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100-152
Explanation Page Permit Number 100-152/ 111111111111 111111111 111111111111111111111111 These well numbers (typically beginning with 100) precede the beginning of the Commission. No permits were issued and no formal folder of record (information) created. Information known to the Commission through other agencies, journals, reports, news or additional historical means has been collected and entered into a database of Well History information. If specific information exists, these pages may be filed in this folder. Occasionally, the information has been obtained from a report that may deal with a general area and many wells. If or when possible, we may be able to 'point' the person interested in this specific well to one or more of these information sources. However, at best, this will be incomplete and independent research should be conducted to locate, if available, further information about a particular well site. BLM Legacy Well Review — August 6, 2014 Notes on wells for file: Fish Creek #1 - {7b 160-10e' Need to update schematic to actual casing depths. Verify fluids and fluid depth with Slickline at some point. Determine cement coverage in 7" casing . Well is near Mooses Tooth Development so could wait on more infrastructure to facilitate the P & A . Topagurak #1 ?T-0 l00— I `l Schematic needs to be corrected to reflect casing points , fluids etc. Has diesel lines buried for refrigeration... still holding fuel. May not be able to easily enter wellbore for drifting (no wellhead). No wellbore plugs are present. Large area of debris with a phantom cellar nearby. Thermistor cables seem to indicate there is most likely diesel in wellbore. East Toagurak #1 /00— IT & Schematic needs correcting. Not sure what fluid was left in wellbore... BLM report states frozen mud but couldn't find any verification in my research (last entry in drilling record said it was bailed to 1029' ft). Has 10 3/" stub sticking up for a "wellhead". Needs SL drift to verify fluid level and type. Skull Cliff Core #1 /pp-- 152, Schematic needs minor corrections and updates (show fish in wellbore at 527'md). This site has a great number of surface debris issues such as barrels and batteries. Fluid in wellbore is diesel but is in contact with the OH section of the well as casing is only set at 30'md. 7" casing stub with cap is "wellhead". No DST's were performed and no hydrocarbon shows ... Needs a slickline drift to verify that diesel is still in place. SCA NEW Skull Cliff Core Test #1 0' Sk--ll Clif+ Core TesI 1j 1 Legacy Wells Summary Report " l ilk I" casing set 0 30'_ Camenled w/10 sx of cement Hole capped wia wooden plug. An 8' Ienglh of 2 X 4 was nailed vertically to wooden plug Hole drilled to 100' using 6 1!S" roc bit Below 100', mote cored w1a Reed KorKing 5 718" core barrel 00 Drill pipe partey @? bL C and couldn't be recovered. No mud circ. for 70 his while waiting for spiral guide. I sole froze io 250 'Valls iced le 525'. Hydraulic hook attempted to pull fish ad. Lowerec to 290' and wds slopped by ice. Hale abandoned Mud baited down to 52?'. Tapped off with 16 bbl of diesel feel Figure 9: Skull Cliff Core Test #1 wellbore diagram. 422 BLM Open File Report 127 • May 2013 ` Legacy Wells Summary Report Skull Cliff Core Test #1 Figure 3: Skull Cliff Core Test #1 and cellar. BLM Open File Report 127 • May 2013 417 CORE TESTS AND TEST WELLS, BARROW AREA, ALASKA DESCRIPTION OF CORES AND CUTTINGS Lithologic description [Where no core is listed, description is based on cutting samples] Core I Depth (feet) I Remarks ------ 0-7.5 Kelly bushing to ground level. ------ 7.5-75 Gravel and sand. ------ 75-82 Sand and gravel. ------ 82-100 No record. 1 100-120 Recovered 4 ft: Clay, medium -light -gray, slightly silty, noncalcareous. Foraminifera (Nonion sp. Cassidulina sp., several specimens 'Elphidiidae) of were found in a washed sample, which was made up primarily of subangular white and clear quartz silt. ------ 120-170 Shale, blue. 2 170-188 Recovered 13 ft: Sandstone, light -gray, very fine grained, silty, noncalcareous, friable, massive - composed of subangular to subrouna grains of clear and white quartz- rare yellow and dark grains. Sandstone becomes slightly coarser and darker with depth. Effective porosity, meas- ured by Washburn -Bunting method, is 38.4 percent at 171 ft, 36.1 percent at 176 ft, 37.0 percent at 180 ft, and 33.1 percent at 185 ft; rock too friable for permeability tests. Sieve analysis of sample at 176 ft showed ruc;t to be composed of 14.2 percent fine sand (particles caught on 120 -mesh sieve), 46.9 percent very fine sand (between 120- and 230 -mesh sieves), and 38.7 percent silt and clay (pass through 230 - mesh sieve). 3 188-206 Recovered 18 ft: Sandstone as above. Effective porosity 36.4 percent at 190 ft, 33.5 percent at 195 ft, 30.1 percent at 200 ft, and 37.1 percent at 205 ft. Rock too friable for permeability tests. Two sieve analy- ses, at 190 and 205 ft, gave the follow- ing results: At 190 ft, rock composed of 1.96 percent fine sand, 56.3 percent very fine sand, and 41.8 percent silt and clay; at 205 ft, of 24.5 percent fine sand, 53.0 percent very fine sand, and 22.3 percent silt and clay. At 191 ft, specific gravity of sandstone was 1.78. ___ 206-310 Shale, sandy. 4 314-317 Recovered 1 ft: Clay shale, medium -light -gray, slightly silty, slightly calcareous; fair shaly cleavage. Mixed with drilling mud. Beds lie flat. ------ 317-347 Shale. ------ 347-425 Shale, blue. ------ 425-605 Shale. ------ 605-665 Shale, sandy. ------ 665-667 Shale. 5 667-685 Recovered 12 ft: Clay shale, medium -light -gray, slightly silty in part, slightly calcareous, fissile in part. Beds lie flat. 575 DRnJANG OPERATIONS Setting up the National 50 drilling rig was begun on October 1, 1944 and completed on the 11th of the month. The rig was not housed. The mud pits were made of two pontoons welded together. Notes from drilling records Depth ( feet) Remarks 82 -------- Hole drilled to 82 ft with 14% -in. bit. When 113/4 - in. casing was set at 67 ft, operations were shut down for 24 hr so the casing would freeze in place. Casing then cleaned out and 'drilling continued with a 10% -in. bit. Attempts at coring were un- successful, as slush ice plugged openings of core bit. 120 _ Mud pipes froze during coring because of wind, cold, and snow, but were thawed with a flamethrower. A Sullivan air compressor was successful in blow- ing mud out of pipes while mud was not being circulated. 667 Mud became warm at this depth (possibly the bottom of the permafrost at well site). SKULL CLIFF CORE TEST 1 Location: Lat 70°54' N., long 158°36' W. Elevation: Ground, 9 feet lower; kelly bushing, approximately 50 feet. Spudded: February 2, 1947. Completed: March 17, 1947. Junked and abandoned. Total depth: 779 feet. Skull Cliff core test 1 is li/, miles inland from the shore of the Arctic Ocean, and about 40 miles south- west of Point Barrow. The coastline in this area is bordered by a cliff some 50 feet high, in which Pleisto- cene and Cretaceous beds crop out. Oil drips slowly from a seep at the base of the cliff; Edward J. Webber described it (written communication, 1947) as coming from a spot a few inches across, in a sandstone bed which crops out along the edge of the ocean. Except for the cliff face, there are no outcrops anywhere in the area, and the need for additional stratigraphic information, as well as the oil seep, determined the location of the hole. It was planned as a 1,500 -foot test, but mechan- ical difficulties caused abandonment at a total depth of 779 feet. DESCRIPTION OF CORES AND CUTTINGS The hole was cored through an estimated 40 feet of unconsolidated sand and gravel of the Gubik formation, Cretaceous sandstone and shale of the Grandstand formation from 50 to about 450 feet, and the Topagoruk formation from about 450 feet to the bottom of the hole. (See pl. 39.) No shows of oil or gas were noted, and the rig was removed and sent back to Barrow. 576 EXPLORATION OF NAVAL PETROLEUM RESERVE NO. 4, ALASKA, 1944-53 Lithologic description (Where no core is listed, description is based on cutting samples) Core I Depth (feet) I Remarks ------ 0-9 Kelly bushing to ground level. ------ 9-15. 25 No sample. ------ 15. 25-30 Sand, yellowish -brown, fine- to very fine-grained; composed of well- rounded clear quartz and some yellow quartz, yellow, gray, and black chert, and rare red chert. Rare chert granules. ------ 30-40 Sample composed entirely of cement. ------ 40-50 Chert pebbles, black, well-rounded; a few pebbles of other rocks. ------ 50-100 Sandstone, medium -light -gray, very fine grained, very silty and argilla- ceous, very slightly calcareous; com- posed of subangular clear and white quartz and some gray chert and dark rock fragments. Chert pebbles, con- tamination from above, make up over half of each sample representing this interval of rock. 1 100-109 Recovered 3 ft: 8 in., drilling mud containing I -in. rounded black chert pebbles. 2 ft 4 in., clay shale, medium -light - gray, slightly calcareous, soft; good shaly cleavage. Beds lie flat. 2 109-119. 6 Recovered 10 ft: 1 ft 1 in., sandstone, medium -light - gray, very fine grained, silty, ar- gillaceous, moderately calcareous, massive; composed of angular to subangular clear and white quartz and rare gray and dark rock frag- ments, muscovite, and carbon- aceous particles. 5 ft 6 in., clay shale, medium -light - 6 149-159 gray to medium -gray, slightly cal- careous, slightly to very silty, slightly to very micaceous (domi- nantly muscovite); siltstone part- ings common; fair shaly cleavage. Beds lie flat. Irregular 1 -in. bed of light -gray crossbedded very fine grained sandstone with carbon- aceous partings present at 112 ft. 7 159-169 Clay shale grades into unit below. 7 in., siltstone, medium -light -gray, very argillaceous, slightly calcare- 8 169-179 ous, micaceous, massive. 2 ft 10 in., clay shale as above. 3 119. 6-129. 6 Recovered 10 ft: Clay shale as above, with rare silty partings. 4 129. 6-139. 6 Recovered 9 ft: Clay shale as above, medium- to medium -dark -gray; rare %- to 2 -in. beds of light -gray argillaceous silt - stone and medium -dark -gray clay shale with carbonaceous plant flakes. 5 139.6-149 Recovered 10 ft: I in., clay ironstone, light -yellowish - gray, noncalcareous, hard, dense; conchoidal fracture; effervesces slightly in cold dilute hydrochloric 10 189-199 acid. 1 ft 1 in., clay shale as above, fissile, abundant carbonaceous plant flakes and fragments in lower 1 in. 10 in., siltstone, medium -light -gray, very argillaceous, very slightly Lithologic description—Continued Core I Depth (feet) I Remarks calcareous, massive. Rare very fine and fine-grained sandstone streaks intermingled in upper 1 in. of siltstone. Rare patches of med- ium -gray clay. 7 in., clay shale as above. 1 ft, siltstone as above; carbonaceous partings in lower 2 in. 6 in., claystone, medium -gray, very slightly calcareous; conchoidal fracture. 3 in., sandstone, medium -gray, fine- grained, slightly silty, noncalcar- eous, friable, massive; composed of subangular grains of clear and white quartz and carbonaceous particles. Carbonaceous streaks common. 1 ft 3 in., intermingled very irregular lenses and laminae of light -gray, fine- and very fine grained sand- stone; medium -gray siltstone, and medium -dark to dark -gray car- bonaceous clay shale. 11 in., clay shale, dark -gray, fissile; coaly partings and abundant car- bonaceous plant fragments. Beds lie flat. 10 in., siltstone, medium -light -gray, very argillaceous, noncalcareous, massive; patches of medium -gray clay and carbonaceous material. 2 ft 8 in., interbedded clay shale, medium -gray; dark -gray carbon- aceous fissile clay shale; and light - yellowish -gray claystone. Beds are 2-3 in. thick. 6 149-159 Recovered 5 ft 6 in.: 84ndstone, medium -light -gray, fine- grained, slightly silty and argil- laceous, noncalcareous, friable, massive; composed of subangular to subrounded clear and white quartz with some gray chert and dark rock fragments; rare carbon- aceous particles and muscovite. 7 159-169 Recovered 9 ft 6 in.: Sandstone as above, fine- to very fine grained. 8 169-179 Recovered 9 ft: 6 ft 3 in., sandstone as above, fine- grained. 2 ft, sandstone, very fine grained; medium -light -gray calcareous silt - stone; abundant irregular laminae and small lenses medium -gray clay - stone and carbonaceous patches totaling about one-third of the rock. 9 in. drilling mud with sandstone and siltstone fragments. 9 179-189 Recovered 2 ft: Clay shale, medium -gray, slightly calcareous, subconchoidal to good shalt' cleavage. Beds lie approxi- mately flat. 10 189-199 Recovered 9 ft: 5 ft 1 in., clay shale as above. 2 ft 9 in., claystone, light -olive -gray, very silty, very slightly calcareous, irregular fracture; small scattered carbonized plant fragments. A 3 -in. bed of medium -light -gray fine- grained very slightly calcareous CORE TESTS AND TEST WELLS, BARROW AREA, ALASKA Litholopic description.—Continued Core I Depth (feet) I Remarks 1E - 12 13 14 Litholopic description, Continued Core I Depth (feet) ( Remarks 577 15 sandstone with rare carbonaceous Recovered 4ft: partings present at 196 ft. 1 ft 2 in., siltstone, medium -light, - gray, slightly sandy, very argillace- slightly silty, noncalcareous; fair ous, noncalcareous, massive. 199-209 Recovered 8ft: 11 in., clay shale, medium -gray, thin (less than 1 in.) beds silty slightly silty in part; some silt - stone partings dip less than 5°. 16 1 ft 10 in., sandstone, medium -light - Recovered 9 ft 6 in.: gray, very fine grained, slightly silty, very slightly calcaerous, mas- sive; composed of subangular clear laminae. and white quartz, and some yellow, 256-266 gray, and dark rock fragments and rare carbonaceous particles. Intergraded claystone and clay shale, 1 ft 11 in., claystone, light -olive -gray, slightly to very silty, noncalcare- ous, massive. slightly silty in part; conchoidal 6 in., siltstone, medium -light -gray, slightly argillaceous, slightly cal- 18 careous, massive. Recovered 9 ft 6 in.: 2 ft 4 in., claystone, medium -light - gray, slightly silty, slightly mi- caceous, noncalcareous; irregular as above; rare flat -lying laminae cleavage; fair shaly cleavage in a few places is caused by micaceous partings. stone. 6 in., siltstone as above. 209-211 No sample. 211-21.6 Recovered 1 ft: Clay shale and claystone as above. Chert pebbles, black, 1-2 in. in 286-296 diameter, rounded; contamination from surface gravel. 11 in., clay shale, medium -light -gray, 3 in., siltstone as above. 216-226 Recovered 9 ft - 8 in., siltstone as above, grades into shale cleavage. unit below. 9 in., sandstone, medium -light -gray, very fine grained, very argillaceous, gray, slightly to very sandy, argil- very slightly calcareous, massive; rare slightly carbonaceous partings. Composition same as core 11 sand. slightly carbonaceous partings that 1 ft 7 in., clay shale, medium -light - gray, slightly to very silty and micaceous, noncalcareous; poor Two 2 -in. beds of medium -gray shaly cleavage. Beds lie approxi- mately flat. 4 in., siltstone, medium -light -gray, 289 ft. Siltstone rarely grades into very argillaceous, noncalcareous. 4 in., clay shale as above. 2 ft, siltstone as above, slightly cal- very argillaceous silty sandstone. careous in part, massive; rare car- 296-306 bonaceous partings. 3 ft 4 in., siltstone and clay shale, interbedded, as above; beds are 2-6 2 ft 6 in., sandstone, medium -light - in. thick and are about half clay - stone and half siltstone. 226-236 Recovered 10 ft: noncalcareous, massive; composed 1 ft 6 in., siltstone, similar to siltstone above; abundant carbonaceous partings composed of particles and clear and white quartz, small flakes of carbonized plants as much as one-half in. long. Partings lie approximately flat. Clay sbale rock fragments, and rare yellow laminae common in basal few inches. 3 ft 6 in., interlaminated and inter- 6 ft 6 in., sandstone as above, but bedded siltstone and clay sliale; beds are' -4 in. thick. 5 ft, clay shale, medium -gray, slightly medium -gray clay shale present at to very silty, fissile to poor shaly cleavage. A 3 -in. bed of siltstone 22 present 1% in. above base of core. Litholopic description, Continued Core I Depth (feet) ( Remarks 577 15 236-246 Recovered 4ft: Claystone, medium -gray, very slightly silty, noncalcareous; fair to good conchoidal fracture; rare thin (less than 1 in.) beds silty claystone. 16 246-256 Recovered 9 ft 6 in.: Claystone, as above, but lacks silty laminae. 17 256-266 Recovered loft: Intergraded claystone and clay shale, medium -dark -gray, noncalcareous, slightly silty in part; conchoidal fracture to fissile: flat lying. 18 266-276 Recovered 9 ft 6 in.: Intergraded claystone and clay shale as above; rare flat -lying laminae and beds (less than 1 in.) of silt - stone. 19 276-286 Recovered 2 ft 6 in.: Clay shale and claystone as above. 20 286-296 Recovered 10 ft: 11 in., clay shale, medium -light -gray, very silty, noncalcareous; poor shale cleavage. 9 ft f in., siltstone, medium -light - gray, slightly to very sandy, argil- laceous. Abundant argillaceous slightly carbonaceous partings that are rarely crossbedded dip V. Two 2 -in. beds of medium -gray clay shale present 6 in. apart, at 289 ft. Siltstone rarely grades into an in. or so of very fine grained very argillaceous silty sandstone. 21 296-306 Recovered 9 ft: 2 ft 6 in., sandstone, medium -light - gray, fine-grained, slightly silty, noncalcareous, massive; composed of subangular to subround grains of clear and white quartz, small amount of gray chert and dark rock fragments, and rare yellow grains and carbonaceous particles. 6 ft 6 in., sandstone as above, but very fine grained. A 2 -in. bed of medium -gray clay shale present at 303 ft. 22 306-316 Recovered 10 ft: Sandstone as above, very fine grained; rare argillaceous, car- bonaceous laminae. A 2 -in. bed of medium -gray claystone with conchoidal fracture 1 ft above base of core; lower contact between claystone and sandstone has %-in. rounded pebbles of claystone in the sandstone. Beds lie approx- imately flat. 23 316-326 Recovered loft: 6 ft, sandstone as above. 4 ft, claystone, medium -light -gray, very slightly silty in part, non - calcareous; conchoidal fracture. 