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• , " MAY 1 9 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A ! ,, WELL COMPLETION OR RECOMPLETION REPORT AN ' la.Well Status: Oil 0 Gas❑ SPLUG 0 Other 0 Abandoned 0 , Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory Q '+ GINJ ❑ WINJ 0 WAGE] WDSPL 0 No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: w Bureau of Land Management . Aband.:3/27/16 100-1900 7 31 tL-140 3.Address: 7.Date Spudded: 15.API Number: 222 West 7th Avenue,#13 Anchorage,AK 99513 11/30/1950 50-279-10028-00-00 • 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: S. 11,T. 18 N,R. 11 W,M.Umiat 1/23/1951 Simpson Core Test No.30 , Top of Productive Interval: 9.Ref Elevations: KB:25ft 1.1- 17.Field/Pool(s): S. 11,T. 18 N,R. 11 W,M. Umiat GL: 20ft BF: NPRA 1 Exploratory Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: S. 11,T. 18 N,R. 11 W,M.Umiat 15' FED-NPRA I 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 1,556,088.58 y- 6,188,905.96 Zone- 5 693' NA TPI: x- 1,556,088.58 y- 6,188,905.96 Zone- 5 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 1,556,088.58 y- 6,188,905.96 Zone- 5 NA Ukn 5.Directional or Inclination Survey: Yes ❑ (attached) No p 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 %AWED MAR 16I.1/ 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 8.625 28 Ukn 15 150 15 150 12.5 63 Sxs Cal-Seal 0 Filled with 0.5 bbl 13.2 ppg Arctic-Set 24.Open to production or injection? Yes ❑ No f 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): NA NA NA trice,ANOctJr� 4E -Vc i?L1 I Or DATE 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. 3�2�1 Me Was hydraulic fracturing used during completion? Yes p No❑ ......_. . . ... /ERIFIt.D Per 20 AAC 25.283(i)(2)attach electronic and printed information I L" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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 - NA .NA NA NA Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only fly h//7-4 - /' 0 %.,16 -16 RBDMS I, , MAY 3 1 2016 G • 28.CORE DATA Conventional Core(s): Yes ❑ 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 ❑ 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.munisteriasolstenxp.com Printed Name: Title: Drilling Engineer Signature: � - ' "� Phone: 907-279-6900 Date: 5- 0-\LQ, 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 • • paw.: MAY 19 2016 AOGCC 0 SOLSTEN,, P It,,AARSHCREEK 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. 30, 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. 30. 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 • • RECEiliki) MAY 19 2016 U.S. DEPARTMENT OF THE INTERIOR 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. 30, 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. 30. 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 OMes:March 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. 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. I. Type of ll 11 Oil Well G ❑Gas Well ED ❑✓ Other 8. Well Name and Na 2. Name of Operator Bureau of Land Management Simpson Core Test 30 9. API Well No. 3a Address 3b. Phone No.(include area code) 50-279-10028-00-00 222 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°55'35.05550"N Sec.11,T.18N,R.11W,M.Umiat 11.County or Parish, State Long:154°42'16.35732"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 ❑Notice of Intent ❑Alter Casing ❑Frachue Treat ❑Reclamation ❑Wel]Integrity ❑Subsequent Report ❑Casing Repair ❑New Construction ❑Recomplete El Other ❑Change Plans 0 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 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. See attached document: 14. I hereby certify that the foregoing is true and correct Name(Printed/Typed) Lucas Munisteri Title Drilling Engineer Signature fit=�' " alt-✓r�ta -- Date 05/10/2016 THIS SPACE FOR FEDERAL OR STATE OFFICE USE Approved lw 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 anymatter 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. 30 API Well Number: 50-279-10028-00-00 Permit to Drill Number: 100-1900 Field: NPRA Township: 18N Range: 11W Section: 11 Meridian: Umiat Latitude:70°55'35.05550" N Longitude: 154°42'16.35732" W Datum: NAD 83 Spud: 30 Nov 1950 Completion Date: 23 Jan 1951 Status Date: 27 Mar 2016 Status: Final Abandonment Final Plug and Abandon Report On March 27 well 30 was fill with %2 bbl of 13.2 ppg cement,samples were taken, and left to cure for 6 hours. Marker plate was then welded on and back filled to complete well abandonment. Arrival Status Departure Status 42. 10 May 2016 1 • • Work Procedure 23 March 2016 Safety meeting-stay in line of sight with operators of equipment when loading out equipment, hazards around handling BOP's working in high winds. Move equipment to well. Weld casing back on with BOP flange. Back fill excavation. Nipple up BOP's and flow nipple. 24 March 2016 Safety meeting- pinch points, check sling before they are used, keep walkways level and clear of trip hazards. The scaffold in well, set up return tank and brine tank, set in test pump and salt. Set boiler and heat up. Run hard line to choke and diverter tank, blow down with air. Hook up accumulator lines.Tarp in well, move in heater and heat up BOP. 25 March 2016 Safety meeting-Testing BOP's, make sure the pressure is bled off before going to next step, Keep walkways clear. Function test BOP's. Heat up mix water, build 13bbls of 9.6 ppg brine. Spot cement unit and berm in. Rig up to test BOPe.Test BOPe, blow down choke. Rig up to run tubing. 26 March 2016 Safety meeting-working on scaffolding, running pipe, pinch points,well control. Heat up the brine, rig up to run pipe.Thaw down to 19', unable to work past an obstruction in well, notifications made. Rig down scaffolding, clean out brine tank and load out, rig down circulating pump, nipple down BOPe, rig down accumulator, rig down choke, rig down the hard line and diverter tank. Pump brine out of the casing. Re-excavate around the casing. Cut off riser pipe and BOP flange. 27 March 2016 Safety meeting-working around the open excavation, mixing cement. Mix cement,fill casing with 1/2 bbl of 13.2 ppg cement,take samples, let cure for 6 hrs. Weld marker plate on well, backfill well. 10 May 2016 2 . I Well Operations Photos r,.r �.T Excavating well area ;1s Xtb r . 1n4 ..e,-,'4,7:." tM ti ew. ;,,,i.. Broken casing stump during excavation I al Rigging up on well 10May 2016 3 1 ' ' '_ • • t i i `2 " 4 \ .. i i S h Testing BOP f,„ \,,,, 4k , 4 .r I � Aiii -, -',,,1 2. Circulating well clean Aiiiiimmi- t • Cement samples taken 41 10May2016 ;� 6: , � ktkj Well full of cement Y a. Y L r Y R xh t.+ Well cut off depth 4 �.. .4` • 1/7/1016x:17 Well Cap 10 May 2016 5 1 • 0 . . . .. „. .... ,'' Ag \V 1110 . . , , . , • s . - — : • ... ‘1. # :. *_ . ...• „,, ....4* ,-. . rrre 0 Well location marker 10 May 2016 61 e N r - Arctic Ocean e Barrow G _ RUSSIA Point -- ( y /. Hope s PROJECT S n ` :mak, Kotzebue• LOCATION a Nome• •Fairbanks '..° fps '+t CANADA ' a/ 4<x� C : Bethel• *Anchorage Juneau ep i • is Bering • sea Port Moller •_ Gult of .._.....—__ ._.. Hu Adak Station Alaska • Arctic Ocean 0 ,f. Chukchi SINCLAIR ,, Beaufort Sea - F ea Barrow - ' Cape Simpson >o Wainwright,, L 4 K E At asuk Nuigsut� Kakto kik Point Lay. q Deadhorse SCT#13 Umiat •LAT:N70°58'58.78" SCT#28 a o ' , LONG:W154°38'25.62" ) 1, p LAT:N70°59'15.69" • 1Point -'55-'-'5,--,-L--- , _ j" LONG:W154°3 12.27" i ; ', Hope R It �g .1.' 0 R C : SCT#15 _Ta Se rn LAT:N70°58'53 68" : ..• ---v ,fcpasim.... i z� LONG:W154°38'58 45" ' . za i 3. N > i - , B E A SCT#14A '" SCT#14 "' --. 1 LAT:N70°58'47.60" �. AI..y 28 E V LAT:N70°58'47.62" \ 0 I LONG:W154°39'31.16" a` • LONG:W154°39'31.22" ,r I- .: .. 3 SCT#31 \v -:3750,---t o. LAT:N70°5T 0.64" \, -- LONG:W154°40'4.75" \ v. SCT#26 - - \. \. LAT:N70°55'54.87" LONG:W154°42'41.96" 5 -- - _- SCT#27 I'. ,- LAT:N70 5553.29" 9 ate•, i a - LONG:W154°41 a„ 41.92', _- ►, SCT#30 .,, - 'V A T 14 'LAT:N70°55'35.06" S', PETROLEUM R E ti- LONG:W154°42'16.36" ' SCT#29 ;"„'-------1a•'»ri I --1 LAT:N70°55'31.53" SCT#30A ; • LONG:W154°43'7.75" LAT:N70°55'34.26" • --.;:=1 .,- LONG:W154°42'17.72" S M I T H z+ 22 • } B A Y f' : ( i IN ALASKA % 'A1 I �r 0 3 %A MMM ;- "'""COORDINATES ARE NAD83 SCALE IN MILES SCALE APPROXIMATE SIMPSON CORE TEST WELL- SITE LOCATION MAP PAGE �0F2 NPRA Legacy Wells P&A Activities UMIAQ PROJECT NO Bureau of Land Management - 30025.15 North Slope,Alaska Date: 3/14/2016 • • J •— N O vO> O -C m ,-I LID Nup NL L n N Ln oo• �Ni cri Ni O O'° ..cs � OC • � ON N r- ci N ,cri CI' v W �i _ Z U u Q C N C Cr to Cr) N O 1--: V) Ln N V) Co 0) C oo .:I- Ol 00 0-1 UD Ol Ln Cr) CO LD u,-i ^ d "0 In Cf O Cr L.C. 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W N L ry N N N N N V) N to N in 0To ro O d C C 0 v O m U o * a Ln C7 D < O cc 0 • t."7:14\ RKB CEMENT- 152' HEIGHT - 63 SKS CAL-SEAL 19' MD/ TVD MARSHCREEK • FISH GROUND LEVEL x n 60' MD / TVD • 12.5" HOLE > 152' MD/TVD , CEMENT 103' HEIGHT j - 7 7 7 V V V 7 - 12 SKS ARCTIC SET 8.625" 28# CASING 150' MD/TVD V V 7 V 7 V 152' MD / TVD 7 7 V V 7 „ V 7 V 7 V V `77 7 7 150' MD / TVD 7 7 7 V 7 V 7 ✓ V 7 V V V V 7 V 7 V 7 V ✓ V V V V 7 V 7 V 7 7 7 ✓ V V V 7 7 V 7 , • DRILLING FLUID V V - 9.0 PPG \77/ V V—\;" 7 7 7 7 V V s- V V V V r. V V C 7 388' MD / TVD 7 7 V V ✓ V 7 V 6.125" HOLE 7 7 V V 565' MD/TVD 217 7 V 7 CORE BARREL ABANDONED DOWN 7 V V HOLE AFTER UNSUCCESSFUL Vj 7 V 7 FISHING AND SIDE TRACKING 77777 G 7 • ATTEMPTS V V V V • 7 v 7 7 V V V V 7 V V V 7 - V V V w T 565' MD / TVD 7 7 W V V ✓ V . V — • 7 V V V V 7 ' ✓ '• V 7 V V • 7 7 7 7 7 T V V 7 7 V ' • 5.875" HOLE >17V V 7 693' MD/TVD I --- — 693' MD / TVD LEGEND r CEMENT 71 DRILLING FLUID DIESEL 71 BRINE WATER I PRODUCED FLUID i..=3�+ FILL F-07 OTHER LAT: 70°55'35.056" N LONG: 154°42'16.357" W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 1,556,089 US FT NORTH: 6,188,906 US FT ZONE: ASP 5 SIMPSON CORE TEST # 30 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10028-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1900 NOV 23 JAN 1951 21 APR 2006OIL PRODUCER DATE: BY: S O L ST E N '.P COMMENTS: CURRENT WELLBORE CONFIGURATION AS 10 MAY 2016 LUCAS MUNISTERI REVISION: SCALE: RELATIVE VERTICAL DISCOVERED 1 RELATIVE HORIZONTAL 406/ea j RKB� CEMENT- 19' HEIGHT 13.2 PPG ARCTIC-SET - 0.5 BBL "'��' 19' MD / TVD MARS HCREEK ' '` FISH • • GROUND LEVEL 'j" f7 60' MD/ TVD CEMENT- 152' HEIGHT 63 SKS CAL-SEAL 12.5" HOLE 152' MD/TVD ' X. CEMENT- 103' HEIGHT - 12 SKS ARCTIC SET 8.625" 28# CASING 150' MD/TVD 152' MD / TVD 150' MD / TVD v v • DRILLING FLUID - 9.0 PPG V 7 V t7 t7 7 388' MD / TVD _ - 7 6.125" HOLE 565' MD/TVD 1,7 I CORE BARREL ABANDONED DOWN SS HOLE AFTER UNSUCCESSFUL FISHING AND SIDE TRACKING ' 9979 © v. ATTEMPTS 9 9 7 7 7 ♦ ' ' 7779 9 V v 7 7 7 7 V V L 7 7 9 • , r, 565' MD / TVD 7 V T • '7 ' 7 77 V � 77 V V V (Y 7 ' ♦ 7 7 7 7V 7 '777 T T '7797 r 1 5.875" HOLE 17 9 V • Q 9 693' MD/TVD I r r 693' MD / TVD LEGEND I CEMENT I� DRILLING FLUID I I DIESEL Ii BRINE I= 1 WATER n PRODUCED FLUID FILL F:71 OTHER LAT: 70°55'35.056" N LONG: 154°42'16.357" W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 1,556,089 us FT NORTH: 6,188,906 us FT ZONE: ASP 5 SIMPSON CORE TEST # 30 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT 44$$:;". FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10028-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1900 30 Nov 1950 23 JAN 1951 27 MAR 2016 ABANDONEDDATE: BY: COMMENTS: FINAL AS ABANDONED SCHEMATIC IO MAY 2016 LUCAS MUNISTERI S O L ST E NaP REVISION: SCALE: RELATIVE VERTICAL 1 RELATIVE HORIZONTAL • ! • PAGE NUMBER: SOLSTEN;,'P Workover REPORT RPT DATE:03/23/2016 RPT NUM.:1 OPERATOR:BLM ELEVATION:'' PTD#:'100-1900 WELL NAME:Simpson Core Test#30 CONTRACTOR:'Marsh Creek • VUO#: FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB: API#: 50-279-10028-00-00 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: PHONE TIME BREAKDOWN FROM TO j HRS PHASE TASK 'ACTIVITY, OPERATIONS 06:30 07:00 0.5 Safety meeting-Stay in line of sight with operators of equipment when loading out equipment,Hazards around handling BOPs, Working in high winds. 07:00 10:00 3.0 Move equipment to well. 10:00 12:00 2.0 Weld casing back on with BOP flange. 12:00 13:00 1.0 Back fill excavation. 14:00 16:30 2.5 Nipple up BOPs And flow nipple. 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 r IPAGE NUMBER: �� Workover REPORT RPT DATE:03/24/2016 SOLSTEN;.'P RPT NUM.:2 OPERATOR:BLM ELEVATION:, PTD#:100-1900 WELL NAME:Simpson Core Test#30 CONTRACTOR:Marsh Creek WO#: FIELD:NPR-A RIG: AFE#: LEASE:,NPR-A RKB: API#:'50-279-10028-00-00 CONTACTS PROJECT MANAGER:Lucas Munisteri PHONE:(907)264-6114 PROJECT LOGISTICS SUPERV:Lucas Munisteri PHONE:(907)264-6114 Kellen McGilvray PHONE:(907)264-6110 RIG SUPERV: PHONE: TIME BREAKDOWN FROM TO 1 HRS PHASE TASK '.ACTIVITYI OPERATIONS 06:30 07:00 0.5 j Safety meeting-Pinch points,Check sling before they are used,Keepwalk ways level and clear of trip hazads. 07:00 10:00 3.0 Scaffold in well,set up return tank and brine tank,Set in test pump and salt. 10:00 12:00 2.0 Set boiler and heat up. 12:00 15:00 3.0 Run hard line to choke and diverter tank,Blow down with air. 15:00 16:00 1.0 Hookup accumulator lines. 16:00 17:00 1.0 Tarp in well,Move in heater and heat up BOP. TOTAL HRS in:: ' PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD: 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten 6 — I I www.wellez.net WellEz Information Management LLC ver_041816bf • • PAGE NUMBER: NJ.'P Workover REPORT RPT DATE:03/25/2016 SOLSTE RPT NUM.:3 OPERATOR:1BLM ELEVATION. PTD#:100-1900 WELL NAME:Simpson Core Test#30 CONTRACTOR:Marsh Creek WC)#: FIELD:NPR-A RIG: AFE#: LEASE:NPR-A RKB: API# 50-279-10028-00-00 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. PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 Safety meeting-Testing BOPs,Make sure pressure is bleed off before going to next step,Keep walk ways clear. 07:00 08:00 1.0 Function test BOPs. 08:00 11:00 3.0 Heat up mix water,Build 13 bbls 9.6 ppg brine.Spot cement unit and berm in. 11:00 12:30 1.5 Rig up to test BOPe. 12:30 17:00 4.5 Test BOPe,Blow down choke. 17:00 18:30 1.5 Rig up to run tubbing. 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: Afa RPT DATE:03/26/2016 SOLSTENA) Workover REPORT RPT NUM.:,4 OPERATOR:BLM ELEVATION:, PTD#:100-1900 WELL NAME:Simpson Core Test#30 CONTRACTOR:Marsh Creek WD#: FIELD:NPR-A RIG: LEASE:NPR-A RKB: API#: 50-279-10028-00-00 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: PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ,ACTIVITY OPERATIONS 06:30 07:00 0.5 Safety meeting-Working on scaffolding,Running pipe,Pinch points,Well control. 07:00 08:00 1.0 Heat up brine,Rig up to run pipe, 08:00 11:00 3.0 Thaw down to 19',unable to work past obstruction in well, Notifications made. 11:00 13:30 2.5 Rig down scaffolding,Clean out brine tank and load out,Rig down circulating pump, 13:30 16:00 2.5 Nipple down BOPe,Rig down accumulator,Rig down choke,Rig down hard line and diverter tank. 16:00 17:00 1.0 Pump brine out of casing. 17:00 17:30 0.5 Re-excavate around casing. 17:30 18:30 1.0 Cut off riser pipe and BOP flange. L TOTAL HRS PERSONNEL EQUIPMENT WASTE MANAGEMENT PERSONEL ON BOARD 6 EQUIPMENT PROVIDER EQUIPMENT TYPE QUANTITY WASTE TYPE UNIT COMPANY NO.PEOPLE Solsten j 6 www.wellez.net WellEz Information Management LLC ver 041816bf • ! PAGE NUMBER: SOLSTEN;f Workover REPORT RPT DATE:03/27/2016 P RPT NUM.:5 OPERATOR:BLM ELEVATION: PTD#:100-1900 WELL NAME:Simpson Core Test#30 CONTRACTOR:Marsh Creek WD#: FIELD:NPR-A RIG: AFE#: LEASE:,NPR-A RKB' API#: 50-279-10028-00-00 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:'' PHONE: TIME BREAKDOWN FROM TO HRS PHASE TASK ACTIVITY OPERATIONS 06:30 07:00 0.5 Safety meeting-Working around open excavation,Mixing cement. 07:00 14:00 7.0 Mix cement,Fill casing with 1/2 bbl 13.2 ppg cement,Take samples,Let cure for 6 hrs. 14:00 18:30 4.5 Weld marker plate on well,Back fill well. TOTAL HRS PERSONNELEQUIPMENT 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 • • forp SOLSTEN1 . P JARSHCREEK NPRA-LEGACY WELL REMEDIATION Simpson Core Test 30 f)(I) /6(- '' 110 Single Well Program Well Abandonment Procedure Date Issued: Wednesday, March 23, 2016 "-to Anticipated Date: Wednesday, March 23, 2016 E.4.4—c_ 010c Expected Rig Name: Excavator SCANNED APR 0 .54 '2 �/ Prepared By/Date 8 ZQ�Q � ---/& Lucas Lucas Munisteri Drilling Engineer Agreed BY/Date Jesse Mohrbacher Manager Approved By/Date Rob Brumbaugh Bureau of Land Management • • SIMPSON CORE TEST 30 - WELL 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: 3/23/2016 M: Jesse Mohrbacher Anticipated Date: 3/23/2016 BLM: Rob Brumbaugh Page 11 • • Overview Simpson Core Test 30 -Well 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 indicates that 8 5/8 inch casing was set as the sole casing string at a depth of 102 feet. The reported rig kelly bushing (RKB)height is 5 feet above ground level(AGL). • The Legacy Wells Summary Report indicates that in 2006 the 8 5/8 inch casing was plugged with 52 feet of cement to surface. • A small diameter drill string was stuck and subsequently abandoned in the well. Top of fish is unknown. • There is no wellhead. • Have equipment and materials on standby to top off casing with cement if there is void space encountered when the casing is cut off. If ice is encountered BLM to confirm if thawing of any ice at the surface is required. • The well is located in an active seep area. Use caution to contain any mobile oil encountered during excavation. REQUIRED EQUIPMENT 1) Rig d) Choke Manifold a) Excavator i) 5 x 2" 10 Ksi valves 2) Well Control Equipment ii) 2 x manual chokes a) BOP e) Accumulator i) 7-1/16 5 Ksi Shaffer Annular i) 4/5 Station Accumulator ii) 7-1/16 5 Ksi Cameron Type U Double ii) Remote Panel Gate 3) Circulating Equipment (1) 2-3/8"—3-1/2"VBR a) 10 Ksi triplex cement pump (2) Blind Shear 4) Cementing b) Kill Line a) Batch Mixer i) 2-1/16"5 Ksi Check Valve i) 2 x 35 bbl batch mixer ii) 2-1/16"5 Ksi Manual Gate valve ii) 10 Ksi triplex pump c) Choke Line 5) Storage Tanks i) 2-1/16"5 Ksi Manual Gate Valve a) 2 x ISO Tanks, =6,600 gal ii) 2-1/16"5 Ksi Manual Gate Valve i) Steam lines iii) Connected to choke with 1502 Hard b) Open Top Tank Line Date Issued: 3/23/2016 DE: Lucas M unisteri Anticipated Date: 3/23/2016 M: Jesse Mohrbacher 2 I P a g e BLM: Rob Brumbaugh • • ABANDONMENT PROCEDURE Upon cutting this well off five feet below the ground level competent cement was not identified at or near surface and this will require additional work to remediate. 1. Weld fishing extension to the stuck assembly.The fishing extension is not to extended into the BOP and needs to be Box up. 2. Weld cut casing back on to the well along with a flange to connect the BOP to the well. 3. Back fill the excavation and create a stable, level work surface. 4. Move in required equipment, cement mixer, heaters, boiler, circulating tanks, piping,generators, scaffolding,tarps, and other wellsite equipment. 5. Nipple up the BOP to the 8 5/8 inch casing and direct returns to open top barrel. TEST BOP PER FEDERAL ONSHORE ORDER # 2 Max Anticipated Surface Pressure=324 psi. In 2006 the well was reported to be incapable of flow due to an ice plug in the well. