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100-117
• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned E] - Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ EXploratoD Service ❑ Stratigraphic Test ❑✓ ❑ 2. Operator Name: Bureau of Land Management 6. Date Comp., Susp., or Aband': 3/17/2018 14. Permit to Drill Number/ Sundry: 100-117.0 3. Address: 222 W. 7th Ave., #13, Anchorage, AK 99513 a Spudded: 4/29/1951 15. API Number: 50-119-10008-00-00 4a. Location of Well (Governmental Section): Surface: 4,735' FNL, 3766' FWL, T1S, R7W, S2 ,Umiat ly'7ib 90.3: Lat: 69.3782208109, Long: -153.507909785 Top of Productive Interval: Lat: 69.3782208109, Long: -153.507909785 Total Depth: /4;40 9 Lat: 69.3782208109, Long: -153.507909785 (,,•2(�- 1p' 8. Date TD Reached: 6/4/1951 16. Well Name and Number: Wolf Creek #1 9. Ref Elevations: KB: GL: '%/Z' BR 71 17. Field / Pool(s): NPR -Alaska 10. Plug Back Depth MD/TVD: Surface 18. Property Designation: 4b. Location of Well (State Base Plane Coordinate , NAD 27L Surface: x- 563,868.05 y- 5,622, f Zone 5 TPI: x- 563,868.05 y- 5,622,337.54 Zone- 5 Total Depth: x- 563,868.05 y- 5,622,337.54 Zone- 5 11. Total Depth MD/TVD: 1,500' 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD 5. Directional or Inclination Survey: Yes L (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD N/A VD: 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, perforation record. Acronyms may be used. Attach a separate page if necessary � N/A JUN 19 2018 SCAM XU p 2qui AOGG and 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 11-3/4" 54 J-55 0 48' 0 48' 13-1/2" Cond. cemented to surface 21 sx 24. Openproductionto or injection? Yes No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 01601 -Q A - J l R 25.TUBING RECORD SIZE DEPTH SET (MD) IPACKER SET (MD VD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ N Per 20 AAC 25.283 (i)(2) attach electronic and printed information ❑✓ . DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 0'-59' MD 12.4 bbls 14.7 ppg Class G Arctic in 11-3/4' csg. 59'-123' MD 14.5 bbls 15.4 ppg Class G Arctic in 11-3/4" csg & OH 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: N/A Hours Tested: N/A Production for Test Period Oil -Bbl: N/A Gas -MCF: N/A Water -Bbl: N/A Choke Size: N/A Gas -Oil Ratio N/A Flow Tubing Press. Casinq Press: N/A Calculated 24 -Hour Rate Oil -Bbl: N/A Gas -MCF: N/A Water -Bbl: N/A Oil Gravity - API (corr): N/A Form 10-407 Revised 5/2017 % // CONTINUED ON PAGE 2JUN d X011 �D�/ Sub it ORIGINAL onl R !rl Ah Ah 28. CORE DATA Convention ore(s): Yes ❑ No ❑� Sidewall CorM. Yes ❑ No ❑✓ 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 ' If yes, list intervals and formations tested, briefly summarizing test resulIts. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: 3160-5; Olgoonik Construction Services operations summary; photographic report; wellbore schematic; daily reports. 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Wayne Svejnoha Contact Name: Jessie Chmielowski Authorized Title: Branch Ch' f, E ergy d Minerals Contact Email: jchmielowski@blm.gov Authorized Contact Phone: 907-271-4190 Signatu �..4c:���� Date: & 1-711.0 INSTRUCTIONS General: Th m and the requi2-.tt.'hments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic dia ram 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 1a: 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 1b: 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12340, and/or Easement (ADL 123456) number. 