24 326-336 Recovered loft: Clay shale, like claystone above but with fair shaly cleavage; infil- trated with drilling mud. Beds lie approximately flat. 25 336-346 Recovered Eft: Clay shale as above; rock badly in- filtrated with drilling mud. 578 Core 26 27 28 29 EXPLORATION OF NAVAL PETROLEUM RESERVE NO. 4, ALASKA, 1944-53 Lithologic description --Continued Depth (feet) 346-356 356-366 366-376 376-386 30 386-396 31 396-406 32 406-416 33 416-426 34 426-436 35 436-446 36 446-456 37 456-466 38 466-476 39 476-486 Remarks Recovered 10 ft: Clay shale as above but with a 6 -in. bed of siltstone that is medium gray, very argillaceous, very slight- ly calcareous in part, and massive. Recovered 8 ft 6 in.: Clay shale as above; badly infil- trated with drilling mud. Recovered 7 ft: Clay shale as above; badly infil- trated with drilling mud in upper part. Recovered 10 ft: Interbedded and interlaminated clay shale and siltstone; some micaceous carbonaceous partings in the silt - stone. Beds range from 34 to 4 in. in thickness, and are approx- imately half clay shale and half siltstone. A 1 -ft siltstone bed present at 379-380 ft. Siltstone is medium light gray, very ar- gillaceous, and very slightly cal- careous in part. Clay shale is medium gray, slightly to very silty in part, noncalcareous. Recovered 10 ft: Clay shale as above. Rare small carbonized plant flakes. A 6 -in, bed of medium -light -gray argilla- ceous slightly sandy siltstone pres- ent at 394 ft. Recovered 6 ft: Clay shale fragments, medium -gray, slightly silty in part, noncal- careous; fair shaly to subcon- choidal cleavage. Beds lie approx- imately flat. Recovered 10 ft: 2 ft, clay shale as above. 1 ft, sandstone, medium -light -gray, very fine grained, very silty and argillaceous, noncalcareous, mas- sive. 7 ft, clay shale as above. Recovered 3 ft 6 in.: 1 ft 3 in., clay shale as above. 2 ft 3 in., siltstone, medium -light gray, very sandy and argillaceous, noncalcareous, massive. No recovery. Recovered 9 ft 6 in.: Sandstone, medium -light -gray, very fine grained, argillaceous, non - calcareous, massive; composed of subangular grains of clear and white quartz, some dark rock fragments, and rare mica, and yellow grains. Recovered 6 ft: Clay shale as above; two 2 -in, beds of medium -light -gray very fine grained sandstone are one-half in. and 1 ft below top of core, re- spectively. Top of Topagoruk formation at approximately 450 feet. Recovered 10 ft: Clay shale, medium -gray, very slight- ly silty in part, noncalcareous; very rare micaceous partings. Recovered 10 ft: Clay shale as above. Recovered 10 ft: 7 in., clay shale as above. 1 ft, siltstone, medium -gray, very Lithologic description --Continued Core Depth (feet) Remarks argillaceous, noncalcareous, mas- sive. 8 ft 5 in., clay shale as above; 4 -in. bed of siltstone at 483 ft. 40 486-496 1 Recovered 10 ft: Clay shale as above but with rare siltstone beds 3i-6 in. thick, in upper two thirds of core. Beds lie approximately flat. 41 496-506 Recovered 10 ft: Clay shale as above but with rare thin 0/i-1 in.) siltstone beds in upper part; beds lie approximately flat. 42 506-516 Recovered 2 ft 6 in.: Drilling mud but with fragments of clay shale as above. 43 516-526 Recovered 7 ft. 6 in.: Clay shale as above; badly infiltrated with drilling mud in part. 44 526-536 Recovered 10 ft: Clay shale as above but with very rare thin (3�-2 in.) beds siltstone, and a 6 -in. medium -light -gray very fine grained noncalcareous silty sandstone bed at 532 ft. Beds lie flat. 45 536-546 Recovered 10 ft: Clay shale as above but medium- to medium -dark -gray; rare silty lami- nae in upper third. Beds lie flat. 46 546-556 Recovered 7ft: Clay shale as above but fissile, in- filtrated with drilling mud. A 6 -in. bed of medium -light -gray crossbedded siltstone has carbo- naceous or argillaceous partings dipping 1°-10°. Clay shale beds lie flat. 47 556-566 Recovered 8 ft. 6 in.: Clay shale, medium -dart+ -gray, slightly to very silty in part, non - calcareous; fair shaly cleavage to fissile. 48 566-576 Recovered 10 ft: Clay shale as above. Beds lie flat. 49 576-586 Recovered 10 ft: Clay shale as above but with rare I -in. beds of medium -light -gray argillaceous siltstone in upper 2 ft. Beds lie flat. 50 586-596 Recovered 10 ft: 5 ft, interbedded argillaceous silt - stone and clay shale; beds are 2-8 in. thick, approximately half silt - stone and half clay shale, and lie flat. 5 ft, clay shale as in core above but with rare laminae of very argil- laceous siltstone, and a 1 -in. bed of siltstone at the top. Beds lie flat. 51 596-606 Recovered loft: Clay shale as above but with 1 -in. bed of siltstone at top. Beds lie flat. 52 606-616 Recovered 10 ft: 3 ft., clay shale as above. I ft 6 in., sandstone, light -gray, very fine grained, slightly silty, very slightly calcareous, massive; com- posed of subangular grains of clear and white quartz with rare dark rock grains. 4 ft 3 in., clay shale as above. 8 in., sandstone as above. 7 in., clay shale as above. CORE TESTS AND TEST WELLS, BARROW AREA, ALASKA Lithologic description --Continued Core Depth (feet) Remarks 53 616-626 Recovered 7ft: Clay shale, medium -dark -gray, slight- ly to very silty in part, noncal- careous; fair shaly cleavage to fissile. Beds lie flat. 54 626-636 Recovered 10 ft: Clay shale as above but with a 4 -in. 66 746-756 bed of light -gray very fine grained sandstone that is very silty and argillaceous, slightly calcareous, at 633 ft. 55 636-646 Recovered 5 ft 6 in.: 5 ft, clay shale as above. Beds lie flat. 6 in., drilling mud with some clay shale fragments. 56 646-656 Recovered 7 ft 6 in.: 2 ft 6 in., clay shale as above; badly infiltrated with drilling mud. 67 756-766 2 ft 7 in., siltstone, medium -light -gray, very argillaceous and micaceous, noncalcareous, irregular fracture; scattered flakes of carbonized plants. Siltstoneggrades to very fine grained very argillaceous sandstone at base. 68 766-776 2 ft 5 in., clay shale as above. 57 656-666 Recovered 10 ft: Clay shale as above. 58 666-676 Recovered loft: 6 ft 6 in., clay shale, medium- to medium -dark -gray, slightly to very silty, noncalcareous; common thin (%-4 in.) beds of medium -light - gray very argillaceous noncal- careous siltstone, decreasing to rare at base. 2 ft 3 in., sandstone, medium -light - gray, very fine grained, very silty and argillaceous; common thin irregular carbonaceous and argil- laceous laminae and partings in upper part; grades to massive in lower part. 1 ft 3 in., clay shale, medium -dark - gray, slightly to very silty in part, micaceous, noncalcareous; very poor shaly cleavage. Beds lie flat. 59 676-686 Recovered 10 ft: Clay shale as above. Beds lie flat. 60 686-696 Recovered 4ft: Clay shale as above; infiltrated with drilling mud in lower part. Beds lie flat. 61 696-706 Recovered 10 ft: Clay shale, medium -dark -gray; very slightly silty in part; fissile to sub - conchoidal fracture. Beds lie flat. 62 706-716 Recovered 10 ft: Clay shale as above. Beds lie flat. 63 716-726 Recovered 10 ft: Clay shale as above. Beds lie flat. 64 726-736 Recovered loft: 2 ft 6 in., clay shale as above. 10 in., siltstone, medium -gray, argil- laceous, noncalcareous, micaceous; abundant carbonaceous and mica- ceous partings totaling half of the rock in upper 2 in. and decreasing to less than 10 percent at base. Upper few inches has excellent pokerchip cleavage along partings; core brea4s into smooth, circular chips less than j4, in. thick. Beds lie fiat. 2 ft 8 in., clay shale as above. 3 ft 6 in., siltstone, medium-light- Lithologic description ---Continued Core I Depth (feet) ( Remarks 579 CORE ANALYSES Core samples from Skull Cliff core test 1 were analyzed by the personnel of the Geological Survey laboratory at Fairbanks, Alaska, and by S. T. Yuster at Pennsylvania State College. Porosity and permeabil- ity were measured by various methods, as given in the following table on porosity and permeability, and found to be very high (as much as 2,370 millidarcys of perme- ability and 35.6 percent porposity) in sandstone samples from depths of 110, 310, and 748 feet. The three samples studied at Pennsylvania showed a large drop in permeability to fresh water, compared to air or brine. Sieve analyses in the following table show the sandstones to be composed primarily of fine to very fine sand and a considerable amount of silt and clay. Petrographic analyses of the same three samples, in the table on petrographic characteristics, show that quartz is the most abundant constitutent and that slate or phyllite particles and chert make up most of the rest of the rock. Interstitial material includes clay minerals and a small amount of carbonate cement. The specific gravity ranges from 1.85 to 2.38; the lightest rocks ase sandstone, and the heaviest ones clay shale—as shown in the fol- lowing table on specific gravity. Heavy minerals were studied by Robert H. Morris who determined that the zoned -zircon zone is present in the hole between the depths of 110 and 450 feet, as shown in plate 40. gray, very sandy, slightly argil- laceous, noncalcareous, massive; faint carbonaceous partings in lower part are crossbedded, dip as much as 10°. 6 in., clay shale as above. 65 736-746 Recovered loft: Clay shale as above. 66 746-756 Recovered IOft: 2 ft 4 in., clay shale as above. 5 ft 8 in., siltstone, medium -light - gray, slightly sandy and argil- laceous, noncalcareous; massive in upper part but has rare faint carbonaceous partings in lower part. A 2 -in. bed of clay shale is M.in. below top of siltstone. 2 ft. Clay shale as above but with rare thin beds (less than 3� in.) of siltstone. 67 756-766 Recovered 8 ft: 3 ft., clay shale as above; infiltrated with drilling mud; rare beds, less than 2 in. thick, of medium -light - gray siltstone. 5 ft, clay shale as above; infiltrated with drilling mud in'part. 68 766-776 Recovered 10 ft: Clay shale, medium -dark -gray, slight- 1silty in part, noncalcarcous; shaly cleavage; fissile in part. 776-779 No sample. CORE ANALYSES Core samples from Skull Cliff core test 1 were analyzed by the personnel of the Geological Survey laboratory at Fairbanks, Alaska, and by S. T. Yuster at Pennsylvania State College. Porosity and permeabil- ity were measured by various methods, as given in the following table on porosity and permeability, and found to be very high (as much as 2,370 millidarcys of perme- ability and 35.6 percent porposity) in sandstone samples from depths of 110, 310, and 748 feet. The three samples studied at Pennsylvania showed a large drop in permeability to fresh water, compared to air or brine. Sieve analyses in the following table show the sandstones to be composed primarily of fine to very fine sand and a considerable amount of silt and clay. Petrographic analyses of the same three samples, in the table on petrographic characteristics, show that quartz is the most abundant constitutent and that slate or phyllite particles and chert make up most of the rest of the rock. Interstitial material includes clay minerals and a small amount of carbonate cement. The specific gravity ranges from 1.85 to 2.38; the lightest rocks ase sandstone, and the heaviest ones clay shale—as shown in the fol- lowing table on specific gravity. Heavy minerals were studied by Robert H. Morris who determined that the zoned -zircon zone is present in the hole between the depths of 110 and 450 feet, as shown in plate 40. 580 EXPLORATION OF NAVAL PETROLEUM RESERVE NO, 4, ALASKA, 1944-53 Porosity, permeability, and carbonate content of core samples from Skull Cliff core test I Number of instrument. Petrographic data on these three samples is Riven on p. 581. Determined at Qeologlml Survey Fairbanks laboratory Determined at Pennsylvania State College by S. T. Yuster Air permeability (mWidarcys) Effective porosity Permeability (millidarcys) (percent) Hayward permeameter tests in- gllnkenberg Depth (feet) Carbon- Effective atepo rosity content API Wash. (peroent) Fresh (percent 1947 1960 perme- burn- Barnes Air Before After Brine water by ameter Bunting methodll uid liquid weight) method Sow flow No. 81 No. 71 No. 71 110'----- ------- ------- 50 -------- --------- 25. 1 ------- 23. 2 ------------- 43.8 35.3 18. 9 0 150------- 7.86 745 ------- -------- --------- ------- ------- -------------------- ------- ------- -------------- 150------- ------- - ------------ - 1,250 ---------- ------ 28.8 -------- ------------------- ------- ------- ------- 150-------------- ------- ------- -------- ----------------------- ------- 870 ---------------------------- [52 ------- 5.36 1,600 ------- -------- --------- -------------- --------------------------- ------- ------- ------- [52 ------- -------------- --------------- ---------------- -------------- 17800-1,850 -------------- -------------- 154------- 5.72 1,600 ------- -------- --------- -------------- ------------------------------------------------ 154---------------------------- 1,500 >1,020 ------- 27.8 ------- -------------------- ------- -------------- 154------------------------------------ --------- ------- ------- ------- 1,800 ------- ------- ------- ------- 157------- 8.23 745 ------- -------- --------- ------- ------- -------------------- ------- ------- ------- ------- 157---------------------------- 2,370 ---------------- 31.05 _ -------------------------- ------- ------- ------- [59 ------- 7.62 1,100 --------------- --------- ------- ------- ----------------------------------------- ------- 159--------------------- ------- 1,220 X1,020 ------- 35.6 ---------------------------------- ------- ------- 162 ------- 8.66 -------------- -------- ----------------------------------------------------------------------- 162------- -------------- ------- 1,540 X1,300 ------- 30.09 -------------------- ------- ------- ------- ------- [64 ------- 9.72 675 ------- -------- --------- ------- ------- --------------------------- ------- -------------- 164------- ------- ------- ------- 710 715 ------- 28.5 _ -------------------------- ------- ------- ------- 166 ------- 8.12 780 ------- -------- --------- ------- ------- -------------------- ------- ------- ------- ------- 166-------------- -------------- 680 690 ------- 28.15 --------------------------- --------------------- 169------- 6.97 1,350 ------- -------- ---------------- ------- --------------------------- --------------------- 169-------------- -------------- ------------------------ 30.6 --------------------------- --------------------- 171------- 4.2 2,470 -------------------------------------------------------------------------------------- 171------- ------- ------- ------- 2,920 >2, 150 ------- 34.0 --------------------------- ------- ------- ------- 173---------------------------- 3,700 X3,000 ------- 34.0 ------------------------------------------------ 173------- 5. 12 -------------- -------- ----------------------- ------- ------------- ------- ------- ------- ------- 176------- 17.6 7.5 ------- -------- --------- ------- ------- 14.0 17.0 ------- ------- ------- ------- 176-------------- -------------- 104- 15 ------- 15.25 ------- -------------------- ------- ------- ------- W------- -------------- 76 ----------------- 16.6 ------- ------- -------------------- ------- ------- ------- 195 ------- -------------- 16.5 - -------- 22.4 ------- ------- -------------------- ------- -------------- ,97------- 13.2 11.2 ------- -------- --------- -------------- ------- -------------------- ------- ------- ------- 197 ------- ------- -------------- -------- --------- -------------- 20.7 -------------------- ------- ------- ------- 198------- 10. 4 48 ---450 - -----420 ------- -------------------- ------- ------- ------- 198 ------- ------- ------- ------- ------- 26. 6-- ------- ------------- ------- ------- -------------- 101------- 17.35 49.5 ------- -------- --------- ------- ------- ---------- ---------- ------- ------- ------- ------- 101------- ------- ------- ------- 96 110 ------- 24.1 ------- ------------- ------- ------- ------- ------- 101 ------- ------- ------- ------- -------- --------- ------- ------- 21.5 60.0 ------- ------- ------- ------- 103------- 11.2 157------- ------------------------------------------------------------------------------- 103---------------------------- 225 205 ------- 24.7 ------- -------------------- ------- ---------- 103---------------------------- ----------------- --------------22.6 153.0 --------------------- ------- 104 ------- 7.0 190------- -------- --------- ------- ------- ------------------------------------------------ 104------- ------- ------- ------- 160 170 ------- 25.6 ------- ------------- ------- ------- ------- ------- 104 ------- ------- ------- ------- -------- --------- ------- ------- 11.5 193.0 -------------- 10.8 450 ------------------------------------------------ ---------- ------- ------- ------- ------- 106------- ------- ------- ------- 560 515 ------- 26.8 ------- ------------- ------- ------- ------- ------- 106 ------- ------- ------- ------- -------- --------- -------------- 24.3 505.0 ------- ------- ------- ------- 110 ------- ------- ------- 530 -------- --------- 28.2 ------- ------- --------------- ----- ------- ------- ------- 110s----_ --------------------------------------- ______ _______ 26.3 ------------- 268 143 113 0 14-------------- ------- 285 ----------------- 27.3 -------------- -------------------- ------- -------------- 117------- 13.3 240------- -------- --------- ------- ------- ------- -------------------- ------- ------- ------- 117------- ------- -------------- 220 210 ------- 24 6 ------- ----------------------------------------- 117------- ------- ------- --------------- --------- ------- ------- 24.0 214. 0 ------- ------- ------- ------- 119------- 28.6 <10 ------- -------- --------- ------- ----------------------------------------- -------------- 119-------------- ------- ------- 500 470 ------- 26.3 ------------------------------------------------ 119------- ------- -------------- -------- --------- ------- ------- ------- <10------- --------------- ------ 121------- 23.2 < 10 -------------------------------------- ------- -------------------- ------- ------- ------- 121---------------------------- -------- 0 ------- 9.07 ------- -------------------- ------- -------------- 121------- ------- ------- ------- -------- --------- ------- ------- 10.6 1.3 _ ------------- ------- ------- 137------- 8.9 86 ------- -------- ---------------- ------- ------- ------------- ------- ------- ------- ------- 137------- - ------ --------------------- - 54 ------- 23.3 ---------------------------- ------ ------- ------- 137------- ------- ------- ------- -------- --------- ------- ------- 25.0 104.0 _ ------ --------------------- 139------- 15.0 78 ------- -------- ------- - ------ ------- 139------- -------------- --------------- 68 ------- 22.1 --------------------------- ------- -------------- 139-------------- ------- ------- -------------- ---------- ------- 24.0 97.3 ------- ------- ------- ------- Al------- 10.8 87 ------ ------- Number of instrument. Petrographic data on these three samples is Riven on p. 581. CORE TESTS AND TEST WELLS, BARROW AREA, ALASKA 581 Porosity, permeability, and carbonate content of core samples from Skull Cliff core test 1 -Continued Number Of Incrnimwnt, r Petrographic data on these three samples is given below. Sieve analyses of samples from Skull Cliff core test I Depth (feet) Determined at Geological Survey Fairbanks laboratory Determined at Pennsylvania State College by S. T. Yuster SC Quartzite, schist --------------------- --- olcanic rocks-------------------------- Air permeability (miMdarcys) Effective porosity 1 9 Permeability (millidaroys) 40 -mesh t0 -mesh 100 -mesh (percent) 200 -mesh ------------- Hayward permeameter tests in- (0.42 (0.42- Klinkenberg (0.119- (<0.047 Depth (feet) Carbon- Effective 0.25 mm) 0.149 mm) 0.047 mm) ate content (per by weight) 660 ------------ API perme- ameter Wash- bun- 8u-nYm saatD04 Barnes method porosity (percent) Air 17.50 Brine Fresh water 1947 1950 Before liquid flow After liquid flow No. 8 1 No. 71 No. 71 441------- ------- ------- ------- -------- 85 ------- 22.9 -------------------- 57.80 ------- -------------- 100.00 ------- 441------- -------------- 54.20 ------- -------- --------- ------- ------- 24.6 97.0 -- ------------ 8.30 ------- ------- '�------- 21.0 37 --------------- 32.45 --------- ------- ------- ------- ------------- ------- ------- ------- ------- 443------------------------------------ 4.60 56.80 18.20 19.00 38 ------- 20.8 -------------------- 71.20 -------------- 3.80 ------- ------- 443 ------- ------- ------- --------------- 13.80 --------- -------------- ---------- 23.0 44.6 ------- ------- ------- ------- 446 ------- 11.3 45 ------- -------- ------------- ---------------------------------------------------------- 7.65 19.15 33.20 40.00 100.00 101--------------------------- 446------- ------- ------- --------------- 41.10 27 ------- 20.7 ------- ------------- ------- ------- ------- ------- 446------------------------------=---------------------------- 2.76 55.00 24.30 18.00 10D. 06 806 ................ ...... 23.3 61.0 ---------------------------- 20.20 99.90 817 ........................... 610--------------------- 6.60 37.20 148 ----------------- 99.90 28.0 ------- ------------------------------------------------ 29.75 34.50 27.45 99.90 821 .................55 732------- - ------- ------ 16.8 --------- -------- 21 2 -------- ------ ------------- -------------- 36.30 ------- ------- 748--------------------- 6.20 10.70 115 ----------------- 99.90 29.2 .......... ---- 10.00 44.60 42.00 99.90 443----------------- 7'482-------------- 6.60 ------------------------------------ 35.90 47.60 99.90 446----------------- ------- 23.6 <10 99.1 99.7 60.6 38. 1 752------- -------------- 6.8 ----------------- 2&6 --- Number Of Incrnimwnt, r Petrographic data on these three samples is given below. Sieve analyses of samples from Skull Cliff core test I Depth (feet) Wentworth scale sand grain size, (percent) - SC Quartzite, schist --------------------- --- olcanic rocks-------------------------- Tr. Tr. 1 7 1 9 Biotite--------------------------------- 40 -mesh t0 -mesh 100 -mesh 200 -mesh 200 -mesh ------------- - ------------ (0.42 (0.42- (0.25- (0.119- (<0.047 Total montmo- mm) 0.25 mm) 0.149 mm) 0.047 mm) mm) 660 ------------ 136_________________ 1.76 8.50 55.10 16.20 17.50 100.05 ISO ----------------- 2.02 8.70 56.15 21.65 11.44 99.96 162----------------- 2.60 12.80 62.25 11.75 10.85 99.95 157_________________ __________ 9.30 57.80 15.80 17.10 100.00 169 ........................... 13.10 54.20 19.90 12.80 100.10 102--------------------------- 7.60 58.60 24.95 8.30 99.95 164_________________ __________ .42 29.20 37.90 32.45 99.97 166----------------- .62 9.23 48.65 23.65 17.65 100.00 109----------------- 1.40 4.60 56.80 18.20 19.00 100.00 171----------------- 6.00 18.60 71.20 3.40 3.80 100.00 178----------------- ---------- 25.50 57.70 3.10 13.80 100.10 176----------------- ---------- 4.50 23.60 44.80 27.00 99.90 297 ................. .......... .40 12.80 X3. 00 53.80 100.00 289--------------_----------- 7.65 19.15 33.20 40.00 100.00 101--------------------------- .72 22.50 35.60 41.10 99.92 103----------------- ---------- 2.90 38.70 27.45 30.80 99.85 am ................. .......... 2.76 55.00 24.30 18.00 10D. 06 806 ................ ...... 6.10 57.80 15.80 20.20 99.90 817 ........................... 6.60 37.20 36.80 19.30 99.90 219 ................. .......... 8.20 29.75 34.50 27.45 99.90 821 .................55 $0.10 44.90 24.40 99.95 487 ........................... 7.40 15.40 40.90 36.30 100.00 4�................. .......... 6.20 10.70 41.90 41.60 99.90 441_--' ............. .......... 3.30 10.00 44.60 42.00 99.90 443----------------- ---------- 6.60 9.80 35.90 47.60 99.90 446----------------- ---------- 2.40 7.20 32.20 58.20 100.00 Petrographic characteristics of sandstone from Skull Cliff core test I [Determined by Paul D. Krynlnel Characteristic Samples by depth 110 feet 310 feet I 748 feet Texture Average diameter range ---------- -mm__ 0.03-0.18 0.04-0.18 0.02-0.08 Principal mode ___________________mm__ O.frt 0.11 0.085 Grains: matrix: cement, ratio In percent- 70:15:15 85:12:3 90:5:5 Grain composition in percent Q11W99--------------------------------- 27 34 48 chert t---------------------------`------- 13 19 5 Vablimar8 8 5 Mlea a0. iotas .. ................. 3 Tr. Tr. 566b26 0-61-2 Petrographic characteristics of sandstone from Skull Cliff core test 1 -Continued 1 Samples by depth Chseaokerlstics 110 feet I 310 feet 1 748 tat Grain composition in percent -Continued Slate, phylute__________________________ 17 21 SC Quartzite, schist --------------------- --- olcanic rocks-------------------------- Tr. Tr. 1 7 1 9 Biotite--------------------------------- Present ----- -------------- Chlorite -------------------------------- Present ------------- - ------------ latawdal material in percent Chlorite--------------------------- ---- 2 2 ----------- - Bericite------------------------- 1 1 ..._.__.__.._. nute---------------------------------- 8 3 i Montmoriuonita; kaolinite-------------- 5 6 : Carbonates ----------------------------- 15 2 400 ------------ Peru spate and characteristics Pore size, principal mode ----- mlcrom_.. 45 60 35 Visible porosity --------------- percent__ 15 25 20 Residual porosity----------------------- Good Very good Good Clatod wall arse, --------- parcent-_ 60 kao- 30 Kaounite, 25 HIlte, kao- Wall costing --------------------- type-_ IMte Very fine grained sandstone. 400 ------------ 2.34 llufte, montmo- linite, Very fine grained sandstone. montmo- rlBonite montmo- 660 ------------ rillonite Siltstone. rlllonite Potential hydration --------------- --__. Very high Very high Moderate Specific gravity of samples from Skull Cliff core test 1 Depth (feet) Specific Rock type gravity 120 ------------ 2. 31 Clay shale. 160 --_--_-_-__- 1. 85 Fine-grained sandstone. 220 ------------ 2.35 Clay shale. 300------------ 2. 05 Very fine grained sandstone. 400 ------------ 2.34 Clay shale. 440 ------------ 2. 00 Very fine grained sandstone. 500 ------------ 2. 31 Clay shale. 660 ------------ 2.19 Siltstone. 760 ------------ 2. 38 Clay shale. 582 EXPLORATION OF NAVAL PETROLEUM RESERVE NO. 4, ALASKA, 1944-53 LOGISTICS A tractor train hauling 500 tons of equipment and supplies to the well site left Barrow on January 20, 1947, and reached Skull Cliff 6 days later. The next week was spent rigging up and searching for a water supply. A Failing 314-C rig was used in this test. Nearby lakes and streams were probed with steam points and found to be frozen solid; water sufficient for drilling operations was not found until a passing Eskimo pointed out a lake 2 miles away where 4 feet of ice covered 15 feet of water. Wanigans (small one -room buildings generally mounted on runners or skids to facilitate moving) were used to haul water to the rig, and to house both the personnel and the equipment. The major items of equipment used are described on page 585. The 6- by 6- by 3 -foot cellar was used for a mud sump before casing was set; a steel drum with the ends cut out was frozen in as a conductor pipe, to prevent mud and cuttings from washing down the hole. DRILLING OPERATIONS Depth Notes from drilling records Remarks Ved) 30-------- Seven-inch casing set at 30 ft and cemented with 10 sacks of cement. It was left under pressure for 14 hr, and then steamed. Steam forced in hole formed bubbles in the cement that twice caused explosions that blew all the water out of the hole, before it was found that the cement plug was higher than the bottom of the pipe and the steam point was being submerged in it. Bubble was prevented from forming again by keeping steam point moving, and cement set satisfactorily. 100------- Hole drilled to 100 ft with 6,% -in. rock bit. 779- - - - - - - Below 100 ft the hole was cored with a Reed Kor- King 5Y8 in. core barrel. Below 150 ft mud made by shale was very viscous, but almost continuous addition of water maintained desired viscosity, although some caving was noticed from upper sand and gravel. Mud temperature kept near 36° F. Outdoor temperatures were as low as 54° below zero, and wind velocities were 10-50 mph. While drilling at 779 ft, drill pipe parted at 527 ft, and could not be recovered. Mud not circulated for 20 hrs while a spiral guide was being sent from Barrow, and hole froze solid from surface to 250 ft and had ice on the wall at least as low as 525 ft. After cleaning out, fishing began again, but unsuccessfully. During another wait, for a hydraulic hook, the mud was heated and circu- lated through the hole, but ice had to be reamed from the wall before the hook could be lowered. It went down to 290 ft, and was stopped by ice; it was pulled out, and hole abandoned. Mud was bailed down to 527 ft, and allowed to stand for 24 hrs. Hole was then filled with 16 bbl diesel fuel, and after standing for 16 hrs, fluid level had dropped a foot. Hole was capped with wooden plug driven in top of casing and marked with an 8 -ft piece of 2- by 4 -board nailed to the plug in an upright position. The wanigans were thawed free of the ground, and the tractor train began the trip back to Barrow on March 17, 1947. In August of 1948 J. H. Swartz and G. R. MacCarthy of the U.S. Geological Survey visited the well site and, after knocking out an ice bridge 5 ft down, lowered a thermistor cable into the hole. Preliminary computa- tions of the temperature at various depths determined from the thermistor data are shown in the following table on temperatures. Temperatures in Skull Cliff core test 1, in August 1948 Depth (Jett) Temperature (°F) 5----------------------------------------- —0.7 10---------------------------------------- —5.0 20---------------------------------------- —9.1 30---------------------------------------- —9.3 40---------------- ----------------- —9.2 50---------------------------------------- —9.2 60---------------------------------------- —9.1 70---------------------------------------- —9.3 80---------------------------------------- —9.5 90---------------------------------------- —9.5 100--------------------------------------- —9.6 200--------------------------------------- —9.6 300--------------------------------------- —8.8 400--------------------------------------- —7.8 500--------------------------------------- —6.7 ARCON BARROW CORE TEST 1 Location: Lat 71°1940" N., long 156a40'01" W. Elevation: Ground, 10.5 feet; kelly bushing, 18.5 feet. Spudded: March 29, 1947. Completed: May 3, 1947. Dry and abandoned. Total Depth: 1,442 feet. After returning the Failing 314—C drilling rig used at Skull Cliff to the camp at Barrow, it was rigged up within the camp area to drill for stratigraphic informa- tion and to experiment with reverse circulation for coring. The test drilled through about 60 feet of gravel and sand with some ice and mud, representing the Gubik formation of Pleistocene age. At 100 feet, coring with reverse circulation was begun, but this procedure was unsuccessful because the mud leaked around the casing and went into the rock instead of back up the drill pipe. The method was abandoned, and conventional circulation adopted for further work. The test was drilled in sandstone beds underlain by a sequence of clay shale that represented the Grandstand formation (60(?),410 ft) and the Topagoruk formation (410 ft to the bottom of the hole), both of Cretaceous age. (See pl. 39.) The test was abandoned at 1,442 feet, the safe drilling limit of the rig. No oil or gas was found, but bailing at 125 feet, after the well had reached the total depth, showed that salt water was entering the hole. PV or/Tye• THE STATE Department of Environmental � o f�T AsKA Conservation } Division of Spill Prevention and Response r GOVERNOR SEAN P A R N E L L Contaminated Sites Program 610 University Ave. ALABn'" Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.5105 p` File: 320.38.010 March 19, 2014 Wayne Svejnoha , BLM—Division of Resources swat) APR 2 2 70 4 222 W 7th Ave, #13 Anchorage,Alaska 99513 Re: Meeting April 3 or 4 to Provide Information Requested in PRP Letter for 10 Legacy Well Sites Dear Mr. Svejnoha: State Director Bud Cribley responded to our February 4 letter identifying BLM as a Potentially Responsible Party (PRP) at 136 legacy well sites. We appreciate BLM's offer to sit down with representatives of ADEC as soon as possible "on a site by site basis" to provide information requested in our PRP letter. This letter is a request for BLM to schedule a 4 hour meeting on April 3 or 4 to review your records on 10 of the 136 legacy well sites. If the files are large, the meeting should take place where they are located. ADEC was not previously aware that Site Inspection Reports had been prepared to document any indication of contaminant release at these sites. I previously sent to you BLM and EPA guidance on what is to be included in a Site Inspection report. It is my hope that our review of your investigation reports and data will answer all of our concerns at these sites. We should also discuss how our agencies can cooperate in the future so that your future sampling is conducted in compliance with both state and federal laws. Thank you again for offering to meet with us to clear this matter. Please contact me at (907) 451-2181 with the meeting time and place. The attached"ADEC Meeting Request" describes in detail the information we expect to review. We will not have time to review all sampling and workplan information at this meeting so I am requesting that you either provide those electronically or allow us to copy the original records. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: ADEC Meeting Request Concerning 10 Legacy Well Sites BLM Letter to DEC Commissioner Hartig dated March 11,2014 ADEC Info Request for NPRA Wells Wayne Svejnoha 2 March 19, 2014 cc: Bud Cribley, State Director,Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet,Branch Chief,Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Lon Kelley, Field Manager,Arctic Field Office, BLM Steve Hartmann, District Manager, Fairbanks District Office, BLM Larryarti Commissioner,Hartig, Cominiss oner,Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,Alaska Department of Environmental Conservation Lori Aldrich, Program Manager,Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager,Alaska Department of Environmental Conservation Jennifer Roberts,Program Manager,Alaska Department of Environmental Conservation G:\SPAR\CS\Contaminated Site Files(38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\3-19-14 Letter\Request for Meeting to Review 10 ADEC Meeting Request Concerning 10 Legacy Well Sites ADEC is requesting that BLM Schedule a meeting on April 3 or 4 to review BLM records concerning 10 legacy well sites. ADEC will review these reports with you "on a site by site basis" as agreed in Mr. Cribley's letter. To limit the scope of this first meeting ADEC has narrowed our request down to 10 specific well sites. Three of these sites are already listed by ADEC as contaminated sites, and seven of them are selected from information in the BLM "strategic plan" and other documents.All except the Skull Cliff site ranked "low" or"none" on the BLM risk ranking system used in the strategic plan report. This meeting may be scheduled either at BLM offices in either Anchorage or Fairbanks if that is convenient, or we will make conference room space available at ADEC offices. We are offering to meet at BLM if that is convenient so that you will not need to transport voluminous files. ADEC has suggested any time on April 3 or 4, and we are open to BLM suggestion of other dates. We encourage BLM to schedule the meeting"as soon as possible" as stated in Mr. Cribley's letter of March 11. Reviewing a site inspection file and site ranking typically takes about 20 minutes each, so we expect this meeting to last about 4 hours. If the site inspection report does not include all of the elements expected this may take less time. We are requesting that BLM provide electronic copies of your files because typically ADEC has specialists review data, lab reports, field notes, and work plans. The purpose of the ADEC review is to determine whether all of the required elements of the SI are present and to determine whether the sampling data supports the BLM determination that no further remedial investigation is required. The Federal regulatory requirements for an SI report are identified in BLM and EPA guidance, and the State reporting requirements are itemized in 18 AAC 75. These guidance and rule documents have been provided to BLM electronically. At the meeting ADEC expects to see the SI reports Mr. Cribley referred to and all supporting information, including the PA that was prepared for each of these sites. If BLM prepared comprehensive reports covering multiple sites that are not on this list we are requesting that BLM bring reports and files for the entire subset the report covers, but to limit specific information, data packs and appendices to just these 10 sites. We have requested that BLM provide electronic copies of all of the records that will be reviewed at this meeting. If these are not available ADEC requests access to the original reports and files out so that they can be scanned. Most of the sites on this list have records documenting historical sampling data confirming petroleum and other contaminant releases. BLM's SI workplans,records and reports will therefore include environmental sampling to support your presence/absence determination. ADEC has formally communicated to BLM that this type of environmental sampling activity requires workplan review and approval under 18 AAC 75, and this approval was not obtained. Please note that one of ADEC's objectives for this and subsequent meetings is to make sure future environmental sampling by BLM is compliant with both state and federal requirements. In the interest of cooperation ADEC will review your data at these sites even though we did not approve the SI workplans prior to the sampling. ADEC understands that the BLM and EPA PA and SI guidance typically does not apply to petroleum releases,however we note that if you followed the BLM guidance during the"site verification",PA, SI,RI, FS, ROD and removal action planning steps then the BLM CERCLA response process will meet