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Home My WebLink About100-189 • k ..Y"ay STATE OF ALASKA MAY 1 9 2n16 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANOSCte 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory [ / GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test L:tµu- 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Bureau of Land Management . Aband.:3/23/16 100-1890 3.Address: 7.Date Spudded: 15.API Number: 222 West 7th Avenue,#13 Anchorage,AK 99513 31-10-50 50-279-10027-00-00 r 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: Sec. 11,T. 18N,R 11W,M.Umiat 26-11-50 Simpson Core Test No.29 • Top of Productive Interval: 9.Ref Elevations: KB:/5ft "- 17. Field/Pool(s): Sec. 11,T. 18N, R 11W,M.Umiat GL: 20ft BF: NPRA 1 Exploratory t Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: Sec. 11,T. 18N,R 11W,M.Umiat 10' FED-NPRA ' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 1,554,375.63 y-6,188,905.96 Zone- 5 700' • NA TPI: x- 1,554,375.63 y-6,188,905.96 Zone- 5 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 1,554,375.63 y- 6,188,905.96 Zone- 5 NA UKN 5.Directional or Inclination Survey: Yes ❑(attached) No E 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 NA (ft MSL) NA 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary None SCANNED MAR 1 661? 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 8.625 Ukn Ukn 10 152 10 152 12.25 50 Sks Cal-Seal 0 Filled with 12 bbl of 12.5 ppg Arctic-Set 24.Open to production or injection? Yes ❑ No ❑r 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): NA NA NA AY34.r40oNED --left.4426.ACID,FRACTURE,CEMENT SQUEEZE,ETC. f)aTLWas hydraulic fracturing used during completion? Yes❑ No 03/ZS(I b Per 20 AAC 25.283(i)(2)attach electronic and printed information /FRIFIF[;, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L t- NA NA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): NA NA Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: 'Choke Size: Gas-Oil Ratio: NA NA Test Period NA NA NA NA NA Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. NA NA 24-Hour Rate I NA NA NA NA Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only , /6 RBDMS LL MAY 3 1 2016 CI • • 28.CORE DATA Conventional Core(s): Yes E No Q Sidewall Cores: Yes ❑ No Q If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes E No ❑✓ Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Ukn Ukn Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval None None information,including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Summary of daily operations,wellbore schematic and photos. Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Lucas Munisteri Email: lucas.munlsterl G(�,solstenxp.com Printed Name: Title: Drilling Engineer Signature: Phone: 907-279-6900 Date: 7' ka—AUL INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • REG m MAY 19 2016 °"") /'S'_ AOGCC 1 ,,,,i\ f . SOLSTENJP A4ARSHCREEK 10 May 2016 Rob Brumbaugh Minerals Specialist Bureau of Land Management 222 West 7th Avenue#13 Anchorage,Alaska 99513 RE: Simpson Core Test Well No. 29, Report of Sundry Well Operations for Final Plug and Abandonment Dear Mr. Brumbaugh, Please find the attached AOGCC 10-407 and BLM 3160-3 forms, supporting documentation for the final plug and abandonment of the Simpson Core Test Well No. 29. If you have any questions regarding the enclosed information, please contact me by email at lucas.munisteri@solstenxp.com or call me at 264-6114. Sincerely, Lucas Munisteri Drilling Engineer SolstenXP Inc. 406 West Fireweed Lane Anchorage Alaska 99503 (907) 279-6900 • • REP111-'1;-; U.S. DEPARTMENT OF THE INTERIOR MAY 1 V LUib BUREAU OF LAND MANAGEMENT AOGCC 10 May 2016 Guy Schwartz Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 RE: Simpson Core Test Well No. 29, Report of Sundry Well Operations for Final Plug and Abandonment Dear Mr. Schwartz, Please find the attached from 10-407 and supporting documentation for the final plug and abandonment of the Simpson Core Test Well No. 29. If you have any questions regarding the enclosed information, please contact me by email at rbrumbaugh@blm.gov or call me at (907) 271-4429. Sincerely, Rob Brumbaugh Minerals Specialist Bureau of Land Management 222 West 7th Avenue#13 Anchorage,Alaska 99513 • • Form 3160-5 UNITED STATES FORM APPROVED (April 2004) DEPARTMENT OF THE INTERIOR OMearch 331,1,2 Expires::March 2007 BUREAU OF LAND MANAGEMENT 5. Lease Serial No. SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to re-enter an 6. If Indian,Allottee or Tribe Name abandoned well. Use Form 3160-3 (APD) for such proposals. SUBMIT IN TRIPLICATE-Other instructions on reverse side. 7. If Unit or CA/Agreement,Name and/or No. 1. Type of 11 LiOil Well 1❑ ❑Gas Welli�h 0 Other 8. Well Name and Na 2. Name of Operator Bureau of Land Management Simpson Core Test No 29 9. API Well No. 3a Address 3b. Phone No.(include area code) 50-279-10027-00-00 222 West 7th Avenue,#13 Anchorage,AK 99513 907-271-4429 10.Field and Pool,or Exploratory Area 4. Location of Well (Footage,Sec.,T.,R,M,or Survey Description) NPR-Alaska Lat:70°55'3L53115"N Sec.11,T.18N,R.11W,M.Umiat 11. County or Parish, State Long:154°43'07.75235"W North Slope Borough,Alaska 12. CHECK APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ❑Acidize El Deepen El Production (Start/Resume) El Water Shut-Off ❑Notice of Intent El Alter Casing ❑Fracture Treat I=]Reclamation El Well Integrity ❑Subsequent Report El Casing Repair El New Construction El Recomplete El Other ElChange Plans M Plug and Abandon El Temporarily Abandon ❑✓ Final Abandonment Notice ❑Convert to Injection ❑Plug Back ❑Water Disposal 13. Describe Proposed or Completed Operation(clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof. If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA. Required subsequent reports shall be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval,a Form 3160-4 shall be filed once testing has been completed. Final Abandonment Notices shall be filed only after all requirements,including reclamation,have been completed,and the operator has determined that the site is ready for final inspection.) Final Well Plug and Abandonment. See attached document: 14. I hereby certify that the foregoing is true and correct Name(Printed/Typed) Lucas Munisteri Title Drilling Engineer Signature �eac �/�rrr Date 05/10/2016 THIS SPACE FOR FEDERAL OR STATE OFFICE USE Approved brL Title Date Conditions of approval,if any,are attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease Office which would entitle the applicant to conduct operations thereon. Title 18 U.S.C. Section 1001 and Title 43 U.S.C.Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false,fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) • i Bureau of Land Management End of Well Report NPRA Legacy Wells Remediation 10 May 2016 Simpson Core Test No. 29 API Well Number: 50-279-10027-00-00 Permit to Drill Number: 100-1890 Field: NPRA Township: 18N Range: 11W Section: 11 Meridian: Umiat Latitude: 70°55'31.53115" N Longitude: 154°43'07.75235"W Datum: NAD 83 Spud:31 Oct 1950 Completion Date: 26 Nov 1950 Status Date: 24 March 2016 Status: Final Abandonment Final Plug and Abandon Report On March 24 well was cut off 6' below ground level, cemented in place, marker plate welded on and backfilled to complete well abandonment. Arrival Status Departure Status r 0000 10 May 2016 1 - • t) IgA Work Procedure 11 March 2016 Move equipment to well, setup around well. 12 March 2016 Safety meeting-staying hydrated, PPE, use the right rigging when lifting equipment. Load equipment and move to well. Move excavator to well. 13 March 2016 Safety meeting-eye and face portion, hazards around nipple up BOP's, pinch points,overhead loads. Remove wood cellar box,set up scaffolding,tarp in, heat up. Install weld flange on well. Nipple up BOPe,and flow pan.Set boiler and heat up,set accumulator and heat up. 14 March 2016 Safety meeting-Keeping tools in good working order, radio communication, caution when using steam,watch for moving equipment. Fill the boiler with water and heat up, build steam. Fill brine tank with 10bbls water, heat up,weight up to 9.5 ppg brine. Rig up the choke and diverter tank. Spot cement unit, air compressor, return tank. 16 March 2016 Safety meeting-proper use of the radios, BLM introduction, Hazards of running pipe, pinch points. Heat up brine tank.Thaw down to 187'take fluid sample from well. Heat up well to until returns were 80°. 