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine(9.6 ppg NaCI Cloud point-7°F). 3. Pressure test the BOP per the attached BOP Testing procedure. a. The BOP will be tested against open hole,if there is no integrity to the ice plug/cement in the well. Due to the lack of a test profile there is no way to isolate the open hole.A pressure drop of more than 10%,50 psi may be experienced.Test will be deemed successful if there are no surface leaks or fluid broaching to the surface. ABANDONMENT PROCEDURE CONTINUED 6. Run 1 inch tubing in the well and circulate warm brine to melt frozen fluids to a depth of 147 feet BGL(152 feet RKB) or until refusal in both the annulus between the casing and the drill pipe and in the drill pipe. 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. Note:If possible during thawing of the annulus,pull and remove the stuck drilling assembly. 7. Circulate warm brine until the returns are consistent and the casing is clean. 8. Mix a sufficient volume of Arctic set cement to fill the wellbore from thaw depth to ground level. 9. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 10. Place the samples in a safe place to cure where the storage temperature will be about 35°F. 11. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank.Take a sample of the returns every 5 bbls, weight the sample in the mud balance and set sample aside. 12. Pull work string out of hole slowly at first to prevent damaging the cement plug. 13. Top off if required. 14. Wait on cement from minimum 6 hours and verify that the plug has not fallen downhole. DE: Lucas Munisteri Date Issued: 3/23/2016 M: Jesse Mohrbacher Anticipated Date: 3/23/2016 BLM: Rob Brumbaugh ccs 13 • Simpson Core Test 30-Well Abandonment Prdure 15. Re-excavate around the well to a minimum depth of 6 feet. 16. Re-cut 8 5/8 inch casing 5 feet below ground surface. 17. Top off the 8 5/8 inch casing if the plug has fallen. 18. Weld a marker plate that meets current regulations on the casing. a. Leave a small weep hole in the weld of the flange. b. Weld the Section,Township and Range to the side of the casing. 19. Backfill the excavated hole and mound the excavation with gravel or tundra organics to account for settling. 20. Return to the site the following summer for stick pick operations. Date Issued: 3/23/2016 DE: Lucas Munisteri Anticipated Date: 3/23/2016 M: Jesse Mohrbacher 4 I P a g e BLM: Rob Brumbaugh • • COMPANY LEASE& WELL NAME TEST DATE Accumulator Function Test 1) Start with the work string placed in the well above the blind shear rams 2) Place All Functioning Accumulator Valves In Open Position Allow Accumulator To Pressure Up Before Shutting Off All Of The Pumps 3) Close Annular& Record Time and Pressure Annular Initial Pressure Final Pressure Time 4) Close Pipe Rams & Record Time and Pressure Top Pipe Rams Initial Pressure Final Pressure Time 5) Close the Blind/Shear Rams & Record Time And Pressure Simulated Blind Initial Pressure Final Pressure Time 6) Close HCR (If Applicable) & Record Time And Pressure HCR Initial Pressure Final Pressure Time 7) On Three Ram Stack Close Bottom Pipe Rams & Record Time and Pressure Bottom Pipe Rams Initial Pressure Final Pressure Time When Done With the Recorded Times and Pressures There Should Be At Least 200 psi Over the Precharge Pressure in the Accumulator (1200 psi) Nitrogen Bottles - Bleed Off Test 1) Finish Bleeding Off Bottles Into Accumulator Tank/Reservoir. 2) Watch and Record Where Pressure Drops (Accumulator psi) Pressure Drop psi The Accumulator Pressure Should Drop At 1100 psi to 900 psi 2 Minute Time Test - Accumulator Pumps 1) Shut Valves to Nitrogen Bottles 2) Place HCR in Open Position (If Applicable) 3) Place Annular in the Closed Position 4) Turn On Pumps And Record Time To Pressure Up Manifold On Accumulator to At Least 200 psi Over Precharge. Within 2 Min or Less Record Time Minutes Seconds 5) Open Valve to Nitrogen Bottles And Pressure The Accumulator Back to Shut Off Point. Then Open All Pipe Rams And Annular Before Pulling Plug And Drill Pipe Out Of BOP. BOP Test Procedure • • COMPANY LEASE& WELL NAME TEST DATE Test# Time Systems Being Tested 1 Choke Manifold Valves(Offline) 5minpsi& 10 min @ 500 psi 2 IBOP(Offline) 5 min @ 50 psi&10 min @ 500 psi. 2 Annular 5 min @ 50 psi& 10 min @ 500 psi. 3 Pipe Rams 5min 50nsig 10 min P500osi 4 Pipe Rams, inner choke line and kill valves, BOP Connection, Casing Weld 5 min @ 50 psi& 30 min @ 500 psi Max pressure drop 50 psi 5 Pipe Rams, outer choke line valve, kill line check valve 5 min @ 50 psi&30 min @ 500 psi. Max pressure . p 50 psi 6 Blind/Shear Rams, Hard line 5 min @ 50 psi&30 @ 500 psi. Max pressure drop 50 psi Test time(hrs.) Pick up assembly 1) Connect pumps to the choke manifold and close the valves and test the manifold valves 2) Open the inner valves and drain the manifold. 3) Connect the TIW valve the test stump and test TIW. 8) Fill Stack 4) Close Blind/Shear rams 5) Run test joint into BOP 6) Close annular and pressure test annular 7) Close pipe rams and test 8) Open Blind /Shear Rams, Close inner valves on Choke and Kill lines 9) Pressure test stack 10) Open inner valves on choke and kill lines and close outer choke line valve 11) Pressure test stack 12) Close the Blind /Shear rams and pressure test them from the lower side. Comments: BOP Test Procedure • • g \�\71//77.4:,t.� THE STATE Alaska Oil and Gas • t •, o LAsKA. Conservation Commission fAr i_ _5. 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Lucas Munisteri Drilling Engineer , Bureau of Land Management 222 West 7th Avenue, Ste. 13 Anchorage,AK 99513 Re: NPRA Field,Exploratory Pool, Simpson Core Test 30 Permit to Drill Number: 100-190 Sundry Number: 316-140 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, Cathy P oerster Chair DATED this ( y of March, 2016. RBDMS u" MAR 1 1 2016 i i RECEIVED 'o16 STATE OF ALASKA07-Lp/l� A ALASKA OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVALS u'k.A., 20 AAC 25.280 1.Type of Request: Abandon Il Plug Perforations L] Fracture Stimulate D. 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 0 Development ❑ 100-1900 3.Address: Stratigraphic CDService FT 6.API Number 222 West 7th Avenue,#13 Anchorage,AK 99513 50-279-10028-00-00 . 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Simpson Core Test No. 30 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10. Field/Pool(s): F.E. iuNkA- NPRA &-ywAOr-TA 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVDsf Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): v1-S t, fib,• Casing Length Size MD TVD Burst Collapse Structural Conductor 145 8.625 28# 150 150 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 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory [] Stratigraphic❑ Development❑ Service ❑ 14. Estimated Date for 3/12/2016 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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 Signature Phone 907-264-6114 FEB 182015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ---- Sundry Number: 3i c40, pyo Plug Integrity BOP Test❑ Mechanical Integrity Test ❑ Location Clearance for -5" kr,".'-L e-06) Other: X PAC t2 d t,GGc- e Ccc 'h� C.4.+-- etig t ,/t.id,.L / `t t4 AI c r n - p 1:4-4-). /p jwc_e,-,ur- p p► c es fl ,c. z 0 4.4c Z_ s'. l/Z(--:-) Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No I-jd Subsequent Form Required: /6-- `-/t; /- RBDMS U`-- 2016 MAR 1 1 f APPROVED BY MAR LU U Approved by: " COMMISSIONER THE COMMISSION Date: 3-/0_ , • as lc. At 2-6.4 4 QLflGINAL % 3-to-_( Form 10-403 Revised 11/2015 Approved application is valid 1 months from the dateappro al. Attachments in Duplicate Form 3160-5 UNITED STATES FORM APPROVED (April 2004) DEPARTMENT OF THE INTERIOR Expire:Mlarch31,2007 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 (A PD) 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. Oil Welk ❑Gas Well ❑Other 8. Well Name and Na 2.Name of Operator Simpson Core Test 30 Bureau of Land Management 9. API Well No. 3a Address 3b. Phone No.(include area code) 50-279-10028-00-00 222 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:70.9308 N Sec.11,T.18N,R.11W,M.Umiat 11. County or Parish, State Long:154.6764 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 ❑✓ Notice of Intent ❑Alter Casing ❑Fracture Treat ❑Reclamation I Well Integrity ❑Subsequent Report ❑Casing Repair ❑New Construction ❑Recomplete ❑Other ❑Change Plans ✓❑Plug and Abandon ❑Temporarily Abandon El Final Abandonment Notice ❑Convert to Injection ❑Plug Back El 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. N See attached document: c. —r1 . r- rr7 r C (c) t3 >'t r'r1 Cv, I) til 41- CD 14. I hereby certify that the foregoing is true and correct Name(Printed/Typed) Lucas Munisteri Title Drilling Engineer Signature Date FEB 1 7 7016 THIS SPACE FOR FEDERAL OR STATE OFFICE USE Approved by_ 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) ` • • tD4444%\ -.--)116/111111111.111: SOLSTEWp MARSHCREEK NPRA-LEGACY WELL REMEDIATION Simpson Core Test 30 Single Well Program Wellhead Cutoff Procedure Date Issued: Wednesday, February 17, 2016 Anticipated Date: Thursday, February 25, 2016 Expected Rig Name: None Prepared By/Date Lucas Munisteri1 ' 2016 Drilling Engineer FEBD Agreed BY/Date Jesse Mohrbacher Manager Approved By/Date Rob Brumbaugh Bureau of Land Management , • SIMPSON CORE TEST 30 - WELLHEAD CUTOFF 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 i S Overview Simpson Core Test 30-Wellhead Cutoff 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 indicates that 8 5/8"casing was set as the sole casing string at a depth of 102 feet. The reported rig kelly bushing(RKB)height is 5feet above ground level (AGL). • The Legacy Wells Summary Report indicates that in 2006 the 8 5/8"casing was plugged with 52 feet of cement to surface. • A small diameter drill string was stuck and subsequently abandoned in the well. Top of fish is unknown. • There is no wellhead. • Have equipment and materials on standby to top off casing with cement if there is void space encountered when the casing is cut off. If ice is encountered BLM to confirm if thawing of any ice at the surface is required. • The well is located in an active seep area. Use caution to contain any mobile oil encountered during excavation. REQUIRED EQUIPMENT 1) Rig a) Not Required 2) Well Control Equipment a) Not Required 3) Circulating Equipment a) Not Required 4) Cementing a) Construction cement mixer 5) Storage Tanks a) Not Required Date Issued:2/17/2016 DE: Lucas Munisteri Anticipated Date: 2/25/2016 M: Jesse Mohrbacher 2 Page BLM: Rob Brumbaugh • , • ABANDONMENT PROCEDURE 1. Identify surface location of the well and check the area for potential gas. Confirm that there is no pressure under the ball valve. 2. Remove any debris from the immediate area of the 8 5/8"casing and carefully excavate to 6 feet 3. Move in required equipment as required to cut casing at 5 feet BGL. 4. Cut 8 5/8" casing 5 feet below ground surface. 5. If void space is found at surface notify BLM,AOGCC, and SolstenXP and prepare to fill the casing to the cutoff with arctic-set cement. If ice is encountered at the surface and BLM desires thawing to TOC, prepare for thawing and circulating operations. Either scenario may constitute a change of conditions depending upon the amount of remedial action required. . ZG 6. Weld a marker plate that meets current regulations on the casing. pe-e Z`'A' 7. Backfill the excavated hole and mound the excavation with gravel or tundra organics to account for settling. 8. Remove any remaining wood piling and debris from the surface of the location and proceed with disposal of waste materials from the site. 9. Return to the site the following summer for stick pick operations. DE: Lucas Munisteri Date Issued:2/17/2016 M: Jesse Mohrbacher Anticipated Date:2/25/2016 BLM: Rob Brumbaugh Page 13 Lit, RKB� CEMENT - 152' HEIGHT Y I— - 63 SKS CAL-SEAL GROUND-)1111/".....‘") LEVEL 1 FISH 60' MD / TVD MARS HCRE EK v v°° CEMENT - 103' HEIGHT 12.5" HOLE '\ 152' MD / TVD - 12 SKS ARCTIC SET 152' MD/TVD VVVVVVVV 150' MD / TVD vvvvvvvv vvvvvvvv vvvvvvvv v v v vy v v v DRILLING FLUID 8.625" 28# CASING v v v v v v v v 'vvvvvv — 9.0 PPG 150' MD/TVD "VVVVVV 7VVVVV VVVVVV VVVVVV VVVVVV Vvvv •i i 388' MD / TVD v v v id vvv • vvvv v ' • vvvv V •vvvvvvvr• CORE BARREL ABANDONED DOWN vvvv HOLE AFTER UNSUCCESSFUL 6.125" HOLE • v v v• FISHING AND SIDE TRACKING vovv 565' MD/TVD v v v ATTEMPTS vVV • 565' MD / TVD v - v vv v • • v vvv • v • • v v V v vvv 5.875" HOLE v v c 693' MD/TVD - 693' MD / TVD LEGEND I-I C• EMENT 11 DRILLING FLUID n D• IESEL F-1 BRINE F-1 W• ATER I-7 PRODUCED FLUID 0 FILL I—I OTHER LAT: 70.9308 N LONG: 154.6764 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST#,###,### US FT NORTH: ###,### US FT ZONE: AAA## SIMPSON CORE TEST # 30 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10028-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1900 30 Nov 1950 23 JAN 1951 21 APR 2006 OIL PRODUCER DATE: BY: COMMENTS: CURRENT WELLBORE CONFIGURATION 15 FEB 2016 LUCAS MUNISTERI S LSTE Nf"I— REVISION: SCALE: RELATIVE VERTICAL 1 RELATIVE HORIZONTAL • • • • RKB - CEMENT - 152' HEIGHT Y - 63 SKS CAL-SEAL fit.'. I ■ GROUND LEVEL FISH 60' MD / TVD MARS I-I CREEK ° VV° vvvvvvc e• �PTY CEMENT- 103' HEIGHT v v v c111\ - 12 SKS ARCTIC SET 12.5" HOLE > 7 v v v�: 152' MD / TVD 152' MD/TVD T v V V vw 150' MD / TVD vvvv vv 'vvvvv vvv v vy v vv vv: DRILLING FLUID 8.625" 28# CASING VVVVVVVV vvvvvvvv - 9.0 PPG 150' MD/TVD VV VVVVV • VVVVVVVV VVVVVVVV ✓VVVVVVV vvvvvvvv :vvvvv 388' MD / TVD vvvvvc- vvvvv , vvvvv v � v V V V V • V V V V • ' CORE BARREL ABANDONED DOWN vvvvv v vvvv v T HOLE AFTER UNSUCCESSFUL 6.125" HOLE vvvv • ' FISHING AND SIDE TRACKING 565' MD/TVD • o c ATTEMPTS 565' MD / TVD V P •V V 5.875" HOLE 693' MD/TVD 693' MD / TVD LEGEND I—I C• EMENT I-I DRILLING FLUID r7 D• IESEL n BRINE n W• ATER n PRODUCED FLUID FILL n O• THER LAT: 70.9308 N LONG: 154.6764 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST#,###,### US FT NORTH: ###,### US FT ZONE: AAA## SIMPSON CORE TEST # 30 SECTION: II TOWNSHIP: 18 N RANGE: II W MERIDIAN: UMIAT FEL: #,### FT FNL: #,### FT ELEV: 20.0 FT RKB: 5.0 FT API # 50-279-10028-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-1900 30 Nov 1950 23 JAN 1951 21 APR 2006 OIL PRODUCERDATE: By: a / COMMENTS: PROPOSED FINAL ABANDONMENT 15 FEB 2016 LUCAS MUNISTERI S O L ST E N , REVISION: SCALE: RELATIVE VERTICAL I RELATIVE HORIZONTAL r • — J Y z i-I Q Y_ ^ U � co V rNNN _ . O O NC))0C,) W r W ****44t* � .. 0 m F-F- F-F-H H F-H F- H - a - :1 N Cl) x wwwwwwwwwww F3 :. 1:- 1.-- F-HF-H HHRH 1-- p k - w W W W W W W W W 1*w w " "CC CC " " N.ii JJ'=i'� 000000000CC CC CC CC CC CC 00 cc<°m :�PatilmAiii. m --,....a..4...� l' zzzzzzzzzzza3, o W 00000000000 OD a I .1 — w aaaaaaaaaaa0) :�CC ; CnCn�CnNfA(nCnN�cn m ii1ijom. •ii�n!�1�� OT";,;:)/ Cie h1- .. ij Q ci Y 2 0 , I W ..mo lf1 cf)H < ''>z �F- Z Cn W m�Q c� ON Q1,CC 215 u J'o 00 ra _ ,0 00 z r Li j Eo LL CV n� O m N 0 O z ❑Nw 0-...„ a ANN 0- H 0 5 ¢ - m 0 u_ o w 3 _ < N o — o o � JI- C7 W W .0_(7) z 0 0 > 0 o V U N 2 til 2 Lu 0 vQ N Q J m Z O J O o f O H Q m 0 (n 0 c W O J L d 0= U J 0< O co - 0¢ . m Z z CD CD w= 0 a „1.��a ®I N N .- 4:7 O i 7 __ �1 16., I 3 Lu = = w Q 0 • • 0 Y O O — ■ U 1 — 0 LL = z T rn %II!ct.mom 0 < ■ H Z Y W z l I (..:2 (-5 N H a cc 0 o O D Z 2 CC p 13 (r O N W W N I-z � 2cc > m00 W \\//// a = CC 0 HHD _ D U) O HLLZZ W Z 00g � 6. m O a C 7 w¢ 0 mN O >w N z O cc CC C H 7 cn �``-- - - • M • 716 5 ori-4° EXPLORATION OF NAVAL PETRO\EUM RESERVE NO. 4, ALASKA, 1944-58 After the casing was set at 350 feet, the side of the ho in preventing the well and meters from freezing. After was scratched from the bottom of the casing to 550 the well began to flow,the shut-in wellhead pressure was feet. The hole was bailed to 550 feet. The results 60 psi and dropped to 0 psi when flowing. No actual of a 4-hour test showed that the well was producing gage was made on this well because it froze up and shut 5 gallons of water and a trace of oil per hour. The off the flow before gaging facilities could be installed. casing was perforated with 144 shots from 289 to 325 An Amerada bomb was stopped at only 5 feet below the feet. The well flowed oil through 210 feet of 23(2-inch casing head. If this well had been cased as was Simp- line pipe at an average rate of 110 barrels of oil per day, gravity 20°API, oil temperature 21°F, and casing son core test 26,it would probably be capable of produc- pressure 47 psi. The well was shut in. ing 120-125 barrels per day. The oil from this well On a 13-day test made 5 months (end of ,March tested 21° API, and no water was indicated. 1951) after the completion of drilling, the well pro- duced at an average rate of 92 barrels of oil and 2,500 GAS AND OIL ANALYSES 3,000 cu ft of gas per day. The bottom-hole pressure The following results were obtained in analyses made ranged from 195 to 215 psi, and the well-head pressure by the National Bureau of Standards from a gas sample was about 25 psi. The oil temperature was 14°-17°F taken at a 395-400 foot depth in Simpson core test 14: and the bottom-hole temperature 13.7°F. Percent 4 The following is a summary of another production E hane a 90.07 test made at the beginning of May 1951: Propane 0.02 Nitrogen 1. 40 Type of flow slug Carbon dioxide 0. 10 Time of flow 116 hours Total production 597 bbls per day' Total 99.99 Maximum rate of production 176 bbls per day Mean rate of production _ 120 bbls per day Weight of crude 21.6° API at 60°F Three samples of crude oil from Simpson core test 26 Formation pressure (static) 250 psig Formation pressure (flowing) 155 psig were tested (table 11). Temperature of crude 14°F Basal sediment and water negligible TABLE 11.-Crude-oil analyses from.Simpson core test 58 1 48-gallon barrels. [Analyses by U.S.Bur.Mines,Bartlesville,Okla.] The we I was again shut in. Depth(feet) 300 300-306 289-325 Simpson core test 27.-When the hole was at a depth of 380 feet, it was bailed to the bottom and was bailed Date sp avvipy�(in degrees) Aug.19,11995000 Aug.19,1951.0 Oct.26,1950 every 3 hours for 24 hours. Oil was recovered at the a yhoit vi Coll: at 100°F1,020 iso <5 Color Greenish black Brownish green Brownish green rate of 3 barrels per day. Sulfur(percent) .41 .40 .36 Gasoline and naphtha .0 .0 .o Simpson core test 30.-When the hole was at a depth Kerosene distillate .0 .0 .0 Gas oll .5 19.2 16.9 of 350 feet, it was bailed dry and a 48-hour production Lubricating distillate 39.6 35.6 37.7 test was run. The hole produced oil at the rate of Residuum 43'6 9 44.7 about 6 barrels per day with a very small amount of gas. A more detailed analysis of a crude sample from Simpson core test 30A.