all substantive state requirements at petroleum sites as well. To fully comply with state law BLM must also submit your workplans to the state of Alaska for approval under 18 AAC 75. Significant time can be saved during the Remedial Action process if the site is "petroleum only" by following the state process and not all of the CERCLA steps. ADEC has informed BLM previously that cleanup decisions must consider both state and federal requirements. The hazard ranking system (HRS) used to determine inclusion on the National Priorities List is not appropriate for a no further action decision under state law, and the state requirement is also recognized under federal law. Regardless of the HRS score,he state of Alaska expects BLM to clean up the petroleum and other hazardous substance releases and mitigate any exposure to contaminants left in place that may continue to pose a threat to human health of the environment. The HRS score may be used, however, to prioritize response actions under state law. We expect to review all of the hazard ranking system inputs for these 10 sites during our meeting. Alaska regulations governing contaminated site characterization and cleanup requirements and ADEC "eco- scoping"guidance were provided electronically. These requirements are pertinent to many of the Legacy Well sites.Your records will be reviewed for compliance with these requirements.Alaska's statutes, regulations and guidance are generally consistent with the BLM and EPA CERCLA process, therefore a PA and SI performed under CERCLA will typically be compliant with state law as well. Screening levels must be developed under both state and federal guidelines in order to select the most applicable or relevant and appropriate requirement. A site inspection report will include identification of contaminants of concern, selection of screening levels, site inspections to determine the presence or absence of these contaminants, an evaluation of exposure pathways, and recommendations based on the investigation. At a minimum ADEC expects to see the SI report for each of the sites below, any workplans and workplan approvals for the environmental site work and sampling, and the Preliminary Assessment (PA) performed prior to the Site Inspection. Reports that include data should have all lab reports, data quality analysis,lab review checklist,chain of custody and other data submittals attached. PA reports should have historical reports and documents attached as appendices along with a summary of the historical information to guide the site inspection. Please have all appendices, figures, and photos for the reports as well. Requested Meeting to review SI reports on these 10 well sites with BLM BLM 2013 Well Name Operator Risk Priority Ikpikpuk#1 USGS Low Koluktak#1 USGS Low South Meade #1 USGS Low Tunalik #1 USGS Low East Simpson #2 USGS Low Cape Halkett #1 ** US Navy Low Inigok#1 USGS Low East Teshekpuk#1, USGS None Skull Cliff Core Test#1 US Navy High Kaolak #1 US Navy Low ADEC appreciates BLM's offer to meet to clear up our confusion about the environmental investigations you did at these sites. Our agency was previously unaware that BLM performed Site Inspection investigations at these sites. Our concerns were based on the fact that when site inspections were performed by the US Army Corps of Engineers at 11 legacy well sites around Umiat all of them were found to be contaminated and 9 of those sites required remedial action. These SI reports of your investigations will certainly alleviate the ADEC concerns that further removal actions may be required at the other legacy well sites. To prevent further misunderstandings like this we would also like to discuss how our agencies can cooperate in the future so that your future sampling is conducted in compliance with both state and federal laws. Workplan approval and ADEC oversight of these types of investigations is a state requirement. Please schedule this meeting as soon as possible with Mr. Fred Vreeman at (907) 451-2181. The enclosed "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. ,0-<191'e,„ United States Department of the Interior ty BUREAU OF LAND MANAGEMENT Alaska State Office 222 West Seventh Avenue,#13 Anchorage,Alaska 99513-7504 http://www.blm.Qov In Reply Refer To: 6717 (AK9300) MAR 112014 Mr. Larry Hartig Commissioner Alaska Department of Environmental Conservation P. O. Box 111800 Juneau,Alaska 99811-1800 Dear Commissioner Hartig: We are in receipt of a Potential Responsibility Party Notice Letter and Information Request from the Alaska Department of Environmental Conservation dated February 4, 2014. As stated in our August 28, 2013 response (enclosed)to your July 11 letter, the BLM is eager to continue working with the Alaska Department of Environmental Conservation as we implement the 2013 Legacy Well Strategic Plan. The BLM's 2013 Legacy Well Summary Report included site history, land status and operator history for each well site,as well as a site by site risk ranking based on information collected during site inspections. As part of the BLM's surface risk assessment process, site inspection reports documented any indication of contaminant release or visible contaminants. My staff is available to discuss any questions that ADEC has concerning potential releases on a site by site basis. Much of the information requested in your letter is available in the Summary Report, and additional information can also be provided. The BLM would like to sit down with representatives of your agency as soon as possible to discuss and share information about wells of concern. My staff will be in contact with your staff in the coming days to schedule a meeting and develop a process to address the issues raised. Please feel free to contact me if you have further questions. Sincerely, Bud C. Cribley State Director Enclosure cc: Fred Vreeman, ADEC Lynn Kent,ADEC Kristen Ryan, ADEC Lori Aldrich, ADEC Steve Bainbridget,ADEC Jennifer Roberts,ADEC 4r: } y, United States Department of the Interior ws.-71,gei y' BUREAU OF LAND MANAGEMENT ~ ►+-1 Alaska State Office 222 West Seventh Avenue,#13 Anchorage,Alaska 99513-7504 htlp://www.blm.aov In Reply Refer To: AUG 2 8 2013 1794(9300) Mr. Larry Hartig Commissioner Alaska Department of Environmental Conservation P.O. Box 111800 Juneau, Alaska 99811-1800 Dear Commissioner Hartig: Thank you for your comments dated July 11, 2013,regarding the Bureau of Land Management's (BLM)National Petroleum Reserve in Alaska(NPR-A)2013 Legacy Wells Strategic Plan. We appreciate the work you and your staff have put into reviewing our Plan and providing us with your feedback. The BLM is eager to continue working with the Alaska Department of Environmental Conservation as we continue with clean-up and plugging efforts at legacy well sites throughout the NPR-A. The 2013 Strategic Plan is based on data compiled through multiple years of site visits and monitoring activities. It outlines priority locations and actions that the BLM will take in the near-term to plug and clean up Iegacy wells in the NPR-A,but does not go into site-specific work plans. The BLM's May 2013 Legacy Well Summary Report includes a site by site description and risk ranking for each well,based on information collected during site inspections and application of a risk assessment methodology. That methodology is described in the report. The BLM considers the Legacy Well Summary Report a thorough review of the status of each site and I do not believe that an additional programmatic review of each site is required at this time. As part of the BLM's surface risk assessment process, site inspection reports documented any indication of contaminant releases or visible contaminants. The BLM will involve your agency in the plan to evaluate and, if appropriate, remediate any sites where there is a known or potential release of contaminants into the environment, including at legacy well sites. I appreciate the discussions we have had to date and look forward to continuing our dialogue regarding ADEC's concern that certain wells appeared to have had confirmed releases. ro ° dr o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 2 My staff is available to discuss any site specific concerns or information that ADEC may have. I Iook forward to continued cooperative and productive coordination between our agencies. Sincerely, Is/Ted Murphy Bud C. Cribley State Director ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties)which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship,that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. 1 177, �A THE STATE l� �vu L of 1. AsCans vatrol r ' KA' Division of Spill Prevention and Response if :-== ",� Contaminated Sites Program „�'._v GOVERNOR SEAN PARNELL + 610 University Ave. ALAS"- Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage,Alaska 99513 Re: BLM Legacy Wells Dispute SCANNED AP 2 5 201 Dear Mr. Svejnoha: The Alaska Department of Environmental Conservation (ADEC) —Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve— Alaska (NPR-A), and the draft National Petroleum Reserve in Alaska: 2013 Legacy Wells Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by AOGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we are outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment or the contingency for assessment of known,likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil,gasses,refined oil and fuel, drilling fluids that include various organics,metals,and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our limited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites,impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down-hole substances that were ejected from the holes over time or during blowouts or drilling operations. . Wayne Svejnoha 2 July 11, 2013 The BLM plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC —Contaminated Sites,Alaska Oil& Gas Conservation Commission, and ADEC—EH/Solid Waste. Other agencies will need to be consulted as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re-visited in the future when they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) This is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an SI is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCLA and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization,but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR,PA,and SI then a RI/FS under CERCLA, or a Site Characterization Report and cleanup plan under 18 AAC 75 is required. DEC recommends that BLM incorporate into the strategic plan the processes outlined in this letter. A team of agencies composed of AOGC, DEC-CS, EPA as required, and DEC-EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utili7e the generic UFP-QAPP workplan format for the required environmental work. If properly prepared,the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi-site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. (:.\cr.AP\CC\ FP,i P.,l Aornriec\flflT\RT.M\Proiects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx Wayne Svejnoha 3 July- 11, 2013 Please review the attached list of specific sites. If you have any questions,please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G:\SPAR\CS\Federal Facilities\Civilian Federal Agencies\DOI\BLM\Projects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx �„ - h' 2 10 T+O-• CO "O 'O t o N a) N C N N co d = a) 0 c m CC CC COco ca ca CO 014 COCO m CO a) COCOCO ° a) 5 co • N N o CC (3 <O (a CO CO N (a CO 0 ul 0) a7 5 a7 a) <O cO 0 <O 0 CO(a. 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Abreak-down of the 136 is as follows: • 39 are uncased core holes that did not penetrate oil and gas zone, have naturally collapsed, and have blended harmlessly into the landscape. • 33 were either transferred to the North Slope Borough through the Barrow Gas Field Act of 1984 or were conveyed to Arctic Slope Regional Corporation. • 20 wells are being used to by the United States Geological Survey (USGS) for climatic temperature and permafrost studies (see Appendix B). • 7 wells are plugged (6 at Umiat, Square Lake #1). • 37 wells that require further evaluation. Following the 2003 field season, members of the legacy well team met to determine criteria for evaluating the risks associated with the above mentioned 37 wells and ranking each well based on these risks. For consistency purposes, the group devised a series of questions to assist in the process: • What is the condition of the existing pad and pits? (e.g. any indication of contamination?) • Is there any solid waste (old equipment, piping, barrels, etc.) or potential hazardous material conditions? • Did the hole penetrate known oil or gas stratigraphy? • Did the well have oil or gas shows, and if so, is the well capable of flowing? • Is the well near human activity, and if so are there conditions present that pose a risk to people? • What is the condition of the wellhead? Have there been any previous problems or repair work? Does the well (in its current condition) pose a risk? • What is the surficial condition of the existing pad and pits? Is contamination a possibility? • Does the presence of unplugged wells have the potential to negatively impact anticipated development? Each of the 37 wells are described in the following pages. Descriptions are ordered in terms of the ranked priority based on the above stated criteria and the concerns identified. Umiat Wells The early Navy wells in Umiat rank at the top of the list. Umiat is located on the north bank of the Colville River 60 miles upstream from the village of Nuiqsut. Natural oil seeps were discovered at Umiat by early explorers. This discovery, along with the detection of seeps at Cape Simpson, motivated the U.S. Navy to conduct a drilling program. Umiat and the Simpson Peninsula were the primary exploration targets in the mid to late 1940s. The Umiat seeps are still visible today. Their locations tend to shift over time. The seeps are currently active in Umiat Lake, just off the northeast portion of the airstrip and in a channel of the Colville River. ~~ s~ 22 ~~ • ~ , The 11 Umiat wells were drilled from 1945 to 1952. These wells are a concern for BLM due to their close proximity to human activity. Umiat is not a village, but serves as a camp for seismic crews: Umiat is also the primary hub for recreational activities in eastern NPR-A and western CAMA (Central Arctic Management Area). It has one of the - few airstrips on the North Slope maintained year-round and is a popular location for purchasing aircraft fuel (Figw•e 10). The Unuat wells all lie within 2 miles of the camp, with the exception of Umiat # 1, which is approximately S miles to the northwest. After the U.S. Navy completed drilling operations in 1952, the U.S. Air Force assumed custodial responsibility at Umiat and established the 8,000-acre Umiat Air Force Station. In Tune of aircraft. 1955 the Air Force returned the facility to the U.S. Navy. Since Umiat is a Formerly Used Defense Site (FUDS), the U.S. Army Corp of Engineers (COE) is responsible for the reduction of risk associated with surficial hazardous, toxic, and radioactive waste. The COE has conducted extensive surface investigations in the area and has identified contaminants at several locations. Varying levels of barium, petroleum, pesticides, and polychlorinated biphenyl (PCB) were identified at the wellsites, the landfill, and the nearby slough (U.S. Arnry COE, 2003). Contamination levels were compared to the Alaska Department of Environmental cleanup standards and were used as a screening level. The COE has conducted site remediation at two well locations, Umiat #2 and #5 (Figure 11), and has plans to continue the surface clean up. To facilitate site remediation, the COE plugged wells #2 and #S in 2002, but plugging the remainder of the wells is the responsibility of the BLM. Four wells were plugged by the BLM in the Winter/Spring of 2004. After the removal of wellheads #2 and #5, the State of Alaska Historic Preservation Office asked the BLM to leave all existing surface objects (wellheads, tanks, pipes) onsite and intact, because of their potential Figure 11: Umiat #2 and #5 prior to removal and historic value. The Alaska Heritage remediation. Photo taken August 2001. Resources Survey (AHRS) included the Umiat wells in an inventory of all reported historic and prehistoric sites within the State of Alaska. This inventory of cultural resources includes objects, structures, buildings, sites, districts, and travel routes generally more than SO years old. Therefore, the wellheads for the other Umiat wells will be left in place after plugging is completed. 23 Umiat #9 • Umiat #9 was spudded in June 1951 and completed seven months later in January 1952. The well is cased to a depth of 1,257 feet. The purpose of the well was to determine the western extent of the producing field. It was also the first hole in which oil-based muds were used in the Umiat area. Umiat #9 is located about half mile to the north-northwest of the Seabee pad. The drill hole penetrated several known oil and gas formations; Ninuluk, Chandler, Grandstand and Topagoruk. Hydrocarbon shows were prevalent within both the Grandstand and the Topagoruk formations. Multiple sands were perforated and tested. Production exceeded 217 barrels per day, thus seemingly showing the benefit of using an oil-based mud. However, the muds did -- not allow the different formations to be distinguished. Cement was used in an attempt to "plug back" and isolate individual formations. Samples were taken and sent to a Bureau of Mines lab where the chemical tracer (used during drilling) was measured and the various sandstone samples were examined. This allowed a study of the different lithologies be conducted. The tracer Aroclor used in the well has raised concerns about PCB contamination. However, the well was allowed to flow for seven weeks at 200 barrels per day (Robinson and Bergquist, 1956) prior to shutting it in, possibly purging the potential contaminants. As it stands today, insufficient energy exists in the reservoir for the well to flow to surface and the wellhead has no pressure on it. The well is located within the Northeast planning boundary (see Map 2) on lease AA- OS 1726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. Surficial wastes around Umiat #9 could present an issue. As was common with early Navy drilling, a gravel pad was not created. Wooden debris exists around the wellhead and there is a pile of drilling muds directly to the north which is void of vegetation (Figure 12). Samples taken by the COE from around the wellhead detected elevated levels of diesel range organics (DRO), residual range organics (RRO) and PCBs (U.S. Army COE, 2003). 