17 March 2016 Safety meeting-staying hydrated, mixing and pumping cement,overhead loads. Heat up the brine, circulate well, heat up to 80°. Mix and pump 12 bbls of 12.5 ppg cement. clean up cement unit. Nipple down BOP and clean up,clean out brine tank. 23 March 2016 Excavate around well. 24 March 2016 Cut off well 6' below ground level,cement in place,well marker plate on and backfill well. 10May 2016 Wage • • Well Operations Photos 4- . „ti,.,,,,, 4'.., , .... 4 ..: ..4.4ilis 4• I Weld flange on casing for BOP 1 .„ r lir „....tir ..., . .,.. ,,,,..._ ,....,to,-7 , . Rig up BOP 01 Ali ,� _ Or 7 . �! ,Fr! f e,t, -•4-:: :') .it'"11.4..:-.,11-,,,...,k-. —.k':1..''1.:''''''1 . ' k.. ilitit Rig up scaffolding 10 May 2016 31 • • �/ 1 , tills M i :�!! f . Spot batch mixer -,,,:,,,;.,:' // .',, . '... 0:::'-,..-,-„. ),k.\.' ' -- .= . `4,44,,,,,; / - iii. -,f:4* ' , ',... , , 7 - tki...:, ',:, A - i ii ,, • 1 • 7j. t . Circulate the well 1 40 fie-x-. r 's; Cut flange off of casing 10 May 2016 4 1i- E • • ID • „ Well full of cement • • 400, . • +13/14/21016 04:KI . . • Well Cap 03/24/O1li 116:17 111 Backfilled site 10 May 2016 5 I • N Arcot Ocean e `W AMA. to.. Barrow / RUSSIA Point r " Hope• PROJECT S, ' C , s.'-- Kotzebue• LOCATION Nome• •Fairbanks .4a ; CANADA ' _ * — Bethel• Anchorage J. • p Juneau 3? 33 i fs Benng Sea a Port Moiler • Gulf o/ Adak • Station Alaska • a Arctic Ocean e Chukchi SINCLAIR ' ` _ Sea Bea red sea Barrow. Cape Simpson Wainwright• * L .q K •At asuk Nuigsut. Kaktovik Point Lay. q Deadhorse• SCT#13 Umiat __ LAT:N70°58'55.78" SCT#28 �"oF H sLoP� _ r��r LONG:W154°38'25.62" } LAT:N70°59'15.69" •, " LONG: 154 312.27" Point i-a_ __- , O W 6' P p y SCT#15 �- 1 a LAT:N70°58'53 68' y Ikapa Simpson ,\ a 21 "'chi LONG:W154°38'58.45" ' '� a i e"� ,-/ A:� B E A ,`' ( SCT#14A r "s - SCT#14 LAT:N70°58'47.62" LAT:N70°58'47.60" \. s > LONG:W154°39'31.22" x LONG:W154°39'31.16" 1_. \ t a.=__,�_`- f.,njf": ,e/ SCT#31 \ ` :" LAT:N70°57'0.64" \. .,.1--I SCT#26 ,..' (.C °' -'- LONG:W154°40'4.75" \\1 \_`LAT.N70°55'54.87" \\ 'LONG:W154°42 41 96" 0 . - i ' . +�, ii,„ % - t .SCT#27 "' a' °' '` LAT:N70°55'53.29" a ,,,,` - . _ LONG:W154°41'41.92" 4 "1--, •-•- SCT#30 ' ,.- VATIOLLAT:N70°55'35.06" `' PETROLEUM RE LONG:W154°42'16.36" i } SCT#29 . I ° LAT:N70°55'31.53" SCT#30A ''LONG:W154°43'7.75" I LAT:N70°55'34.26" SMITH -- s_ ` _ LONG:W154°42'17.72" • pr 2 �' n ` , r -.).-:4iN B A Y ` IN ALASKA 2 Il h � �� . - '' COORDINATES ARE NAD83 SCALE IN MILES t ., , SCALE APPROXIMATE SIMPSON CORE TEST WELL— SITE LOCATION MAP PAGE. 10F2 NPRA Legacy Wells P&A Activities PROJECT NO Bureau of Land Management — 30025 15 North Slope,Alaska Date: 3/14/2016 L./ U• J 9, u A O C d i i H Co co m •-i LO N l• Ln 00 N l• r•-• (1;6 N 3 Q' z fY N ci c-I m f, Ln (OV 111 ZU_ U Q = M Ct to O) N O I� L() Lf) N Ln 00 U) 00 Cf O) 00 O) l0 O) Ln m m l0 —, u N CD Cr LO l0 m O) NJ N N l0 ^ LS 0 NJ NJ Lf) Cr Lf) NJ l0 Ln Lf) c-1 d 'U c Q co N .--I dr 01a) N N Cr) N N •C Z Ln 00 ri .--I N 0 -1 o C N m m Ln ri O c'I ri O • 00 To-) in00 N ;--1 l0 m N N O ('J m m Cr) y 3 O �= o) RO Ln In In In Ln Ln In Ln In Lf) In 0 Q C -i Hi Hi .-1 ,-I Hi .-l Hi Hi -I ri 0 N D M Cr in O) m l0 (M O Ln O Co to 00 I� Cr M d" 00 .--I 1.0 c-I In .-i O) Q I, Cr) In ri N 00 co ri Ln co Ln Q N co c1 00 co CO 00 Cr) In In Cr) Z N� lD lO l0 00 N l0 Lf) O N LU 00 N N m 4 Cr) Ln ,-i Ln 4 O a) Ln d- dr co Ln Lf) c-I M M M O 10 00 00 Co 00 in Ln O) In in Ln N 7 Ln Ln in Ln L.n Ln Ln Ln Ln Ln Ln C ▪ O O O O O O O O 0 0 0 O 4-, h, N N N N N N N N N N J Z Z Z Z Z Z Z Z Z Z Z CD U O C J O — 'a 7.5 ., a) ', N N w (1) N 0) W 0) a) a >, ti - m t.0 QJ (/LL L L L L L L L a) 4) >. a) N a) a) o) 0) o) a) o) a) 0 > 4-, ((00 4-, 4-0 4-' 4-, 4-, 4-, 4-, 4-, 4-, C = ++ v a) a O) a) 0) O) a) 0) 0) 0) a) N C OUUUUUOOOOU N C N a Q 0 O O N —,VI N on E Q > OJ o1 0) cu > > > > (O N a.+ rO Ti) N Q) y co C U Q < Q CO CO CO .. .. 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CEMENT - 152' HEIGHT r^v t 4 I 50 SKS CAL-SEAL GROUND LEVEL vv 1 r MARS HCREEK 12.25" HOLE -152' MD / TVD 152' MD/TVD 8.625" CASING 152' MD/TVD 256' MD / TVD DRILLING FLUID 6.125" HOLE > - 9.9 PPG 700' MD/TVD G` COV vvv vVV Trvv ° 700' MD / TVD LEGEND CEMENT DRILLING FLUID DIESEL BRINE Y1 WATER FT PRODUCED FLUID 1- FILL - I ' OTHER LAT: 70°55'31.531" N LONG: 154°43'07.752" W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 1,554,376 US FT NORTH: 6,188,568 Us FT ZONE: ASP 5 SIMPSON CORE TEST # 29 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT , FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10027-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1890 31 CT 0 26 1950 26 Nov 1950 P&A COMMENTS:S CURRENT VWELLBORE CONFIGURATION DATE: BY: 10 MAY 2016 LUCAS MUNISTERI REVISION: SCALE: RELATIVE VERTICAL r+ RELATIVE HORIZONTAL • RKB� CEMENT - 152' HEIGHT 50 SKS CAL-SEAL GROUND LEVEL • CEMENT- 187' HEIGHT MARS HCRE EK 12.5 PPG ARCTIC-SET 12.25" HOLE —lax-152' MD / TVD 12 BBL 152' MD/TVD 187' MD / TVD 8.625" CASING 152' MD/TVD 256' MD / TVD • DRILLING FLUID 6.125" HOLE r - 9.9 PPG 700' MD/TVD �vvTV V V vv vvv Tvvv vvv vvv vvv vvv vov vvv vvv V v V vvv vvv vvv - vvv v V 4 V v v 700' MD / TVD LEGEND Nx/1 CEMENT DRILLING FLUID F-71 DIESEL BRINE WATER Fri PRODUCED FLUID j FILL F-7 OTHER LAT: 70°55'31.531" N LONG: 154°43'07.752" W DATUM: NAD 83 us DEPARTMENT OF INTERIOR EAST: 1,554,376 US FT NORTH: 6,188,568 us FT ZONE: ASP 5 SIMPSON CORE TEST # 29 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT f \ FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10027-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1890 31 COMMENTS: FINAL AS ABANDONEDSCHEMATIC cr S0 26 Nov 1950 23 AR I6 �NEo DATE: BY: SOLSTEN ti" IO MAY 2016 LUCAS MUNISTERI / f�++ REVISION: SCALE: RELATIVE VERTICAL 1 RELATIVE HORIZONTAL • • PAGE NUMBER: i:P Workover REPORT RPT DATE:03/11/2016 SOLSTEN RPT NUM.: 1 OPERATOR:BLM ELEVATION:20 PTD#:1100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:FMarsh Creek WD#: FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB:5 API#: 50-279-10027-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT ENGINEER:Lucas Munisteri PHONE:(907)264-6114 LOGISTICS SUPERV:Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:Shane McGeehan PHONE:, TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY, OPERATIONS 12:00 21.00 9.0 Move Equipment to well,Set up around well TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 wwwwellez.net WellEz Information Management LLC ver_041816bf • ® PAGE NUMBER: SOLSTEN;P Workover REPORT RPT DATE.03/12/2016 RPT NUM.:2 OPERATOR:BLM ELEVATION:,20 PTD#:100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek WO#: FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB:5 API# 50-279-10027-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT ENGINEER:'Lucas Munisten PHONE:(907)264-6114 LOGISTICS SUPERV:Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:Shane McGeehan PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 Safety meeting-Staying Hydrated,PPE,Use the right rigging when lifting equipment 07:00 18:30 11.5 Load equipment and move to well.Move excavator to well. TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver 041816bf • • PAGE NUMBER: SOLSTEN�:P Workover REPORT RPT DATE:03/13/2016 RPT NUM.:3 OPERATOR:BLM ELEVATION:20 PTD#:100-1890 WELL NAME:,Simpson Core Test#29 CONTRACTOR:,Marsh Creek WO#d FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB:5 API#: 50-279-10027-00-00 CONTACTS PROJECT MANAGER:' PHONE:Munisteri (907)264-6114 PROJECT ENGINEER:LOGISTICS SUPERV:Kellen McGilvrays ri PHONE:'(907)264-6114 PHONE: (907)264-6110 RIG SUPERV:Shane McGeehan PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY, OPERATIONS 06:30 07:00 0.5 Safety meeting-Eye and face portion,Hazards around nipple up BOPs,Pinch points,Over head loads. 07:00 09:30 2.5 Remove wood cellar box,Set up scaffolding,Tarp in,Heat up. 09:30 11:30 2.0 Install weld flange on well. 11:30 15:30 4.0 Nipple up BOPe,and flow pan. 15:30 18:30 3.0 Set boiler and heat up,Set accumulator and heat up. TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver_041816bf • PAGE NUMBER: RPT DATE:03/14/2016 Workover REPORT ORT RPT NUM.:4 OPERATOR:BLM ELEVATION:20 PTD#:100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek WO#: FIELD:NPR-A RIG: AFE#: LEASE:!NPR-A RKB:5 API#: 50-279-10027-00-00 CONTACTS PROJECTMANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT ENGINEER:Lucas Munisteri PHONE:',(907)264-6114 LOGISTICS SUPERV:,Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:,Shane McGeehan PHONE: TIME BREAKDOWN FROM r TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 Safety meeting-Keeping tools in good working order,Radio communication,caution when using steam,watch for moving equipment. 