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 5/2017 Submit ORIGINAL Only 0 i CoPp!aflon r r►.. Olgoonik Construction Services, LLC. 3201 'C' Street, Suite #700 Anchorage, Alaska 99503 April 24th, 2018 Bureau of Land Management (BLM) 222 West 7th Ave. #13 Anchorage, Alaska 99513 RE: Sundry Notice (Permanent Abandonment) Well: Wolf Creek Test Well #1 TRS: 4,735' FNL, 3766' FWL, T1S R7W, Section 2, UM Dear Ms. Eagle, Olgoonik Construction Services, LLC. hereby gives Final Abandonment Notice for a Sundry Approval to Permanently Abandon the WC #1 Exploration Well. All work has been completed per the approved conditions of approval as of 3/17/2018. Pertinent information attached to this application includes the following: 1) Form 3160-5 Sundry Application 2) Executive Operations Summary 3) Photographic Report 4) Wellbore Schematic 5) Detailed Daily Operations Reports The following is the OCS designated contact for reporting responsibilities to the BLM: James Nunley General Manager (907) 232-9952 If you have any questions or require further information, please don't hesitate to contact me. Sincerely, Zach Sayers Engineering Manager Foran 3160-5 UNITED STATES FORM APPROVED OMS No. 1004-0137 (lune 2015) DEPARTMENT OF THE INTERIOR Expires: January 31, 2018 5. Lease Serial No. NIA BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS 6.1rIndian, AllonceorTribrName Do not use this form for proposals to drill or to re-enter an abandoned well. Use Form 3160-3 (APD) for such pro osals. NIA SUBMIT IN TRIPLICATE - Other instructions on page 2 7. If Unit ol'CA/Agr",ment, Name and/or No. I Type of Wcli N/A 8. Well Name and No. Wolf Creek Test Well #1 ❑ Oil Well ❑ Gas Well ® Other 2 Name ofOpemlor Bureau of Land Management 9, API Well No. 50-119-10008-00-00 3a Address 222 W. 71h Ave, #13 Anchorage, AK 99513 3b. Phone No. {include area code) 10. Field and Pool or Exploratory Area (907) 271-4354 Wolf Creek, NPR -Alaska 4 Location of Vt'etl (Footage, Sec. T,R ,ht , nrStrn•cr Description) 11. Country or Parish, State 4,735` FNL, 3,766 FWL. TIS, R7W, S2, Umlat / Lat: 69.3782208109, Long:- 153.507909785 North Slope Borough, AK 12. CHECK TILE APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE, REPORT OR OTIIER DATA TYPE OF SUBMISSION TYPE OF ACTION ❑ Notice of intent ❑ Acultze ❑ Deepen ❑ Production (Start/Resumc) ❑ %ater Shut -Off ❑ Alter Casing ❑ Ilydmulic Fracturing ❑ Reclamation ❑ Weil Integrity 0 Subsequent Report ❑ Casing Repair ❑ New Construction ❑ Rccomplete ❑ Other ❑ Change Plans © Plug and Abandon ❑ Temporarily Abandon ❑ Final Abandonment Notice F-1 Convert to Injection ❑ Plug Back F-1 Water Disposal 13. Describe Propowd or Completed Operation: Clearly state all pertincrot details, including cstimawd starting date ofany proposed work and approximate duration thereof. If the proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA Required subsequent reports must be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or rccomplction in a new interval, a Form 31604 must be filed once testing has been completed Final Abandonment Notices must be filed only after all requirements, including reclamation, have been completed and the operator has determined that the site is ready for final inspection) Notice of Final Completion of Well Abandonment and Surface Remediation Activities. Plugging Operations began 3/08/2018 and were completed 3/17/2018 Please see attached reports for in depth details The to was plugged with a cement plug to surface and tested to 500 psi compressive strength. The IA was cemented from 119' to surface (GL measurement). The existing casing at surface was cut off during the BOP rig up. A marker plate was welded on 5' below ground level, 44 cu yards of soil was removed from WC #1 around the wellhead and cellar and 55 cu yards of fresh clean fill were replaced 14 1 hereby certify that the foregoing is true and correct. Name /PrintcrdlT ped) Zach Sayers Title Engineering Manager Signature: ' ,r. it Date 0412412018 ,.