24 • • The wellhead is equipped with two bull plugs, a flange and a 2 '/-inch nipple. There are no fresh water aquifers in the area, but due to potential contaminants downhole and existing contaminants on the surface, the well does pose a risk to human health and the environment in its current condition. Umiat #6 Umiat #6 was spudded August 1950 to test the southern limits of the Umiat anticline. The hole was drilled to a depth of 825 feet. The well was cased to 35 feet and a 42-foot cement plug was placed on the bottom of the well in order to stop water influx fioin sands a.t the base of the. permafrost. The well encountered very poor shows in the Killik Tongue (Chandler Formation} and a productive sand in the upper Grandstand Formation. Oil recovered in open-hole pumping tests was produced at rates averaging 53 barrels of oil per day. Insufficient energy exists in the reservoir for the well to flow to surface and there are no fresh water aquifers present. Major caving of the hole occurred and the well was backfilled with mud (Robinson and Bergquist, 1956). The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. The well lies about 500 feet to the northwest of a gravel spur road which connects the Colville River to the eastern edge of the Umiat airstrip. The well is located in wet tundra adjacent to an empty 55-gallon drum. The well is left open with 8 5/8-inch casing to the surface. It has no gauges, valves or a cover plate. Two thermistor protrude to the surface and rests on the lip of the casing. This well poses no threat to human health or the environment unless development occurs. Umiat #7 Umiat #7 was drilled in 1951 to a depth of 1,384 feet, cased to 1,196 feet and completed as a dry ~~ hole. It was the southern most well drilled on the ~`-~~ _ Umiat anticline. The ~ objective was to further delineate the southern extent of the producing Figure 13: Umiat #7 summer and winter photos. field. The well encountered residual hydrocarbons in the Chandler and Grandstand formations. Oil recovered in bailing tests was so minute that it was measured in gallons. The small amount of crude recovered in each test is indicative of residual oil staining. The sands encountered in Grandstand are downdip of the productive reservoir and are water bearing. Minor gas shows were encountered at 260 feet (Robinson and Bergquist, 1956). The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the 25 next 20 years but since the well is located below the oil/water contact it has less potential to be adversely affected or affect future development. The wellhead assembly consists of 7-inch casing (with collar) clamped inside 11 3/-inch casing at a total height of 30 inches (Figure 13). Surrounding the open hole is wet tundra with no indication of remaining debris or other surficial issues. The hole poses no tlueat to humans or the environment. The well location is cun•ently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional Umiat Work Umiat has been a site of recent cleanup projects. The cleanup process began in 1994 with the removal of about 1,000 drums, some containing petroleum and transformer oil with PCBs, from the main gravel pad. Another 200 cubic yards of PCB-contaminated soil was removed in 1998 along with 60 cubic yards of lead-contaminated soils. In 2001, 50 cubic yards of PCB soil was excavated with an additional 10 cubic yards removed the following year by the Corps of Engineers (U.S. COE, 2003). J.W. Dalton #1 J.W. Dalton #1 was drilled in 1979 to a depth of 9,367 feet. It is cased down to 8,898 feet and plugged back to 1,530 feet. (Husky Oil NPR Operations for U.S. Geological Survey-J.W. Dalton, 1982). The primary objective of the well was to determine if hydrocarbons were present within the Sadlerochit and Lisburne Groups. Gas shows were encountered in trace amounts in the Ivishak Formation, and the Lisburne and Endicott Group. Poor to good oil shows were discovered in the Ivishak Formation and in the Lisburne Group. A drillstem test of the Lisburne Group recovered 22 barrels of oily water (Gyrc, 1988). This well has been a USGS monitor well since its completion in 1979. Approximately 230 barrels of diesel fuel were placed downhole to act as a neutral medium for collecting wellbore temperatures. In the summer of 2004, warmer temperatures, wind, and wave action eroded 200 feet of the coastline adjacent to the well (Figures 14, 15). This erosion placed the J.W. Dalton #1 well and reserve pit precariously close 26 Figure 14: Photo of J.W. Dalton taken October 26, 2004. Soil cracking is occurring around the wellhead and the north and east side of the cellar is exposed. Figure 15: J.W. Dalton wellhead with pilings. Photo was taken August 2000. to the edge of the Arctic Ocean. As a result, casing is now exposed to a depth of 15 feet on the present day beach (Figure 16). The top of the diesel is approximately 60 feet below the present beach level. The reserve pit has been breached on the northwest coiner from the advancing shoreline (Figure 17). The pit is known to contain chromium, cobalt, zinc, and barium. However, chromium, cobalt and zinc were detected in background levels, due to the east-west water movement into and out of the pit. Barium is a constituent of the drilling muds and is consolidated with other sediments (U.S. Bureau of Land Management, U.S • Geological Survey, 1992). The well is located within the Northeast planning area (see Map 2), on a tract currently closed to leasing. This well is in danger of becoming engulfed by the ocean. The diesel fuel in the well and In its cunent condition, the well does not pose a threat to humans or the environment, but if the casing were to break in its exposed condition, the diesel fuel would, over time, leak into the ocean. The release of heavy metals from the reserve pit may pose an immediate risk to human health and the environment. The pit was sampled October 26, 2004, and results are pending. 27 Figure 16: J.W. Dalton with exposed conductor (left), and rat hole (right). The mouse hole (not pictured) is completely exposed. ~ ~ ~~~ ~~ ~~ r i. t ~'~ ~,~ _ 7 .= . __ _~: ~~~° ~;~ y,,,_s ~ ` 14~A . „f$11Ap60n ~~ ~ 3Q/~l - ~ ai SWI7~&Wl #t{ S -°^, '{ ~, ~ '';{ ~ Q Figure 18: Simpson Peninsula showing well locations. Simpson Core Test #26 Simpson Core Test #26 was drilled in the middle of one of the larger, active oil seeps in NPR-A (Figure 19), The Navy described this location as Seep 3. The hole reached a total depth of 1,171 feet and was cased to 350 feet. The well encountered one very poor gas show and one productive oil sand in the Ninululc/Seabee undifferentiated formation. In production tests, the well flowed at rates averaging 110 barrels of oil per day (Robinson and Brewer, 1964). Other formations encountered include the Gubik, Seabee, and Grandstand Formations. Gas bubbles have been observed around the base of the casing since the 2000 field season. Bob Burruss of the USGS, sampled and analyzed gas from Simpson Core #27 which is part of the same oil field, located less than half mile to the east. His findings showed the gas to be biogenic methane indicating that microbial alteration (breakdowns) of the hydrocarbons has generated the gas. Additionally, oil sampled in the well was extteinely biodegraded. Simpson Figure 19: The wellhead is located in the center of Core #26 has a wellhead flanged to the the photo. The green color liquid defines the area of active seepage. The orange color is oil-eating casing, a 2-inch line pipe, and four bacteria. wing valves and will likely flow oil if Simpson #28 Minge6, ~ psi E88t Simpson lC2~ ~~~ ,~~~,~ 4 Y +rrk-' 28 • the valves are opened. Access to the wellhead is limited by the depth of oily-water sui7•ounding its base (Figure 20). There are no concerns with contaminating fresh water aquifers if the well is left unplugged, but the well could potentially flow oil and cause damage to surface resources if the well equipment corrodes or, through human intervention, the well is opened or damaged. The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased, receiving a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The area around the wellhead looks to have been bulldozed in an attempt to collect the seeping Figure 20: Simpson Core #26 drilled in the middle of an oil. The scraped-up earth waS oil seep. Depth of the oily-water prohibits access to the then used to build berms around Wellhead. the depression. Light amounts of trash appear to have been buried in these berms. The Navy cleaned up the site in the late 70s, removing most of the drums and other debris, but solid wastes, including half barrels and other drums can be found in the wet tar that fills the depression. Simpson Core Test #31 29 psi. The well also penetrated the Gubik and Seabee Forniations, which were unproductive (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the. next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. A drilling pad does not exist as the well was drilled in an active oil seep, which remains active today (Figure 21). The Simpson Peninsula contains few permanent settlements, but a multitude of summer camps. The well had been a source of fuel for the inhabitants as evidenced by a 10-foot extension pipe hooked up to the wing valve. The extension allowed for the oil to flow down the pipe and collect in a bucket. In 2000, BLM learned that oil was seeping out of a corroded swedge on the wellhead. The potential harm was mitigated by the fact oil was seeping into a natural oil seep. In June 2001, BLM spent $35,000 to remove the old wellhead and install a new master valve and needle valve. Oil and gas samples were taken by the USGS prior to the replacement. There are no fresh water aquifers in the well so there are no risks to sub-surface resources but there are risks to surface resources if the well is left unplugged. Oil will flow to surface if the wellhead or casing corrodes or if the well is left open. There are no solid wastes or hazardous materials (besides the natural oil) that would present a concern or pose a risk to the health and safety of the land and people. Simpson Core Test #30A Simpson Core Test #30A is an oil well drilled in 1951 to a depth of 693 feet and cased to 152 feet. The well encountered some very poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. The well was bailed and averaged oil rates of 6 barrels per day dw•ing bailing tests (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The wellhead consists of casing swedge, a nipple, and a brass gate valve and will flow-oil to surface if the valve is opened. There are no sub-surface fresh water aquifers at risk. However, if the well is left unplugged it could pose a risk to surface resources. In its current state, oil could flow to surface if the well is damaged, corroded, or the valves are opened. Additionally, concerns have been raised regarding the bubbling around the base of the casing. When the valve is opened, the bubbling subsides. This indicates a small leak around the base of the casing or through a hole in the casing. The gas was sampled by the USGS and has been identified as reservoir-produced biogenic gas. While the well does pose a risk, it is mitigated by the fact that the well is drilled in an active, natural oil seep. 30 Simpson Core Test #30 Simpson Core Tests #30 and #30A were drilled about 100 feet apart in the same oil seep. The seep is part of the same regime that contains Cores #26 and #27. These wells were drilled to gain an understanding of the producing field limits and to help determine underlying structure. Simpson Core #30 is an oil well drilled in 1951 to a depth of 1,500 feet. No plugs were set and the well was cased to 102 ft. The hole encountered the same formations as Cores #26 and #27; Gubik, Seabee, undifferentiated Ninuluk/Seabee, and the Grandstand with a few poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. Poor oil shows were also noted in the deeper Grandstand Formation. During production tests of the shallow oil sand the well was bailed at rates averaging 5 barrels of oil per day (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The well was left with sheared„ open casing above ground. Even though the well produced oil 50 years ago, it is static today. This suggests the hole has collapsed below the shallow casing. There are no fresh water aquifers in the well, however, since the well was drilled to a reservoir with sufficient energy to flow oil to surface, the well should probably be considered a risk if left unplugged. This well would probably be plugged by placing a 100 foot surface plug downhole to eliminate risks to surface resources. The potential risk is alleviated by the fact that the well is drilled in an active, natural oil seep. There is no drill pad as the Navy drilled within the seep and camped on the tundra. Some light trash is present in the seep between the Core #30 and Core #30A, which may prove difficult to clean (Figure 22). The well lies three tenths of a mile from both Core #26 and #27 (Figure 18). Simpson Core Test #27 Simpson Core Test #27 is an oil well that was spudded February 1951 and completed one month later. Total depth of the well is 1,500 feet, with casing down to 102 feet. Oil was encountered at a depth of 380 feet and was bailed at a rate of 3 barrels per day. The core test encountered the same formations as Simpson Core Test #26, with a few very poor gas shows and one productive oil bearing sand in the Ninuluk/Seabee undifferentiated formation. Oil-based muds were used from the drilling depth of 325 to 661 feet. At that point the oil was displaced and the drilling crew resumed using water based muds. 31 Figure 22: Light trash is present in the seep between Cores #30 and #30A. Additional crude was added downhole at a depth of 1,320 feet. The drill pipe was stuck and the two front derrick legs collapsed below the four-foot extension in an effort to free the pipe. The drilling muds in place were re-circulated during the repair process. In an attempt to free the pipe, 73 barrels of crude and 23 barrels of diesel were used to replace the muds and the pipe was worked free. The oil was gradually replaced by mud as the drilling continued, however, some oil remained in the hole after completion. The crude used downhole came from Simpson Core Test #26 (Robinson and Brewer, 1964). There are no fresh water aquifers in the well so there are no risks to sub-surface resources but there are risks to surface resources if the well is left unplugged. Oil could flow to surface if the well equipment corrodes, the well is damaged, or left open. This potential risk is mitigated by the fact that the well is drilled in an inactive, natural oil seep. The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. There is no existing pad. The wellhead consists of 8 5/s-inch casing, a flange and a brass gate valve. The casing was set in a small inactive oil seep. It will flow oil to surface if opened. There is no surface debris present at Core #27 (Figure 23). The well poses little threat to human health and the immediate environment around it in its current condition. Simpson Core Test #29 Simpson Core Test #29 is a dry hole drilled in 1950 to a depth of 700 feet and cased to 152 feet. The purpose of the well was to determine the limits of the producing field encountered at Core #26. A very poor oil show was identified in the Seabee Formation. The productive sand present in the other Simpson Cores does not exist in this well. The test hole also penetrated the Gubik and Grandstand Formations. No oil was recovered from this well (Robinson and Brewer, 1964). The well is grouped higher on the priority list due to its close approximation to Simpson Cores #26, #27, #30 and #30A (Figure 18). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development if left unplugged since any development will likely target deeper, more productive formations. The well was left with 8 '/2-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables proriude from the casing. It is located in a four-by-four foot wooden 32 Figure 23: There is no surface debris present at Simpson Core #27. r~ l.~ cellar filled with water. A drilling pad .was never established. There is some light trash around the wellhead including drill pipe, and various sized wooden scraps. A small barrel pump and other small debris can be seen in the casing and within the cellar (Figure 24). This well poses no threat to the human population or the environment. Umiat #1 Umiat #1 was spud in 1945, and completed in 1946. Total depth reached was 6,005 feet and the well was cased to 685 feet. The well encountered residual hydrocarbons and a few poor gas shows in the Seabee, Ninuluk, Chandler, Grandstand, and Topagoruk Formations. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are located five miles to the east. Oil recovered in bailing tests was so minute that it was measured in pints and officially recorded as a trace. Lab tests determined the oil to be of a different type of crude oil than that found in the productive Umiat wells (Robinson and Bergquist, 1956). The small amount of crude recovered in each test is indicative of residual oil staining. No fresh water aquifers exist in the Umiat area, so this well poses no tlueat to sub-surface water resources. There is no pressure on the wellhead and it is fitted with a blind plate, a 2-inch nipple and a brass gate valve (Figure 25). The well is located on an unleased tract at the crest of a hill that divides the north and south forks of Seabee Creek. Future development is unlikely because of its location outside the Umiat structure. Left unplugged, the well poses no threat to the environment and has no potential to adversely affect future development. The surficial landscape is dominated by willows with the exception of three piles of drilling muds that are located to the east and north of the wellhead. Vegetation is absent on the slick, clay- type material. The COE tested the piles and found them to be contaminated with barium, Figure 25: Umiat #1 is located about 5 which is not surprising given that barite is a miles from the Umiat airstrip. common drilling fluid component. Through sampling, the COE determined the barium has not migrated down the hill and poses no danger to the Seabee Creek drainage (Ecology and Environment, 1999). There is no 33 Figure 24: Simpson Core #29 indication of stressed vegetation down-gradient from the drill muds. Additionally, .solid waste in the foam of steel framing and scrap metal are near the wellhead. The solid wastes pose no threat but are unsightly. Umiat #11 Umiat #11 was spud June 1952 and completed two months later. The well reached a total depth of 3,303 feet with 486 feet cased. One cement plug was placed at 440 feet. The objective was to test production possibilities of the Grandstand Formation on a fault that parallels the Umiat anticline. The well encountered residual hydrocarbons in the Seabee, Ninuluk, and Grandstand Formations but no oil or gas was recovered during production tests. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are over one mile to the south. The well is located within the Northeast planning boundary (see Map 2). The tract is located on lease AA-084141 but there is little possibility of the well interfering with future development due to its location outside the Umiat structure. The well was drilled in the alluvial plain of Bearpaw Creek, 0.6 miles from Umiat #8. A drilling pad was never created as operations consisted of mounting the drill rig on a sled and then placing it on top of large timbers that were secured to pilings (Robinson and Bergquist, 1956). A pile of unvegetated chilling muds is present 30 feet west of the wellhead in between the wellhead and the creek. The wellhead consists of a 10 3/-inch open-ended casing with a collar sticking up inside a 30-inch conductor that is filled with water. Minor wood debris can be found around the wellhead. The well poses no risk if left unplugged. Wolf Creek Area Three test wells were drilled in the Wolf Creek area. The wells were drilled in the early 1950s with the intent of testing the northwest-trending Wolf Creek anticline structure. Wolf Creek #1 and #3 (Figure 26) are located at the crest of a hill with about 250 feet of relief from the valley. Wolf Creek #2 is located about one and one- third miles north within the Wolf Creek valley. Wolf Creek #2 and #3 are open holes but Wolf Creek #1 is equipped with a wellhead. Wolf Creek #1 Wolf Creek #1 is a gas well drilled in 1951 to 1,500 feet and cased to 48 feet. The well encountered very poor gas shows in the Killik Tongue and productive sands in the Grandstand Formation. The well produced at rates up to 881 MCFPD in open hole tests 34 Figure 26: Wolf Creek #1 after adding a new ball valve to the wellhead. August 2004. • of the Grandstand. The well is equipped with a blind plate, a 2-inch nipple and a brass gate valve (Figure 26). There is a small gas leak in the threaded wellhead flange and, if the valve is opened, the well will flow about 10 MCFPD but the pressure is so low it does not register on a gauge. In its current condition, the well does not appear to pose a risk to surface or sub- surface resources. The drill pad is shared with Wolf Creek #3. Tlvoughout the pad, there are some wooden pilings, metal anchors and scrap metal. The scraps should not be considered hazardous in this remote region. The leaking gas is of minor concern, however given the weak gas pressure and remote location; the overall risk is very minimal. Wolf Creek #2 Wolf Creek #2 is a dry hole. The well was drilled in 19S 1 to 1,618 feet and cased to S3 feet. It is located roughly 1 '/ miles north of the other Wolf Creek test wells. The purpose of drilling was to determine if the gas-bearing sandstone beds previously encountered in Wolf Creek #1 would contain any oil. The records indicate a very poor gas show was encountered in the Killik Tongue but no oil or gas was recovered in production tests (Collins and Bergquist, 1959). The hole also penetrated the Seabee, Ninuluk, Chandler, and Grandstand Formations. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The wellhead consists of a plate welded onto the 11 3/-inch casing cut off at ground level (Figure 27). There is no existing drill pad. Solid wastes consist of a few empty SS-gallon drums upstream along the upper floodplain of the creek. The well poses no threat to surface or sub-surface resources and has no potential to adversely affect future development. Wolf Creek #3 Wolf Creek #3 is a gas well. The well was drilled in 1952 to a depth of 3,760 feet and cased to 62S feet. It is deeper than the other two Wolf Creek wells because its primary purpose was to test the Grandstand Formation (the producing formation around Umiat, 3S miles to the west). The Grandstand Formation produced from four different sands. In 3S Figure 27: Wolf Creek #2 had casing cut off at ground level. open hole flow tests of the well produced at rates up to 445 MCFPD. The gas appeared to be sufficient to supply a small camp, but not of commercial proportions (Collins and Bergquist, 1959). Two plugs were set in the well above the Grandstand Formation. The top of the shallowest plug is inside the casing at 554 feet. In addition to the Grandstand, the hole penetrated the Ninuluk, Chandler, and Topagoruk Formations. Upon abandonment, the hole was filled with oil-based drilling muds and left open to the environment. A total of 103 barrels of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The well poses no tlueat to surface or sub-surface resources and has no potential to adversely affect future development. The drill pad is shared with Wolf Creek #1. There is some minor debris at the site as noted in the Wolf Creek #1 description. The wellhead was cut off six inches from the ground surface. This allows seasonal precipitation to accrue in the hole and spill over the sides, but the well poses no threat to surface or sub-surface resources and has no potential to adversely affect future development. Fish Creek #1 Fish Creek #1 was drilled by the Navy in 1949 near an oil seep. Total depth of the well was 7,020 feet. The well was plugged back to approximately 2,550 feet, drilled to a new total depth of 3,018 feet and cased to 3,017 feet. The well was drilled to test a large gravity anomaly that suggested the possible presence of petroleum-bearing rocks and some structural anomaly that might be a trap for oil. Very poor oil shows were identified in the Topagoruk Formation at depths from 5,550 - 6,000 feet and a productive sand was reported at 3,000 feet. The well is not a flowing well but was pump-tested at rates averaging 12 barrels of oil per day through agravel-packed completion. It also produced a small amount of methane gas. The hole encountered the Gubik, Shrader Bluff, Tuluvak, and Seabee Formations. 36 • producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infiastiucture is established. Surficially, there are still some solid wastes present. The drilling pad and cellar construction consists of concrete reinforced with steel matting. The concrete, matting, and pilings are still in place today, albeit heaved by permafrost (Figure 28). Several 55- gallon trash drums filled with debris are located off the concrete pad. Other light debris is also present within 500 feet of the pad. The oil seep is located about 1.5 miles to the southwest of the well site and is inactive. The USGS 305-I reports the dimension of the seep as being 6' x 20' (Florence and Brewer, 1964), however, BLM personnel located the seep in 2001 and noted its dimension to be 3' x 6'. Simpson Core Test #28 Simpson Core Test #28 was drilled in September 1950 to a total depth of 2,505 feet and cased to 110 feet. Despite the depth, the hole did not encounter any hydrocarbon shows. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. A drill pad does not exist, however a large area of disturbance is visible. The wellhead consists of open casing inside a wooden cellar. There is considerable solid waste near the well. These include: numerous metal pilings, drill pipe, large wood fragments (spool, plywood, timbers), and some partially crushed drums. The solid wastes are unsightly, but pose no threat to humans or the environment. Simpson Core Test #13 Simpson Core Test #13 was drilled in the summer of 1949. It was a relatively shallow test and did not generate any significant oil or gas shows. The well encountered residual hydrocarbons in the Seabee and Grandstand Formations at depths of 1,079 - 1,084 and 1,138 - 1,148 feet (Robinson and Brewer, 1964). No oil or gas was recovered during production tests. The well is over three miles north of the Simpson Core wells that penetrated productive Grandstand sands. Total depth of the well reached 1,438 feet. The top 26 feet are cased and the hole was filled with water-based drilling mud. Fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. 37 A drilling pad does not exist. Seven-inch casing was cut off at ground level and is very difficult to locate. The well is open to the atmosphere. There is no solid waste, nor is there anything hazardous regarding this location. It should not be considered a risk to surface or sub-surface resources. Simpson Core Test #15 Simpson Core Test #15 was drilled in August 1949 near an active oil seep. The well was drilled to a total depth of 900 feet and cased to 18 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations (Robinson and Brewer, 1964). No oil or gas was recovered during well tests. Additionally, fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. There is no existing pad. The well was drilled about '/8 of a mile north of a natural seep. The well consists of open ended casing with a height of 18 inches (Figure 29). The area is clean with no solid waste. This well poses no risks to the environment or human activities. Simpson Core Test #14 Simpson Core Test #14 was drilled in 1949 to a depth of 290 feet. The records do not clearly state how much casing was run but the well was left with casing above ground open to the atmosphere. Its present day location lies within 1000 feet to the west of an active oil seep. The well was not drilled deep enough to encounter the hydrocarbon stained sands evident in the Simpson Core #14A well. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years. This shallow well did not penetrate any hydrocarbon bearing zones and poses no risk to surface or sub- surface resources, nor does it have the potential to adversely impact future development. 38 Simpson Core Test #14A Simpson Core #14A was drilled in 1949 to a depth of 1,270 feet and casing was set to a depth of 32 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations. No oil or gas was recovered during tests (Robinson and Brewer, 1964) and fresh water aquifers are not present. Present day location of the well is approximately 1000 feet to the west of an active oil seep. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. East Simpson #2 East Simpson #2 was drilled in 1977 to 7,505 feet and cased to 6,427 feet. Five cement plugs were set, with the top of the shallowest plug set at 1,997 feet. The primary objective of the well was to test the Ivishak Sandstone where it onlaps the Pre-Devonian age basement rock (Husky Oil NPR Operations for U.S. Geological Survey, 1982). Small scale faulting was found between the wells in the area, possibly accounting for the thin section representing the Sadlerochit Formation. The well encountered very poor oil shows at 6,000 feet in the Torok Formation and Endicott age sandstones were cored with poor porosity and dead oil shows. The well is officially listed as a dry hole. Upon completion of the production tests, the well was plugged back to 1,997 feet and filled with approximately 280 barrels of diesel to facilitate permafrost temperature measurements. However with East Simpson #1 less than five miles away, the USGS has no plans to use this well for temperature monitoring. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this 39 • well will have an adverse impact on development. If this exploration and development establishes infrastructure nearby, it would greatly facilitate plugging this well and significantly reduce costs. The wellhead consists of a casing head, side gate valve, a master gate valve, and a needle valve. The drilling pad is of the thin pad variety and is slowly being reclaimed by natural processes. Exposed pilings stick up a height of two feet from the surface, but no other objects needing removal are present (Figure 31). The cellar is a wooden 12' x 12' with standing water. With the existing plugs and the static condition of the well, there is no risk to surface or sub-surface resources. Kaolak #1 Kaolak #1 lies in the northwest portion of NPR-A and is considered one of the more remote well sites within the reserve. Kaolak #1 was drilled in 1951 to a depth of 6,952 feet and casing was set to 1,000 feet. Drilling served two purposes, to determine the presence of any reservoir characteristics, and to determine if oil or gas shows were present in this remote portion of the reserve. The site was chosen based on a seismograph survey in 1950 that identified an anticline at this location. The intent was to drill to a depth of 8,000 feet, but a windstorm destroyed the derrick. After the storm, the hole was abandoned due to unsatisfactory oil and gas shows. Findings indicated some very poor oil and gas shows in the Chandler Formation and very poor Figure 32: Kaolak #1 with cabin on the drill pad. shows in the Topagoruk Formation. Gas shows were attributed to association with the coal beds (Collins and Bergquist, 1958). Upon abandonment, no plugs were set and the hole was filled with heavy muds. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. Exploration and development in the area is a possibility within 40 Figure 31: East Simpson #2 is partially submerged during the spring thaw. Photo taken June 2003. • the next 20 years, but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. There are no major surface issues. The working area is still visible due to a multitude of wooden pilings around the wellhead and a cabin on the north end of the pad (Figure 32). Off the pad, the area is clean. The wellhead is missing its upper components. All that remains is the top flange above the base plate and the casing spool, leaving 11 3/-inch casing open to the enviromnent. The well is left with a casing head and is open to atmosphere. The wellsite is 45 miles southwest Wainwright, which is the nearest community. There are no hazardous materials or anything that would pose a risk to the general health and safety of the land. The cabin may be a concern, but dealing with the situation is outside the scope of this report. Meade #1 Meade #1 is a gas well drilled to a depth of 5,305 feet in 1950. The well was cased to 2,785 feet and two cement plugs were set, with the top of the shallowest plug tagged at 2,783 feet inside the casing. The well encountered some gas shows in one productive sand within the Grandstand Formation. The gas tested at rates up to 1.1 MMCFPD during openhole flow tests of the sand at 2,949 - 2,969 feet. The well is estimated to have gas reserves of 10 BCF. Gas pockets are relatively common in this portion of NPR-A due in large part to the underlying coal. At one point while conducting tests, some problerns were encountered while attempting to pull a testing tool out of the hole; aball-peen hammer was inadvertently dropped downhole, causing the tubing to stick. The tubing could not be freed and as a result, it twisted off leaving tubing in the hole. When the lost tubing could not be pulled out, heavy muds were pumped downhole and the well was abandoned (Collins and Bergquist, 1958). The well is located within the Northwest planning area (see Map 2). The well is adjacent to a recently leased tract that received a high bid of $10.26 per acre during the 20041ease sale. Exploration and development is a distinct possibility within the next 20 years and has the potential to target the Grandstand Formation. If left unplugged the well has no potential to adversely affect future development. There is no pad present at Meade #1 Several pilings and light trash are present, but at ground level and consists of an open flange bolted to the top of the casing (Figure 33). This differs from the Navy reports that indicate the wellhead was abandoned in place. There is no record as to why it was removed. A BLM field crew bailed the hole and discovered a swedge and 2-inch needle valve junked downhole. This site is very remote (30 miles south of Atgasuk) and since the gas zones are currently isolated below the cement plugs there is a limited risk of adverse impacts to surface or sub-surface resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 Titaluk #1 was drilled in 1951 to a depth of 4,020 feet and is a dry hole. The well was drilled on the end of an anticline to test the oil and gas potential of formations within the Nanushuk Group. A few very poor oil and gas shows were encountered in the Grandstand and Topagoruk Formations, but no oil or gas was recovered during multiple production tests. The Ninuluk and Chandler Formations were also encountered, but with no shows. One cement plug was set at 3,471 feet. The placement of this plug is curious since the shows (albeit poor) were reportedly discovered above this level (Robinson and Bergquist, 1959). The well remains in a static condition. Titaluk #1 is located within the Northwest planning area (see Map 2) on an unleased tract. No offers were received. in the June 20041ease sale. Near-term development is unlikely. Surficially, there are no concerns with this well. The well is open, 10 %- inch casing above ground to a height of 3 feet. It is open to the atmosphere. The area of disturbance is completely revegetated with no solid waste concerns. The wooden cellar is in a state of disrepair and filled with water (Figure 34). The site is clean with very little debris. There are no hazardous conditions associated with the surface. The nearest settlement is Umiat, 60 miles to the east. The well poses no risks to human safety or the environment. Skull Cliff Core Test #1 Skull Cliff Core Test #1 was drilled in 1947 to a depth of 779 feet and is a dry hole. No shows of oil or gas were reported while drilling through the Gubik, Grandstand, and Topagoruk Formations. While drilling to the target depth of 1,500 feet, the drillstring was lost in the hole and fishing attempts were unsuccessful in recovering the lost drillstring. The drilling mud was bailed down to the top of the fish and the remainder of the well was filled with diesel to 54 feet to prevent the wellbore from freezing and facilitate downhole temperature measurements. It is plausible that the casing could corrode and the diesel fuel could seep into the sub-surface strata, but since there are no fresh water zones in the well it is not considered a risk that would adversely impact sub-surface resources (Collins and Brewer, 1961). The well is located within the Northeast planning area (see Map 2). The well lies adjacent to a recently leased tract that received a high bid of $10.77 per acre during the 20041ease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 Figure 34: Titaluk #i wellhead with wooden cellar. is unlikely this well will have an adverse impact on development since industry will likely target deeper, productive formations. An oil seep located at the base of Skull Cliff (land/ocean contact) was observed and documented in the 1940s, which influenced the Navy's decision to drill. BLM and USGS crews searched for the seep when they were in the area but nothing was found at the cliff/beach contact. However, another seep was reported in 1996 by a group from the Academy of Natural Sciences in a small gully about a mile to the east near the old radio tower site. This seep was never confirmed by BLM. Surficially, a drill pad was never established, but