07:00 10:00 3.0 Fill boiler with water and heat up,Build steam. 10:00 12:00 2.0 Fill brine tank with 10 bbls water, Heat up,Weight up to 9.5 ppg brine. 12:00 14:00 2.0 Rig up choke and diverter tank. 14:00 16:00 2.0 Spot cement unit,Air compressor,Return tank. -------- TOTAL HRS PERSONNEL _ EQUIPMENT WASTE MANAGEMENT_ PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver_041816bf • • • PAGE NUMBER: j P Workover REPORT RPT DATE.03/16/2016 SOLSTEN RPT NUM.:6 OPERATOR:BLM ELEVATION:20 PTD#:100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek VMO#:' FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB:5 API#: 50-279-10027-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT ENGINEER:Lucas Munisteri PHONE:(907)264-6114 LOGISTICS SUPERV:,Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:Shane McGeehan PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 'Safety meeting-Proper use of the radios,BLM introduction,Hazards of running pipe,Pinch points. 07:00 08:00 1.0 Heat up brine tank. 08:00 17:00 9.0 Thaw down to 187'Take fluid sample from well. 17:00 19:30 2.5 Heat up well to until reums were 80 degree. TOTAL FIRS, PERSONNEL EQUIPMENT WASTE MANAGEMENT_ PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE 1 QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver_041816bf • PAGE NUMBER. Workover REPORT RPT DATE:03/17/2016 SOLSTEN;'P RPT NUM.:7 OPERATOR:BLM ELEVATION:20 PTD#:100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek WC)#: FIELD:NPR-A RIG: AFE#:I LEASE:NPR-A RKB:5 API#: 50-279-10027-00-00 CONTACTS PROJECT MANAGER:;Lucas Munisteri PHONE (907)264-6114 PROJECT ENGINEER:Lucas Munisteri PHONE:(907)264-6114 LOGISTICS SUPERV:Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:Shane McGeehan PHONE: ,,„/"A! TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 safety meeting-Staying hydrated,Mixing and pumping cement,Over head loads 07:00 12:00 5.0 Heat up brine,Circulate well,Heat up to 80 degree 12:00 14:00 2.0 Mix and pump 12 bbls 12.5 ppg cement 1 18:00 4.0 Clean up cement unit 18:00 20:00 2.0 Nipple down BOP and clean up,Clean out brine tank TOTAL HRS, PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver 041816bf • • PAGE NUMBER: RPT DATE:03/23/2016 SOLSTEN;CP Workover REPORT RPT NUM.:8 OPERATOR:BLM ELEVATION:20 PTD# 100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek WO#: FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB:'5 API#: 50-279-10027-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE (907)264-6114 PROJECT ENGINEER:'Lucas Munisteri PHONE:(907)264-6114 LOGISTICS SUPERV:Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:Shane McGeehan PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 16:30 18:30 2.0 Excavate around well • TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEzl Information Management LLC ver 041816bf • S PAGE NUMBER: SQLSTEN;.'P Workover REPORT RPT DATE.03/24/2016 RPT NUM.:9 OPERATOR:I BLM ELEVATION:20 PTD#:100-1890 WELL NAME:Simpson Core Test#29 CONTRACTOR:Marsh Creek WO#: FIELD:NPR-A AFE#: LEASE:NPR-A RKB:5 API# 50-279-10027-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT ENGINEER:Lucas Munisteri PHONE:(907)264-6114 LOGISTICS SUPERV:,Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV:I,Shane McGeehan PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 17:00 18:30 1.5 Cut off well off 6'below ground level,Cement in place,Well marker plate on and back fill well. TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD:i 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 www.wellez.net WellEz Information Management LLC ver 041816bf .s.,OF T� • • g9,,, �y��4., THE STATE Alaska Oil and Gas ti�;; �, of e T � ®® Conservation Commission ::.,.,,€ ALAs��.rl Stt �� 333 West Seventh Avenue " '' ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Lucas Munisteri Drilling Engineer Bureau of Land Management - 1.. -16 7th Eg 'n. 222 West Avenue, Suite 13 Sat* Anchorage, AK 99513 Re: NPRA Field, Exploratory Pool, Simpson Core Test 29 Permit to Drill Number: 100-189 Sundry Number: 316-141 Dear Mr. Munisteri: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1°. (4 Cathy‘°,Foerster �{�� Chair DATED this 2. day of February, 2016. RBDMS L U'FEB 2 9 2016 . • • RECEIVED FER 2 2 2016 • STATE OF ALASKA D -7-5 z(2cf/ , ALASKA OIL AND GAS CONSERVATION COMMISSION ,A0GCC APPLICATION FOR SUNDRY APPROVALS vv��✓✓ 20 AAC 25.280 1.Type of Request: Abandon ❑ - Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number. Bureau of Land Management • Exploratory ❑ • Development ❑ 100-1890 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 222 West 7th Avenue,#13 Anchorage,AK 99513 50-279-10027-00-00 • 7. If perforating: 8,Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Simpson Core Test No. 29 • Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): FF�-��1'VA_ NPRA r G}4P1 rc+Qr—LI 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD .) Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7' ?co r �j Casing Length Size MD ND Burst Collapse Structural Conductor 147 8.625 152 152 Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): NA • NA NA NA NA Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): NA NA 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program CI BOP Sketch 0 Exploratory CI ' Stratigraphic ❑ Development❑ Service ❑ 14.Estimated Date for 3/14/2016 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 „ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Lucas Munisteri Email lucas.munisteri@solstenxp.com Printed Name Lucas Munisteri Title Drilling Engineer ap.Signature �. 5i 9 Phone 907-264-6114 Date i FEB 1 8 7016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness "--Sttflttry Nomb#t: Plug Integrity V BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Su'I 1 Lc/4 Other: 10- pito+s d e_c,., C a Srrj c& L 6 ` L)�a� s. k c_AP . Afters - /p1 `J pjd'`Jr.."� Uv'�i,er-�7l-a , . s CeS ,_ Zj`-!/z_ ') Post Initial Injection MIT Req'd? Yes CI No LI1 L�� P 4.,.., Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /)-- ( C 7 ib S"CO p S.:, P41.&44-71."--- ed--"Z APPROVED BY ' / Approved by: COMMISSIONER, i./„4 THE COMMISSION Date: 2.- 2J _I� J R I l 1 INAL Submit Form and Form 10-403 Revised 11/2015 Approved applicati a d o a date of approval. Attachments in Duplicate RBDMS ►ry FEB 2 9 2016 • • Form 3160-5 UNITED STATES FORM APPROVED • (April 2004) DEPARTMENT OF THE INTERIOR OMes:Mar h31,2 Expires:March 31,2007 BUREAU OF LAND MANAGEMENT 5.Lease Serial No. SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to re-enter an 6. IfIndian,Allottee orTribe Name abandoned well. Use Form 3160-3 (APD) for such proposals. SUBMIT IN TRIPLICATE- Other instructions on reverse side. 7. If Unit or CA/Agreement,Name and/or No. 1. Type o I I Oil Wel I ❑Gas Well❑D n Other 8. Well Name and Na 2.Name of Operator Bureau of Land Management Simpson Core Test 29 9. API Well No. 3a Address 3b. Phone No.(include area code) 50-279-10027-00-00 222 West 7th Avenue,#13 Anchorage,AK 99513 907-271-4429 10.Field and Pool,or Exploratory Area 4. Location of Well (Footage,Sec.,T.,R.,M,or Survey Description) NPR-Alaska Lat:70.9297 N Sec.11,T.18N,R.11W,M.Umiat 11. County or Parish, State Long:154.6919 W North Slope Borough,Alaska 12. CHECK APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ❑Acidize ❑Deepen ❑Production (Start/Resume) ❑Water Shut-Off E Notice of Intent ❑Alter Casing ❑Fracture Treat ❑Reclamation ❑Well Integrity Subsequent Report ❑Casing Repair ❑New Construction ❑Recomplete ❑Other ❑Change Plans 0 Plug and Abandon ❑Temporarily Abandon n Final Abandonment Notice n Convert to Injection ❑Plug Back ❑Water Disposal 13. Describe Proposed or Completed Operation(clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof. If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No. on file with BLMBIA. Required subsequent reports shall be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval,a Form 3160-4 shall be filed once testing has been completed. Final Abandonment Notices shall be filed only after all requirements,including reclamation,have been completed,and the operator has determined that the site is ready for final inspection.) Final Well Plug and Abandonment. rV See attached document: cr+ ,.Cal rri W - .- N >t1"1 t1) •Ah 0 14. 1 hereby certify that the foregoing is true and correct Name(Printed/Typed) Lucas Munisteri Title Drilling Engineer Signattue Date THIS SPACE FOR FEDERAL OR STATE OFFICE USE Approved lt. Title Date Conditions of approval,if any,are attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease Office which would entitle the applicant to conduct operations thereon. Title 18 U.S.C. Section 1001 and Title 43 U.S.C.Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false,fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) . 0 • 0 Ell , ,--)1111-.0‘4 .f .) SOLSTENJPN. MARSHCREEK NPRA—LEGACY WELL REMEDIATION Simpson Core Test 29 Single Well Program Plug and Abandonment Procedure Date Issued: Wednesday, February 17, 2016 Anticipated Date: Thursday, February 25, 2016 Expected Rig Name: Globe 40 Ton Crane Prepared By/Date Lucas Munisteri Drilling Engineer 4 ! u " FEB , 7 lois Agreed BY/Date Jesse Mohrbacher Manager Approved By/Date Rob Brumbaugh Bureau of Land Management • SIMPSON CORE TEST 29 - PLUG AND ABANDONMENT PROCEDURE Information used to develop this program was gathered from all available public sources of information on this well.The current configuration of this this well was determined to the best ability and interpretation of the information. Due the nature of this well and its history there may be some inaccuracy's in the current well configuration.This program covers the final abandonment of the well as it has been interpreted.Therefore, caution needs to be taken at all times during the operation and error on the side of caution. Contents Overview 2 Abandonment Procedure 3 APPENDIX Wellbore Schematics DE: Lucas Munisteri Date Issued:2/17/2016 M: Jesse Mohrbacher Anticipated Date: 2/25/2016 BLM: Rob Brumbaugh Page 11 • • Overview Simpson Core Test 29-Plug and Abandonment Procedure OVERVIEW During the winter of 2015—2016 BLM has contracted Marsh Creek and SolstenXP to perform the successful abandonment of legacy wells drilled in NPRA along with the remediation of the location. OBJECTIVE 1. Perform all work without causing damage to the environment, harm to people or equipment. 2. Perform all work in a safe and efficient manner. 3. Perform the successful final abandonment of the legacy wellbores. WELL HISTORY • The Legacy Wells Summary Report and historical drilling records indicate that 8 5/8"casing was set as the sole casing string at a depth of 152 feet. The reported rig kelly bushing(RKB)height is 5 feet above ground level(AGL). • Records and photos indicate that 2 thermister cables are in the well. Use caution when thawing into the well to avoid becoming entangled in these cables. • Minimal debris is in the immediate area of the well cellar but there is some trash within the wooden cellar box. Complete site clearance prior to commencing well operations. • There is no wellhead on this well. ' REQUIRED EQUIPMENT 1) Rig e) Accumulator a) Globe 40 Ton Crane i) 4/5 Station Accumulator 2) Well Control Equipment ii) Remote Panel a) BOP 3) Circulating Equipment i) 7-1/16 5 Ksi Shaffer Annular a) 10 Ksi triplex cement pump ii) 7-1/16 5 Ksi Cameron Type U Double 4) Cementing Gate a) Batch Mixer (1) 2-3/8"—3-1/2"VBR i) 2 x 35 bbl batch mixer (2) Blind Shear ii) 10 Ksi triplex pump b) Kill Line 5) Storage Tanks i) 2-1/16"5 Ksi Check Valve a) 2 x ISO Tanks,=6,600 gal ii) 2-1/16"5 Ksi Manual Gate valve i) Steam lines c) Choke Line b) Open Top Tank i) 2-1/16"5 Ksi Manual Gate Valve ii) 2-1/16"5 Ksi Manual Gate Valve iii) Connected to choke with 1502 Hard Line d) Choke Manifold i) 5 x 2" 10 Ksi valves ii) 2 x manual chokes Date Issued:2/17/2016 DE: Lucas Munisteri Anticipated Date: 2/25/2016 M: Jesse Mohrbacher 2 I P a g e BLM: Rob Brumbaugh . • • ABANDONMENT PROCEDURE 1. Identify surface location of the well and check the area for potential gas. 2. Remove any debris from area around the cellar. 3. Remove general debris from cellar and remove any wood cribbing or pilings piling obstructing the cellar work area. 4. Identify condition of surface casing string and top of ice in the wellbore. Records indicate that the 8 5/8"casing has been cut off 1 foot above ground level and is open to atmosphere and has ice to surface.There are 2 thermister cables in the well which might impede progress when thawing. 5. Remove any debris from the immediate area of the 8 5/8" casing and carefully excavate same to a convenient depth below ground level to accommodate flow line and returns barrel. 6. Move in required equipment, cement mixer, heaters, boiler, circulating tanks, piping,generators, scaffolding,tarps, and other wellsite equipment. 7. Weld 4 inch flow nipple to the 8 5/8 inch casing at the desired height for circulating and direct returns to open top barrel. --+ R,..5z....r 7sz e, i sl...al �-- sem'`P', 8. Run tubing in the well and circulate warm brine to melt frozen fluids to a depth of 147 feet BGL(152 feet RKB)while attempting to recover any loose thermister cables, or until refusal. Refusal is defined as not being able to make further progress after 30 minutes of circulating. In this case, notify BLM, and AOGCC that an impassible bridge has been encountered and that cement will be set at a shallower depth than the target depth. 9. Circulate warm brine until the returns are consistent and the casing is clean. 10. Mix a sufficient volume of Arctic set cement to fill the wellbore from thaw depth to ground level. 11. Displace well to cement until clean densified cement is observed at the top of casing. J''CC .'4.6414( 12. Pull work string out of hole and top off if required. `�613`. 13. Wait on cement from minimum 6 hours and verify that the plug has not fallen downhole. 14. Excavate around the well to a minimum depth of 6 feet. 15. Cut 8 5/8"casing 5 feet below ground surface. 16. Top off the 8 5/8 inch casing if the plug has fallen. 17. Weld a marker plate that meets current regulations on the casing. pea Z c Ark °'' IZc_ at: 18. Backfill the excavated hole and mound the excavation with gravel or tundra organics to account for Ata c-(-- lit A settling. ��30,e: "prig. Remove any remaining wood piling and debris from the surface of the location and proceed with ' �,✓ disposal of waste materials from the site. 20. Return to the site the following summer for stick pick operations. 5 r k (i/e 4. ^ ---- Su..Yf,:`,," Z"CA (.T DE: Lucas Munisteri Date Issued:2/17/2016 M: Jesse Mohrbacher Anticipated Date:2/25/2016 BLM: Rob Brumbaugh page 1 3 • • • RKB CEMENT - 152' HEIGHT "V v v u•v v v v 50 SKS CAL-SEAL r, :vvv 7 7 V V v '" GROUND LEVEL—/ 7777777,77 vvvv 79777 vvvvvvvvv -. MARSHCREEK 7°77 ° 9,77977777 '2999 vvvv 9 vvvvvvvvv 152' MD / TVD 12.25" HOLE vvv vvvv 152' MD/TVD 9 7 7 9 9 7 7,7 vvv 7777 99779770 8.625" CASING vvv v v v,7 152' MD/TVD77777799 vvv c® 256' MD / TVD VVVV _ vvv DRILLING FLUID 6.125" HOLEjo,bV av v 7 vvvv V,7vV - 9.9 PPG 700' MD/TVD 777,77977 779 vvvv vvvvvvv7 vvv VVVV vvvvvvv7 777 vvv7 vvvvvvvv vvv vvvv vvvvvvvv vvv vvv7 vvvvvvvv vv7 vvv7 vvvvvvv7 vvv vvvv vvvvvvv7 vv7 VVVV 777,77,7,77 v VVVV 'vovvvV 7 VVVV 999997 VV VV V v VV 700' MD / TVD a .S? 4 r p dcc�7 68`1(4 5-6F- O<2,`{ (.ZfMt C"^r LEGEND n CEMENT 1/71 DRILLING FLUID 1,, I DIESEL rI BRINE FT WATER I-I PRODUCED FLUID = FILL ni OTHER LAT: 70.9297 N LONG: 154.6919 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST#,###,### US FT NORTH: ###,### US FT ZONE: AAA ## SIMPSON CORE TEST # 29 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT j'$0.Th FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10027-00-00 / SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1890 \��,ra,/ 31 OCT 1950Nov 1950 26 Nov 1950 DATE: BY: S O L ST E NXP COMMENTS:S: CURRENT WELLBORE CONFIGURATION S FEB 2016 LUCAS MUNISTERI REVISION: SCALE: RELATIVE VERTICAL RELATIVE HORIZONTAL RKB CEMENT - 152' HEIGHT � � 1— - 50 SKS CAL-SEAL GROUND LEVEL ' CEMENT - 152' HEIGHT MARSHCREEK - II BBL 152' MD / TVD 12.25" HOLE 152' MD/TVD v 8.625" CASING a v C 152' MD/TVD a o <. °v, 256' MD / TVD aaaaae c n- a a DRILLING FLUID 6.125" HOLE > c - 9.9 PPG 700' MD/TVD v v ' V V C' ;ac a a O V V9V 771777 V',aaaa aaaavv '7,avav VVVVVV 7,777,77 'vaaaac vaaaa -77,77 -ava vaav VT VT V c 7 O O- 700' MD / TVD LEGEND CEMENT 1 1 DRILLING FLUID 1771 DIESEL f l BRINE WATER 741 PRODUCED FLUID h H FILL I-7 OTHER LAT: 70.9297 N LONG: 154.6919 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST#,###,### US FT NORTH: ###,### US FT ZONE: AM ## SIMPSON CORE TEST # 29 � SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10027-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1890 31 Ocr 1950 26 Nov 1950 26 Nov 1950 P&ADATE: BY: ;/moi /a�� LS COMMENTS: PROPOSED FINAL ABANDONMENT 15 FEB 2016 LUCAS MUNISTERI S V T "' rJ tP REVISION: SCALE: RELATIVE VERTICAL 1 RELATIVE HORIZONTAL J J III Y In ii YU ±W LI' %. CO F-F-F- F-F-F-Fr u-F-r u) ; a u)u) �cncncncncn w� r0 ww�wwwwwwujw rn I--F-F_F-F-F-F-F-F-F_F-r�0 — * _ vJ ww wwwwww 'E'2 kwCC " " ° -i r 1r ,LA ¢¢�¢oCOC¢¢LCi¢Ypa : I�M!Iialt� 11�rFiaq �I r=-_ - 00000000000a m .