-When the hole was at a Simpson core test 31 at 354 feet made by the U.S. depth of 350 feet, it was bailed dry and a 24-hour pro- Bureau of Mines is given in table 12. duction test was run. Oil was bailed at the rate of 5 Simpson crude is less desirable than that found at barrels per day. When the hole was at a depth of 423 Umiat (Collins, 1958) because it has a somewhat higher feet, gas blew up to the top of the derrick but decreased sulfur content and an API gravity of only 19.5°-21°., considerably thereafter. When the hole was at a total The viscosity is so high (480-1,020 sec. Saybolt at depth of 701 feet, it was bailed to 365 feet, where the 100°F.) that it would require special treatment to bailer stopped on an ice bridge. After reaming out, ship through a pipeline. The pour point is less than the hole was bailed to 701 feet. No oil came in and plus 5°F, as there is no gasoline-naphtha content and only a slight amount of gas. very little gas oil; it contains a fair quantity of good Simpson core test 31.-While coring at 355 feet, the lubrication stock. well began to flow oil. On a 65-hour test the well The sample contained no gasoline. Inspection data flowed an estimated 120-125 barrels of oil and 2,000- on a 629°F diesel fuel prepared from the crude oil by 4,000 cu ft of gas per day. There was some difficulty the Bureau of Mines are tabulated in table 13. ~ Explanation Pag ~ 100-190,%" Pe~m~N~mee~ ~u~~~~~~~~~h~~~~~~~~~~H 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. -rte ~~ ~- :~ -t~.A ~~,,~ P~ ~ -tom ~-~- R~WRys 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 oF 41,1'',1'\ 1//7.'<s, THE STATE r:::a,a,:r Eat (If Env'zcni."i" er d: STATE b., F ^u�� of 7 y Conservation = - Division of Spill Prevention and Response • sllli= J" ? r;g GOVERNOR SEAN P A R N E L L Contaminated Sites Program N ,P 610 University Ave. .41/3.6 Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Wayne Svejnoha wale) APR 2 g 201+ Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 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 utilise 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. 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, ,0400, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director,Bureau of Land Management Steven Cohn, Deputy State Director for Resources,Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G:\SPAR\CS\Federal Facilities\Civilian Federal Agencies\DOI\BLM\Projects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx c C 2 V -J m A.•«O m 't m N ; 0 a) h a m a ° m Y - a Cl.) 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Q a 3 a U) a) W c0 > c C C C C C C C C) Z QQ Z Z Z Z Z Z Z Eg Z Y y_ M r N, �-' 2 0 C C C C C C C C C C CO a z Z Z Z z Z z Z Z Z rn 0 0 0 0 0 co co co co co 13 U) U) U) 0) U) O. a a 0. a /6 0 0 0 00 J CO CO U) CO CO a 2 L L L L L co 2 2 O O O O O 2 o] m -J Z Z Z Z Z J « m > CO `$i CO cr) Z 0 LLQ Z 2 2 2 Z 0 O co U ) CO CO CO CO CO CO CO CO D > > D D D D D 4- M K _ ) 0) 0 CD . * 4* * 4* a3 3 E C L 0 t 0 0 t h It Z DO. a) 0 m m m m m m a 3 ~ .0 L L .0 .0 .0 03 a) d N 0 0 0 0 0 0 f0 W - U) to COOU) U) U) • • Well Ranking .,.-1.1~'~;; ",9Q t" `~ ~~~~h Before identifying the risks associated with the legacy wells, the BLM reviewed the list of wells to determine ownership and well status. 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 1 ~ ~~ • • 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 LAMA (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 Unuat 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. Army 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 drill hole penetrated several known oil and gas formations; Ninuluk, Chandler, Grandstand and Topagoruk. Hydrocarbon shows were prevalent within both the Grandstand and the Topagoiuk formations. Multiple sands were perforated and tested. Production exceeded 217 barrels per day, thus seemingly showing the benefit of using an oil-based mud. However, the muds did not allow the different formations to be distinguished. Cement was used in an attempt to "plug back" and isolate individual formations. Samples were taken and sent to a Bureau of Mines lab where the chemical tracer (used during drilling) was measured and the various sandstone samples were examined. This allowed a study of the different lithologies be conducted. The tracer Aroclor used in the well has raised concerns about PCB contamination. However, the well was allowed to flow for seven weeks at 200 barrels per day (Robinson and Bergquist, 1956) prior to shutting it in, possibly purging the potential contaminants. As it stands today, insufficient energy exists in the reservoir for the well to flow to surface and the wellhead has no pressure on it. The well is located within the Northeast planning boundary (see Map 2) on lease AA- 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 Figure 12: Aerial view of Umiat #9. • • 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 fi-oin 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 Z) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. The well lies about 500 feet to the northwest of a gravel spur road which connects the Colville River to the eastern edge of the Umiat airstrip. The well is located in wet tundra adjacent to an empty 55-gallon drum. The well is left open with 8 5/8-inch casing to the surface. It has no gauges, valves or a cover plate. Two thermistor protrude to the surface and rests on the lip of the casing. This well poses no threat to human health or the environment unless development occurs. Umiat #7 Umiat #7 was drilled in 1951 to a depth of 1,384 feet, cased to 1,196 feet } and completed as a dry ', hole. It was the southern 1 most well drilled on the Umiat anticline. The s 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 threat 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 Umiat Work Umiat has been a site of recent cleanup projects. The cleanup process began in 1994 with the removal of about 1,000 drums, some containing petroleum and transformer oil with PCBs, from the main gravel pad. Another 200 cubic yards of PCB-contaminated soil was removed in 1998 along with 60 cubic yards of lead-contaminated soils. In 2001, 50 cubic yards of PCB soil was excavated with an additional 10 cubic yards removed the following year by the Corps of Engineers (U.S. COE, 2003). J.W. Dalton #1 J.W. Dalton #1 was drilled in 1979 to a depth of 9,367 feet. It is cased down to 8,898 feet and plugged back to 1,530 feet. (Husky Oil NPR Operations for U.S. Geological Survey-J.W. Dalton, 1982). The primary objective of the well was to determine if hydrocarbons were present within the Sadlerochit and Lisburne Groups. Gas shows were encountered in trace amounts in the Ivishak Formation, and the Lisburne and Endicott Group. Poor to good oil shows were discovered in the Ivishak Formation and in the Lisburne Group. A drillstem test of the Lisburne Group recovered 22 barrels of oily water (Gyrc, 1988). This well has been a USGS monitor well since its completion in 1979. Approximately 230 barrels of diesel fuel were placed downhole to act as a neutral medium for collecting wellbore temperatures. In the summer of 2004, warmer temperatures, wind, and wave action eroded 200 feet of the coastline adjacent to the well (Figures 14, 15). This erosion placed the J.W. Dalton #1 well and reserve pit precariously close t `~ . ~~ w. 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. facility. 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 current condition, the well does not pose a threat to humans or the environment, but if the casing were to break in its exposed condition, the diesel fuel would, over time, leak into the ocean. The release of heavy metals from the reserve pit may pose an immediate risk to human health and the environment. The pit was sampled October 26, 2004, and results are pending. 27 Figure 16: J.W. Dalton with exposed conductor (left), and rat hole (right). The mouse hole (not pictured) is completely exposed. i ~ 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 fmdings 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 pipe, and four bacteria. wing valves and will likely flow oil if 28 ~ i 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. 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 sunmier 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 hams 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 chilled 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 cLUrent 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 N'igure 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 baiTels 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/~-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 cuiTent 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 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 threat 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. cormnon drilling fluid component. Through sampling, the COE determined the barium has not migrated down the hill and poses no danger to the Seabee Creek drainage (Ecology and Environment, 1999). There is no 33 Figure 24: Simpson Core #29 • indication of stressed vegetation down-gradient from the drill muds. Additionally, solid waste in the foam of steel framing and scrap metal are near the wellhead. The solid wastes pose no threat but are unsightly. Umiat #11 Umiat #11 was spud June 1952 and completed two months later. The well reached a total depth of 3,303 feet with 486 feet cased. One cement plug was placed at 440 feet. The objective was to test production possibilities of the Grandstand Formation on a fault that parallels the Umiat anticline. The well encountered residual hydrocarbons in the Seabee, Ninuluk, and Grandstand Formations but no oil or gas was recovered during production tests. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are over one mile to the south. The well is located within the Northeast planning boundary (see Map 2). The tract is located on lease AA-084141 but there is little possibility of the well interfering with future development due to its location outside the Umiat structure. The well was drilled in the alluvial plain of Bearpaw Creek, 0.6 miles from Umiat #8. A drilling pad was never created as operations consisted of mounting the drill rig on a sled and then placing it on top of large timbers that were secured to pilings (Robinson and Bergquist, 1956). A pile of unvegetated 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 cui7•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 diy 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 primary 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 enviromnent. A total of 103 barrels of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The well poses no tlueat to surface or sub-surface resources and has no potential to adversely affect future development. The drill pad is shared with Wolf Creek #l. 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. Current condition of the wellhead is that it has no pressure at surface and consists of two wing valves and a master valve. The well is located within the Northeast planning area (see Map 2) on lease AA-081857 where, in 2004, ConocoPhillips Alaska Inc. drilled an exploratory well within seven miles. The target of the exploration is in the Upper Jurassic at depth of approximately 8,000 feet and it is not likely that this unplugged well will adversely affect development in the area. The recent Alpine Satellites EIS approves oil and gas development in this area. ConocoPhillips has proposed roads and a drilling pad less than eight miles from this well and will likely be 36 • producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infi•asttucture is established. Surficially, there are still some solid wastes present. The drilling pad and cellar construction consists of concrete reinforced with steel matting. The concrete, matting, and pilings are still in place today, albeit heaved by permafrost (Figure 28). Several 55- gallon trash drums filled with debris are located off the concrete pad. Other light debris is also present within 500 feet of the pad. The oil seep is located about 1.5 miles to the southwest of the well site and is inactive. The USGS 305-I reports the dimension of the seep as being 6' x 20' (Florence and Brewer, 1964), however, BLM personnel located the seep in 2001 and noted its dimension to be 3' x 6'. Simpson Core Test #28 Simpson Core Test #28 was drilled in September 1950 to a total depth of 2,505 feet and cased to 110 feet. Despite the depth, the hole did not encounter any hydrocarbon shows. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. A drill pad does not exist, however a large area of disturbance is visible. The wellhead consists of open casing inside a wooden cellar. There is considerable solid waste near the well. These include: numerous metal pilings, drill pipe, large wood fragments (spool, plywood, timbers), and some partially crushed drums. The solid wastes are unsightly, but pose no threat to humans or the environment. Simpson Core Test #13 Simpson Core Test #13 was drilled in the summer of 1949. It was a relatively shallow test and did not generate any significant oil or gas shows. The well encountered residual hydrocarbons in the Seabee and Grandstand Formations at depths of 1,079 - 1,084 and 1,138 - 1,148 feet (Robinson and Brewer, 1964). No oil or gas was recovered during production tests. The well is over three miles north of the Simpson Core wells that penetrated productive Grandstand sands. Total depth of the well reached 1,438 feet. The top 26 feet are cased and the hole was filled with water-based drilling mud. Fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. 37 • A drilling pad does not exist. Seven-inch casing was cut off at ground level and is very difficult to locate. The well is open to the atmosphere. There is no solid waste, nor is there anything hazardous regarding this location. It should not be considered a risk to surface or sub-surface resources. Simpson Core Test #15 Simpson Core Test #15 was drilled in August 1949 near an active oil seep. The well was drilled to a total depth of 900 feet and cased to 18 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations (Robinson and Brewer, 1964). No oil or gas was recovered during well tests. Additionally, fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. There is no existing pad. The well was drilled about '/8 of a mile north of a natural seep. The well consists of open ended casing with a height of 18 inches (Figure 29). The area is clean with no solid waste. This well poses no risks to the environment or human activities. Simpson Core Test #14 Simpson Core Test #14 was drilled in 1949 to a depth of 290 feet. The records do not clearly state how much casing was run but the well was left with casing above ground open to the atmosphere. Its present day location lies within 1000 feet to the west of an active oil seep. The well was not drilled deep enough to encounter the hydrocarbon stained sands evident in the Simpson Core #14A well. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years. This shallow well did not penetrate any hydrocarbon bearing zones and poses no risk to surface or sub- surface resources, nor does it have the potential to adversely impact future development. 38 • Simpson Core Test #14A Simpson Core #14A was drilled in 1949 to a depth of 1,270 feet and casing was set to a depth of 32 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Foiniations. No oil or gas was recovered during tests (Robinson and Brewer, 1964) and fresh water aquifers are not present. Present day location of the well is approximately 1000 feet to the west of an active oil seep. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. East Simpson #2 East Simpson #2 was drilled in 1977 to 7,505 feet and cased to 6,427 feet. Five cement plugs were set, with the top of the shallowest plug set at 1,997 feet. The primary objective of the well was to test the Ivishak Sandstone where it onlaps the Pre-Devonian age basement rock (Husky O.il NPR Operations for U.S. Geological Survey, 1982). Small scale faulting was found between the wells in the area, possibly accounting for the thin section representing the Sadlerochit Formation. The well encountered very poor oil shows at 6,000 feet in the Torok Formation and Endicott age sandstones were cored with poor porosity and dead oil shows. The well is officially listed as a dry hole. Upon completion of the production tests, the well was plugged back to 1,997 feet and filled with approximately 280 barrels of diesel to facilitate permafrost temperature measurements. However with East Simpson #1 less than five miles away, the USGS has no plans to use this well for temperature monitoring. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this 39 • ~ well will have an adverse impact on development. If this exploration and development establishes infrastructure nearby, it would greatly facilitate plugging this well and significantly reduce costs. The wellhead consists of a casing head, side gate valve, a master gate valve, and a needle valve. The drilling pad is of the thin pad variety and is slowly being reclaimed by natural processes. Exposed pilings stick up a height of two feet from the surface, but no other objects needing removal are present (Figure 31). The cellar is a wooden 12' x 12' with standing water. With the existing plugs and the static condition of the well, there is no risk to surface or sub-surface resources. Kaolak #1 Kaolak #1 lies in the northwest portion of NPR-A and is considered one of the more remote well sites within the reserve. Kaolak #1 was drilled in 1951 to a depth of 6,952 feet and casing was set to 1,000 feet. Drilling served two purposes, to determine the presence of any reservoir characteristics, and to determine if oil or gas shows were r present in this remote ~"'~ ~ ~' ~~ °~' < < ~' portion of the reserve. The '` _ ~ ~" i _1 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 #i 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 problems 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 ~• ~ -~ ~~~ ~s at ground level and consists of an open flange bolted to the top of the casing (Figure 33). This differs from the Navy reports that indicate the wellhead was abandoned in place. There is no record as to why it was removed. A BLM field crew bailed the hole and discovered a swedge and 2-inch needle valve junked downhole. This site is very remote (30 miles south of Atgasuk) and since the gas zones are currently isolated below the cement plugs there is a limited risk of adverse impacts to surface or sub-surface resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 • Titaluk #1 was drilled in 1951 to a depth of 4,020 feet and is a dry hole. The well was drilled on the end of an anticline to test the oil and gas potential of formations within the Nanushuk Group. A few very poor oil and gas shows were encountered in the Grandstand and 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 drillstring was lost in the hole and fishing attempts were unsuccessful in recovering the lost drillstring. The drilling mud was bailed down to the top of the fish and the remainder of the well was filled with diesel to 54 feet to prevent the wellbore from freezing and facilitate downhole temperature measurements. It is plausible that the casing could corrode and the diesel fuel could seep into the sub-surface strata, but since there are no fresh water zones in the well it is not considered a risk that would adversely impact sub-surface resources (Collins and Brewer, 1961). The well is located within the Northeast planning area (see Map 2). The well lies adjacent to a recently leased tract that received a high bid of $10.77 per acre during the 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 r 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 Ouinalik Anticline and drilled with the intent of revealing the oil, gas, and water content of the penetrated stratigraphy. Two cement plugs were set, the shallowest of which is inside the casing at 2,543 feet. Very poor oil and gas shows were reported in the Grandstand Formation, and poor gas shows were noted in both the Topagoruk and Oumalik Formations. Small undetermined volumes of gas were recovered during multiple production tests. It is believed that the gas encountered was large enough to furnish fuel to a camp but not large enough to become a commercial producer. The gas encountered during drilling showed high gas pressure, but the sandstones in which they were observed are thin with low porosity (Robinson and Bergquist, 1956). The gas zones are currently isolated by the cement plugs and pose no risk to sub-surface resources. The wellhead and a fabricated plate are below ground level. Two 2 '/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 i • 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 Atqasuk. 