—THE SPACE FOR FEDERAL OR STATE OFICE USE Brenc�ilef,nercty end MinPrats mato c5%T/i8" Conditio a rove/, if any, are Kl. Approval of this notice does not warrantor certify t a rat holds I t or uitable title to those rights in the subject Kase Office which wu entitle the applicant t nduct operations thereon Title 18 U.S.0 Section 1001 and Title 43 U.S.0 Section 1212, make it a crime for any person knowingly and willfully to make to any de runCnt or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within «s Jurisdiction (Instructions on page 2) From: Zach Sayers Date: April 24th, 20 i s • • RE: Wolf Creek Test Well #1 Executive Summary • • • • r - �„_ Well Background Wolf Creek Test Well #1 was drilled by the U.S. Navy in 1951. This well was drilled to a TD of 1,500' MD with the 11-3/4" casing string having been set at 48' MD. Slight gas shows were observed at 863' and 1,152' MD. No cement plugs were set and drilling mud was displaced with fresh water and left to freeze in the wellbore. A small gas leak was detected in the threaded wellhead flange in 2003, and repaired using a JB Weld patch since shoring up the leak. Operations Summary: OCS began the rig up on location on 03/08/2018. A snow pad was built to level the wellsite and provide a working area for the well equipment. Prior to spotting the well work equipment, the existing wellhead master valve was opened to atmosphere and the gas sampled. The composition of the gas registered an atmosphere concentration above 100 % of the lower explosive limit (over 50,000 ppm CH4). This prohibited the planned well operations to cut off the existing wellhead with a torch and weld on a new starting head. Further, OCS observed that the fluid level was below 708' MD. A bullhead kill was attempted using 38 bbls of 9.7# NaCl brine with no success. A second bullhead kill was attempted using 38bbls of 8.33# fresh water with no success. On 3/09/2018 a bullhead kill using a 14bbl high visc bentonite pill followed immediately by a 14 bbl 15.6# cement pill was pumped. The well was shut in overnight. On the morning of 3/10/2018 the well was opened up and still producing explosive gas. The fluid level was measured to be below 708'. OCS elected to attempt to top -fill the wellbore with a garden hose for the remainder of the day. After pumping 62 bbls of fresh water, fluid level was brought to surface. OCS elected to mobilize the well equipment to the nearby WC #3 well to complete operations while developing a plan forward strategy for WC#1. On 3/14/2018 well work resumed on WC#1. The full column of fluid killed the gas production, the existing wellhead was cut off, and a starting head was welded on. A cellar was dug using the excavator and a frost bucket. The BOP was nippled up and remaining well equipment spotted on location. Well equipment included a cement unit, steam boiler, fresh water car, tool conex, hose conex, and pit. On 3/15/18, after successfully testing the BOPE, an Artic Cement Platform was lowered into the open hole and set at 119' below ground level (BGL). Immediately after setting the platform plug, cement was pumped from 119' to surface inside the 11-3/4" IA. 5.5 bbls of lost circulation were noted during the cement job. The workstring was pulled out of hole and laid down. The following day top of cement was tagged at 54' BGL. 1-1/4" workstring was lowered into hole and a second cement job was performed successfully bring cement to surface. Proceeding the cement job, the workstring was pulled out of hole and laid down. The remaining wellhead and stub of 11-3/4" casing were cut off and capped with an API marker plate 5' below ground level. The surface equipment was rigged down and removed from location. The well cellar area was back filled with fresh fill and all surface debris was cleaned from location. Operations were