�P►..iali:: m , — 11► i1�yg1`: x .1--- 00000000000> 0 a __ : _ zzZzzzzzzZza�� - W 00000000000 OD ; p ,1 u)u) cnrncncncnU) cn CC C) La. aaalZaaalLaaa ¢y ;, •I _ . 222222222 < r. u)0(N co 0 0 0 0 cn u) 4111-jua..l. �il�ju!_i1re ,m ' 1(e/71--( All\ W Y C rr ¢N `�U j a mN ,U J co JZdNm !nU 0-f'..,_ co I g 2;7 m mQm¢ ° CO U_ Jm0 UO 1-Q �_ u_ UO Z r ° 7�Q jN "N Qm N O t!•) y Z oNcn 0 3 i-,.., � -I 3 Q wQ N m o CO w IL Y6 L w LI- O 0 cn o D J F- 7.---.-----.- -----------\----/-"--N____.... 1ww f O 0} O o •'.1.1�1�1111• oO 0 0ell ❑ p �_ O Z ro a" av NUw a N cz o cz a —1 Q o f o f F- U U ) WnQ ¢ mLLOoz Oa 02 =1UJ w O I— N 0 c N m Z 1 r J"5 4d al o N — W i I 17.- w = w a , Y J O — el.evilliiiiiin.l11! f— Z W U •_ • U Y O O _ ■ ,i — O LL co = Z T rn ju!,t•,IMm�.e0I I. 0 < • _ F- Y z Lii J I I V a N f¢— cc 0 o a (Ao - Z I CC o O CC O N w w EN H CC 0 Z 2 ct W m00 F- cc 1 ~ D 2 DcnC7 (i) O I— IiZ wZ w 00 m 00 ow Y CO C 7 w 1- O CU 0 >w m z Occ cc U Simpson Core Test#26 0 • Legacy Wells Summary Report Minga' .:S!mpsn tae Test#13 ,.f tt�� ,!4„j.ipson Core Test#15 Esst Simpson#2• Sinipsori Core Test #14&14A k i' 'n k. Y *I ,A xs ID xx ' - x s # ',I. a t �' # f s°4 s .rot , q '�"'ti --,..., :..,: :=,,, o a s Core Test i.�1 A-1.-11k, ",,,- .:. -,,,,,...... ,„.. -;;-11.,,,,, :4- -,.4-.4._ e_,, `' .far-m � C. " Simpson Core l est#2T 1� A Simpson Core Test t126 Simpson Core Test#30&30a Simpson Core Test#29 r O.r� f I Solo q00 h�Ates pSOR#1 m g., Figure 1: General map of the cased Simpson Core Tests. 370 BLM Open File Report 127 • May 2013 Explanation Page Permit Number 100-189 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. 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.doe% 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[.Ni\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 I BLM 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 f+lone IYOMWil Low RNooe ane None 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 ncf drill fluid assessmcnf &work Ian dnllxs fluids tett rn hale no data well skelch 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 hole 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 & Workplan 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 berm 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 None 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. neve 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 Care #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 t 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 openrigd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden cellar, 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 san 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 f'tone 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 2004 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openrigd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden cellar, 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 see 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 valve on city ground; rig 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 Cemented at 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 None 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 test #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 I 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 Knifeblade #1 US Navy! 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% sticking 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 casing 7? No Cleanup no data data Not abandoned, site not cleared, 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 concrete 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 Test 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 MonthlyMeeiin 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 remediated surface site remediated suriacx V le remediated surface site remediated 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 Yes, 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 k0to—k ctst \��/, % THE STATE !�!�i� ?° > �iE G L.LVIZCi2m- ASEA Bali 4t4hup -Z-lk Of A Li Conservation Division of Spill Prevention and Response SltaE_ _ Contaminated Sites Program ' 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 sCANNED APR 2 8 a014 Anchorage,Alaska 99513 Re: BLM Legacy Wells Dispute 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 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. n•\enau\ FPriP.a1 Aopnripe\nnT RT.M\Proiects\Le¢aevWells\71113Letter toBLM onLegacy 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.vreernan@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 O L. 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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. 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 (Figure 10). The Umiat wells all lie within 2 miles of the camp, with the exception of Umiat #1, which is approximately 5 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 June 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. Arnly 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 #5 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 remediation. Photo taken August 2001. historic value. The Alaska Heritage 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 50 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 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. 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 3/-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 from sands at 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 j and completed as a dry ~ ; hole. It was the southern j 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 currently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional U~niat 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 drillstein 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, wanner 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 ,> _~,~. rs-w r= ~ ~ =~:~ ~~~ n ~; ~ r ~. ~ # 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. 26 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 reserve pit contaminants raises concerns. The concerns can be eliminated by pumping out the diesel, or displacing the diesel with water and adding a bridge plug and cement to close off the hole. The casing would be cut off below surface. The diesel would be disposed of at the nearest Figure 17: Aerial view of the breached reserve pit. faC111ty. If necessary, the reserve pit could be excavated down to remove contaminated soils, which would be placed into Super-Sacks and hauled out by Cat-Train for grinding and injection into a Class II well or other approved disposal site. 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 irmnediate 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. 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 Ninuluk/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 extremely 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 p1pe, and four bacteria. wing valves and will likely flow oil if 28 the valves are opened. Access to the wellhead is limited by the depth of oily-water sun-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. ~ ~ ~ ~, ~, ;._ ~ ~~ ,,~ s L .~ r :~ ~, `•_ - ,~ _x ,:. s p tq =F 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 Formations, 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 during 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 bai7els 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/g-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 '/z-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables protrude 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. 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 r~ U 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 a ~- 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 drilling 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 cui-~•ent 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. Tlu-oughout 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 1951 to 1,618 feet and cased to 53 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 55-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 625 feet. It is deeper than the other two Wolf Creek wells because its primacy purpose was to test the Grandstand Formation (the producing formation around Umiat, 35 miles to the west). The Grandstand Formation produced from four different sands. In 35 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 threat 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 ban•els of oil per day tluough 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 infrashucture 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 $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. There is no existing pad. The well was drilled about '/$ 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 tun 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 beating 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 Foinlations. 