a large area of activity is defined by roughly 200 drums, metal tracks, wood debris and various other scraps that litter the site (Figure 35). Presently, the well consists of open casing with a wooden plug shoved into it. There does not appear to be any stressed vegetation that might indicate a hazardous situation. Since the well did not encounter oil and gas Figure 35: Solid waste primarily in the form of empty formations and has no pressure at drums litter the area around Skull Cliff Core Test. The the surface, it is not considered a wellhead is in the upper left portion of the photo. risk to surface resources. The only potential risk is that this site lies near a popular winter route between Barrow and Wainwright and it is possible for a snowmachine to impact the solid waste. Barrow is approximately 30 miles to the northeast and Wainwright is about 60 miles to the west. Oumalik #1 Oumalik #1 was drilled in 1950 and is a dry hole. The well was drilled to a total depth of 11,872 feet and cased to 2,762 feet. It is the deepest well drilled by the early U.S. Navy program. The well location was positioned on the apex of the Oumalik Anticline and drilled with the intent of revealing the oil, gas, and water content of the penetrated stratigraphy. Two cement plugs were set, the shallowest of which is inside the casing at 2,543 feet. Very poor oil and gas shows were reported in the Grandstand Formation, and poor gas shows were noted in both the Topagoruk and Oumalik Formations. Small undetermined volumes of gas were recovered during multiple production tests. It is believed that the gas encountered was large enough to furnish fuel to a camp but not large enough to become a commercial producer. The gas encountered during drilling showed high gas pressure, but the sandstones in which they were observed are thin with low porosity (Robinson and Bergquist, 1956). The gas zones are currently isolated by the cement plugs and pose no risk to sub-surface resources. The wellhead and a fabricated plate are below ground level. Two 2 'h-inch nipples open to the atmosphere are above ground to allow thermistor cables to be run into the well. The well is located within the Northwest planning area (see Map 2) on unleased tract that received no bids during the lease sale of 2004. Near-term development is unlikely. If left 43 unplugged, the well has no potential to adversely affect future development. The existing pad contains piping from a ground refrigeration system similar to Topagoruk #1. The ground in this area is somewhat swampy with high susceptibility to permafrost melt. Circulating cooled diesel fuel in the pipes enabled drilling to occur without thawing the ground. The steel pilings were pulled from the ground to be reused at another site (Robinson and Bergquist, 1956). However, steel pipe filled with diesel fuel remains. A 6- inch circumference of stressed vegetation was noted around several of the low-cut pipes. Despite the diesel, the well does not pose a risk to any existing communities or habitation. It is in a remote location approximately 55 miles southeast of Atgasuk. Overall, the well poses no risk to people or the environment. East Oumalik #1 East Oumalik #1 was drilled on a ridge that overlooks an unnamed tributary of the Oumalik River. Topographic relief is approximately 100 feet. The drill site is highly remote as the nearest village (Atgasuk) is 65 miles away. The well was drilled in 1951 and reached a total depth of 6,035 feet and is cased to 1,100 feet. It is a dry hole. Very poor oil and gas shows were reported in the Grandstand Formation and very poor gas shows were reported in Topagoruk Formation. The well is located within the Northwest planning area (see Map 2) on an unleased tract that received no bids during the lease sale of 2004. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. The well was left with open casing below ground level and has thermistor cables protruding from inside the casing. The casing is marked by a 7-foot, 3/-inch pipe. The open pipe lies within awater-filled cellar. The standing water has produced numerous algae and other aquatic vegetation obscuring the wellbore. Surficial hazards consist of several 10-foot timbers and a few 4-foot pipes (probably rig anchors) sticking up out of the ground. The site is mostly overgrown with shrubs and appears to be relatively clean. The airstrip, incoming, and outgoing trail scars are obvious and can be used to navigate to the wellsite. There are no risks associated with the well in its current condition and was given this ranking due to its close proximity to Oumalik #1. Topagoruk #1 Topagoruk # 1 was drilled in 1951 to a depth of 7,154 feet and is a dry hole. The intent was to test a small, buried anticline and the various formations associated with it. The well was cased to 6,073 feet, plugged back to 6,175 feet and then drilled to a new total depth of 10,503 feet. Prior to re-drilling to total depth, approximately 250 barrels of crude oil from Cape Simpson were added downhole to help offset lost circulation and caving. Additionally, 20 ban•els of diesel were added downhole during the drilling phase. No plugs exist in this well. The well is left with open casing to the surface and thenmistor cables protruding from the casing (Figure 36). The well encountered the following stratigraphic units while drilling; Gubik, Grandstand, Topagoruk, and Oumalik Formations, Middle and Upper Jurassic rocks, Shublik Formation (Triassic age), Permian rocks, and Lower-Middle Devonian rocks. Hydrocarbon shows were limited to a few very poor gas shows in the Oumalik Formation. No oil or gas was recovered during 44 multiple production tests (Collins and Bergquist, 1958). The well peneri•ated no fresh water aquifers and does not represent a tlu•eat to surface or sub- surface resources. The well is located within the Northwest planning area (see Map 2). It is adjacent to a recently leased tract, receiving a high bid of $50.00 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. There is not a visible pad, but rather an area of disturbance. Disturbance stretches 1/4 mile in an Figure 36: Topagoruk #t casing on its east-west direction and /8 of a mile in a north- side. When the casing was pulled out of south direction. Solid wastes exist in the form of the ground, thermistor cables were piping remaining from a refrigeration system that discovered. circulated diesel to keep the permafrost frozen. A potential hazard exists because diesel still occupies the ground circulation lines. These lines stretch approximately 750 feet to the east, 250 feet to the north, and 100 feet to the south from the wellhead. Other debris on site include some large, partially-burned timbers, awater-filled wooden box (Figure 37) that resembles a cellar ('/4 mile east of the wellhead), and drilling muds. Atqasuk is the closest village approximately 30 miles to the southwest. The well is remote with the exception of a subsistence camp approximately one mile southwest of the wellhead along the Topagoruk River. East Topagoruk #1 Topagoruk's wellhead consists of an open hole cut off at the ground surface with several thermistor cables. A thin piece of weathered metal fits around the cut-off casing to resemble a marker. The weathered metal has been smashed at the base and now lies bent in half on its side. Overall this site poses little hazard to the environment or human population. East Topagoruk #1 was drilled on top of a small ridge in the Chipp River delta in 1951. It reached a total depth of 3,589 feet and is cased to 1,100 feet. The purpose of the well was to test an anticline with closure as well as test the fluid content of the permeable Cretaceous sandstone (Collins and Bergquist, 1958). A very poor gas show in the Topagoruk Formation is the only reported hydrocarbons encountered in the well and no oil or gas was recovered during multiple production tests. One cement plug was set in the 45 Figure 37: Drilling muds and a wooden box that resembles a cellar are located about '/ mile east of the wellhead. well at 1,049 feet. The well is located within the Northwest planning area (see Map 2) on a recently leased tract. The tract receiving a high bid of $84.99 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. A drill pad does not exist. There are a few rig anchors near the wellhead, but no other surficial debris. The current state of the wellhead is open-ended 10 3/-inch casing. Casing height is three feet above the ground surface. It is housed in a small 9' x 9' water-filled cellar. The area is remote and poses no health and safety risks to humans or the environment. Knifeblade Wells There were three shallow test wells drilled in the Knifeblade Ridge area. Knifeblade #1 was drilled on the ridge at the head of a small stream, with wells 2 and 2A drilled about a mile downstream. The wells are in a highly remote location with Umiat being the nearest settlement, 65 miles to the east. Knifeblade #1 Knifeblade #1 is a dry hole drilled in 1951. The well was drilled to a depth of 1,805 feet and cased to 1,211 feet. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). The well encountered very poor gas shows in the Killik Tongue of the Chandler Formation and very poor oil and gas shows in the Grandstand Formation. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. 46 Figure 38: Knifeblade #1 is located in a marshy area at the headwaters of a small creek. • Knifeblade #2 Knifeblade #2 is another dry hole drilled in 195 L It was the first of the three Knifeblade wells drilled and reached a total depth of 373 feet, cased to 45 feet, before being junked and abandoned. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). The well did not encounter any hydrocarbon shows. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Surficial issues are negligible. A drill pad does not exist and the wellhead consists of open-ended casing. There are approximately eight empty drums near Knifeblade #2 and #2A. The wells are highly remote and should not be considered a threat to the enviromnent or human activity. Knifeblade #2A Knifeblade #2A, also drilled in 1951, reached a total depth of 1,805 feet and was cased to 38 feet. The well lies 28 feet to the north of Knifeblade #2A. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). Only very poor oil and gas shows were reported in the Grandstand Formation. The well was left with casing open to the atmosphere and poses no threat to surface or sub-surface resources in its current condition. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Simpson #1 Simpson #1 test well was drilled with a rotary rig in 1948 by the U.S. Navy. The well was drilled to a total depth of 7,002 feet and cased to 5,954 feet. The purpose of the well was to test the various formations of the Lower Cretaceous and Upper Jurassic rocks. The well encountered several very poor oil and gas shows and one productive gas sand in the Lower Jurassic at a depth of 6,183 - 6,193 feet. The well produced gas at rates up to 3.0 MMCFPD during open hole flow tests of this Lower Jurassic sand. The gas zones are currently isolated from other formations and the surface by two cement plugs set above the productive sand. The top of the shallowest plug is at 5,520 feet (Robinson and Yuster, 1959). The well is located within the Northwest planning area (see Map 2) adjacent to recently leased tract that received a high bid of $7.51 per acre during the lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years and this exploration has the potential to target the Lower Jurassic. Since the well is partially plugged, however, it poses little risk to surface or sub-surface resources and will not likely adversely affect any future development. 47 The pad is highly visible and was constructed in the same fashion as Fish Creek #1 in which concrete was used as a working pad. Concrete was poured over a landing mat which was placed on pilings. As a result of ground movement from pernlafrost freeze/thaw cycles, the concrete has buckled in numerous places creating apartially- collapsed surface. This feature provides excellent shelter to small animals and rodents. Additionally, there is a small pile of drilling muds near the wellhead. The well was left equipped with a casing flange, spool w/ side bull plug, and another flange and nipple and is shut-in with no pressure at surface. The components past the flange have since been removed. Overall, the current condition of the site is non-threatening to the sparse human population and the suiTOUnding environment. North Simpson #1 North Simpson #1 was drilled in 1950 to a depth of 3,774 feet and cased to 109 feet. No hydrocarbon shows were reported during the drilling of this well as no sandstone was encountered (Robinson and Yuster, 1959). Upon completion, no plugs were set and the hole was filled back with muds. The well is located within the Northwest planning area (see Map 2) adjacent to a recently leased tract that received a high bid of $12.76 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. South Simpson #1 South Simpson #1 was drilled in 1977. The purpose of the hole was to test the Sadlerochit Formation where it laps onto the south flank of the Barrow Arch. The well was drilled to 8,795 feet and cased to 7,206 feet. Reports show that poor gas shows were identified in the Nanushuk Group, Kingak Shale and Shublik Formation. Gas flowed at a rate of 75 MCFPD between 6,522 - 6,568 feet within the Kingak Shale (Gyrc, 1988). The gas contained more than 70% nitrogen. The origin of the high nitrogen content is unknown, but appears to be a localized phenomenon (Burruss, 2003). Sandstone tongues 48 (Simpson sand) within the Kingak Shale in the Simpson and Barrow localities are known to display good gas reservoir quality (Houseknecht 2001). Poor oil shows were discovered in the Nanushuk Group and Shublik and Torok Formations. Drill stem tests did not recover any oil. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $5.01 per acre during the lease sale of 2004. Exploration and development is a distinct possibility in the near future since the well is properly plugged it will have no adverse impacts on development. Surficially, the pad and pits are in good shape. The cellar has been backfilled rigure 4u: youth Simpson #1 had its cellar backfilled with silt, with silt which resulted in consequently burying the casing head. the burial of the Casing head (Figure 40). Above the surface, the wellhead consists of a 4-inch line pipe and a master valve. The master valve is frozen in the open position. The needle valve previously located above the master valve no longer exists. Beneath the casing head the well is plugged to surface and has no potential to adversely effect surface or sub-surface resources. The wellhead stands about eight feet high. Aplumb-bob was dropped and hit solid at 8 feet and stuck. It was subsequently lost. An old, stripped snowmachine sitting next to the wellhead is the only sizable object that would be considered solid waste. Overall, there is no risk associated with this well. Inigok #1 Inigok #1 was drilled in 1979 to a depth of 20,102 feet and cased to 17,432 feet. The well objective was to test astructural/stratigraphic trap within the Sadlerochit and Lisburne Groups (Husky Oil NPR Operations for U.S. Geological Survey-Inigok, 1983). Some very poor gas shows were recorded in the Sag River, Nanushuk, and Endicott Group. Poor oil shows were reported for the Kingak Shale and Lisburne Group. The best shows were found in the base of the Torok Formation at 8,852 feet. No oil or gas was recovered during multiple production tests. The wellhead consists of three spools, each with a gate valve, a master valve, and a needle valve. Ten cement plugs were set in the well and it is plugged to surface. The well is located within the Northeast planning area (see Map 2) on a recently leased tract that received a high bid of $20.34 per acre during the lease sale of 2002. Total E&P Incorporated drilled an exploratory well 15 miles north of Inigok # 1 and used the gravel 49 • pad and airstrip near the well for staging areas and a camp. It would be fairly simple to remove the wellhead but the well has no potential to adversely affect surface or sub-surface resources. Additionally, the well poses no threat to adversely affect future development. Inigok #1 is one of the few logistical Centers Figure 41: Aerial view of Inigok #1. The drill pad and reserve pit Within NPR-A (Figure are visible in the top of photograph. A road leads from the apron of 41). The airstrip and pad the airstrip to the drilling pad. are maintained with no solid wastes present. The wellhead poses no risk, and with the plugs already in place, could be removed. Additionally, this well has ayear-round airstrip and serves as a logistical base to various NPR-A activities. USGS Monitored Wells The USGS has used wells drilled in the NPR-A for collecting temperature data to better understand both the global temperature pattern and its effects on the permafrost. The wells that are currently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is anon-corrosive agent, and even if the casing should corrode there would be no impact to the surface resources and minitnal impact on the sub-surface resources as there are no known fresh water aquifers in NPR-A. The following wells are monitor wells with surficial issues. It is difficult to establish a rank since the wells are sufficiently plugged. The cleanup priority is difficult to determine as the primary threat lies with wells having downhole issues. However, political concerns could influence the timing in which the surface issues are dealt. East Teshekpuk #1 East Teshekpuk #1 was spudded in March 1976. The well was drilled to a depth of 10,664 feet. It is an active USGS monitor well that was properly plugged. The top of the shallowest plug is located at 2,400 feet. From that point to the surface, the hole is filled with diesel fuel. With the well properly plugged and diesel fuel being anon-corrosive agent, there is no downhole issue with the well at this time but there are solid wastes buried on site that may warrant removal. 