completed on 3/17/2018. Sincerely Zach Sayer Engineering Manage Ah Am 01goonik low -.0 Construction Well Photo Report Services LLC Well Name & Number: Wolf Creek Test Well #1 API Well Number: 50-119-10008-00-00 Field: Wolf Creek Exploration Area �r a Surface prior to mobilization activities Cement to surface after wellhead cutoff 8/01/2017 3/17/2018 E r- Well marker plate Surface photo after abandonment activities 3/17/2018 3/18/2018 Location of Well V Government Section: 4, 735' FNL, 3766' FWL, T1S R7W S2, Umiat Meridian State Plane Coordinates: X: 563,868.05 V. 5,622,337.54 Zone 5 (NAD27) Latitude/Longitude: 69 °2241.59 "N / 153 °30'28.48"W (NAD 83) Bucyrus -Armstrong Cable Rig Spud: April 29`h, 1951 Completed: June 4`h, 195 4' MD/TVDOriginal Ground LeveD_ --------------------------------------- '/" "9arkin5 Plate welded on with 1/8" weep hole OH Cement Basket—Top Basket @ 123' MD s Water left in wellbore below cement 10" OH f/ 48' MD t/ 940' MD/TVD Fish at 1,490' MD (Core Barrel Stuck In Hole) 8" OH f/ 940' MD t/ 1,500' MD/TVD P&A Cement Plug i Cement circulated up IA 59' MD—Ground Level 12.4 bbls total cement pumped (returns taken to sur ace) 75 sx Class 'G' Artic Grade cmt 0.93 ft3/sk yield, 14.7 ppg CIP — 03/16/2018 Conductor 11-3/4", 45#, J-55 CSG to 48' MD/TVD (11.00" ID, 10.84" Drift, 3,070 Burst, 1,510 Collapse)* *Assumed specs (nearest design 47#) Cemented with 21 sx of Cal -Seal (Poured) Expected TOC at surface P&A Cement Plug Cement circulated up IA 123' — 59' M D 14.5 bbls total cement pumped (returns taken to surface) 87.5 sx Class 'G' Artic Grade cmt 0.93 ft3/sk yield, 15.4 ppg CIP — 03/15/2018 Wolf Creek Test Well #1 As -Plugged Schematic TD: 1,500'MD/TVD Wolf Creek Exploration Area 01 oonik NPRA, Alaska / st PBTD: Surface Drawn By: Construction Date API # 50-119-10008 PTD # 100-1170 vs Services LLC iw 4/23/2018 Elevation KB: 714' RKB — GL: 4' WC #1 DOR Daily Operations Report Well Name: Well Type: Wolf Creek Test Well #1 Operator: BLMReport Oil & Gas Exploration Well API #: 50-119-10008-00-00 #: lRep.rt Date: Contract#: 1 8 -Mar -18 L16PC00005 Field: NPR -Alaska PTD #: 100-1170 Contacts Weather Supervisor: Site Manager: Proj Eng: BLM PI: share McGeehan lames Nunley Zach Sayers Amanda Eagle Phone#: Phone #: Phone #: _ Phone #: 801-556-0946 Gen. Conditions: Calm 907-232-9952 Phase: - 281-615-1408 Wind Direction: South Wind Gusts (mph): 5-10 MPH Temp. (Low, High): 2 113 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 PBTD: RKB, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: Unknown OH ID, in: loll/8" Operation Days: 1 Last BOP Test: Last Safety Mtg: 3/8/2018 Last Evac Drill: Csg String ':OD (in) Depth (ft) '<Weightg (#/ft) Integrity Issues Outer Most: Conductor: Surface: 11-3/4 48 45 Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) Triplex Mud Pump Wil Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Fresh Water 8.33 38 Brine 9.70 38 Cumulative Volume (bbls): 76 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbls.) Cumulative Volume (bbls): 0.00 Operations Report 24 Hour Summary: MIRU, Monitor gas, Attempt to bullhead kill with 9.7# brine then 8.33# fresh water. 24 Hour Forecast: Plan Forward to follow after morning conference. HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00 - 6:00) 7:00 7:15 0:15 Well left open to vent over night. Sniff well with 4 way monitor. Composition of the gas registers an atmosphere concentration above 100 % of the lower explosive limit (over 50,000 ppm CH4) Stop venting well (close top valve). 7:15 7:40 0:25 Spot ISO tank #1 (Class II - brine for re -use). 7:40 8:15 0:35 Spot Cement Unit. 8:15 8:30 0:15 Spot Green Heater in front of cement unit. 8:30 8:45 0:15 _ Spot Tool Connex. 8:45 9:00 0:15 Spot Generator & Power Panel. 