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. Tlie 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 pa.d 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 =tr ' ~ `" '' ' °T` 3` :i T ~ ~ 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 probletns 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 2004 lease 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 sat 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 Atqasuk) 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 diy 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 Gi°andstand and Topagoiuk 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. 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 diillstring 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 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 • • 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. 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 Ournalik 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 Topagoiuk 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 '/2-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 U 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 barrels 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 thermistor 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 penetrated 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. C~ There is not a visible pad, but rather an area of disturbance. Disturbance stretches '/4 mile in an Figure 36: Topagoruk #1 casing on its east-west direction and '/g 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 cun•ent 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 • • Knifeblade #2 Knifeblade #2 is another drv hole drilled in 1951. 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 environment 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 perniafrost 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 surrounding environment. North Simpson #1 North Simpson #1 was drilled in 1950 to a depth of 3,774 feet and cased to 1.09 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. Surficially, the area is wet with the wellhead partially submerged intermittently throughout the suiruner (Figure 39). The drill site lies only a few miles from the Arctic Ocean. The work area is visible with metal pilings around the wellhead. It is unknown if additional solid wastes exist under water. The well was left with a bull plug installed on top of a swedge. The well is not near human activity, and does not pose a threat to surface or sub-surface resources. 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 (Bunuss, 2003). Sandstone tongues 48 Figure 39: North Simpson #1 is partially submerged in the summer. (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 Figure 40: South Simpson #1 had its cellar backfilled with silt, with s11t 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 a non-con•osive agent, and even if the casing should corrode there would be no impact to the surface resources and minimal 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 drilling 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 summer 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 Atqasuk. 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. annual basis Tunalik # 1 ~~ ~~~~~ . . .~~.~,. ~. =~ ; ~. 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. 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 drilled 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), Topagoiuk 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 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 s ~ hansported 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#1, was spudded in December 1946 and drilled to test some of the oil bearing zones encountered while drilling Umiat #l. The well was drilled on the northeast corner of Umiat Lake just below the hill from Uiniat #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. Umlat 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 aside 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 tlueat 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 Foiniations. Oil was found in the upper and lower 54 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 envu•onment. 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 barrels 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 Inay 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 Unuat 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 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/g-inch casing is flared and open at the top. This well was plugged May 6, 2004 (Figure 47). with Aquagel and water (per barrel) were used 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. ~ s APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Atigaru 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 Vilest 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 ./' e _ ~'. =,¡oo. ,~O, 'I â", i' r), ¡, ;::: ~ "'F' 'k! " ¡p" "j. 'e;;' 'D ~-:¡; Cß f" ¡-- ;;'~ '¡ ,"" L~ <'==__'") j ,",.l~, ç~,- ~,~¡g' ~'''-",,,,, ~J"~~~ Uò S,> GEOLCG·¡CAI, SUi1.1ff,Y tTavy Oil Un! t Lè.bo"!'~);~,,!'y :\!'air'l,8.lL.tcsr, Al¿Skt~, cc> f,JÓí :~.~:~2:j'::: sn-n:>SON CORE 'l9S'l'~IO" 29 Siln'DGOn Core Test !:To" 29" located ¿to :£'~to ?(P575 " 32'¡ 1I 8...1''1(1 Long9 15'1043~12" lfè ä'PpToxisna.tely 2500$ sou",hêrly from Cor& Test 1JTo~ 26 wa$9:µudd.~d in on Octobar 51;} 1950 and was cornol@tsd November 2ß" 19500 lH$vatlü¡.¡ :::1,t the 1;0'0 ()f the kell;r driV6 bushing waft ]'5~ 0' Coring started in the C-ublk and 'ðenst:rat\!ld. '1;h'8 Crêta~eoua a.t a. de1'1;b of 85v 0 f.øne F '-n th1 s teSlt contäins ßOIDà sand IIJfd ch i 13. 'Z¡ìmna~ . to Zona 1i1 ('Dro bably reworked R) but diffé:rØ 1~ tba:t the sand is cementêQ by- à Üg:h-); coloX'nð. argillaceous ma.teria.l (benton! tic1'),~' Radiolaria a¡>@) common" TÞ~ contact b8tw~en Zone F and Zon~ m oc~rg ~0m~whe~ø in the drilled interval 469-679~ 'but c'!tnnot be1dentified. by di teh !3:9..mr.leso The b;¡,'eeeia Sêl9n near the "baM of ZOI!.ê F "ro'bably <Continu~ft to 490 v a"..d tÐt1 ac·t'M.l eOD.ta,ct m~ be at '1;his ds"tbe, Co:" 3ß, 41 '7~427' f> 'Canta-iuÐ a. mi::re:9. 2:one ]' "' T¡ fau.na, 'P:t'ol¡a'bly "becauge of Zonê m f1'agme!1.'ts in tbe b%"eceia" !h0 bottom ooreo No, 40 679=6S9Qo eonta1n~ LaÐ7ident81i~~ Ghella and a good Zon~ ~~...~~~- m m:t~rofauna~ A. few fair oil outs wsre obtained in tbe aa."ld;l ZO!1-$ 1" Mction from 300 tQ 400 f'@et" '!'he following 4&8C1'1 "Otton is 1:uased on d%'~' co.:ì"f,)3~ t<Jaahed d:¡' teh ~'Olt9fJ~ and~ to t>. limited, iðxtet:t.t. on the well gêologist~<1 rs-po2't a...:l tha elec'1,;T.ic logo. Paleoll'liologi© id$nt1fiœ~ion.e and correlations wère mað.ê by R., )3:< :ae:rgqui13tu 2.2!'.! ' De1'Jth _ .--4 fu!ºO~8~ f!,!~iíJeri 'ô'~:9A Q...·?19 'No saJIl-p193. :ree~~l ved 'in Fair'bankß". Well geolog1 st re-pórtä;¡ tlCl9.;'?" v~ry aôf,t(, çay to dark gr2..Y~ ~nd and. ~m$,':U (]h~T.'t 'Peiibla~ scattered throughout,'!" , w. "11=131 q lOij 0[$ 496ft ClaYt> medium l:t~ht GjH·'V@ g7B:Y... simHar to lOWG:1:' 1nt1U'11Eìl of 'this r.~o:re but htu ~mallt9l'" amount G:t' sand. al1.d <Joa.-rSt:l material" Cor~ is rat'h~1' 'broken 73:G., 5 í! S II Sands"hò n0 ø mB tJ;l'ura li gh t 011. 'IT" gI'a:¿{ ~ roadi um @1)7'1;,;' v~)'ry' a:.rgtU£109Q'\.1~=·"'tlsm.~nt.3d with clðJp SB..'1d Vf~;r;f 'Poorly fJo'rted~ ¿~:t'a111 j}1ze :ra.n~S9 frt)J'I1 very fine;;(¡ V'I!J~ c!}ax-~e~ in ganeral the smaller grains ~iéJ ¡iiX;c, g'>J.lar and th0 1,~1"g9r are rounded. to well :rO\.~¡dÐ(l a."bou.t '70~ art') c:~earLlua¡>tzp the balancé a¡>@ tW-rk gra, and 1:Ilä(;k.~ha:rt ·.-ñth a t3mall adm1x·~u.i."f.J (~:? "',~T:'. ~olo1"8d mate:t'ia19" ,H3c¡;t¡:¡ionä1 rack f':oagm8n'Ìì~ 1:-'}]:'Ð':c1'm.', Inel'.1d.-ad alooa:':"~ g'r;IDule9 and "00bþl139 UTi to incho9 in. diElJD..9t$:z' oCt.'U:ì:"r~.ng at randomthn.ü,gh.i)\] the in'tøl'"'1alo made U'!-1 for the m(H~t TI¿:¡:>'~ of ¡'{H¡;,?(¡ I}2.!¿1~2 ,¡): ..., 81~9J" ¡ì IL~,!:9Y~~ lO;} f,)¡l~ e e ll.s ~:1,,£~E;11?!~,Ql* e!;,2:r~:, r.J,r6 'ttð.1'1 c.t."t:'rt 9,r;~d I1n1'0$t::;11€}'J CCJZ"8: "G€:1(ls ~t.o¡ ~O:t!