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 (Atqasuk) 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 diy 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 threat 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 pact, receiving a high bid of $50.00 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. • There is not a visible pad, but rather an area of disturbance. Disturbance stretches t/4 mile in an Figure 36: To a oruk #1 casin on its east-west direction and '18 of a mile in a north- side. When the asing 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 h•act. 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 cunent 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 dry 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 pa.d 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 109 feet. No hydrocarbon shows were reported during the drilling of this well as no sandstone was encountered (Robinson and Yuster, 1959). Upon completion, no plugs were set and the hole was filled back with muds. The well is located within the Northwest planning area (see Map 2) adjacent to a recently leased tract that received a high bid of $12.76 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. summer. Surficially, the area is wet with the wellhead partially submerged intermittently throughout the sununer (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 • • (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 backtilled with silt, with silt which resulted in consequently burying the casing head. the builal 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 vai7ous NPR-A activities. USGS Monitored Wells The USGS has used wells drilled in the NPR-A for collecting temperature data to better understand both the global temperature pattern and its effects on the permafrost. The wells that are currently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is anon-corrosive agent, and even if the casing should corrode there would be no impact to the surface resources and 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 tlu•eat 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 sununer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of Atgasuk. Awuna is the most remote well in the entire petroleum reserve. The well was drilled to a total depth of 11,200 feet. Drilling was conducted over two consecutive winters. Ice roads and an ice airstrip were constructed for logistical support. The project cost approximately $6 million (Husky Oil NPR Operations-Awuna, pg 5). Due to the orientation of the pad, the prevailing winds force wave action into the drilling pad, undermining the sands and silts which make up the pad. Below the sands and silts, Styrofoam was used to insulate the underlying permafrost. Wave action has eroded tens of feet into the drilling pad, exposing the Styrofoam, which consequently breaks loose and blows away. Wooden pilings exposed from erosion show how much attrition has taken place. Styrofoam can be seen all around the pad with pieces blown up to 5 miles away. Downhole, the well is in good shape with sufficient plugs. Diesel fuel fills the top 4,000 feet. The well is an USGS monitor well. Wellhead components are in working condition with no problems. 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 Figure 42: Awuna wellhead with exposed wooden pilings and up and erosion progress Styrofoam. should be monitored on an annual basis. It is also worth mentioning that the same type of scenario is unfolding at Tunalik #1 (another USGS well). Wave action from the reserve pit is beginning to 51 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 envu•onment. 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 l+'igure 43: Core samples from Simpson Core Test #25, an uncased core test, are stored in the Alaska Geologic Materials Center. w Plugged Wells Square Lake #1 C~ Square Lake #1 is a Navy well that was drilled to a depth of 3,984 feet. Its primary intent was to test the Cretaceous rocks in east-west trending anticline structure (305H pg 424}. No significant shows of oil were found. Gas shows were encountered in various sandstone beds between 1,600 and 1,900 feet, but otherwise the hole was dry. Upon completion, four plugs were reported to be set with the upper plug at 728 feet, well above the gas shows. Two other plugs were reported to be set in the gas zone, spanning depths of 1,640 - 1,840 and 1865 - 1934 feet. In addition to the six plugs, water and mud fill the remaining distance to the surface (Collins and Berquist, 1959). Upon successive visits to the site, BLM field crews dropped aplumb-bob down the hole and hit a solid obstruction between 8 and 10 feet. Don Meares, Northern Field Office, visited the site in August 2003 with an underwater camera and determined the solid surface to be cement. The Square Lake area is clean of debris with a few deadmen pilings (anchors) near the wellhead that could pose a ground hazard. The wellhead is open casing cut off at ground level. Umiat #2 and #5 The Umiat #2 and #5 wells were plugged and abandoned in 2002 by the COE (Figure 44). The wells were drilled on a common four-acre pad in 1947 and 1951. The purpose of the wells was to test for producing lithologies and determine petroleum quantities. Umiat #2 penetrated the Gubik Formation, Nanushuk Group (Chandler and Grandstand Formations), Topagoruk Formation and Oumalik Formation. Problems .with the drilling muds were encountered while drilling Umiat #2. Analysts determined that the fresh water drilling fluid caused formation damage and the Umiat #5 well was drilled adjacent to the #2 with acable-tool rig. The well produced 400 barrels per day with the most productive sandstones in the lower Chandler and upper Grandstand. Below a depth of 1075 feet, 107 barrels of crude oil from both Umiat and Simpson were used as a drilling fluid, as well as 11 barrels of diesel fuel (Robinson and Bergquist, 1956). In 2000, the Colville River threatened to erode both wellsites away. The COE took action under the FUDS program in the winter of 2001-2002 to plug, abandon and remove any surface features. The concrete lined cellar of Umiat #2 and wooden platform Figure 44: Plugging operations at Umiat #5. M from Umiat #5 were removed. Costs were approximately $25 million dollars due in part, to soil Approximately 30,000 tons of petroleum-contaminated soil was excavated. remediation. The soil was 53 transported on an ice road to the Umiat camp where it was thermally treated in a rotary kiln to remove petroleum residues. Small quantities of PCB contaminants were unexpectedly encountered after the excavation was completed. The source of the PCBs has been linked back to the #5 well and the fluids used downhole. The ever-shifting Colville River continues to erode the north bank and is approximately 50 feet from the old wellbores. With the removal of hazardous soils, this site should not be considered a threat to humans or the environment. Umiat #3 Umiat #3, also known as Umiat Core Test #l, was spudded in December 1946 and drilled to test some of the oil bearing zones encountered while drilling Umiat #1. The well was drilled on the northeast corner of Umiat Lake just below the hill from 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 ba.nels 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 site, however seeps are common in the area, including an active seep in Umiat Lake. An extensive piping system is still visible. The pipes probably supplied water during the drilling phase. They connect Umiat #3 to #4 which then follow the hill from Umiat #4 to 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 Formations. Oil was found in the upper and Iower 54 Figure 45: The view from Umiat #4 looking southwest toward Umiat Lake and Umiat. Umiat #3 is located on the near shore of Umiat Lake. sandstone of the Grandstand Formation. Drilling encountered good oil shows around 300 feet with a total 500 barrels produced (Robinson and Bergquist, 1956). The wellhead consists of 11 3/-inch casing protruding 36 inches above the ground surface. The casing is capped with a steel plate. Upon removal of the cover, the hole was open to the environment. No valves or gauges are present. The well was plugged by the BLM on May 9, 2004. The well poses no risk to humans or the environment. Umiat #8 Like the other wells drilled in the 1950s, Umiat #8 was drilled using cable tools. The well was spudded May 1951 and completed August 1951. It is located on top of a ridge that separates Umiat from the Bear Paw Creek valley. Drilling intention was to determine the quality and quantity of hydrocarbons in the Grandstand formation near the crest of the anticline structure. The hole encountered the Seabee, Ninuluk, Chandler, and Grandstand Forniations. The Grandstand Fornation produced approximately 60-100 ban•els per day of oil and more than 6 million cubic feet per day of gas. The well was shut in with a gas pressure of 275 pounds per square inch. The gas was analyzed by the Bureau of Mines and determined to be 97.3 per cent methane. Brine was mixed (35 lbs of salt per barrel of water) and used in the drilling fluid to prevent freeze up. Brine solution of approximately the same ratio of salt per barrel of water was used to kill the well and set the plug while cementing casing. A total of 21,695 pounds of salt were used in the well (Robinson and Bergquist, 1956). The well was plugged May 2, 2004. Prior to plugging, the well was nicknamed the "Whistling Well" due to the gas of which was escaping through fittings and valves in the wellhead. The wellhead is easily the most complex of the 11 Umiat test wells. It consists of five valves and multiple gauges. It has several homemade components and reaches a total height of ten feet. After reporting the seeping gas in 1996, two new valves and gauges were installed in 1997. The new gauges have been checked regularly since 1998 and have consistently read 250 psi. Despite replacing the two valves and gauges, gas continued to leak from the wellhead. The largest of the leaks occurred just above the top flange where a 4-inch nipple and collar are welded together. Other leaking occurred at the fittings of some of the gauges. The wellhead is sited on a gravel pad. A series of piping extends from the wellhead to a small stock tank about 100 feet to the south. The tank probably was used as a holding tank for the oil while testing the production potential of the hole. The sanie style of stock tank is present in various old photographs found in the Umiat area and may be the same 55 Figure 46: Umiat #4 prior to plugging. The wellhead is located in the center of the photograph. tank. Oil from inside the tank was sampled in 2004 with test results positively identifying PCB contamination which is slightly below the level of concern. Umiat #10 Uiniat #10 wa.s 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 with Aquagel 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 5/8-inch casing is flared and open at the top. This well was plugged May 6, 2004 (Figure 47). and water (per barrel) were used ~4~ ~,;~ 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. U 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 West Dease HOLE DEPTH(meters) 648 884 640 600 727 735 615 582 227 856 532 625 660 591 393 549 399 556 756 823 *Are also part of the CALM network (Circumpolar Active-Layer Monitoring). 57 • • Cape Simpson Well Pluggings - 2006 Operations Summary BLM initiated well plugging operations in the Cape Simpson area on April 11, 2004 under contract to Cruz Construction with the assistance of a drilling crew from the USGS in Denver, CO. The following legacy wells were plugged before the cessation of operations on April 22, 2004: • Simpson Core Test #2^J • Simpson Core Test #3oA • Simpson Core Test #26 • Simpson Core Test #3i ~• Simpson Core Test #30 Plugging operations were conducted to prevent several wells capable of flowing oil from potentially leaking. At the completion of operations, the well heads were preserved due to their potential historical significance. The wells were drilled within naturally occurring oil seeps during the U.S. Navy's exploration efforts in the late 1940's and 50's in the formerly named Naval Petroleum Reserve - 4. The Simpson Core Test wells are located on the Simpson Peninsula approximately l55 miles northwest of Prudhoe Bay. ~.~ ., `1 .gin `"M. i r! ,,,, 'u:r .~:,,' Y~ -±q~ ~ ~ ~,~ . _ 1 ;~ ~ m fit.; ~~~ MAC Z 8 X010 ~vC~- l`~v • Figure 1 -Map of Simpson Core Test well locations ~. i ... ~~.. ,~., ~~° . v~ ~, ~ , . .,. - ,. M __ .~ -.._ _ _ _, .. ~ ~ ~, ~~ a., -_ P ~ ~.... ~~f~lA~ ~~Nri,.F7 ` ~ ~ ~ ~ ' ~ d6 ~. .~:. ; ~ T~Iaj #. `~~ °f~ ' ,.; ~ v `; w - Fy .~ ~ ~ '~' r _ i" _ .. . Figure 2 -Simpson Core Test Wells #27 (left) and #30A (right). ~ -' : ~~ ~, ~"".. ~, .< Y ~~_ Figure 3 -Simpson Core Test Wells #26 (upper left), #31 (upper right), and #30 (center). • • s~ ~,~ i ~ s, r, kY~ ~ ) ~ ~ ..+.• ~ la, ±+ .~..w v 3' * .~",, . , ~- ~igvre ~ - ~~ ell p~u~gin~ e~uiprr~e~~ rsaounted o~n ~L'hxa9enger ~'a-ailers • .~ _~ i..- ~ .: ,~ } x ks a °' x ~_. °~~' Figure 6 -Operations at Simpson #27 ~a - { ~ f. :'$~~ `~. ~?._ '- `~ ~H ,~ tf F ~~ ~ ... k C~StC_ -^« k~, . . ... «. ;i 'a,~ £.~ _ °~. -~ r ~; ~` ~, -'` .~ ~j' . *r~~.. } ~= ~f ~~_ Figure' -Operations ;it Simpson #.30.~ _._ _ _~ ~ ~. ~_ +? $5 ~. ~ ~'' `~ ; ~:, t .. ~ ' 4sre ..~~ . ~. I .. ~•w~~..- ~ y~~.N_ ~ :~fJ' -'~: _. LL°0v+sg ~~' e ~ ,. J • ~~~ ~~ ~~~ ~~ ':5 -t , ~~°% `e .p ~ ~ ~ 9 - ~ ~` ~~ ~~ ~. `~ ;~ ~,f K .: Y .P ~, .. G ~ = ___....:_:..~ ___ .__ _ P Figure I i - ®rillon~~ o er~ations ioadt~ited bi tt~e ~ tid;ti ~irillina crew o+~ ~ir~~,~;on #30 • 2®~6 Vllell Plugging 1490' • Current Il~l~llbore ®iagraen _ Ri Failing 1500-S Rotary Rig t ' Simpson Core #27 S ud: February 8, 1951 r - Meridian Township Range Section Barrow ~' r Simpson Core Tests Umiat 18N 11W 11 53mi ~ ~ {,, GL 24' A MSL KB: 29' AMSL Atqasuk ` , Pluooed Schematic - Agril 2006 ° ' 649' W 154° 41 71 mi \_ . N - 55.893 70 12 112" Hole 6 118" Hole 5 718" Hole S~sx~ps®n C®re Test #27 20 gal Follow-up Water Surface Plug to 15' KB 103 feet thick 24 sz of Arctic Set Lite 100 gal Fresh Water Spacer Casit';,g and Tulsittg DeEail Sim NFei hl T Grade ID To 8tm 35/8" Z4 Cond~h"cor --- 8>?3? .. P2 Drilling Fluids Base 6epths Weight Additives Water 0-115 --- Steam in mutl yanks Oil 115-380 8 7-10 3 10 bbl Simpson oil. 5 bbl diesel Oil 380-641 --- Oil corxmued to be used as drilling mud Oil 641- 01 _- Cd displaced with water basetl dolling mud Water 961-1320 91-g.5 --- Oil 1320-1385 --- Aquagel. then 73 bbl Simpson oil and 23 bbl diesel Oil 1385-1500 -- Oil replaced by mud gradually. but some oil remained Formation Geology A De hs S;hows Gubik Quaternary No sample --- Seabee UpperGretaceous 102-146 -- Unconformrty --- 146 `- NlnuluklSeabee Undiff Upper Cretaceous 146-450 Oi] Grandstand Loser Cretaceous 450.1500 -- Base o< Perrnairost --- -- --- Fistt/Fill lrtformatwn Item Date De h Comment Base of Permafrost 9 A 3;14/51 o Rotar]~ Drilling f31ud leftm hole (o~~ r; r.,:-I ) ~, i TD = 1500' PBTD = 1500' Max production = 3 bbl/day Producing Zofte Depth _Spt Oil Rate Test type _~ G-36i? ~^t'>r-.n h;oie 3 Ct-1ld ~4aiimg test over 24 hrs Oil-based iWud Oil show Oil produced Gas show a'1~= Gas produced Fluoresence-Cut I" CaC12 Calcium Chloride ~ Water Portland Class A cement Simpson Oil Simpson Care #26 Crude I dement 5~70i2006 VII{jllldl RR~ ~ J.Y I~WV¢ v~ • 2006 Well Plugging Sompson Core Test #3OA Current Wellbore Diagram Ri Failing 1500-5 Rotary Rig Simpson Core #30A S ud: January 23, 1951 '. Meridian Township Range Section Barrow %~ i ~ Simpson Core Tests Umiat 18N 11 W 11 54 mi `~ -- ~ GL: 20' A MSL KB: 25' AM SL Atqasuk ' Pfuaoed Schematic -April 2006 ° ' 29 154° 42 1' W 71 mi .. ~ . 55.588 N - 70 vny~nai Rno - v.v nw.c v~ 12 114" Hole 5 118" Hole 20 gal Follow-up Water Surface Plug 105 feet thick 24 sx of Arctic Set Lite Casing and Tubingbetall Size Weight Type Grade ID Top Btm 8 578" 28 Conductor -- R 01" 0 100 Drilling Fluids Base Depths Weight Additives UVater 023 8 8-10.4 Salt. Baroid. Heated water 423-701 85-11.0 Salt Baroitl Gutxk Ouatemary 5-85 - Seabee Upper Cretaceous 85-143 --- Unconformity --- 143 -- Ninuluk/Seabee Undiff Upper Cretaceous 143-445 Oil/Gas Grandstand Lower Cretaceous 44593 -- Base of Permafrost --- -- --- ;h/Fill InfotmaLioo 5 718" Hole I Item Date Depth Comment i ;; 2!5!51 Rosary Onilinq "dud let[ in hole I. ... ,._. y._.. ,.. ,.... - _ ,.... Producing 'Zone De h S f Oil Rate 7esY e -3'r3 Opc'n Naie 5 5b1(o 3aiRing fast o~~er 24 acs Drilling Mud Oil show Oil produced r'i Gas show Max production = 5 bbllday ~~+~ Gas produced .. Fluoresence-Cut ;ia CaC12 Calaum Chlonde Portland Class A cement ii t;r'003 • 2006 ~Uel9 Plugging Somas®in C®re 1°est #~26 CuPrent Y~elVbore ®6algralm ~ Ri Failing 1500-S Rotary Rig ~ Simpson Core #26 S ud: August 13, 1950 „_ Meridian Township Range Section Barrow a', -'~ ~ ~ ~ Sim son Core Tests p Umiat 18N 11 W 11 54 mi ;~ ~ ,~ ' 06 GL: 20' A MSL KB: 23' AM SL Atqasuk ~Y ~ l N - - ~ Plugged Schematic -April 20 70° 55.919' N - 154° 42.684' W 71 mi rtK~s = s.u raoove u~ Casing and Tuning Detail Size `P4<et ht T Tirade iD Ta Btm t. ,~ 8 516' 29 Conductor ?33 0 -3y0 2 f./2" 65 Tudmg 2 iG1' GLiG 10 5l8" Hole Wellbore on vaccum 7 5l8" Hole 6 118" Hole Drilling Fluids Max production = 176 bbl/day Base Depths Weight Additives Water 0-360 91-127 Aquagel, Baroid, Na,O;PZ Water 305-860 6 33-12.0 Used water, then switch to 12 ppg mud Water 66095 6.33-14.4 Used water. then switch io 14 4 ppg Water 895-913 86-10 4 Aquagel for dril0ng, Baroid to kdl well Water 913-1171 9.2-106 --- Water 1171 9 33-9 0 Reaming ops used fresh and salt water - Formation Geology A e De the Shows Gubik Quaternary 03-67 --- Seabee Upper Cretaceous -- --- Unconforrrirty --- 67 -- rWnuluk/Seabee Undiff Upper Cretaceous 87x720 Oil/Gas Grandstand Lower Cretaceous 420-1171 -- Base of Permafrost --- --- -- Drilling Mud ~ Crude Oil & Gas ~ .