50 • East Teshekpuk #1 was drilled on a small peninsula on the southeast side of Teshekpuk Lake. The southern shore of the peninsula is protected from the prevailing northerly winds, however the north shore doesn't have the luxury of a barrier and is subject to erosion. Unfortunately, solid wastes from the camp and di711ing operation were buried on the northern portion of the pad, possibly in the old reserve pit. The northern shore has been battered by numerous storms which have eroded the shoreline and exposed the solid wastes. The wastes are unsightly and potentially hazardous. While the nearest village of Nuigsut is 52 miles to the southeast, Teshekpuk Lake is rich in subsistence resources and numerous sununer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of Atgasuk. Awuna is the most remote well in the entire petroleum reserve. The well was drilled to a total depth of 11,200 feet. Drilling was conducted over two consecutive winters. Ice roads and an ice airstrip were constructed for logistical support. The project cost approximately $6 million (Husky Oil NPR Operations-Awuna, pg 5). Due to the orientation of the pad, the prevailing winds force wave action into the drilling pad, undermining the sands and silts which make up the pad. Below the sands and silts, Styrofoam was used to insulate the underlying permafrost. Wave action has eroded tens of feet into the drilling pad, exposing the Styrofoam, which consequently breaks loose and blows away. Wooden pilings exposed from erosion show how much attrition has taken place. Styrofoam can be seen all around the pad with pieces blown up to 5 miles away. Downhole, the well is in good shape with sufficient plugs. Diesel fuel fills the top 4,000 feet. The well is an USGS monitor well. Wellhead components are in working condition with no problems. annual basis Tunalik # 1 The immediate concern with this site is the blowing Styrofoam, but as the years progress erosion could become a major issue (Figure 42). The loose Styrofoam should be cleaned up and erosion progress should be monitored on an . It is also worth mentioning that the same type of scenario is unfolding at (another USGS well). Wave action from the reserve pit is beginning to 51 Figure 42: Awuna wellhead with exposed wooden pilings and Styrofoam. • undermine Styrofoam from the drilling pad. Tunalik #1 differs from Awuna #1 in that prevailing wind direction does not force erosion in the direction of the wellhead. Uncased Core Tests There are thirty-nine uncased core test holes. These holes were typically left filled with drilling mud and abandoned without being plugged. Drilling depths ranged between 500 and 1,500 feet depending on the purpose of the test. By nature, core tests were drilled to test soils, permafrost, or lithologic units. They were not chilled for oil or gas exploration purposes and did not encounter hydrocarbons. Many of the cores are stored in the Alaska Geologic Materials Center (Figure 43). The BLM has examined the cores and they are extremely friable. It is likely that these uncased core holes have naturally collapsed and harmlessly blended into the environment. There is no surface indication of their location and BLM has been unsuccessful in locating them during several visits to their reported location. They do not pose any potential risks. Barrow Gas Wells The Barrow Gas Field Act of 1984 (P.L. 98-366, 98 Stat. 468, July 17, 1984) allowed the U.S. Navy to transfer several wells to the North Slope Borough. The Navy drilled six shallow wells between 1953 and 1974 to test the natural gas potential. Between 1974 and 1982, 10 additional wells were drilled to help supplement the local gas supply. The wells were developed for use by the local government agencies and Barrow residents. The act conveyed the sub-surface estate, held by the federal government and any other interest therein, to the Arctic Slope Regional Corporation (ASRC). The BLM acknowledges the surface and sub-surface lands as conveyed and the Office of the Regional Solicitor has confirmed that the Transfer Act included the wells and well locations, and any liabilities associated with these wells are the responsibility of ASRC. 52 test, are stored in the Alaska Geologic Materials Center. • • Plugged Wells Square Lake #1 Square Lake #1 is a Navy well that was drilled to a depth of 3,984 feet. Its primary intent was to test the Cretaceous rocks in east-west trending anticline structure (305H pg 424). No significant shows of oil were found. Gas shows were encountered in various sandstone beds between 1,600 and 1,900 feet, but otherwise the hole was dry. Upon completion, four plugs were reported to be set with the upper plug at 728 feet, well above the gas shows. Two other plugs were reported to be set in the gas zone, spanning depths of 1,640 - 1,840 and 1865 - 1934 feet. In addition to the six plugs, water and mud fill the remaining distance to the surface (Collins and Berquist, 1959). Upon successive visits to the site, BLM field crews dropped aplumb-bob down the hole and hit a solid obstruction between 8 and 10 feet. Don Meares, Northern Field Office, visited the site in August 2003 with an underwater camera and determined the solid surface to be cement. The Square Lake area is clean of debris with a few deadmen pilings (anchors) near the wellhead that could pose a ground hazard. The wellhead is open casing cut off at ground level. Umiat #2 and #5 The Umiat #2 and #5 wells were plugged and abandoned in 2002 by the COE (Figure 44). The wells were drilled on a common four-acre pad in 1947 and 1951. The purpose of the wells was to test for producing lithologies and determine petroleum quantities. Umiat #2 penetrated the Gubik Formation, Nanushuk Group (Chandler and Grandstand Formations), Topagoruk Formation and Oumalik Formation. Problems with the drilling muds were encountered while drilling Umiat #2. Analysts determined that the fresh water drilling fluid caused formation damage and the Umiat #5 well was drilled adjacent to the #2 with acable-tool rig. The well produced 400 barrels per day with the most productive sandstones in the lower Chandler and upper Grandstand. Below a depth of 1075 feet, 107 barrels of crude oil from both Umiat and Simpson were used as a drilling fluid, as well as 11 barrels of diesel fuel (Robinson and Bergquist, 1956). In 2000, the Colville River threatened to erode both wellsites away. The COE took action under the FUDS program in the winter of 2001-2002 to plug, abandon and remove any surface features. The concrete lined cellar of Umiat #2 and wooden platform Figure 44: Plugging operations at Umiat #5. M from Umiat #5 were removed. Costs were approximately $25 million dollars due in part, to soil Approximately 30,000 tons of petroleum-contaminated soil was excavated. remediation. The soil was 53 • transported on an ice road to the Umiat camp where it was thermally treated in a rotary kiln to remove petroleum residues. Small quantities of PCB contaminants were unexpectedly encountered after the excavation was completed. The source of the PCBs has been linked back to the #5 well and the fluids used downhole. The ever-shifting Colville River continues to erode the north bank and is approximately 50 feet from the old wellbores. With the removal of hazardous soils, this site should not be considered a threat to humans or the environment. Umiat #3 Umiat #3, also known as Umiat Core Test #l, was spudded in December 1946 and drilled to test some of the oil bearing zones encountered while drilling Umiat #1. The well was drilled on the northeast corner of Umiat Lake just below the hill from Umiat #4 (Figure 45). Umiat #3 penetrated the Gubik Formation and the Nanushuk Group. The Grandstand Formation within the Nanushuk Group is considered to be the primary source of oil between the depths of 258 and 514 feet. The hole produced 50 barrels per day prior to shutdown. The well was re- tested nine months later with production dropping to 24 barrels per day (Robinson and Bergquist, 1956). The wellhead consists of homemade components with a single water service type valve and is capped with a needle valve. There is no seeping present at this Figure 45: The view from Umiat #4 looking southwest site, however seeps are common in toward Umiat Lake and Umiat. Umiat #3 is located on the area, including an active seep in the near shore of Umiat Lake. Umiat Lake. An extensive piping system is still visible. The pipes probably supplied water during the drilling phase. They connect Umiat #3 to #4 which then follow the hill from Umiat #4 to a side channel of the Colville River. Their function was to either carry water to the drilling sites or assist during the well's production phase. The overall surficial conditions including the wellhead and piping, do not pose a threat to human health nor the environment. BLM plugged the well in May 2004. Umiat #4 After encountering relatively poor oil shows on the first three wells, operations were suspended until 1950. Cable tool drilling rigs were introduced to determine if the fresh water muds had hindered the oil production in the previous wells (Robinson and Bergquist, 1956). Cable tool wells did not require the excavation of a cellar; therefore Umiat wells #4-#7 did not have cellars. Umiat #4 is located on top of the hill to the northeast of Umiat #3 (Figures 45, 46). The well was drilled May 1950 to a maximum depth of 840 feet. The hole bored through the Ninuluk, Chandler and Grandstand Formations. Oil was found in the upper and lower 54 r~ L sandstone of the Grandstand Formation. Drilling encountered good oil shows around 300 feet with a total 500 barrels produced (Robinson and Bergquist, 1956). The wellhead consists of 11 3/-inch casing protruding 36 inches above the ground surface. The casing is capped with a steel plate. Upon removal of the cover, the hole was open to the environment. No valves or gauges are present. The well was plugged by the BLM on May 9, 2004. The well poses no risk to humans or the environment. Umiat #8 Like the other wells drilled in the 1950s, Umiat #8 was drilled using cable tools. The well was spudded May 1951 and completed August 1951. It is located on top of a ridge that separates Umiat from the Bear Paw Creek valley. Drilling intention was to determine the quality and quantity of hydrocarbons in the Grandstand formation near the crest of the anticline structure. The hole encountered the Seabee, Ninuluk, Chandler, and Grandstand Forniations. The Grandstand Formation produced approximately 60-100 ban•els per day of oil and more than 6 million cubic feet per day of gas. The well was shut in with a gas pressure of 275 pounds per square inch. The gas was analyzed by the Bureau of Mines and determined to be 97.3 per cent methane. Brine was mixed (35 lbs of salt per barrel of water) and used in the drilling fluid to prevent freeze up. Brine solution of approximately the same ratio of salt per barrel of water was used to kill the well and set the plug while cementing casing. A total of 21,695 pounds of salt were used in the well (Robinson and Bergquist, 1956). The well was plugged May 2, 2004. Prior to plugging, ,the well was nicknamed the "Whistling Well" due to the gas of which was escaping through fittings and valves in the wellhead. The wellhead is easily the most complex of the 11 Umiat test wells. It consists of five valves and multiple gauges. It has several homemade, components and reaches a total height of ten feet. After reporting the seeping gas in 1996, two new valves and gauges were installed in 1997. The new gauges have been checked regularly since 1998 and have consistently read 250 psi. Despite replacing the two valves and gauges, gas continued to leak from the wellhead. The largest of the leaks occurred just above the top flange where a 4-inch nipple and collar are welded together. Other leaking occurred at the fittings of some of the gauges. The wellhead is sited on a gravel pad. A series of piping extends from the wellhead to a small stock tank about 100 feet to the south. The tank probably was used as a holding tank for the oil while testing the production potential of the hole. The same style of stock tank is present in various old photographs found in the Umiat area and may be the same 55 Figure 46: Umiat #4 prior to plugging. The wellhead is located in the center of the photograph. tank. Oil from inside the tank was sampled in 2004 with test results positively identifying PCB contamination which is slightly below the level of concern. Umiat #10 Uiniat #10 was spudded September 1951 and completed January 1952. This well was drilled to test the Umiat anticline and is located about a half mile northwest of Umiat #8. Total depth of the well is about 1,573 feet. When the well was bailed, it produced 222 barrels of oil in a 24-hour time span. The most productive layers occurred at 980 feet and 1,095 feet, penetrating both the Ninuluk and Grandstand Formation (Robinson and Bergquist, 1956). Also encountered were the Seabee and Chandler Formations. The hole was somewhat problematic as it caved considerably during drilling. Operations consisted of a drill rig set on a foundation of 12" x 12" timbers with a thin layer of gravel in between. Twenty-five pounds of salt mixed with Aquagel and downhole to help lubricate the drill bit above the 650-foot marker (from the surface). More Aquagel-brine mud was used down to about 1,000 feet to keep the hole from caving. The wellhead contains two valves; a master and a gate, both are closed. The total height of Umiat #10 is approximately 10 feet. The 8 5/$-inch casing is flared and open at the top. This well was plugged May 6, 2004 (Figure 47). water (per barrel) were used v 1,, The surface near Umiat #10 is in good shape. There is no existing pad and no solid wastes. With the recent plugging of the well, it is not a risk to human health and safety or the environment. 56 Figure 47: Plugging operations at Umiat #10. May 2004. • APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Ati garu Awuna* Drew Point East Simpson #1 East Teshekpuk West Fish Creek #1 * Ikpikpuk Kugura Koluktak* Kuyanak Lisburne North Inigok North Kalikpik Peard Bay Seabee* South Meade South Harrison Bay Tunalik* Tulageak West Dease HOLE DEPTH(meters) 648 884 640 600 727 735 615 582 227 856 532 625 660 591 393 549 399 556 756 823 *Are also part of the CALM network (Circumpolar Active-Layer Monitoring). 57 • in remote areas of the leased acreage. These staging areas have the potential to aid BLM's future remediation work associated with the legacy wells. Map 3 shows the relationship of usable airstrips to legacy wells. BI,M efforts 1976-1982 The USGS initiated cleanup of the early Navy wells in 1976 and contracted Husky Oil NPR Operations, Inc. to manage the project. The NPR-A was divided into four quadrants; Arctic Coastal Plain, Northwest, Southwest and Southeast. The cleanup effort focused on the solid and hazardous materials that were abandoned in place by the Navy and was carried out during two phases. After the spring thaw, crews would travel by helicopter to new sites to break down and transport the wastes to an accumulation site. If a suitable site was located, non-combustible solid wastes were buried. While the ground was still frozen in the spring, aCat-Train crew retrieved wastes from storage sites established the previous summer. When hazardous materials (explosives and full drums of barite) were found they were transported to the storage site and hauled out the next spring. There is no evidence of anything hazardous remaining on site. In 1978, an extensive cleanup occurred at East Ou~nalik, .East Topagoruk, Knifeblade; Ikpikpuk (explosives), Skull Cliff, Square Lake, Titaluk,_ Topagoruk, and Wolf Creek. A total of $1.87 million dollars was spent and 7.2 million pounds of solid wastes were handled, stockpiled or burned. During 1979; cleanup occurred at Fish Creek, ----------- Grandstand, Gubik, Oumalik, and --_ several other areas in which a well was planned but not drilled. Approximately $1.8~ million dollars were spent and 24.1 million pounds were handled, stockpiled or burned. Field work for 1980 consisted of cleaning up what had been stockpiled and over-wintered from 1979. There is no recorded swnmary of cost or amount of wastes handled past 1979. In 1981, Husky discharged itself as contract operator and put out an invitation for bids. While waiting for bids, Husky continued its scheduled spring cleanup work at East Oumalik (Figure 5), Wolf Creek, Fish Creek, Kogru River, Meade,_Oumalk, Square -- _ - Lake, and__Ttaluk. The USGS did not fund additional work at Skull Cliff. The contract received no bids and Husky did not return. The USGS drilling program ceased in 1982. u' h~ ~'~ 1~ is void of surficial debris. The cellar is visible in the mid- right portion of the photo. }L,)2 ftt7¿,/j f,d-n E~ OF NAVAL PETROLE 640 SOUTH BARROW TEST WELL 5 Location: Lat 71°15/51" N.,long 156°37/59" \V. Elevation: Ground, 25 feet; kelIy bushing, 38.3 feet. Spudded: May 17, 1955. Completed: June 17, 1955. Gas well: maximum stabilized rate of flow, 7.9 million cubic feet per day, with no water. Total depth: 2/456 feet. In 1955, after t.he U.S. Navy had suspended explora- tory operations in Naval Petroleum Reserve No.4, a private const.ruction firm, Puget Sound and Drake, drilled South BaITow test well 5 for the U.S. Air Force installation at Barrow; the well is a standby well for South Barrow test well 4, replacing South Barrow test well 2 which had been abandoned. South Barrow test ,veIlS is between the two older holes, about a third of the way from test well 2 to test well 4, and penetrated the I same section, except that it wàs not drilled quite as deep. It was successfully completed as a gas well and proved to be better than the the other two, producing at a maxi- mum stabilized rate of 7.9 million cubic feet per day, or at. a safe productive rate of 1.4 million cubic feet per day, wIth no water. C~TEST 1 at 7005LN., IOng158~!.· /00 -/5';;). I'ounel;-it·fee~lower; 1reIIYoushing, approximately Location: Elevation: 50 feet. Spudded: Februarv 2, 1947. Completed: l\Iarch 17, 1947. Junked and abandoned. Total depth: 779 feet. Skull Cliff core test 1 is 1}~ miles inland from the shore of the Arctic Ocean, and about 40 miles south- west of Point BaITow. The coastline in this area is bordered by aeliff some 50 feet high, in which Pleisto- Cene and Cretaceous beds crop out. Oil drips slowly from a seep at the base of the cliff; Edward J. Webber described it (written communication, 1947)· as coming from a spot a few inches across, in a sandstone bed which crops out along the edge of the ocean. Except for the cliff face, there are no outcrops anywhere in the area, and the need for additional strat.igraphic information, as well as the oil seep, determined the location of the hole. It was planned as a 1,500-foot test, but mechan- ical difficulties caused abandonment at a total depth of 779 feet. A V AK TEST WELL 1 Location: La.t 71°15/02" N., long 156°28/06" 'V. Elevation: Ground, 1.8 fcet; kelly bushing, 17.3 feet. Spudded: October 21, 1951. Completed: January 14, 1952. Dry and abandoned. Total depth: 4,020 feet. ! \ ¡ IJt ' t'~'M " ¡ ¡ ~~~.r.::-,__.___-:-=::::"~ :_~ 15c:.C.¡ 1\ 1\ - .; 'IV iW Jr...",-h",,", 1'/11",,: ! ' , ¡ t f S. PÚI'/'ot<J i"fê//-6IS¡ ¡ -""',....<..~,........-''''.......~-..-.-......".--'<+~_............., ") Q() I (tot- w~ù~ ¡ /+ II;¿" 1. Iß ! ¿,o/ i ¡ j a 1.. 4- ' rLo'^- ¡..J. 1..1 J(. ¡ ¡ , ¡ I 'I ¡ ¡ ¡ ¡ ¡ I l I I !: I ,! I I i ~ I; , ¡! ¡ I I ¡ ; i I I I, I I ! I ! I ' I ! I I J ,'I I I:" 18 í 2.~ 1 , ¡ ¡ ! I I ~ .. ! 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