~lf}}~ ~l;rr({gula.rly naz'al181 thA bed.d.:tn!?;-:. '['9.1'\3 12.mii12le cf c"n:;b01J..9.0BOU¡¡; mif'"térié.L c;s.1ça;«~~<)lA3,> rZ;I"8,) 7.~t,·~~ te r:.;}!1'8.);O;!:.1od $11"~11 :t'r:?...€:"", men't~ ®ç;l;tt~¡'ßJ 5..::ö~r) ~ c 'Tar;: rB,Z'~ Gu!)i>: mi {;!'¡,fo gpil. i"J" '~:3~ 3ðtldg"te,n~,J ;f]r;~ :L r~. lcVl~~T' ·lr.t~~r?~;;,l of Core 1.J V!JJr;r ~ -è¡;x {'l!:'",y tö!.1¿"tt'd 'b.!t@~~ 3~:,f~ Cl.a,y Itglr·t gra;,yi'c Btoftü .f~~tIDll:}lit~ 1t.·ii\,-~ 11 Ht;:¡ t.>.hin¡J 1,i::t}'îl {iTi\'3ð. cut\> g11 t;¡r varting'~L) goðd, o13a1;.ð1,f')"~ }.€'l D8r:.dln.gí: t·en~:l~~n,cSi- té.Y!{Jal~d W&T"'1 t",;<1 'I 'P'1"g.t:'t;:J7"'-"" )'ìJ·"n~j:;:£'}"''''~E''''·a.'''·' d:1 'l"i ?',~lùÇ) . , \J...... ....~."._ .....,.. L ",.. . ..,. 1;:1, ................... I <L~~ ¡#4i1;;:þ-:¡ r . ~Ra.~ ~ ,:1~'1J)i}r TIlt :t~rW\ í~ð; ~l~111 ~. ;-; 9;~=10;;j¡ \~t~lJ1Jt7.>'·t()11 ~~'f C.t~~,~t,a.~~jtl~ 1 ~ ~'t 2:,1j"(~{j ~::1. ma ti!il., Eð \~ ~ ba~'~ of 4. lCr2=<~ 12~ ú :) :i.l2~~122i !,~} :t ?2-··~:t. :52:1 ~-;¡ 1~32= 8' 14~=i.52~ 11'} 1J) '\; 0 i~ 101 Or¡ It; 't () ~r )~O '¡ ();f 8Q5¡':) 't590ft' Gl~~'J" -:tu~m l:lgbt, g:X~äYf¡ rneå.3.;cro ffi£jftft QX{H!:<Llðl'l't, lJl~9a·v.~~g&,~ l,",glli i:::;rð:.'l :$111;y trar··tlnš:iiJ.~ ~h3.~Otill:t eh fiZl?&l~);' d1 SiJ"Jmj,'C;a.~}.~d l);V!"~i t~~i2'!. iKm~ c:.f ".;h"l '';aT"ing~¡ niB> ·tJa.l~:u·l~Ö~¡ê!t 5~t:·~ . lú·OGi Lin;.~~t-çin.(~.;t mfJdlu1}~ 1·.iè~bt~. f;r~t tQ m{~dlul!1 tr;r~~n h~~rd.;· a!)gi 11,aer~~tt,~(, -Œ·tyr\ tE'.iïl f;} D11, '::.-~~ i r~1?~!:~'!:~J.a1? f',ì:ê?';;: t'lTê,,; ß G (~l~y £;:ha.l~, h ,~t~ .i!?~ fi:e i1t ,. 't1 t·e:r7al ü -(,thJ.,f! CÕrt~;> Trf.fr;~l[¡fL1. :r:~t~Ë\e'~'(t\:r€'~ .Q.()n'='"'~r·,le~a,~1:'eðt'lS~ di'p 40:· ~\,li ,cTJ'.}fo ~t '¿.i 1 ~ f:tl:: g~!r:~~ Cla.\7 Sh'f1..1.d" Jni';::Uum l:lght g;.'æ¡r mad:tam flofit" :'.1. .gr.ay :91J. 'n~r'tlr.~.ge(1 \t)x¡:;t;116i1Ì1 r:l~avag'~'(' ~'~a:t)ti'~Bo-: trai;;tur&; nOJ;>.~èËlw,Tø;)tI;š1~ d,1:µ2";5ö . 7:1' i (;;;¡~:,d Ob 'd 1.1 ¡o¡ oS 'b ~jSfj \' , Clay ~hB-.l~r aì'J:J,l)ov!" n:'T¡:>i te in r',a1'1;il1gtll, üit:, 4= ]-lii ~r.:)f() ~:,~11 fJJ ~ft ~,e~'ü t,,: Cla'y~l1El@t ail ;'1"b~PT~r' 1h9rM.1Jal j¡>:r<-":.~tur@; dip Microfossils ah~6ntQ ;-PO" Clay 'ijhal,~, e"{' att'!'v~;: (},h; 3t~ 11 IDA !.t{~}l.~~(- ::tIücl:t'~~G Ë;,rfl~V D tJ¿9.;lÞ{l,p 2\.t$gl11a,{;·f5ou~i) lr:re.:gu.le,J,'Jo i~r8-ettXj;'et Cla;f i!r1:'J,l~" H.ght; f7a:]~e medi'.¡m light &"'ta~2" Söf'4Î '.1 1. t,~;'h~'~j ~-:;¡?1'.Y ," t'~il J. t~)r " ~c'd:r'tl.úgg¡.! a.x~t911~n,-t nOï1=eal~~jo\l¡¡¡; d.:î:r:; 3c~fj'\' M1 e!',) f (I S131 1 i!î a:b i">1'311 ¿" ~ f"< ;-, 1,1 ~.~ \} .., 1 "f6f:~ ClaY' St~äl{i}) äû in lö'W"a~}'·t ir;.·t~r-'W,:;'tl ()f ðC;¡~~ (¿, id~h f,,)'Wa:f. 311 'Da.:r·~t1'\,.,;¡:£" g¡.;¡'Od. "tô ~:"ire:~"nŒ¡1: "py:,~- 'J;<1! :1 f! y¡a:.r·t:t ng~~ r.v:F¡~caJ..,~a!';;H)U~¡ di'(j :Mi C1"()"Fos,gH iJ a;'~ent c of',' .-," COTe ~- 9 10 11 1~ 13 14 15 15 17 18 19 ~ ~eco"{er¥ 152-1639 119 On 163-173" 109 On 173=183\) 119 0:1 183=1939 109 A" 193=æð9 lOü O¡~ 203-Z1Sr. 213-223° 223-23Zr, 233-243 r, 343-353Q 253-2639 10' otl 1û 0" '10') 0" lO~ O!'! 10 ~ 0 I' 109 Off e e .~SCl"~:rltM!! Olay shaleo an imm9diat~ly above; non-ealcareouêl~ d1µ 0_50 H1crofosdls ai:>~~nt> Clay I3halsa HfT,ht gray to medium light gra,.v" softo psxt of core tønds to mM~bl$ into tiny chi~s wh~n dried oute rare light g1!~ s11 147 uart1ngsQ fair cl~av.age uaral1~1 the bedding~ much haek17' cleavage; non·~ea1eareou.§~ di"ð ZJ Mlûrofoss11a v~ry rare. Clay ~hale(} light gJ:ayo medium soft~ backl,. and smooth cleavag,'3" stl tyo "Oart1ng8~ non~ca.lea."('eou8g å.l.., l-~ . Mi èrofosd13 !',:HJant. Oldy shalee as .iL1madiately a.bOV0g non-cal:carsou.s~ di 'P 1=20 M1cr©~ossils ai:>sent> Ol8..Y g:Þ..alao af¡ a'bovs; no;r¡.",œl~.m,rsouß: dip -;P Mi crofosslls abl!l9nt" (na.y shale" medium light gr~1> mèdtutn lofto fa.ir to excéllentclaavagl)g some haekly clßa:'Q'agê~ non- o¿l~areouø~ di~ 0-1° I'H.crofosallß "lory :rare" Cl~ shalêo ïnß<l!wn light gf'?;Y'fJ 'POOl" to i'ail9 ha©kly clemvélg'e~ non~ealcar@ouš¡ dip 1,0 i4icrôfos~11a vø:!."y :t'ar~~ Clay sha.lsp light ftf2:Y 1¡(j medium light gra'Jfp fair to excellent (~eavagn; nQn-caleareoúe~ d1~ 0_10 Mi~xcfos~119 e~sønt~ Clay ahalêø 1$6 ä'bO'r!"@o 1'.1(},;¡r to fair cleava.ge;) V@J",J..'Y rare ~i1·r.T -pa,l:'1.ingG~ non=œloareðus~ d1-p 10 M1crofossi18 a.h9~nt,c, Clay shale" light f!7a:y t¡~ medium light g,'rEqa fa3..T to e::reellønt cleavaF,'i!ìo t)J:'le $raal1 fIsh aea1e nol,t;¡d a:t 252q ~ di-p O=·):~) '- MicrofossHs absent" As 1mrnediatel.Y abov~(, va~ :ra:t"é 'blu.1t!Jh gray da;'r 'Partings: non~~alcar@ou9; di'j:) 1° Mi 13ro fa sa'. 1 Ð aJ) asn t." 3 !¿!:1Q1t '863-~2?3í' 81 21Z:-~'.8g~31ì 22 28~·29:C_;\1 .;-':t¡,;:t' ",J"" 2.4 ~~,~:)3'"'"'313ij ..,;:: (..".\.. ;31 ~-;~,~ ~;.8~) iÌ .~"".~, ,-<:/0' 323~..,3t3~3~ ~ßC_'J.~.&2'::t 10') 10'1 O¡I 9\) 0 10') O(i: 1()" 0:\ 10" 0') 10') 01< e e }-jE~;~(~!'i llt~ Cl¿;;r sh,ÜG,J" LLght gl'a;l ~-GO m~)!;H,l)l.r,¡; light §l'¡>a"Ih IDÐdit.w :ßçj'«'~;icì @~~;g·el1nJJ.~~ c:l'~,~l:Va2:ot". ôüæ~:al~:Z1i:11 'üartl11,gß ·i¡il th f'tn.øly d.1 n gßm~na í¡>j(l \7~'f:r'1 ~If'!; ygr;y :r ?:ï:l'$ 11.ght gI'e:;;7 ~~:il'ty T-"jart'ln{§:;.3 t~rÁt:1. l~11ilî.f'~€r~ t\,~:o ~f'1:g11 DQne fra.gmt9nt~ ne'1;o<3.,. 3:Lt: 5,;:)'i;l¡.e ~ cf IJ.ffiß- g ton~" medium <Lvk: gra"v,) "fl'$ry ha7'd" d.e"'~$ a~ 8ô5iì t: gh8.1í~ :L'j nOll=eal~a!'aert!.'S~ 11'P 0,-1 () ,t,.ifl ç;l'(~f(.j ~H~il ~ a)H:!S¡;¡t G:;.a,;:r sr.:gle" r~;;¡ a1:'I;;,!;')" W'B'X':r r¡'1,;c;8 JJili¡y 'Dartinga. szo~6'dif1g1J': j';l:t'ebl~id!ðh gtay ,;,1BJ"^ naxting$, nö¡)\~ M,l()al'øt!'1.l~,; (li:j) 0=.;5') ï~Qfc ng'~li~ 1~o3sn.'t!.-, nlay shElf:) anI -Jl.a~r})'t,~:al?~(. rned.:~"(lIAi 11€~ht y:a::J~ ~l1~':¿11Th'J1 po,~r to tai¡ç' c1.~],e.~L·:.&:Ø If f¿ra.{;~~1.ïrf; a t~va:r1 ö"~_:~~j .a:J. gl ~ ~ r, ra.:r@ ;T,l (~Gì/.JeOll·~ :~¡:l(l :~,~~:ç~ bo Ì~;.;~~]ott ¡§ :fl@ "t~~ ~ ~' V'~A "1:7 ~~, ··¡f1:¡=.t.,.g!n21:i1.'7~ð~ \fv!t~'Y (¡1'1gb,tIlt' tCal:ca'~;'t:~()l_:~EL": Ò.~~·i 1~~~~;0 2'1"1 t~l~ C' f\2 I;J ~i 1 ! / ;~~}:r;'f ~!t<fQ;~'~ ,; ahi-ll2t¡J 1..1gb':; €;1}E4/"ij v'f]:1:;! ~~)ft}(i 9X,t;@.tlfJiI~ ~1~a7.ð£~~ 'into V~l~:r th1:p, "µi~30B'2~fJ r~xr~al':B 3.nto ~rn;:;~11 ê~.:d:f:1~ wjl.0r~ d!~c~':ed f)~'J.{~~, l:.{itrt~~;rIt~v lriJ.;t~y "p";ar'ting;¡:; a.nd }.i3.HÜ1.a.ê :i¡:':.i.'!rfk\~"-I J.n n.1,ti1\bö:"tí:n,.yard,p()ttom of' CO;;;'ì'Jp, tj~}m'f} v~;e;r ~fi fl"a {~~"l?a~t }:lêd. ~Jan.clv T~ar~tin,<:~~ ÍI1I1th fai.':.:- oil öd.o!' ~ n(j¡;,¡,~,~lGa.7."ei~Hï.¡;j~; d.J.þ 0° crofù'H!:!.l ~ ':?;?¡J:'7l il'E'¿·'ð., Ißj'~~:f'bi!jèld..)'l (fL¿¡jT 151:.1EÚ«3 70~~ and. £I¿¡'~nd¡'§<t',}n~) 3('fþ" (:l~~f ~ha¡@¡; m,::¡(Üw:! tgjxt g".e'3;j7 and Ciand¡¡¡t,(¡n:'9~, light; t:rB.T- fir] f~) tn..1- "; n¡j ti g ~;)f -;; 21.$ i:õtJ::t' ~ E. ì:H;}g\,> ,0 $ .1:~j~11 $Xl i; ~1 ~Ja-:.,.aif4D',1 @xe\J"o-t !ltn.@ :tn{~~11.ifj ~ ~~;.t 308;¡ thê ®~':':,i.. ,~,~-{ ?"1:r ö fiQ t ~)1f"~~~ i)X'..@ 1 ~0.{~1.1 til'l t~~~: ð Sa,n.d. t ®: tì1'O'Ll't 6C(~'< '4;2"i tê a.nd.ðledlt'· ~:-Ü~; tI.m:'k: ,Çy.,,81' ¡, ~nd tJðt)!;'~' 'b(j;l1a1;:~{jH)Lð f'/:"a~m;3'"(J.'\',<¡¡ <Cluj. {,i8 a tit~, 0'1.' tr~wn:1 s :t',~11.(~1tI {:FlaJ~t~~. ~l.Q¡';-tí:; (f)a-,;:Fl@ 1..,¡Jl~. 't;$ \~:"~..1.':1\f)o ið1~'-b,;:.~):~;:'_·].- f1!lG g;ri:j.J:l.f~di IDom~2"<?~gð¡, 11Ðl'!; eölQ~?;3d ¿rr~dl1 ~';'U(_:D'. "1"~+'''''~1~"' 0 """,;'" ",~,,\ ..,'"X' I'" """1 "',' ¡¡·S.." ~~L f'-."),.ii :>~jè.''''T, ¿]!:"... "Jt:}L C,,"-, -3' :J:.(",.;"..-_....- ....;.ç.¡¿, I...,.,r::",,- ~3V·"'·!b':. \J,,~~; ~ ~I ~- ..ø..... ~ - u t;;1t;:\, a,ud 'b:(" 0 111)"1,' ,9h ¡'¡'l;ì51,dl'1,i!s :t':;?¡:»!Jì ;308'; P3:@fo ~:li!~ll 9 ~,jþ-'b[1g~:t·t '.~ lx~ tarbÐf.d~tl :~rj}.\¡"f~~ 3rtd 3ft!ldstCjfia 15~:~ ¡" u(~1~tø ':J:1:tJ:ì. larlirlä8'~ nvTI:-·iJ.~~1.·.c.D.Tt!ö;~·:]~ 2tjd~.~~~ ~fa~.r.lt Ct,lt.;J1;."Jf) 'j~·'(Jl:t;~I.1 B'tl'{1 ;?,w:td In.'!G-tm.:l 9J'1 y~ll~ìt:l· /'"0;'; f'd;OIrl 31\7';¡ };li croff) r~31:~ S ~'_j;h~~,!J]l't 1 n.i';@1·1'ìed.d.€d. Ð<)'1'ElstQ)l:"~ ~t ';J m~ dl t.~n 11 è~:';':' -l'; gJ'.:~r l1 l:t gh 1;, ~Ti~ a~~1l' i) ~JJ* t grl ~~1¿? ~~( 1 '\,,1/'" ;; -:',,;~, ~b>ll (:} r;l/=.\:t .-~aG. m.ndl\1.m ~J¡Jf=~·~,;; Sa.!le.~'-~61fJ,/~ '~õftj~'r tb,a:fi1- 't·b.-$ ~.n,aL@., ;~LJ: fi '~ !j-ºl'~ D~ï;!~l1 ;?'l 333~3.i13a ~~8 :;4z... 35 4 0 ~:9 354=365 ü zt) 36 s....375 ,; ~1 375~~85f; 32 386-;:,96 ¡j He co vel"1 -=>-""""- ~,~ 10'; OU 10" 0.1 :1.00 OrJ 10° OIl ll~ 0111 109 0" e " e ;l~~,~.£r:l. ?1!i~E: ConE'¡;~. tü.,mtß'S'ß 1.1:'. (>~:rÐ 24 abo iN', Moti te abunêtant in o$rt¿in l~ye~~~ fine g~ainÐd~ rara ~art1ngs of ca::ròona,c(;JCv.~; T;~t€lri~,l~ rt(}I?=~lœl'eOu.g~ diTJ 2()~ fair ode.ì;¡>~ 31'0U,0\;1 c;;;.t~ b?0itlîl1 sh yello·.g resldu@ at 325:1 r4iCTQf'ctT311ß 'v®:r;¡." :ra;~"eü Int~~ñedd~d 2œ~dßton0 60% and clay shala ~oaß immed.ia't<ely a1.')'