~~ Brine Oil show t~~-J Oil produced ~`s Gas show FormPress = 250 psig -r+~\ Gas produced Fluoresence-Cut FlowingPress = 155 psig Na,P,O- tetra Sodium Pyrophosphate (controls pH levels) FormTemp = 14°F Cal-Seal Gypsum cement ~ enr=ae~ ! ~ 2006 Well Plugging Simpson Core Test #~1 current Wellbore Diagram #31 C Ri Failing 1500-S Rotary Rig ~ Simpson ore S ud: March 20, 1951 - _ _ - Meridian Township Range Section Barrow -~ Simpson Core Tests Umiat 19N 11 W 36 55 mi ~ ~ •~ 6 GL: 14' A MSL KB: 19' AMSL Atqasuk rl ..~-~"' `~° Plugged Schematic -April 200 70° 50.302' N - 154° 59.397 W 73 mi Vrl9lrlal Rr~O -'.V f1UVVC VV 25 gal Follow-up Water 12 1l4" Hole Surface Plug 105 feet thick ~-~~- 24 sz of Arctic Set Lite Casing and Tubing Detail Size Wei ht T e Grade ID To Btm 8 5/8" --- Conductor --- -- 0 101 Drilling Fluids Base Depths Weight Additives Water 0-186 9 4 --- Water 186355 --- Na,P°O, Geology 6 1/8" Hole 5 7I8" Hole Formation A e De the Shows Gubik Ouatemary 5-110 --- Seabee Upper Cretaceous 110-186 -~ Uncanformiry -- 186 --- Ninuluk/Seabee Untliff Upper Cretaceous 186355 Oil/Gas Grandstand Lower Cretaceous -- -- Base of Permafrost --- --- --- FishlFill Information Item Date De th Comment A 4!2151 ~ Rotary Dniling Mud left m hole Producing Zone De th S f Oil Rate Gas Rate Grav Tem 355 Gpen Hole 1255b1/d 4 MCr'D 21° --- Drilling Mud Oil show Oil produced Gas show ~?> ~- Gas produced Fluoresence-Cut .1., Na,PZO, Tetra Sodium Pyrophosphate (controls pH levels) Cal-Seal Gypsum cement 2006 Well Plugging ~6rvaps®~ C®re Test #30 Current Wellbare I)iagrerro Ri Failing 1500-5 Rotary Rig Simpson Core #30 S ud: November 30, 1950 Meridian Township Range Section Barrow ~~ ~:a Simpson Core Tests Umiat 18N 11 W 11 54 mi ~ ,~ _ ~~ ` GL: 20' A MSL KB: 25' AMSL Atqasuk •. 3• ~. ~; _.. _.. Pluoaed Schematic - Aoril 2006 70° 55.571' N - 154° 42.320' W 71 mi 12 114" Hole 6 1/8" Hole Rr~O ~ J.V MWtlC VL 12 sx of Arctic Set Lite Surtace Plug to 7' KB 52 feet thick 6 314" drill bit 8 60' 2 1l2" rods Junk in hole? or Bad casing? 69 112' KB Casing and Tubing Oetail Size 1Nei ht T Grade ID To Btm 8 5r8" 28 Conductor --- 8 017" 0 152 Drilling Fla~ids 8mse Depths Weight Additives Water 0.283 9 2-9 9 ~-- Water 283-303 9 5-9 6 --- taster 30329 8 7-9 2 --- ' Water 429F>30 90-9 1 Mutl Dated Water 630E93 9.0-9 2 Mud heated Water 693 8.7-9 C Mud heated Geology Formation A e Depths Shows Gubik Quaternary 5-85 --- Seabee Upper Cretaceous 85-143 --- Uncontormity --~ 143 --- Ninuluk/Seatx°e Undiff Upper Cretaceous 143-445 Oil/Gas Grandstand Lower Cretaceous 44593 C41 Base of Perma6ost --- --- -- Fis h/F it I Information 5 718" Hole TD = 693' PBTD = 693' Max production = 6 bbl/day I Item Date De th Comment i A 1 1/23/51 695 RotaryDmBno lJlud!eft~nhokr , B 38B' Core barrel and DP P depth Spf roducing Zo Ui) Rate u ne Test type _ 3.350 'Open Nple 5 bbl/d Bolling test cver 48 hrs Drilling Mud Oil show Oil produced Gas show Gas produced Fluoresence-Cut Cal-Seal Gypsum cement ~ Cement >- 30i 2COb FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539. PHONE (907) 279-1433 FAX (907) 276-7542 September 8, 2006 Henri R. Bisson State Director Bureau of Land Management 222 West 7`h Avenue, # 13 Anchorage, Alaska 99513 ~ too - ~qo- o ~~~~~1 ~~e" ~ ~U~tiJ Re: Recent Work at NPRA Simpson Wells and Prior Umiat Work Dear Mr. Bison: The Alaska Oil and Gas Conservation Commission ("Commission") recently received Reports of Sundry Well Operations (Form 10-404) for work conducted on five Simpson wells in NPRA. These reports document work conducted in mid to late April of this year. Our review has identified two concerns with the submitted documents. These new concerns are in addition to other lingering matters from similar work conducted at Umiat in 2002 and 2004. Since these latter issues have remained unresolved despite multiple requests to BLM staff members, the Commission would like to bring all the issues to vour attention. 1. 20 AAC 25.280(d) requires the operator to file a Report of Sundry Well Operations 30 days after completion of workover operations. While the work was completed on these wells in late April, these reports were not submitted to the Commission until August 16. 2. It appears from these five Simpson well Reports that the work actually performed on the wells is substantively different from the work plan that was originally described in the Application for Sundry Approvals (Form IO-403) submitted for each well and approved by the Commission. A change to an approved program or activity may not be undertaken without Commission approval. If operational necessity requires prompt action, oral approval of a change may be obtained from the Commission. The Commission has staff available to address regulatory variances 24 hours a day, either by contacting our North Slope inspector at 907- 659-2714 (pager 907-659-3607) or the after hours duty engineer at 907-244-1467. 3. Reports of Sundry Well Operations (Form 10-404) have not been submitted for work done in early May 2004 in Umiat wells 03, 04, 08 and 10, although description of the work was provided to the Commission. • Henri R. Bison September 8, 2006 Page 2 of 2 • 4. Well Completion or Recompletion Report and Log (Form 10-407) have never been filed for the plugging and abandonment work done on Umiat wells 02 and OS by the Corp of Engineers in March 2002. Again, work descriptions from your onsite Inspector were received but not Forms 10-407. I know you agree that compliance with applicable Federal and State oil and gas regulations is of critical importance to all of us here in Alaska. Your assistance in helping ensure regulatory compliance and in prov these documents so that the AOGCC's well files can be brought up to date wil e ap eciated. RE~I~'' STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM~N AUG 1 !~ REPORT OF SUNDRY WELL OPERATION~sk~ 0i1 &;fas;~C~s.~~~ ..._.._ . 1. Operations Abandon ~ Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Bureau of Land Management 4. Current Well Class: 5. Permit to Drill Number: Name: Development ^ Exploratory^~ 100-190 • 3. Address: 6881 Abbott Loop Road Anchorage, AK Stratigraphic^ Service^ 6. API Number: 50-279-10028-00 7. KB Elevation (ft): 9. Welt Name and Number: 25' RKB 20' GL Simpson Core Test Well #30 8. Property Designation: 10. Field/Pool(s): AA-085547 ' 758100 - 11. Present Well Condition Summary: - Total Depth measured 693 feet Plugs (measured) UnknOWn true vertical 693. feet Junk (measured) 388 Effective Depth measured 693 feet true vertical 693 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 152 8 5/8" 152 152 Surface et~ / / Intermediate .~r74 rT ~ ~! Production O~y Liner DATE Perforation depth: Measured depth: N/A ~~-,_ lD VER ED T V rti l d th rue e ca ep : N/A ____ Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): drilled out frozen oily drilling mud, cemented stuck drillstring at 69 1/2" Treatment descriptions including volumes used and final pressure: pumped 3.28 bbls of Arctic Set Lite cement followed by 5 gal water 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 6 0 . Subsequent to operation: 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run No Exploratory0 Development ^ Service ^ Daily Report of Well Operations Yes 16. Well Status after proposed work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: - 0 9 d o/ ~ Contact Stan Porhola Printed Name Stan Porhola Title Petroleum Engineer Signature ~ ~ ~ ~ Phone 907-267-1469 Date ~ 1~6 fob ZLW, w'L G. Form 10-404 Revised 04/2004 ;~ _ SEP p i 2D06 ,~-,~ l~~ Submit Original Only ~/~ • • 2006 Well Plugging Simpson Core Test #30 Current Wellbore Diagram Si #30 C Ri Failing 1500-S Rotary Rig ~~ mpson ore S ud: November 30, 1950 T t Si C Meridian Township Range Section Barrow ~ ore mpson es s Umiat 18N 11W 11 54 mi Pl h ti A il 2006 d S GL: 20' A MSL KB: 25' AMSL Atqasuk ema pr uaae c c - 70° 55.571' N - 154° 42.320' W 71 mi urlglnal ri:rcrj = s.u~ Aoove c;l_ 12 1/4" Hole 61/8" Hole 5 7/8" Hole :I I -'i id1 ii' . ,. ~` Water 303-429 8.7-9.2 --- Water 429-630 9.0-9.1 Mud heated Junk in hole? y~/ater 630-693 9.0-9.2 Mud heated or Water 693 8.7-9.0 Mud heated Bad casing? 691/2' KB _ _____ T_ 12 sx of Arctic Set Size Wei ht Casing and Tubing Detail T e Grade ID To Btm Lite 8 5/8" 28 Conductor --- 8.017" 0 152 Surface Plug to 7' KB 52 feet thick _ Drllling Fluids 6 3/4" drill bit Base Depths Weight Additives g I Water 0-283 9.2-9.9 --- 60' 2 1/2" rods Water 283-303 9.5-9.6 --- TD = 693' PBTD = 693' Max production = 6 bbl/day Formation Geology A e De the Shows Gubik Quaternary 5-85 --- Seabee Upper Cretaceous 85-143 --- Unconformity --- 143 --- Ninuluk/Seabee Undiff Upper Cretaceous t43-445 Oil/Gas Grandstand Lower Cretaceous 445-693 Oil Base of Permafrost --- --- --- Item ~~ Fis Date De th h/Fill Inform Comment ation A 1/23/51 69.5 Rotary Drilling Mud left in hole B 388' Core barrel and DP P De th S f roducing Zo Oil Rate ne Test e 0-3 50 Open Hole 6 bbl/d Bailing test over 48 hrs Drilling Mud O Oil show • Oil produced ~£- Gas show Gas produced ® Fluoresence-Cut cal-Seal Gypsum cement ::',.1'.; ~'~ ~? Cement 5/26/2006 • Cape Simpson Summary Simpson Core Test #27 Operations began April 14, 2006. The well was capable of flowing crude oil at 34 bbUday with a pressure of 15 psi. The well was plugged with 24 sacks of Arctic grade cement creating a 103' cement plug in the well. The wellhead was returned to its original configuration per the State Historic Preservation Office's (SHPO) request and the site cleaned of all debris on April 17, 2006. Simpson Core Test #30A Operations began April 17, 2006. The well was capable of flowing crude oil at a pressure of 65 psi. The well was plugged with 24 sacks of Arctic grade cement creating a 105' cement plug in the well. The wellhead was returned to its original configuration per the State Historic Preservation Office's (SHPO) request and the site cleaned of all debris on April 18, 2006. Gas bubbling up around the base of the casing began to subside while the cement was being pumped into the well. The site was visited over the next several days with no further gas bubbling around the casing. Simpson Core Test #26 Operations began April 19, 2006. The well was capable of flowing crude oil at a pressure of 40 psi. The well was plugged with 36 sacks of Arctic grade cement creating a 158' cement plug in the well. The wellhead was returned to its original configuration per the State Historic Preservation Office's (SHPO) request and the site cleaned of all debris on Apri120, 2006. Simpson Core Test #31 Operations began April 20, 2006. The well was capable of flowing crude oil at a pressure of 70 psi. The well was plugged with 24 sacks of Arctic grade cement creating a 105' cement plug in the well. The wellhead was returned to its original configuration per the State Historic Preservation Office's (SHPO) request and the site cleaned of all debris on April 20, 2006. Simpson Core Test #30 Q ~ ~~~(~, ~t1 Operations began April 18, 2006, but were suspended until Apri120, 2006 following the discovery of an ice plug in the well. The well was incapable of flowing crude oil because of the ice plug. Drilling of the ice plug and frozen drilling muds was done down to 69.5' before the drillstring became stuck.The well was plugged with 12 sacks of Arctic grade cement creating a 52' cement plug in the well, with the drillstring left in the hole. The wellhead was returned to its original configuration per the State Historic Preservation Office's (SHPO) request and the site cleaned of all debris on Apri122, 2006. I • • Daily Loy -Simpson Core Test #30 4-18-06 (Tuesda ~~April 18tH) Start @ 0530: Wakeup Ops @ 0545: Morning safety meeting Ops @ 0600: Tucker w/ USGS to #30A Ops @ 0615: Turn on Red heater burners for rig/bean to warm up Ops @ 0630: Back to camp Ops @ 0645: Pickup mushroom tank on 4th Challenger trailer Ops @ 0700: Back to #30A Mike Kunz w/ Tucker to Ice road Picking up water bottles, drop trash, pickup Rob B. Ops @ 0800: Open well, 65 psi, gas vented (same response as previous day) Ops @ 0805: Attach flowlines to brass gate valve in preparation for water injection Ops @ 0822: Flow back circulating water to mushroom tank Ops @ 0830: Tighten wellhead assembly Ops @ 0845: Stop pumping water, setup for grouting Ops @ 0900: Fix air compressor, start up air Ops @ 0915: Begin pumping operations @ 120 psi Ops @ 0940: Completed pumping operations on Simpson Core Test #30A 100 gal water + 24 sx cement + 20 gal water Ops @ 1010: Base of #30A gas bubbling subsiding Ops @ 1040: Remove flowlines Ops @ 1100: Back to camp Break @ 1115: Lunch Ops @ 1330: Pickup pipe fittings @ BLM camp for #30 2 heater trunks on 300 gallon water tank Fi11300 gallon water tank Ops @ 1630: Down to #30, weld on riser Ops @ 1730: Set flow tee on well Ops @ 1800: Back to camp from #30 Break @ 1830: Dinner 4-19-06 (Wednesday, April 19th) Start @ 0515: Wakeup Call @ 0600: Greg/Elaine Ops @ 0630: Morning safety meeting Ops @ 0700: Tucker to Simpson Core #30 Ops @ 0800: Open well, no pressure Ops @ 0815: Pump cold water, peg meter (1000 psi) Ops @ 0830: Bleed off pressure/water into mushroom tank Tarp well, place heat on well Ops @ 1000: Check well, pressure at 25 psi, bled just air Call @ 1100: Greg • Break @ 1200: Lunch Ops @ 1330: Down to Simpson Core #30 Ops @ 1338: No pressure on well, valve left open, water in well w/ ice Ops @ 1400: Back to BLM camp Ops @ 1500: Check out pad size at Simpson Core #26 Ops @ 1515: Cleanup Simpson Core #30 site Ops @ 1530: Move trailers to Simpson Core #26 Ops @ 1630: Back to BLM camp Break @ 1800: Dinner Ops @ 1930: Check on heat on Simpson Core #26 Open well, pressure at 40 psi, vent gas Ops @ 2025: Back to BLM camp 4-20-06 (Thursday, April 20tH) Start @ 0600: Wakeup Ops @ 0615: Tarp well, fuel up vehicles, back to BLM camp Ops @ 0700: Morning safety meeting Ops @ 0800: Pick up Darla Pindell from Ice road Call @ 0830: Jeff Miller, Elaine, Greg Ops @ 0900: Head out to Simpson Core #26 Ops @ 0915: Begin pumping operations @ 80 psi Ops @ 0945: Completed pumping operations on Simpson Core Test #26 50 gal water + 36 sx cement + 50 gal water Ops @ 1005: 50 gal cement rinseate to disposal Ops @ 1055: Back to BLM camp Ops @ 1115: Move trailers to Simpson Core #31 Ops @ 1215: Back to BLM camp Call @ 1245: Elaine Call @ 1355: Greg Ops @ 1400: Head out w/ Tucker to Ice road to meet w/ Tim Ops @ 1415: Drop off USGS at Simpson Core #31 Ops @ 1430: Pickup extra cement sack and BLM staff Ops @ 1500: Back to Simpson Core #31, well pressure of 70 psi Ops @ 1535: Begin pumping operations @ 450 psi Ops @ 1600: Completed pumping operations on Simpson Core Test #31 25 gal water + 24 sx cement + 25 gal water Ops @ 1635: BLM staff in Tucker back to BLM camp Ops @ 1730: USGS staff back to BLM camp Ops @ 1735: Darla/Rob B. heading back to Ice road Ops @ 1800: Park Tucker at BLM camp Break @ 1815: Dinner Call @ 1845: Jeff Eman 4-21-06 (Friday, Apri121 std Start @ 0545: Wakeup Call @ 0600: Jeff Eman • • Ops @ 0730: USGS down at Simpson Core #30 welding new riser Ops @ 0830: Arrive at Simpson Core #30 Ops @ 1205: Leave Simpson Core #30 Break @ 1215: Lunch Call @ 1315: Greg Ops @ 1418: Start drilling/circulating Ops @ 1430: Drilling through frozen drilling muds Ops @ 1447: Stop @ 10', new rod connection being made Ops @ 1501: Continue drilling ahead Ops @ 1514: Stop @ 20', new rod connection being made Ops @ 1524: Continue drilling ahead Ops @ 1532: Stop @ 30', new rod connection being made Ops @ 1543: Continue drilling ahead Ops @ 1552: Stop @ 40', new rod connection being made Pump circulating fluids into disposal tank Ops @ 1604: Finish disposal = 200 gal Ops @ 1610: Continue drilling ahead Ops @ 1615: Stop @ 50', new rod connection being made Ops @ 1621: Use lath to cleanup buildup at top of well Ops @ 1623: Continue drilling ahead Ops @ 1630: Swivel leaking Ops @ 1640: Stop @ 60', new rod connection being made Ops @ 1650: Continue drilling ahead Ops @ 1652: Gas meter detecting 1 % CH4 Ops @ 1700: Hung up at 69.5', torqued up drillstring Ops @ 1730: Break connection free w/ torch, Steiger winch Ops @ 1838: Begin pumping operations down drillstring and bit 20 gal water + 12 sx cement + 20 gal water Ops @ 1945: Cut tubing at surface, cap well Ops @ 2005: Leave Simpson Core #30, head back to BLM camp Ops @ 2015: Back at BLM camp Break @ 2030: Dinner 4-22-06 (Saturday, Apri122na~ Start @ 0530: Wakeup Ops @ 0600: Morning safety meeting Ops @ 0630: Head out to Simpson Core #30 Ops @ 0720: Cleanup site Ops @ 0825: Leave Simpson Core #30 Ops @ 0830: Back at BLM camp Ops @ 0900: Head out to Ice road to meet with Tim/Rob B. Ops @ 0945: Back to BLM camp Begin moving BLM camp offsite w/ camp, vehicles, trailers Ops @ 1600: Drive in Cruz Van w/ Tim/Rob B. to Cape Simpson Ops @ 2100: Back to BLM camp now located next to Ice road Photo 1 of 6 Photo 2 of 6 4~ • f ,l ~_ l 7,~~. Simpson Core Test #30 April 19, 2006 Wellhead altered for well plugging operations Photo 3 of 6 C • Simpson Core Test #30 April 19, 2006 Setup for pumping operations (failed attempt) Photo 4 of 6 • • Simpson Core Test #30 April 21, 2006 Setup for drilling operations Photo5of6 • r: Simpson Core Test #30 Apri 121, 2006 During drilling operatoins - ~~ ~" r Simpson Core Test #30 April 21, 2006 Post-well plugging operations ~.-~. Y_ a w,h{~ Y ~, Photo 6 of 6 ~ ~ .~ _ _ ~,~ ~w~~ 11 I K ~n_4 ( _ ~~~, -. ° ~~. ~: ~?~ ...~ ~. ~~~.. `~ ~ ~~ `,~' , 1 ,~~- r y al . r~ r' • • ~, STATE OF ALASKA 'F~:! Fir i ~ _ `' °'1.~~ ALA OIL AND GAS CONSERVATION COMON ~_,~ APPLICATION FOR SUNDRY APPROVALS Alas~~ ~~ ~~~ ~~,~~ Co~rarnission `"~ 20 AAC 25.280 ~ , 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate Waiver ` ' ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Bureau of Land Management Development ^ Exploratory ~ 100-190 3. Address: Stratigraphic ^ Service ^ 6. API Number: 6881 Abbott Loop Road Anchorage, Alaska 99507 50-279-10028-00' 7. KB Elevation (ft): 9. Well Name and Number: 25' RKB 20' GL ~ Simpson Core Test Well #30 8. Properly Designation: 10. Field/Pools(s): AA-085547 ' 758100 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 693' 693' 693' 693' N/A 388' Casing Length Size MD TVD Burst Collapse Structural Conductor 152' 8 5/8" 152' 152' Surface Intermediate Production Liner Pertoration Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^~ BOP Sketch Q Exploratory ^~ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed,ay rk~c~'V ~ Commencing Operations: 4/3/2006 Oil ^ Gas ^ / Plugged ^~ Abandoned ^ ~~ C ~} 16. Verbal Approval: Date: ^ GINJ ^ ~INJ ^ WDSPL ^ WAG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Printed Name Stan Porhola Title Petroleum Engineer Signature Phone 907-267-1469 Date ~ ~3 d6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ` Other: ~ o~~.SS ~T ~ ~ ~ ~~ VJC7.\~~ ~~lt~C~ ~~~~i`~ SU ~ti"L1tiSiC ~'~`1 ~' S SS S ~' Subsequent Form Required: ~..~® ~ ~ ~~ ~~~ ~-~ APPROVED BY I , /~D~ A ( ~•6 pproved by: COMMISSIONER THE COMMISSION,~c Date: T v ~~ ~ 1RBDMS ~3f L >aril 2006r .6~ 3 ~3~•v~ Form 10-403 Revised 07/2005 Submit in Dupli to .