T. 18 N., R. 13 E., • Fairbanks Meridian, northeasterly to public lands. The uses allowed are those listed above for a twenty -five (25) foot wide trail easement. m, (EIN 27b C4) A one (1) acre site easement upland of the ordinary high water mark in Sec. 12, T. 18 N., R. 13 E., Fairbanks Meridian on the right bank of the Yukon River. The uses allowed are those • listed above for a one (1) acre site; • n. . (EIN 30 C4, K) An easement sixty (60) feet in • width for an existing road, pipeline, and communication lino from East Third Avenue of the • Fort Yukon Townsite in Sec. 17, T. 20 N., R. 12 E., Fairbanks Meridian, easterly to the Fort Yukon Air Force Station withdrawn in Public Land Orders 1396 and 1996, The uses allowed are those listed above for a sixty (60) foot wide road easement and those activities associated with the construction, operation, and maintenance of the pipeline and communication line. • THE GRANT OF THE ABOVE- DESCRIBED LANDS TS SDBJECT TO: 1. issuance of a patent after approval and filing by the Bureau of Land Management of the official plat of survey confirming the boundary description and acreage • of the lands hereinabove granted; 2. Valid existing rights therein, if any, including but not limited to those created by any lease (including a • lease issued under Sec. 6(g) of the Alaska Statehood Act of July 7. 1958 (48 U.S.C. C. 2. Sec. 6(g))), • contract, permit, right -of -way, or easement, and the right of the lessee, contractee. pexmittee, or grantee •• • to the complete enjoyment of all rights, privileges, and benefits thereby granted to him. Further, pursuant to Sec. 17(b)(2) of the Alaska Native Claims Settlement • Act of December 18, 1971 (43 U.S.C. 1601 1616(b)(2)) . ( ANCSA), any valid existing right recognized by ANCSA shall continue to have whatever right of access as is • now provided for under existing law: • • interim Conveyance xo. 651 Date MAY 2 4 1983 • MAY-21-2004 FRI 02:57 PM BLM ENERGY & MINERALS FAX NO, 907 267 1304 P. 15 • IC_0651_008.djvu • • F- 14857 -A F- 14857 -8 • • • • 3, The following third -party interests, identified by the U.S. Department of the Interior,. Fish and Wildlife . Service, as provided by Sec. 14(g) of the Alaska Native . Claims Settlement Act of December 18, 1.971 (43 U.S.C. 1601, 1613(g); • a. Public airport lease M- 153•YF (formerly F- 029281), located in Secs. 5. 8, and 17, T. 20 N.,,R, 12 E., Fairbanks Meridian, issued to the State•pf Alaska, • Division 211 -214), provisions of amended; and • b. A granted road right -of -way permit, R-141-YT (formerly F- 52057), issued to the State of Alaska, Department of Transportation and Public Facilities, under the provisions of the Act of August 27, 1958 • (29 U.S.C. 317), for a Federal Aid Secondary Highway, located in Sec. 8, T. 20 N., R. 12 E., • Fairbanks Meridian. 4. Requirements of Sec. 14(c) of the Alaska Native Claims Settlement Act of December 18, 1971 (43 U.S.C. 1601, 1613(0)), as amended, that the grantee hereunder convey those portions, if any, of the lands hereinabove granted, as are prescribed in saidsectien. IN WETNESS WHEREOF, the undersigned authorized officer of the Bureau of Land Management has, in the name of the United States, set his hand and caused the seal of the Bureau to be .hereunto affixed on this 24th day of May, 1983 in Anchorage, Alaska., UNITED STATES OF AMERICA • c ng As to t o a Director for Conveyance Management • • • • Interim Conveyance No. 65 j . Date MAY 2 4 1983 DIANA RICHARDS Not Valid After 60 Days 129 BOX 25046 DFC MS 406 For Official Use Only DENVER CO 80225 US GaTe9ment Tax Exempt D 1 Ui: ' it r -A21- ( 4 68 U. S. DEP T E .,... NT OF THE INTERIOR - U.S. GEOLOGICALSJRyEy PAY To THE i (- t...71 el. ---•' --------- -----— 1 $ ,c c .0,' tib qU-iu /()( ... _, _______ ....,.. NOT VALID FOR CASH Not Valid For More Than $2,500.00 Bank of America Bank of America, NA. (USA) ) r: 4: Payable through N \ 1 ../• , : . 4 - F. _J ,° %1* k.X.A - ,.._N.._ • ..,..v 'N4 ji_4 (' i f.-., ,- J.L ., _ by 1 : 0 5 L 0 0 0 0 L 71:0 Si3 6 913 3 20 Lit 38 Lo 0 L 29 e Harland IOW 1 • o TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME go T^ ©� f - yr) PTD# - 2.©V -- o i?3 Development Exploration Service - - X Stratigraphic CHECK WHAT ADD -ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60 -69) above. PILOT HOLE In accordance with 20 AAC 25.005(0, all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 1 . '❑ � A . f , ' f e � i Field & Pool Well Name: DOI -04 1A Program STR Well bore seg ❑ PTD#: 2040830 Company U S DEPT OF INTERIOR Initial Class/Type STR / OBSW GeoArea _ Unit On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached Yes 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool No 5 Well located proper distance from drilling unit boundary Yes This well wilt be a stratigraphic test, without any sustained production 6 Well located proper distance from other wells Yes correlative rights of any adjacent owners will not be affected 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included NA 9 Operator only affected party Yes 10 Operator has_appropriate bond in force No The requiremts for bond are to be waived for this federal operation on federal land 11 Permit can be issued without conservation order No see above Appr Date 12 Permit can be issued without administrative approval Yes RPC 5/19/2004 13 Can permit be approved before 15 -day wait No 14 Well located within area and strata authorized by Injection Order # (putlO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 ACMP Finding of Consistency has been issued for this project NA Engineering 18 Conductor string provided NA Re -entry. 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes Core well bore to be abandoned with grout and bentonite plug. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Core rig. 25 If a re- drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separationproposed Yes 27 If diverter required, does it meet regulations Yes 100 psi stripper head. Appr Date 28 Drilling fluid program schematic_& equip list adequate Yes Fresh water - gel mud. WGA 5/25/2004 29 BOPEs, do they meet regulation NA Alternate BOPE is approved. • 30 BOPE press rating appropriate; test to (put psig in comments) NA 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No 36 Data presented on potential overpressure zones Yes near by offset well experienced no overpressure Appr Date 37 Seismic analysis of shallow gas zones Yes reflection_ seismicline has no velocity anomolies RPC 5/19/2004 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes Arthur Clark 303 - 445 -4608 Geologic Engineering Publ c Commissioner: Date: Commissioner: Date , �i, r Date D 7'3 Si 81--- .4„, id e r I -7/0,7„--