.)'V~r' ¡)artinga t1on.1iaining black car~ 'boP...'lCa0111 roati;H'ial" ,:>ccaJional va:r.1a'ble d1i.')8 dUG to èr~sß~beaœ12g~ non~~alcareou8~ diu lðò fairly good. G/11 odor,) Y$110111 cut," brõ'wni 9h yellow residue at 342~ M1t.'7.'ofo9ið:US a~'$~mt, In t$:r'bsdded cl¿:ty- sÌ';.a,le "¡'rf;& sandst.one 30%~ as abOV8t nO!1·~r.;alca;raou.~-; di-p lo~ fa.ir ,)dot',;, yellow C",1t~ 1);¡;>¡:n.ml Sh"';1911wl l"è sl du,~ f;;>c!n 348 ~ Mi C~:~ fo M ¡;¡j.l $ 'TSTY 1't.".;i'® 0 Sa,¿;"d.t.rtonê0 lig'o.t g¡;~-o rnsrl1um 30ft" æ:Jonta,llUJ numerou~ pa:r'tingr!l of M2Ï1.: oa:r"bm1aGoou.~ matø:ria1" ~ome laminae of með3<,.Uffi Hgh[; gra,v cla.$-'" shaJ.e¡; ~1.d 1\'1 8~ whi'te and cIaax- qua'i'~2~ ,;:¡,lJO "Dlack ca.:r'bonac$oua :f:t'agm'3nt~Ð d::¡,:rk chel~t axÜl yellôH q:U:1!'tz~ goma "bioti tê~ su'b= anglùara VÐJ?Y :::i.)1:!~(J fi'.1.~ grained¡, cemAntsd wi t,h v~¡>y Ugh'!; colored. ElI'g111acaoutJJ materialÐ some cro~s= "b!~d.ding~ lJ,on~ca.l t.mr~(n.H\~ éli-p l.}o~ fair oô.@ro yellow cu.t and 'brown13h Y'911ow Tt'J9idu@ from 3540 Mi Cl'o:fo asH s a))aaat, In:torbsdé},ød clüY shale ?Wß and sand:'Jtone 2..~fJ same aitl eJ,eso:ri1'Jed in COJ'Mj a'b"ve~ very thin laminäEtQ ¡;;,Q Ðand~ th1. cleaT 'i;ll:an ~'i- 1n~hp 1l1L.'D.@lrOu.5 CJ.B:rk OaT= 'bo''1'lac\!Jo'll~ ')ar t~}1g'3; :ra:t'f3 C1"O ~H~= b$dding; non- caV;;a:r00U:t~t d1~' lC» ,> FO 9>->"'"'''5 .P' ß - ..~""';;. r-Hcx'of()fw1.1Ð V;'Y~'jl' ;'Ð..T-8c In tß:rbBð.d\9d ;m:D,d.~'tQnf;; 605& élud {\lsy shäle 40% ç. Clay w1.al@ ltJJ !ß8ê'd. ~iJ1J H gh t gray" m s<.l1:am soft 3XC'311= en 1; eleavàg!ji" S2XJ.d.3tO!.'-t.1;. t) H.ght €)'ÐY" ßoft" gO% whi ta and~l,gax q'W'..:rt'Z" aJ. ¡gí) d.ark cÞ...ert" '1)la(jg r(Jgäly particle~o yell~w q~¿art.~0 Bome b1@t1ted8Ubangtt12~" ver~ fine to IDedi\m! ~Tainedn eame~ted q~th veTY light gY:Ð.i!argillä;ç¡soUZ m¡;;,hr1a.ln :b..a.\S fa1:d.y common b13i¡;k 'Partings of co~;ly 'part'clel3r 'r~:ry sroa.ll 2mov.nt üf crc~~='beddinm !ton-<:äl©:s.¡·0öus~ di'O (¡,=4{;; no od~,.,p ~o cu.to gre¿fiW 1:11m i~ '3"V8;ooraì:tng dish f":rt.,¡r: ::38~.V !'li C¿'OfQ9t111 í!l 'V·t,ry :.ì>ars" Intðrbßdà~d ~a~d~tonê 10% e:za.~tly as i¡¡eCfre a'b()v~t no 9ho1lTÐ. I'!1crofö9s11~ vrl':ry f':::t.:<::'Ja and ~la~r !!1Ml49 3(/0~, c' n()n.=<.ml('~~.re(nu!~ <Up 4- ~ 5 £"£!:t~ ~!ttë 3~; ~,96-407" 34 407=41"'1~ ...¡;:: ,,1~" 417=42'7"1 3õ ~~28~43B Q 37 438,..449 q ReCOVíS/r1õ' ..<õI231>;:S: ..t. ~-""_> 11 q 0" 5q ot, 50 Oft 6Q O~ 100 ot! e [J06f~ Ik ~ fY¡ e }~?£tl")~5"ç¡~ Sana.2!tonê~ light gray" ¡Joft@ 'colUpot!1tion similar to s.a,nd. in C(~ra 31 above. qui ta a bit of òioti tee :fin~ grained.v rar~ meitium g¡>äineø cla;¡ey matrixu carbon~caous na7tlngs. cccaðional m~dium light g,rt~ clay sr.äle lsm:,ua:3' nCiu=caleareou,£j¡ 111') ~, no !lJnOWfI! Mic~ofcßflil~ vo~y r~Teo San.1ß'to.ne" a¡iI 1.:1 r;or:$J immøtliat.ely a'bov~, C1~y" 2hale and 4:::1,"JY$t('!n~,) light gray to medium light gray. medium ~o1t~ ~o~r t~ good cl@avag3" one foot from the to'IJ of the Jr0C07Sry i$ a 1/16 inch thiclt .. , layi~r of vary light gz'~~ òanton~'¡¡1© ela;¡r~ non- ca,lça:reou'Bø dlTI!3 '7à.'t'iaôlø 3=25° or h1gh~r. Hi6:ro:fo ss11s aò¡~en.t. Cl~rfJtons and (Ù.a;1 ~ælá!1ø mød1um light gra;yr, 'Pc)01r t@ fair eli!3a7~..gsg 3Hcl:ðrHJid!~f diþuingup to 40° in fi:ï:,,~t §1:x ;'l1ch@\:l of c'Ôrall a. ~a,ll amoun:t of brecCli1 wH;h f¡'t~gm~ntB of coal and ôluinh gf.'a;s" "bentonlti.¡:; cl~~ nt'liU' r:ag", o'! the CO:t'j3p a. brown fish scale äil. inoh in dia.metGI' in 4th\') t6J'P th:r@1'I} inches of recovsred 1n'~arvðl~=th1a i $ 31m11o;,1' to fitlh !'ical~HJ found in Zt):!'w ]'c-f Sim1O$(!)'f, Co:.r~ Te~'!ìt No.>Zß~ light oolored, miorofossUs ,~ø vi>at"bltJ to th~ na.,'!{sd sJl"(! in 'the haml aþs¡:¡i¡n,~n~ non~~lcsri~oiUl~ à.:1:ps vaI':lablsa lo~ to nteErpo ~{1c:rofoas:nÐ a1:t.:mdänto Brec.cti9. with cl2.ytl'toD.¡z, n\E>.\~ri~o medium light çay to msdi. mu gra:y ø cor $ 1 Œ 'badly brí)keno numerou.s 911 ch-:@n.~ dde~ a:t v.m·iou.'B ant::::lafh ds..Yâ·\,;on@ (:öntaln~ angul~r :tragmsntg '\X'D to an inch in diameter of dark gray and 'blacl:: c!)aly ma,t<3:rtal,; medium light g¡.'a;;'" clay ~hal~Ð light gL'!iJ! 'OeD. ton3.. 'I.te cla,ÿ Ð gray1. ah yellQw ,clay iron:aton.e and ¡'ara :rmmded bla.ck chart 'Pebbla~;> :rare fi~h fragmgnt9" '1yr'.t~fh Ona large gPè,.yish yellow cl~ irongt,on~ oon{~~tlon in about the-middle of thø cClr~~ nt;¡n=c:~lca:reCl:l8; l..noce:r~ ,.,1'1 ems in mi crofo s~11 cu:í¡o ?Qr~minif®ra. aDs~ntß ~rTltiß radiolaria common 0 :0;rI';c,cia ,-rt th el~ytliorJ.e ma,t:ri~1' as? t3t:>re imml'd1a'þel;r a'bove~ f'e:1fN.lT ~li ü'k:~nì.@1d.o~ and not ([111 te as 'broke!:,] . l'ragmarl';.í§ 'In cl3.Y' £'.!>I!J sl),ghtly. 1,~g~:r=-ê():n'\Ìain !&ome chupk'~ of' :1l.ed1um lip;ht gray. msd.iu!'ú gra.ineêl Zona E tyþ~ 1!E!,nio fragmsnt of [~ -pelf3ey¡?od in tht'i! ~d~ nön=~lca;,"@ou~2 dl'¡J~ iJ.U to vartiea.l 1:n;!:~ genera.lly about 200Z Ln..oee¿>~~ '{)rt~e in mit'J'ö= fossU cu:t., lVI1 crofoMHs 'fie:'!;,! rare., r- '() 'f Sa~J.,d9ton~'1 lig::'1~1¡ g-:r~t to mødiw\1 light ça:yv in '¡:¡art ha,:ç>d an,{1. "Jr.l'th "fB'3.4;¡ cal{1areou.ø cementc medium t@ ~02l:i:> ~~ g1'ai:n(lC\o ~1J.'bar;gu.1Æ1r p a'bm2.1; ~ ?Jhi te and cli!Ja;r qt\;:œ'l;iZ~ al 00 dark Chêl"t~ l'öck fragmen'lj'i'jp coal 1),3X~' 1;1 ¡elt1~f' fJIDMl flill0U.:P.'t of 1)',ot1't~ Gl¿;¡.y r m~tl:turn l\ght {;¡.'t?Jy Cl£1.Ya D1~(',j:1Jm l:S.ght g¡?a~r ;9.iî.d sand@ medium light 9"a.'f¡. fina -;;0 ¡¡¡ad,ium g:¡:~alJ'J.t9d~ yellowi øh graf1 cla.y iro~= stonê 5l0=ao~~ ~evð~~l vary coarc~ ~tiele~ of coal 520-:30 Q ¢ San.åp m~c.\ium H.ght ~~ra fine to f!tsð.ium grained (more f'.na tl-.02ll medivmL 80% whi tG and clear qt1.~:r'~'Z(, balance it!! mOfj~jly daTK g:r~ cÌ1ðrto bla.ck coaJ. 118,,1'- t1cles and chal~? ~hit~ ~artiQlê~ (~oøaibly altBTed ch~rtL Olayo medium H.ght gay and. s.and Sando finG to !Il'i!J{'l1wn grained Clay and. sand. sa.na.~..tonøa m6di~ light gayo madi.um to tCoa.1"~e gra1n~do harrio baa tiM. t~ very ca,l car eotUI ma:tl"1.x,) S¿'ß.d~ton.~1'i ms.Hum l:t;ght gJ.~a"vr> m~d:1ml soft and f:ri~, able, ma3si'vêr gu.ba:n~1'I.tla."(" to i%D.g1J;larr mOl5t mediwn 'but ä ff}\!/ coa..T<legra.Ü'H~fJ 50.% 'tihH;e and clear qUJ:œt2o 307; dark: rock: :fragmantn and cÎ.1$rtg lœt mediwn bard. ohalky white f~a£mên~s0 SOID$ biotite" loosely ¢smellhd by a:t.'g:'dla.c€Jous mat@rlal" Phs sandstone (,Io'!1talD.Ð" 'Par't1.cularJ.y in up'Psr l! feet and o~œ~ionall.y thro1i.ghou'Ìì COTSn angu1àr fragments up to an l.n.c:!¡, in ¡jJ.:9mlSter ox variou{I shades 0:1" gra.y cl.~tY !!ha1s a.T1d. ailtston$(I alf!~ Yf.!111o\dsh gr~ clq ir'Q\n~ton~" S$~2 l.neh®-g ;'J¡T modium g;l?t:q c1a.y shal@ at arrproxima,to:ty 466\; 0 good cleavð.gao containa 1'1 an 'bone fragmentí3" eli{1b!}n~id.e~ at steep anglesD dip of bed~ 150n Q@dding not vlsiòlê in ~and@ton8ï 9a,:Qd\;'ltonii! Y~J;jP 1)01'0"<.1."3 1¡@ ð:ro~ tør.t~ nonpea.leareo'lJ..g~ no 3hoWI!! Mii:;rQf'o!l!'Jll~ .a1)~øllto 6~51! Breccia. ~ th clays tons matrix" B-ß above~ core brokt!lil U'pv slidŒnsid.$~ B,t 'Jaí36 of interval. di"a of bada .' @' up to 55 () 2Q '(II Sandetone !1Xtd l)r@cci.~ wi th \3andy ma:tr1x~ medium light gc ay ~ Vø:fy ao:t't and i'ria'ble~ 50% wh:1. te and clear qUâ;"1't~(' .;10% da;t'k;er !11!tnerals ~mð. coal" suOOngtÙ.äI'\) medium ~ained~ Borne b1otite~ claY$7 matr1xQ, Last si 2 inchas at òo ttcm cd:" c"rB 1 a l1a.rd~ has very calcareoiJ,!rJ tìsm~n't~ COn"tai113 ang.ilar 'Pi~©~e of wIt gr~ and mad1um grð;y cl;l"t i'!h~.1~ ~\nd 'broimi 911 çÐ:$ -cl~., 1r(',HlstQn¡~ Ul) to 1;,;'l(:! inehøj! in diam~te:rft ~qi c::f'o1'oM1.1f!! vøry %'a4:>eo 12eß_~r;~ w\¡i9Il e 10(1 011 9~ 01' R~VE~ e 550-6:20'¡ 820."#0630 ß 5~640" 540.".6501¡ 630-550" 490=500 (I 500...530° 470~490¡¡ 459=4ß9 '1 39 449=459° ;38 D~TI~ !;o!'~ 'y' ~::;.c~ ~D!ª 650-660 'Î 660-670~ 4.0 6';9-=689° 690= 700-} Recovl'}Z'X loa 011 e e ,.ge.~~~i "Otio n grains a¡).ba..'1gu1ar~ 65'ß l-ihi is and clear quartz(, a.òundant dar}: gray !änd 'black I'Û151'tc 'black coal "OÐ.Ttlcle1=J~ ä fs'V¡ TI}Ck' fragments" a"bundant grayf.ßh 'bro~m clay ironßton~ ~äTticlesc S¿nd~ 8..13 a"bo-v€)" :fin/!' to medium gTdn8d~ 'but wi th no caJ.ea.'t'801Ut <:smtmt" No sant¡")l $ Claystone and cl~ shale" medium light g!'S'¥r. medium soft" 'Poor c10avage~ ÒI'øa.!.¡:s irreg.¡larly" containa nU.msI'CiUr, lamin.aa p1' ¡ned-1um light gray ell t 9bal-Ð~- 1Xp to on,~ foot thick at 686<+8'7° 6 Uwer 1mlf of the COX'S 1>.a$a~t)und.ant Laevldenta11um remains usually in clust~rso slso ~~l~ëÿñod~heíl~agmentB~ nQ!.I.- ealcaraou~; diµ 7~ MiCT@foteilg Doromon~ Clay m¡d aand~ 1ina gra:in3clQ i!;¿'~<Lï?¿~~ ._ Flor~nc0 Ro"blnso!1" Geolog1, 8t F~brua~ 2~ 1951 IS