+~' 3i'#~~~' ~~~i~E~ STATE OF ALASKA ALA .OIL AND GAS CONSERVATION COMI~ION MQK `~ G I ilOb APPLICATION FOR SUNDRY APPROVALglasica Oil & Gas Cons. Commission 20 AAC 25.280 n....~,...,...,. 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate Waiver ular Dispos. Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Other ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drilt Number: Bureau of Land Management Development ^ Exploratory 0 100-190 3. Address: Stratigraphic ^ Service ^ 6. API Number: 6881 Abbott Loop Road Anchorage, Alaska 99507 50-279-100 0 7. KB Elevation (ft): 9. Well Name and Number: 25' RKB 20' GL Simpson Core Test Well #30 8. Property Designation: 10. Field/Pools(s): AA-085547 758100 ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth jVD ): Plugs (measured): Junk (measured): 693' ~ 693' 693' 693' ~~/ N/A 388' Casing Length Size MD TVD Burst Collapse Structural Conductor 152' 8 5/8" 152' 152' Surface ~' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubin Size: Tubing Grade: Tubing MD (ft): N/A N/A N/ N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 12. Attachments: Description Summary of Propos ~ 13. Well Class after proposed work: Detailed Operations Program Q 80P Sket Q Exploratory ^~ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/27/2006 Oil ^ Gas ^ Plugged ^~ Abandoned ^ 16. Verbal Approval: D WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is tru and correct to the best of my knowledge. Contact Stan Porhola Printed Name Stan Porhola Title Petroleum Engineer Signature Phone 907-267-1469 Date 3l~ 6 ~, COMMISSION USE ONLY Conditions of approval: Notify mmission so that a representative may witness Sundry Number: ® ~' 0 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Regaired: BY ORDER OF Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 12/2003 -+ INSTRUCTIONS ON REVERSE '~ ~ ° ~ f Submit in Duplicate Statement of Work Simpson Core Test #30 1 -Move in and position trailers around well on the ice pad according to the Wellsite Layout as shown in Attachment 8. 2 -Move in and position snow melter, and cat camp as shown in Attachment 8. 3 -Cut top of wellhead to make clean surface for installation of new flange. 4 -Install new flange, 8" divertor with flow tee, and hoses to circulation tank. 5 - MU drillstring with 7 7/8" bit on 2 '/2" drill steel and RIH (BHA # 1). 6 -Work down casing to 150' KB while recirculating well fluids down drillstring. 7 -POOH and prepare to RIH with inflatable packer and control line run on drillstring (BHA #2). 8 - RIH with inflatable packer to 150' KB. At depth, set packer using N2. 9 -Rotate drillstring to separate from packer at adapter and pickup 10' off packer. 10 -Mix 1.5 bbl water spacer followed by 8.0 bbl Arctic Set Lite (10.7 ppg) cement taking returns into circulation tank. ~ba~ on ub\`is~~~~r~c.~s`~'av~s ti g ~~ bb\S 11 -POOH with drillstring. Wait on cement (WOC) for 5 hours. RIH to tag plug with 7 ~ ~ ~,~~~ 7/8" bit on drillstring applying SOO lbs of weight on cement top. Begin rig down. ~~~ c 12 -Remove new WHCs and return wellhead to original configuration. Mobilize to next ~~j wellsite. ~"'1 ~3 3/23/2006 BL,M 14 '.~~ Attachment 1 Simpson Core Test #30 Wellhead /Photo Oil seep around surface! sheared 8 5/8" casing wood stubs ----~-' ~ -- Simpson ', Overall Height ~ Oore #30 1.5 feet BLM _ 3/13/2006 ~ ~ "' " ~ 21 Attachment 2 r~ Sian a~ Core Test #30 ~ Current Wellbore Diagram Ps `' # RI Failing 1500-S Rotary Rig 1~,%1! Sim son Core 30 p S ud: November 30, 1950 . ~ ~ ~ T Meridian Township Range Section Barrow t - :x: ests Simpson Core Umiat 18N 11 W 11 54 mi ,x; ~~.-_,,, '.i~ - * h ti b S GL: 20' A MSL KB: 25' AM SL Atqasuk ., r ore ema Current Well c c 70° 55.571' N - 154° 42.320' W 71 mi vngtnat Rn6 = D.V raoove u~ ~, ~~ • Casing and Tubing Detail •~,:• ~ Size Wei ht T Grade ID To Btm i ~ 8 518" 28 Conductor --- 8.017" 0 152 12 114" Hole 63 sx of Cal$eal j ~: 6 1/8" Hole 5 7/8" Hole - ~ Depth: .~' ~ 263'-283' • r ~.} Depth: j ® 283'-350' ~~ , '• y Depth: :'C( JJG ~' ~ 0'-350' ' ~ - ~ Depth: ' .~~~ 408'-419' ~~' Depth: / ~ 451'-471' ~' 565' • ~~~• - •~ l~~. ... ~ Depth: ~~~~ . 584'-590' Depth: ~ 620'-670' t .. TD = 693' PBTD = 693' N1ax production = 6 bbl/day Base Depths Weight Additives Water 0-283 92-9.9 -- Water 283-303 9.5-9.6 --- Water 303-429 8.7-92 --- Water 429-630 9.0-9.1 Mud healed Water 630-693 9.0-9.2 Mud heated 'Maier 693 8.7.9A Mud heated Formation Geology A e De the Shows Gubik Quaternary 5-85 -- Seabee Upper Cretaceous 85-143 -- Unconformly -- 143 --- NinwuklSeabee Undiff Upper Cretaceous 143-445 Oil/Gas Grandstand Lower Cretaceous 445-693 Oil Base of Permafrost --- - --- Item Fish Date De th /Fill Inform Comment ation A 1/23151 Surface Rotary Drilling Mud left in hole B 388' Core barrel and DP De Pr th S f oducing Zo Oil Rate ne Test e -3fi0 OOer Hole S bb!:d 3ailing'tast o>.er 18 airs Drilling Mud . Oil show • Oil produced ~- Gas show Gas produced ® Fluoresence-Cut Cal-Seal Gypsum cement 3/13/2006 26 Attachment 3 • • Simpson Core Test #30 Proposed Wellbore Diagram Option 1 /( Sim #30 C RI ~ Failing 1500-S Rotary Rig , ~~~ ^ pson ore S ud: November 30, 1950 LL..JJ lll..J//_ 1_ , T t Si C Meridian Township Range Section Barrow Y, ~.. s a~ * ~ ^, mpson ore es s Umiat 18N 11 W 11 54 mi ~'~ e~ ~ ~i~ P d W llb S h ti GL: 20' A MSL KB: 25' AMSL Atqasuk „~,,,, ' - ore c ema ropose e c 70° 55.571' N - 154° 42.320' W 71 mi vngtnaf rcna = o.u Hoove v~ 12 tl4" Hole 6 1/8" Hole 5 7!8" Hole f•.'.=' ~• 'r'~ .. .~ ~•B'~ 565' - .! • :1 - ,~ f., Max production = 6 bbl/day Surface Plug to10'KB IrHlatable Packer 150' KB Casing and Tubing Detail i Size Wei ht T Grade ID To Btm I 8 5/B" 28 Conductor --- 8.017" 0 152 1~-. ~._ _, _ _ ____ _ _.._ __---~ a__.~.`.-._W~~ ._ Drilling Fluids Base Depths Weight Additives Water 0-283 9.2-9.9 --- Water 283-303 9.5-9.6 --- Water 303-429 8.7-9.2 --- Wafer 429-630 9.0.9.1 Mud heated Water 630-693 9.0-9.2 Mud heated Waler 693 8 7-9.0 Mud heated Formation Geology A e De the Shows Gubik Ouatemary 5.85 - Seabee Upper Cretaceous 85-ta3 - Unconformity --- 143 - Ninuluk/Seabee Undiff Upper Cretaceous 14345 Oil/Gas Grandstantl Lower Cretaceous 44593 Oil Base of Permafrost -- - - Fish /F i I I Inform ation Item Date De th Comment A 1/23/51 Surface Rotary Dnlhng Mud left in hole B 388' Core barrel and DP De Pr S f oducing Zo Oil Rate ne Test pe 03 5G Open Hole 6 bollc Bailing lest !:ver 48 hr; Drilling Mud . Oil show • Oil produced ~ Gas show Gas produced ® Fluoresence-Cut Cal-Seal Gypsum cement 3/13/2006 31 TD = 693' PBTD = 693' • Statement of Work -- T ~~~~~ U.S. Department of the Interior Bureau of Land Management Well Plugging Simpson Core Test Wells FY 2006 National Petroleum Reserve -Alaska March 13, 2006 oc n~Fnrtcninc Bureau of Land Management -Alaska Division of Energy and Solid Minerals Branch of Energy 6881 Abbott Loop Road Anchorage, Alaska 99507 (907) 267-1469 Phone (907) 267-1304 Fax and Northern District Office Arctic Field Office 1150 University Avenue Fairbanks, AK 99709 (907) 474-2303 Phone (907) 474-2282 Fax Statement of Work Table of Contents Background ..................................................................................................................................................... 3 Project Description ........................................................................................................................................ ..4 1 -Planning and Permitting ...................................................................................................................... ..4 2 -Project Management and Engineering ................................................................................................ .. S 3 -Coordination with Other Activities in the Area ................................................................................... .. S 4 -Site Reconnaissance ............................................................................................................................. .. S S -Project Mobilization -Demobilization ................................................................................................ .. 6 6 -Remote Camp Operations .................................................................................................................... .. 6 7 -Personnel ............................................................................................................................................. .. 6 8 -Fuel Use and Supply ............................................................................................................................ .. 7 9 -Water Use and Supply .......................................................................................................................... .. 7 10 -Air Support ......................................................................................................................................... .. 7 I1 -Equipment .......................................................................................................................................... .. 7 Flat-bed Trailers .................................................................................................................................... ..7 Heaters ................................................................................................................................................... .. 8 Light Plant ............................................................................................................................................. ..8 Cat Camp ............................................................................................................................................... ..8 Fuel Sloops ............................................................................................................................................ ..8 Pumping Equipment .............................................................................................................................. ..8 Mixing Tank .......................................................................................................................................... ..8 Connexes ............................................................................................................................................... .. 8 Disposal Tank ........................................................................................................................................ ..8 Safety Equipment .................................................................................................................................. ..8 12 -Materials ............................................................................................................................................ .. 8 Cement .................................................................................................................................................. ..9 Barite ..................................................................................................................................................... .. 9 Gel ......................................................................................................................................................... .. 9 Bridge Plugs .......................................................................................................................................... ..9 Piping Needs ......................................................................................................................................... ..9 Well Control .......................................................................................................................................... ..9 Spill Prevention ..................................................................................................................................... 10 Tarping/Scaffolding .............................................................................................................................. 10 Fluid Pumps .......................................................................................................................................... 10 13 -Vehicles .............................................................................................................................................. 10 Steiger Stx375 ....................................................................................................................................... 10 Challenger ............................................................................................................................................. 10 Volvo A25 ............................................................................................................................................. 10 Tucker Sno-Cat ..................................................................................................................................... 10 14 -Well Plugging Procedures ................................................................................................................. I1 Simpson Core Test #26 ......................................................................................................................... 11 Simpson Core Test #27 ......................................................................................................................... 12 Simpson Core Test #30 ......................................................................................................................... 12 Simpson Core Test #30A ...................................................................................................................... 13 Simpson Core Test #31 ......................................................................................................................... 13 1 S -Wellbore Fluid and Waste Disposal .................................................................................................. 14 16 - Wellhead Removal ............................................................................................................................ 14 17 - Attachments ....................................................................................................................................... 14 Attachment 1 -Wellhead Diagrams and Photos ................................................................................... 14 Attachment 2 -Current Wellbore Diagrams ......................................................................................... 14 Attachment 3 -Proposed Well Plugging .............................................................................................. 14 Attachment 4 -Deleted ......................................................................................................................... 14 Attachment 5 -Bottom Hole Assemblies ............................................................................................. 14 Attachment 6 -Wellhead Components ................................................................................................. 15 Attachment 7 -Route Map ................................................................................................................... 15 3/13/2006 BL,M Statement of Work Attachment 8 - Wellsite Layout ............................................................................................................ 15 Attachment 9 -Equipment Spread ........................................................................................................ 15 Attachment l0a -Project Timeline, March ........................................................................................... 15 Attachment l Ob -Project Timeline, April ............................................................................................ 15 Attachment 11 - A.M. Working Shifts ................................................................................................. 15 Attachment 12 - P.M. Working Shifts .................................................................................................. 15 Attachment 13 -Christensen CS1000 P6L Coring Rig Specifications ................................................. 15 Attachment 14a -Deleted ..................................................................................................................... 15 Attachment 14b -Deleted ..................................................................................................................... 15 Attachment 15 - Wellbore Fluid Volume Diagrams ............................................................................. 15 Table of Figures Figure 1 -Project Location .............................................................................................................................3 Figure 2 -Aerial View of Locations ...............................................................................................................4 Background The Simpson Core Test Wells were drilled by the US Navy between 1950 and 1951 and are located approximately 10 miles south of the Cape Simpson DEW Line site (See Figures 1, 2). The wells involved in this project are numbered #26, #27, #30, #30a, and #31. The wells were drilled to depths between 355 and 1500 feet, produced oil from a shallow reservoir in the permafrost at rates between 5 and 175 barrels per day, and were left unplugged. ~Stmpsnn - ~ p. i -, .~ ,~ o pson t13i _ ~ S oo "';;n ~ Simpson . ~~ -~,~ 4 _ -- ~ \.r -~ - -. _ ~ - - ~. Figure 1 -Project Location 3/13/2006 ~~,,~ 3 • • Statement of Work Project Description ~ ~, , The goal of this project is to plug and abandon five (5) wells located near Seep #2a and~~'~~ ~°~ ~ ~~ coo #3. The BLM will oversee the project and grant final approval of work performed. Final P approval is granted: When the well has been plugged to the satisfaction of both BLM and ~c3~y~~~t' AOGCC or having been field assessed as having an issue preventing plugging. ~;,`~~~~„r~, .,~i~ The contractor shall provide all materials, supplies, equipment, labor, and supervision to `~~- ' ' t accomplish the work except for those tasks that will be performed by the government ~~ ~ USGS drilling crew. The contractor's bid price shall cover any and all costs associated ~' with the project, including, but not limited to subcontracting, planning, permitting, reporting, communications, mobilization/demobilization, transportation, catering, fuels, inspections, removal and off-site disposaUdemolition of all wastes and junk, clean-up, pollution fines, penalty costs for regulation violations, etc. 1 -Planning and Permitting Contractor will meet with BLM to refine the Plan of Work for the wells, accounting for the unique characteristics at the wellsites. Also, all permits will be identified for which the contractor must submit to various government agencies for approvals and waivers. The necessary permits include but are not limited to: Permit A enc 3/13/2006 $L,M Figure 2 -Aerial View of Locations Statement of Work Incidental Take LOA FWS Fish Habitat/Stream Crossing AF&G Temporary Water Use DNR State Well Plugging Approval AOGCC Federal Well Plugging Approval BLM Right-of--Way BLM Coastal Zone Review ACMP NPDES EPA Ice Runway Use (Concurrence) FEX L.P. Spill C-Plan DEC A winter time schedule will be agreed upon which will allow for operations to take place from late March to early April of 2006. The expected duration of operations is 16 days. The average tundra travel closure date since 2000 has been approximately May 7th. Plans should be made to have all well plugging operations completed before this date. A timeline for operations is shown in Attachment 5. The contractor is responsible for developing a Site Specific Health and Safety Plan for the duration of the operations and for maintaining a copy of it on-site. 2 - Proiect Managerrcent and Engineering The ultimate responsibility of coordinating people, equipment and supplies will be the responsibility of the contractor. Preparation is critical in securing the necessary equipment and supplies to make certain that the project will be executed on time. This will include coordination of activities with the USGS drilling crew which is responsible for the coring rig and well plugging operations. A final report on the project will be submitted detailing all the work carried out. The report will be a typed compilation of each day's hourly log of the work performed incorporated with those tasks performed by the USGS drilling crew. Documentation for each hour of the working day, documenting rigging up, vehicle travel, fluids volumes generated or pumped and depths of cement plugs will be required. 3 -Coordination with Other Activities in the Area Other activities in the area include the potential drilling of oil exploration wells by FEX L.P. 20 miles south of the project location. The contact for FEX L.P. is Chris Bellis at 614-6949 in Calgary, Alberta. It is planned that the mobilization into the FEX L.P. well locations will be through multiple efforts including overland travel from the Cape Simpson DEW Line site and Prudhoe Bay/Kuparuk infrastructure, and by air utilizing a 5000 feet ice runway. This may provide an opportunity to mobilize equipment and/or utilize equipment already on location for the FEX L.P. operations for the Simpson Core Test well pluggings. 4 -Site Reconnaissance 3/13/2006 ~L,M 5 Statement of Work Site reconnaissance is anticipated for this project. The main concern is the potential risks of traveling on the tundra near the oil seeps. Primary importance will be given to the prevention of tracking and spreading oil seep material on the tundra. The contractor will be required to set up an avoidance plan that will involve identifying seep locations and what steps will be taken to avoid contact with the seeps. This reconnaissance will be in preparation for ice pad construction and equipment mobilization. The BLM staff has photographic and documented information on the sites that will be provided to the contractor to aid in this effort. A map of the proposed routes to the wellsites is shown in Attachment 7. S - Proiect Mobilization -Demobilization The project will begin with setting up equipment in Deadhorse. This will last approximately 4 days prior to mobilization to Cape Simpson, and will involve 2 days in Deadhorse at the conclusion of operations of the Umiat project. This will be done if it will be viable to coordinate the Cape Simpson and Umiat projects. Equipment, supplies, and personnel used for the project will be mobilized to the site either by low pressure ground vehicles, aircraft, or any combination of these methods. The project location will be located 20 miles north of FEX L.P.'s drilling operations where it is anticipated one or more 5000 feet ice runways will be located and maintained to support equipment, fuel, and personnel flights. It is unknown how long the ice runway will be used and maintained as this will depend on the decisions made by FEX L.P as their drilling program progresses. The necessary equipment spread (i.e. camp and trailer strings) required for the project can be seen in Attachment 9. 6 -Remote Camp Operations Camp facilities will be required at or near the project location. The camp space necessary for this project will be 22 beds plus 6 spare beds for a total bed space of 28. Camp staff is expected to be two 12 hour crews each with one attendant and one cook and two late shift workers. A mobile sled camp called the "Gypsy Camp" will be on location for the FEX L.P. operations and may be available with some of the necessary bed space during their winter drilling program. It is a possibility that not all the beds in the "Gypsy Camp" will be available and some bed units may need to be mobilized to the site. 7 -Personnel The required personnel for well plugging operations are expected to be two-12 hour crews. The first crew will have one project manager, one medic (EMT III), two vehicle operators, one mechanic, one cook, one bull cook, four USGS drilling crew members, and two BLM staff members for project and regulatory oversight. The second crew will be made of three vehicle operators, four USGS drilling crew members, and two BLM staff members for additional project and regulatory oversight. Two additional Challenger drivers will be needed for the mob and demob from Deadhorse and will not be needed 3/13/2006 ~~,~ 6 Statement of Work during the well plugging portion of the project. These work shifts can be found in Attachments 11 and 12. Certain workers will be required to provide documentation of current certification or documentation in (1) 40 Hour HAZWHOPPR and concurrent 8 Hour Refresher; (2) Fit for Work Statement. 8 -Fuel Use and Supply Rough estimations of fuel usage are at a maximum 2000 gallons per day of diesel for vehicle, equipment and camp usage and a total project consumption of 32,000 gallons of diesel. Fuel tanks and portable fuel sloops maybe available during FEX L.P.'s operations for the Simpson Core Test well plugging operations. Fuel may also be mobilized into the site by either air or ground support prior to commencement of well plugging operations. 9 -Water Use and Supply A supply of lake water from a permitted source will be needed for ice pads, well plugging, and camp operations. A snow melter will be necessary at the well locations. A pump will be required along with associated hoses to transport the water from the snow melter to the Connex with the water tank. Permitted volumes are up to 50,000 gallons per day for 10 days for a total of 500,000 gallons. 10 -Air Support Government cost estimates were developed assuming air support would include flights by Twin Otter, Cessna Caravan, Dash-8 or like aircraft for personnel transport. Flights through ERA Aviation may be available from Anchorage to the ice runway at the FEX L.P. drilling locations. Additional air support may come in the form of either L-382 or DC-6 for fuel and equipment supply. In case of a medical emergency, a medical emergency flight should be available to move a person or persons to the nearest available medical facility. 11 -Equipment The following equipment is what will be required to accomplish the project. The contractor is encouraged to think of alternatives if it will improve the quality of the project and reduce costs. Flat-bed Trailers Flat-bed trailers with rubber tracks (Marcep trailer or equivalent) will be used as the platforms from which the well plugging operations will take place. A total of four trailers will be necessary for the entire duration of the well plugging operations. The trailers should have dimensions of at least 8' x 40' trailers. The maximum load expected for any of the trailers will be 42,000 lbs. 3/13/2006 $~,~ 7 • Statement of Work Heaters Two Chinook 800 or equivalent heaters will be needed during the project. Light Plant One 6 Kilowatt portable light towers will be needed during the project. This will be supplied by the USGS out of Deadhorse. Cat Camp A four-man mobile trailer with generator, bathroom, kitchen and four beds will be needed at the wellsites for the entire duration of the project. Fuel Sloops Two 5000 gallon fuel sloops will be needed during the operations. Pumping Equipment The pumping equipment should be capable of pumping a cement slurry into the well by mixing water and cement sacks in a hopper and pumping cement down pipe at a maximum surface pressure of 300 psi into the wells to achieve the desired 100-150 feet cement plug. This grout pump will be supplied by the USGS out of Deadhorse. Mixing Tank A heated water tank will be required to hold at least 300 gallons of water and provide heat to the water to raise the temperature uniformly to 80°F. This water will be used for making the cement slurry. A second 300 gallon tank will be used to temporarily hold displaced fluid from the well before entering the heated tank. Connexes The necessary pumping and mixing equipment should be placed in connexes to provide adequate shelter from the elements. The connexes should be no more than 21 feet long and 8 feet wide to both fit on a flat-bed trailer with other equipment and provide some protection from the elements. Lighting and heat will be necessary inside the connexes. Disposal Tank A double-walled tanks capable of holding 5000 gallons should be used to store displaced fluids from the wells including crude oil, brine, drilling muds and cement rinseate. This tank should be transported to the site bylow-pressure ground vehicle. Safety Equipment Necessary safety equipment includes proper PPE, certified fire extinguishers and rental of complete gas detection equipment and protective masks. Satellite or radio communications will be needed for possible emergency situations. Medical personnel should be trained in CPR and First Aid. 12 -Materials 3/13/2006 BL,M 8 • Statement of Work The following materials are what will be required to accomplish the project. The contractor is encouraged to think of alternatives if it will improve the quality of the project and reduce costs. Cement Artic LiteCRETE has been chosen because of its permafrost capability, its lower density of 10.5 - 12.5 ppg, and the ability to create an impermeable plug between the well bore and the surface. Approximately 294 sacks (65 lbs/sack) of Arctic LiteCRETE cement would be used to set the surface plugs in most of the wells. The cement should be brought to the Simpson wells in dry form in sacks on pallets of 42 sacks per pallet. For heavier cement needed in Simpson Core Test #26, Arctic Set I cement with a density of 15.8 ppg will also be needed for setting of balanced plugs in this well. The amount of cement needed is 210 sacks (65 lbs/sack) of Arctic Set I. All cement will be purchased by the USGS or BLM and will likely be flown into the location. Barite Barite in 50 lb sacks will be needed for well circulation procedures. At a maximum, a total of 420 sacks or 10 pallets will be needed. All barite will be purchased by the USGS or BLM and will likely be flown into the location. Gel Bentonite gel in 50 lb sacks will be needed for well circulation procedures. At a maximum, a total of 420 sacks or 10 pallets will be needed. All gel will be purchased by the USGS or BLM and will likely be flown into the location. Bridge Plugs A bridge plug, cement retainer or similar plug will need to be set in all of the wells at varying depths within the casing of each well. Any associated equipment needed for setting of the plugs will need to be brought to the well locations on the appropriate trailer. All plugs will be purchased by the USGS or BLM and will likely be flown into the location. Piping Needs Associated flowlines, including check valves, pipe elbows, tees, and flow nipples will be required. Pipe lifting equipment will be a Christensen CS1000 P6L coring rig (see Attachment 13) provided and used by the USGS drilling crew. Light weight steel pipe for use in running plugs and spotting cement will be provided and used by the USGS drilling crew. Attachment 5 shows the bottomhole assemblies (BHAs) that will be used during the project. All pipe for rig use will be purchased by the USGS or BLM and will likely be flown into the location. Well Control 3/13/2006 BL,M "~' i Statement of Work Adequate well control equipment will be provided by the USGS drilling crew to insure proper well control is maintained at all times during well plugging operations. Attachment 6 details the wellhead components (WI3Cs) that will be used on each well. All well control will be purchased by the USGS or BLM and will likely be flown into the location. Spill Prevention Adequate spill prevention materials should be placed on the ice pads to prevent any spilled fluids from draining off the pad into the surrounding tundra. Additional spill prevention materials such as duck ponds should be used underneath all idling vehicles. Tarping/Scaffolding To provide protection from wind and the elements, tarps will need to be set across the tops of the connexes with a small opening available for the rig mast. Other tarps will be set up across the front and back of the connexes to help insulate the coring rig and USGS drilling crew during well plugging operations. Fluid Pumps Fluid pumps will be necessary to move water from the water tank to the pumping equipment. Additional pumps may be necessary for fuel transfers, water pumping, and wellbore fluid transfers to disposal tanks. 13 - .Vehicles The following vehicles are what will be required to accomplish the project. The contractor is encouraged to think of alternatives if it will improve the quality of the project and reduce costs. Steiger Stx375 One of these vehicles will be used during mobilization and demobilization to the wellsite and/or camp. It will be responsible for assisting in pulling trailers and fuel sloops. Challenger Three of these vehicles will be used during mobilization and demobilization to the wellsite and/or camp. They will be responsible for assisting in pulling trailers and fuel sloops. Two vehicles will be on stand-by during the well plugging operations. Volvo A25 Two of these vehicles will be used during mobilization and demobilization to the wellsite and/or camp. Both will be responsible for construction of the ice pads. After construction of the ice pads, one Volvo will be dedicated to transporting water and one Volvo will be responsible for holding the disposal tank and moving it from site to site. Tucker Sno-Cat 3/13/2006 BL,~ 10 ~, _ Statement of Work • This vehicle will be used to move personnel between wellsites and the camp location. One Tucker Sno-Cat will be necessary and should be able to transport at least five people, preferably 12 people. 14 -Well Plugging Procedures The well plugging procedures for each well will be detailed in the following section. Well plugging operations will be conducted using the Christensen coring rig mounted on the back of a challenger trailer and will operated by the USGS drilling crew, with occasional assistance from other project staff. A diagram and photo of each well is shown in Attachment 1 and a current wellbore diagram is shown in Attachment 2. The method used in setting plugs is shown in Attachments 3. The required bottomhole assemblies (BHA) and wellhead components (WHC) used are shown in Attachments 5 and 6. A step-by-step procedure for each well is as follows: 1 S -Wellbore Fluid and Waste Disposal It will be necessary to displace fluids from the wells. This displaced fluid will be a mix of crude oil, brine, drilling muds and cement rinseate. The fluid should be stored on location in double-walled tanks until demobilization. The fluid will then need to be disposed of in an approved location either on the North Slope or Fairbanks area. The anticipated fluid volume is 2500 to 5000 gallons. 16 - Wellhead Removal After the conclusion of cementing procedures, the wellheads will not be removed due to the historic nature of both the wells and the oil seeps. If the wellheads are altered in any fashion, they must be returned to the original configuration and appearance after the conclusion of operations. Equipment necessary to alter the wellheads may include welding torches, saws, or non-combustible methods for hot work. 17 - Attachments Attachment 1-Wellhead Diagrams and Photos Attachment 2 -Current Wellbore Diagrams Attachment 3 -Proposed Well Plugging Attachment 4 -Deleted Attachment 5 -Bottom Hole Assemblies Attachment 6 -Wellhead Components Attachment 7 -Route Map 3/23/2006 BLM 11 ~,~ Statement of Work • Attachment 8 - Wellsite Layout Attachment 9 -Equipment Spread Attachment l0a -Project Timeline, March Attachment lOb -Project Timeline, April Attachment 11 - A.M. Working Shifts Attachment 12 - P.M. Working Shifts Attachment 13 -Christensen CS1000 P6L Coring Rig Specifications Attachment 14a -Deleted Attachment 14b -Deleted Attachment 15 - Wellbore Fluid Volume Diagrams 3/23/2006 $L,~/( 12 ~~~~~ ~~~~Q~es ii ---~ I`; ~: ~; ~~~ ~: 2 1/2"'IdX:Drilt Rods ~ 1/2" Sub. 7.718°' Drill .Bit 2 'I/2"=I~iX:Drill'f~ods fi/4" Control Lane Adapter sub ~ 9/2" lnflatabfe Packer 3l'1312Q~6 ~ ~ ~ 39 BH;~ #2. Attachment 6 ___ ~ ~ ~ i.r; ~~,1 ~~ IF~ J ~~_ a -_- << ~ _ :I j ~ }/ \T\~ ~' I ii WHC #1 8 518" flange w/ gasket 2 threaded side outl~;t „8 5/>)" casing riser 8 5/l3" flange w/ gasket WHC #2 2" threaded line piK,e 2" gate valve 2" threaded line pipe WHC #3 2" threaded bleed valve 1/4" pressure gauge WHC #4 tubing slips pack-off 2" threaded pipe WHC #5 2 ball valve 3" flow tee 2" ball valve 2' threaded line pipe Wellhead Components Wells: =',,;,~ - - ~„ Simspon #26 \\- Wells: Simpson #27 ! WHC #6 s.wL~: ~ ~~ `~- 8 5/8" flan Simpson #30 Simpson #30 4 ~ ,,~ 9e Simpson #30A ~ 10 3!4" x 8 5/8" swedge Simpson #31 ,,. 10 3/4" flange ~' f } 10 3/4" flange w/ gasket 10 3!4" casing w/ packing Wells: ~''~ - Simspon #26 (x2) ~. Simpson #27 Simpson #30 ~ Simpson #30A ~' 'i~`j~ WHC #7 Wells: Simpson #31 ~-^- '_ 2" ball valve Simpson #30 2" threaded Simpson #31 Wells: ~ 8 5/8" x 2" swedge Simspon #26 ;~ ea."`~"'~"~' '~ 6 5/8" flange Simpson #27 r, f~' Simpson #30A WHC #8 Wells: Wells: ~ ~,~ -. 8 5/8" flange welded Simpson #30A Simspon #26 onto Simpson #30A Simpson #27 ~° Simpson #30 ~ ` , ,~~, WHC ~ Wells: 3 1/2" tubing slips Simspon #26 Simpson #30A Simpson #27 Simpson #31 Simpson #30 Simpson #30A • Wells: Simpson #31 Simpson #27 Simpson #30A $~~ - 40 3/13/008 Attachment 7 • • Route Map BLM 3/13/2006 ~ 41 Attachment 8 Wellsite Layout Cape Simpson • • I Ice pad I I 1 60' tall ~ I 1 80' wide I I I I I I 1 r Spill Control .................................................................................................................... I I I I 1 I ~ I I 1 I I ~ ( i _. Stairs I I ! I ~ ` f 1 1 I ~ F~ ~ r l a w 'q p ~. k x r ~ A 1 I ~ ,. 4 d i~"~T9 N'SP{ 7 4 ( d I I y yc, +~ ~ ~, atMS.n l ~ WF t I Clrc Tank ~ I 1 I I ~t ~Y) l~tj.~ wrt ~ 1 ~.. I ~ A ~ ~ ~ .. I I "",s.~ I .~, ~. ~ x Nr Compressor ~ ~ t I 1 BLM Carlnp Rly I lnvnrMrt I 1 I I I i :_'_' Up{wr Mu i .. .r-. __.__,. _..-._-__~ - I . .i,Pd15'~ ' 1 I I Tank __ 1 I ~ ~ ~ I II .to7 ~ J+1:? I 1 Grout Pump ~ I I I 1 jX7i L-~~ 1 l )i[7iYc I I I I I ~ . I ~ I I , I I ~ ~ Stairs I I I I I ~ I I I . I 1 1 I .................................................................................................................1 I I I I I 1 I I I I I I I I I I 1 1 I I I I I t I 1 I I I I I !__~____~______________________ _~_~~________________________~~~___~_~_____~___________~_________~______~_____e____1 3/13/2006 Legend Feet BLM ~ ~~ o s ~o ~s xo 42 Attachment 9 Equipment Spread Cape Simpson • Drivers: 1.) Project Manager 2.) Volvo A 3.) Volvo B 4.) Steiger 5.) Challenger A 6.) Challenger B 7.) Mechanic ®Q0~ A25 Volvo A2S Volvo BL_M 3/13/2006 '~ ' ~ - ~~~~ ~~ • Sun Mon • 5 12 6 13 Tue 14 Wed 1 C: 15 2 9 16 3 10 17 19 20 21 22 23 24 26 27 28 29 30 31 USGS Deadhorse Deadhorse Deadhorse Deadhorse Cape Simpson DEl®1 to Al®1C Mob Day #1 Mob Day #2 Mob Day #3 Mob Day #4 Mob Day #1 Cape Simpson Project Schedule As of 3/08/06 Sat 4 11 18 25 • • ' ~ 11. Sun Mon 2 Cape Simpson Mob Day #3 9 Cape Simpson Work Day #7 16 23 30 3 Cape Simpson W®rk gay #1 10 cape limpson Work 1)ay #~ 17 24 Tue 4 Cape Simpson Work I)ay #2 11 Cape Simpson Work Day #9 18 25 Wed 26 Thu 27 Fri 28 29 Cape Simpson Project Schedule As of 3/08/06 Attachment 11 Work Shifts A.M. Hours Shift Name 0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00 4:30 5:00 5:30 6:00 6:30 7:00 7:30 8:00 8:30 9:00 9:30 10:00 10:30 11:00 11:30 Work period 'Overlap BLM 3/13/2006 ' '' " ' 45 Attachment 12 Work Shifts P.M. Hours Shift Name 12:00 12:30 13:00 13:30 14:00 14:30 15:00 15:30 16:00 16:30 17:00 17:30 18:00 18:30 19:00 19:30 20:00 20:30 21:00 21:30 22:00 22:30 23:00 23:30 1 Project Manager . , __ 1 ... Steiger Driver 1 Volvo Driver 1 Mechanic _ : 1 ........ .Medic... 1 _,. .. r ..._. BLM Surface 1 BLM Subsurface 1 .,.._,_ , USGS Boss 1 Bull Cook . , _ , 2 Challenger Driver ~ ~` 2 Volvo Driver ~~~a " k. ~,~ 2 BLM Surface ~~tr3 t_ , 2 BLM Subsurface t ~~`: ~ €~, _ 2 USGS Boss ` 2 USGS Crew ~ ;r, t ~' ~~ u _. 2 USGS Crew _ _. x ~ .N s ~ . 2 USGS Crew _ ,. ~ .. E ~. a~ 5 TL . ... .. ~_ ~ Legend F Work period :Overlap ;i *,~. .... y BLM 3/13/2006 45 • • Christensen CS1000 P6L Core Drill C DEPTH CAPACITY CORING (WIRELIKE OR CONVENTIONAL) B WIRELIKE 4,500 FT (1,370 M} N WIRELIKE 3,500 FT (1,070 M) H WIItELINE 2,400 FT (730 M) P WIRELIKE 1,300 FT (400 M) DEPTH RATINGS ARE BASED ON VERTICAL AND DRY HOLE MAIN HOIST SINGLE LIIvE CAPACITY: BARE DRUM 12,000 LB (5,443 KG) DOUBLE LINE CAPACITY: BARE BRUM 24,000 LB (10,886 KG) LINE SPEED: BARE DRUM 132 FT/MIN (40 M/MIN) CABLE SIZE: 110 FEET (335 M) x 9/16IN (14.3MM) WIRELIKE CAPACITY: 6,000 FT (1,830 M} OF 3/16IN (4.76 MM) 3,200 FT (975 M) OF if4 IN (6.35 MM) LIMB PULL BARE DRUM: 2,500 LB (1,134 KG) LINE PULL FULL DRUM: 700 LB (318 KG) LINE SPEED: BARE DRUM 390 FT/MIN (i 19 M/MIN~ FULL DRUM 1,500 FT(MIN (457 M/MIN) MAST AND FEED SYSTEM FEED TRAVEL: 11.5 FT (3.5 M) FEED SPEEDS: FAST ARID SLOW WITH VARIABLE CONTROL THRUST: 12,250 LB (5,556 KG) PUZL: 20,000 LB (9,070 KG) DRILLING ANGLE: 45 TO 90 DEGREES ROD PULL LENGTH: 20 FT (6.09 M) POWER UNIT MFG.: CUMMINS MODEL: 6BTA 5.9 LITER 6 CYLINDER POWER: 175 HP (131 KW) RPM: 2,500 ENGINE TYPE: DIESEL TURBOCHARGED/AFTER COOLED COOLING: WATER OTHER ENGINESAVAILABLE ONREQUEST HYDRAULIC SYSTEM PRIMARY PUMP: 3,500 PSl-43 GPM (24.1MPA-162 LPM) SECONDARY PUMP: 3,000 - 15GPM (20.6 MPA - 56 LPM) AUXILIARY PUMP: 2,500 PSI - 8 GPM (17.2 MPA - 30 LPM) HYDRAULIC OIL COOLING: AIR DRILLHEAD AND SPINDLE SPEEDS POWER: HYDRAULIC MOTOR-VARIABLE SPEED/REVERSIBLE FINAL DRIVE: 4IN HV CHAIN DRIVE IN OIL BATH-2.5 RATIO SPIDIDLE: 4 5/81N (117MM) SPINDLE SPEEDS: GEAR RATIO SPEED (RPM) TORQUE, FT LB (NM) 1 ST 6.63:1 130-196 3,232-2,218 (4,382-3,007) 2ND 3.17:1 270.410 1,545-1,060 (2,095-1,437) 3RD 1.72:1 500-756 839-575 (1,138-780) 4TH 1.00:1 857-1,300 488-335 (662-454) RANGE SELECTION: MANUAL CONTROL FROM OPERATOR'S STATION HINGED HEAD: SWING AWAY CHUCK ASSEMBLY TYPE: HYDRAULIC OPEN, SPRING CLOSED MAXIMUM INSIDE DIAMETER: 4 5/8 IN (117MM) HOLDING CAPACITY: 40,000 LB (18,143 KG) DRILL BASE SUPPORTS QUANTITY: 4 PAD DIAMETER: 12 IN (305 MM) TRAVEL LENGTH: 12IN (305 MM) • WEIGHT HIGHWAY FLY-IN MAJOR TOTAL WET TOTAL WET COMPONENTS WET 9,205 LB (4,176 KG) 8,605 LB (3,904 KG) 8,120 LB (3,683 KG) DRILLHEAD: 1,040 LB (472 KG) 1,040LB (472KG) 1,040LB (472KG) DRILL BASE: 680 LB (309 KG) 680 LB (309 KG) 680 LB (309 KG) LOWER MAST: 2,000 LB (908 KG) 2,000 LB {908 KG) 2,000 LB (908 KG) UPPER MAST: 800 LB (363 KG) 800 LB (363 KG) 800 LB (363 KG) ENGINE COMPONENT WET: 1,500 LB (681 KG) 1,500 LB (681 KG) 1,500 LB (681 KG) HYDRAULIC COMPONENT WET: 900 LB (408 KG) 900 LB (408 KG) 900 LB (408 KG) DRAW WORKS COMPONENT INCLUDING CABLE: 1,200 LB (545 KG) 1,200 LB (545 KG) 1,200 LB (545 KG) TOWING PACKAGE & MISCELLANEOUS FUEL TANK WET: 125 LB (57 KG) 125 LB (57 KG) BATTERY BOX & BATTERY: 134 LB (61 KG) 134 LB (61 KG) DRILL BASE SUPPORTS (4): 100 LB (45 KG) 100 LB (45 KG) OPERATOR'S PLATFORM: 22 LB (]0 KG) 22 LB (10 KG) MUD TANK OUTRIGGERS (4): 104 LB (47 KG) 104 LB (47 KG) WHEELS & STUB SHAFT (4): 400 LB (182 KG) HITCH: 200 LB (91 KG) DIMENSIONS LENGTH WIDTH HEIGHT DRILL BASE: 114 IN (2,896 MM) 64 IN (1,626 MM) 58 IN (1,473 MM) LOWER MAST: 200 IN(5,080 MM) 26 IN(660 MM) 33 IN(838 MM) UPPER MAST: 145 IN(3,683 MM) 21 IN(533 MM) 29 IN(737 MM) ASSEMBLED MAST: 28.8 FT (8.8 M) DRILL HEAD: HORIZONTAL VIEW 31 IN (787 MM) x 44 IN (1,118 MM) VERTICAL VIEW 21 IN (533 MM) x 44 IN (I,118MM) ENGIiVE COMPONENT: 43.5 IN (1,105 MM) x 49 IN (1,245MM) x 29IN (737 MM) HYDRAULIC COMPONENT: 37.5 IN (953 MM) x 49.5 IN (1,257 MM) x 29 IN (737 MM) DRAW WORKS COMPONENT: 27.8 IN (706 MM) x 56.5 IN (1,435 MM) x 26 IN (660 MM) STANDARD EQUIPMENT -HYDRAULIC MAST RAISE -DERRICK IN TWO SECTIONS -TOWING PACKAGE -FUEL TANK 34 GAL (125 L) -HYDRAULIC OIL RESERVOIR FII.L -FUEL FILTER & WATER PUMP & FILTRATION SEPARATOR OPTIONS -HYDRAULIC P-SIZE HOLDING CLAMP -SINGLE, LARGE DIAMETER MAIN HOIST SHEAVE -HYDRAULIC DRIVEN MUD PUMP FMC W1122BCD MAX FLOW: 37 GPM (140 LPM; MAX PRESSURE: 700 PS 1 (4.9 MPA) -HYDRAULIC MUD MIXER -MAST LIGHTING KIT -HYDRAULIC JACKS -SKID MOUNTING -CRAWLER MOUNTING ALL WEIGHTS AND DIMENSIONS ARE APPROXIMATE AND SUBJECT TO CHANGE Atlas Copco Exploration Products 640 McKeown Avenue, North Bay, Ontario Canada Tel (705) 472-3320, Fax (705) 472-6843 Attachment 15 Wetlbore Fluid Volumes • i p+q l ~aaa ~'~~ 13.08 t>a 9 ~. iz~..:.,.-~~~, } : i 8.825 in tag ,.: ~~ %:? - 28.OOIfrrYft ~ 350 ft ~ i atria '1493 hd - f ~~/~,~~~ - `~ ~% Arcre sac wa wa~i ca>;ha sa 26 350 37.05 27 720 27.35 30 150 33.51 30a 100 22.34 31 101 22.55 SftRt Total Cament Totals 14280 SF = 1.5 214 Pallets 5 Oroered B Arctic Sef Life cao,a~c rasa a.4a 1c3ra, 1.568 ft3/sx 11.7322174 affiisz BLM 3N 3/2006 1-i•~QIIC$1OOiC'° - "a rm~k of Schlurrberga~ Simp Core JK1O p+p I-~'IOII~OOiC" - *a rfv~k of Schlurku~ga s~^-. v'J _o~°~~. 3~.~,~m~:.~~~ .,~.,~, ~ s~ ~d~nutact~rers ri Rot~t~ne~ r1;:a~s ;+n~ J~v~rters try Fir ual, Cas, 3:n~ G~th~r~nal ~rillin3 • Model 3022 DIVERTER SYSTEM • f -...: ~~: ~,}_. « i • !~ '_ ~:`:' The 3022 with stripper rubber open and compression dock attached Cal! or s`nd us your inquiry for pricing. The 3022 with stripper rubber closed and compression lock attached tatle a CLICK HERE FOR DIMENSIONS BACK TO DIVERTECH MODELS The 3022 Diverter is manufactured to work on your casing. It can be flanged to casing, threaded on casing, or can be made up with the compression lock system, which is simple and foolproof. Simply slide the diverter over casing and tighten 3 to 6 bolts on compression ring. The rubber rings enclosed are then compressed around your casing providing aslip-proof lock and seal on plastic casing as well as steel. It utilizes the 3010 series stripper rubber. Because of the 3010's two- piece construction, bit and/or hammer can be lowered into casing by simply opening the stripper rubber, passing the tool, and closing back around drill pipe. Drill cuttings are now contained and diverted to desired location through the flow line. Compte ~n -~ [HOME] (ABOUT US] [OUR PRODUCTS] [CONTACTING US] [SEND US YOUR INQUIRY] [EVENTS] .~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ a x ~' s ~ > ~ ~~ FRANK H. MURKOWSK/, GOVERNOR ~/~7~ OIL ~ ~ 333 W. 7"' AVENUE, SUITE 100 C011TSER~A'1`IO1~T CODII~i155I0I~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Stan Porhola FAx (907) 27s-7sa2 Petroleum Engineer Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507 Re: Cape Simpson Area, Simpson Undefined Oil Pool Simpson Core Test Well #26 PTD: 100-186 Sundry: 306-100 Simpson Core Test Well #27 PTD: 100-187 Sundry: 306-101 Simpson Core Test Well #30 PTD: 100-190 Sundry: 306-102 Simpson Core Test Well #30A PTD: 100-191 Sundry: 306-103 Simpson Core Test Well #31 PTD: 100-192 Sundry: 306-104 Dear Mr. Porhola: Enclosed are the approved Applications for Sundry Approval relating to the above referenced wells. Please note the conditions set out in the enclosed forms. The Commission strongly encourages the BLM's efforts to plug these legacy wells. Proper well plugging serves multiple purposes. These include isolation of fluids to their native formations for environmental and conservation reasons, protection of fresh water, and isolation of the wells from the surface environment. The work at Cape Simpson is complicated by the remoteness of the location, the age of the wells, and the potential presence of hazardous materials in the wellbores. Based upon our previous meetings we understand that the proposed work plans submitted in the Sundry applications are a practical alternative to isolate old wellbores from the surface environment. 1 These plans do not represent a proposal to fully abandon the wells. Rather, they have a more limited purpose: to manage the most pressing problems or potential problems associated with the wells' current conditions. Additionally, we understand that placing surface plugs as planned will not preclude your re-entry into the wells at some later date for additional plugging and abandonment operations. Accordingly, approved copies of 1 See attached correspondence. • copies of the Sundry applications for Simpson Core Test Wells #26, #27, #30, #30A, and #31 are attached. Please note that the Commission's records will classify these wells as having surface plugs, but not as abandoned. Abandonment requires: • Downhole and surface plugs in accordance with 20 AAC 25.112; • installation of an abandonment marker in accordance with 20 AAC 25.120; and • clearance of the location in accordance with 20 AAC 25.170. As a condition of this approval, BLM must provide to the Commission a Report of Sundry Well Operations (Form 10-404) and history of operations for each of the above referenced wells within 30 days of the completion of plugging operations. When providing notice for a representative of the Commission to witness any required test, please contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of April, 2006 Encl. • `- -~- ~ ~ ,_ _ .__.W .- _ _; -_ FRANK H. MURKOWSK/, GOVERNOR OW ~ ~ 333 W. 7'" AVENUE, SUITE 100 CO~TSEItVATI011T COAIMISSIOlY ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 April 21, 2004 Mr. Greg Noble Mr. Stan PorhoIla Mr. Steve Martinez Bureau of Land Management Campbell Track Facility 6881 Abbott Loop Road Anchorage, AK 99507-2599 Re: Proposed Plugging of Wells at Umiat Umiat #6 PTD: 100-214 Sundry: 304-115 Umiat #8 PTD: 100-216 Sundry: 304-117 Umiat #9 PTD: 100-217 Sundry: 304-116 Umiat # 10 PTD: 100-218 Sundry: 304-114 Gentlemen: On April 20, 2004 a meeting was held between staff members of the Alaska Oil and Gas Conservation Commission ("Commission") and the Bureau of Land Management ("BLM") at BLM's office. The purpose of the meeting was to discuss upcoming work to place surface plugs in the referenced wells. This meeting followed earlier oral discussions and a-mail correspondence with Commission staff concerning this project as well as discussions with Commission staff on April 15 and 16, 2004. I want to thank you for meeting with Commission staff members to discuss the planned work. At the meeting, an approved copy of the proposed abandonment plan for Umiat # 8 was delivered. Please note that the Commission's records will probably not classify this well as abandoned, since the location clearance requirements in connection with well abandonment include removal of the wellhead and installation of an abandonment marker in accordance with 20 AAC 25.120 and 25.170. Discussions have indicated that since these wells were drilled more than 50 years ago, they require protection as historic sites and therefore the wellheads are to be reinstalled. If your plans change in this respect, please let us know so our records can be updated accordingly. With regard to the remaining well plans, the most recent meeting has allowed the Commission to confirm the study and preparations BLM has made to design workable plans to place surface plugs in the remaining wells. The Commission initially had concerns that the plans as proposed would not meet Alaska plugging requirements at 20 AAC 25.112. Proper well plugging serves multiple purposes Thee„include isolation of fluids to their native formations for env,~F~onrz~~.tah~°a~ck' conservation • Stan Porholla April 2 I , 2004 Page 2 of 2 reasons, protection of fresh water, and isolation of the well from the surface environment. The work at Umiat is complicated by the remoteness of the location, the age of the wells, the potential presence of hazardous materials in the wellbores and on the surface, and realistic appropriation limits. During the meeting yesterday, the geology, well construction and present condition of all 11 Umiat wells were reviewed and the proposed work for each well discussed, along with available funding. As represented to Commission Staff, the proposed work plans submitted in the Sundry applications are the most practical alternative to isolate the old wellbores from the surface environment. We now better understand that the work plans do not represent a proposal to fully abandon the wells notwithstanding incomplete plugging. Rather, the work plans have a more limited purpose, to manage the most pressing problems or potential problems associated with the wells' current conditions. Placing surface plugs as planned will not preclude re-entry into the wells at some later date for additional plugging operations. Accordingly, approved copies of the Sundry applications for Umiat #6, #9 and # l0 are attached. The Commission strongly supports your efforts to plug and abandon these legacy wells and we stand ready to assist in any w an. Please feel free to contact the Commission staff at any time to discuss o mate this or any future well work. man, ~~_: a ,_.~ ,~ ,_ ., _._,-~ Simpson Core #30 Subsurface Report • • U.S. Department of the Interior Bureau of Land Management Well Plugging and Abandonment Summary For Simpson Core Test No. 30 Operator: US Navy Well Name and Well#: Simpson Core Test No. 30 Location and Field: LAT- 70°55'51" N. LONG-154°40'35" W ( WGS 84 70 55 586----154 42 282 ) Spud Date: 11/30/1950 Completion Date: 1/23/1951 Total Depth: 693' Effective Depth: 693' Hole Size: 3 7/8"- 5 7/8" T.D.M.W.: 9 ppg Special Mud Additives/Concerns: ? Status: Junked and Abandoned Plug and Abandonment Date: 1/23/1951 Surface Equipment/Status: Open Casing 6" above ground level file:///D:/SCore30.htm1 Casing Hole Size Casing Size Weight Grade Depth Cement Conductor Surface 8 5/8" 28# 150' 63 Sacks Cal Seal Intermediate Intermediate Production Tubing Well Remarks: 1 of 2 4/10(2006 9:23 AM Simpson Core #30 Subsurface Report file:/l/D:/SCore30.html Ice, made hole tight throu bout drilling, twisted off drill i e at 30{1' -Fished 2 da s tried to drill ast g pp Y p fish -bit followed old hole, mixed up cement which flash -set in tank and pump- six days circulating and cleaning pump Hole filled with drilling mud Last visit 9/15/2001 Plug Remarks: 285'- 3I5' -Set plug (6 sacks Cal Seal) Copies/Drawings of: A. ~~'ell :Bore Schematics B. Completion Reports C. Abandonment Head 2 oft 4/10/2006 9:23 AM a' 20fl' 1000' Simpson Core Test 30 • • 283' After waiting 6 days for cement, hole reamed free of ice and 8 518°. 28» casng was set at 150' wi63 sx of Cal-Sea!. Hole bailed to bottom of casing to prevent freezing while cement set. 429' Ice fom~ed in the hole and had to be reamed out several times. 2.5 days spent freeing drill pipe stuck at 80' bemuse of a loose double, jammed between drill collar and casing 630' tce continued to make hole tight, in spite of intermittant mud heaiings 693' (TD) Twisted off drH pipe ai 300', leaving core barrel and drill pipe in hole. Fished 2 days. circulated mud 6.5 days waiting for tools from Barrow camp. Set plug of six sacks of Cal Seai at 285'-315' and drifted past fish; bit kept following old hole -would not dritl past fish ai 388'. Mixed 72 sacks of Cal-Seal; mix flash set in tank and pump. Spent 6 days circulating, while cleaning and repairing pumps. Attempts to whipstock were unsuccessful because the bit hit the fish, and the hole was abandoned. Open casing projects 6' at:~ave ground levet, and the hole is filled with drilling mud Attachment 2 i Simpson Core Test #30 Current Wellbore Diagram - Ri : Failing 1500-S Rotary Rig ~ Simpson Core #30 S ud: November 3Q 1950 Meridian Township Range Section Barrow - - _ Simpson Core Tests Umiat ' 18N 11 W 11 25' AMSL 54 mi asuk At ~°:, A GL: 20 MSL KB: g Current Wellbore Schematic 70° 55.571' N - 154° 42.320' W 71 mi vnymai nno - a.v .+uvo v~ Casing and Tubing Detail f~~ ' '.; . Size Wei ht T e Grade ID To Btm R ` 63 sx of Cal-Seal 8 Sl8" 28 Conductor --- 8.017" 0 152 ' ' Drilling Fluids Base Depths Weight Additives Water 0-283 9.2-9.9 -- Water 283-303 9.5-9.6 -- • • , Water 303-429 8.7-9.2 - ' ~ Water 429-630 9.0-9.1 Mud heated . . •' •' " . . ° . Depth: Water 630-693 9.0-9.2 Mud heated { 0 B : '.' 263'-283' Water 693 8.7-9.0 Mud heated ~• ~ • • ® ~ ~ • Depth• ,,..... . . . ~,~ , , .• r 283 350 Geology • Depth: Formation A e De the Shows 0'-350' Gubik Quaternary 5-85 - •. Depth: Seabee Upper Cretaceous 85-143 ~ ' ~ ~ ' ' Unconfonnity -- 143 • • • ~ ;~ ' 408 319 Ninuluk/Seabee Undiff Upper Cretaceous 143-445 OiUGas ~ Depth: Grandstand Lower Cretaceous g45~93 Oil ' ' ' ~ ~ 451'371' Base of Permafrost -- - ` . . . E ' 565' ~ ii .:~ ' ' Fish/Fill Information ;: ' ,' Item Date Depth Comment . G Depth: h l l ft i : ~ ~ 584'-590' A 1/23/51 o e e n Surface Rotary Drilling Mud : :~ g 388' Core barrel and DP ~. O Depth: 820'37 ' PBTD = 693' Max production = 6 bbllday Drilling Mud • Oil produced Gas produce Cal-Seal Gypsum cement Fluoresence-Cut • THIS REPORT IS FILED Ili WELL FILE 1fl0-486 Core Tests Simpson Area, Alaska By FLORENCE M. ROBINSON Kith a section on Temperature Measurement Studies By MAX C. BREWER EXPLORATION OF NAVAL PETROLEUM RESERVE NO. 4 AND ADJACENT AREAS, NORTHERN ALASKA, 1944-53 PART ~, SUBSURFACE GEOLOGY AND ENGINEERING DATA GEOLOGICAL SURVEY PROFESSIONAL PAPER 305-L Prepared and published at the request of and in cooperation with the U.S. Department of the Navy, O~ice of Naval Petroleum and Oil Shale Reserves UNITED STATES GOVERNMENT PRINTING OFFICE, WASH INGTOi~T 196 • THIS REPORT IS FILED IN WELL FILE 10~-0~~~ Natural Landmark Site Evaluation -Alaska 1979 SIMPSON SEEPS National Petroleum Reserve-Alaska CX-9000-7-0052 Steven B. 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