9:00 9:15 0:15 RU electrical cords. Fill generator with fuel. 9:15 9:45 0:30 Fuel Equipment 9:45 10:00 0:15 Spot Hose Connex. 10:00 11:00 1:00 Pull 1/4" x 2" NPT bushing from top brass ball valve. Vent Gas. Mobilize equipment out of Tool Connex. SIMOPS: Transfer Class II brine from ISO to cement unit. 11:00 11:30 0:30 RU flow line to wellhead. Build Scaffolding around well. 11:30 12:00 0:30 Break for lunch 12:00 13:30 1:30 Cut NaCl in active system to. bring weight up to 9.7 ppg. A total of 38 bbls of 9.8# NaCl brine available. Brine temp - 42°F 13:30 14:00 0:30 Complete wind shelter around wellbore 14:00 15:45 1:45 Pump 38 bbls of 9.7#, 41°F NaCl brine into wellbore down the wellhead connected to the existing 2" tree. Pressure limited below 60 psi. 15:45 16:15 0:30 Let well breath. Sniff well with 4 way monitor. Composition of the gas registers an atmosphere concentration above 100 % of the lower explosive limit (over 50,000 ppm CH4) 16:15 17:15 1:00 MU plumb bob and RIH. Ran out of string at 706' MO. 17:15 17:45 0:30 Discuss Plan forward with BLM Engineer. 17:45 18:30 19:00 0:45 0:30 Transfer fresh water from water maker to cement unit. Pump 38 bbls of 8.33#, 387 freshwater into wellbore down the wellhead connected to the existing 2" tree. Pressure limited below 60 psi. 18:30 19:00 19:30 0:30 Let well breath. Sniff well with 4 way monitor. Composition of the gas registers an atmosphere concentration above 100 % of the lower explosive limit (over 50,000 ppm CH4) 19:30 19:30 0:00 Well left open to vent over night. Ho Total urs: Remarks: 12 3 0 :..:.... .-. ..:... .... .......-,,.....-.-. ,..,.. -....: ... ...... . WC #1 DOR WC #1 DOR Daily Operations Report Well Name: Well Type: Wolf Creek Test Well #1 Operator: ELM Report #: Oil & Gas Exploration Well JAPI #: 50-119-10008-00-00 Report Date: 2 9 -Mar -18 L16PC00005 Field: NPR -Alaska PTD #: 100-1170 Contract#: Contacts Weather Supervisor: chane Phone M. McGeehan 801-556-0946 Gen. Conditions: Ice Fog Site Manager: lames Nunley Phone #: 907-232-9952 Phase: - Proj Eng: Zach Sayers Phone #: 281-615-1408 Wind Direction: East BLM PI: Amanda Eagle Phone #: Wind Gusts (mph): 5-10 MPH Temp. (Low, High): -6 1 Well Status TD: 1,500 GL, it: 714 Planned Days: 4 PBTD: RKS, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: Last BOP Test: Unknown OH ID, in: loll/8" Operation Days: 2 Last Safety Mtg: 3/9/2018 Last Evac Drill: Csg String OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: Conductor: 11-3/4 48 45 Surface: Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) Triplex Mud Pump Wil Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbls.) CLASS I Cement Rinsate N/A 7.86 Cumulative Volume (bbls): 7.86 Operations Report 24 Hour Summary: Monitor Wellbore. Wait on additional water delivery. Bullhead High Visc Pill followed by Cement Pill 24 Hour Forecast: Monitor Wellbore. Discuss Path Forward. HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00-6:00) 7:00 7:30 0:30 Check Well for Gas. Still venting gas to surface registering an atmosphere concentration above 100 %of the lower explosive limit (over 50,000 ppm CH4). 7:30 8:00 0:30 Crew preparing to go to lake for water. 8:00 8:30 0:30 Discuss Path Forward with BLM Engineer. Verbal Sundry Change Approval Given to perform high visc pill and cement squeeze to shut-off losses. 8:30 12:00 3:30 Wait On Water. 12:00 12:30 0:30 Break for lunch 12:30 13:00 0:30 Transfer Water to cement unit 13:00 13:30 0:30 Mix Bentonite Pill 13:30 14:00 0:30 RU to wellhead for pumping 1400 16:00 2:00 Perform high vise pill squeeze from surface A total of 14 bbls of high viscosity bentonite pill pumped. 0-30 psi. Perform cement bullhead squeeze in the 11-3/4" casing and 10" open hole from surface. Take on 7.4 bbls of fresh water, add 4 gal of retarder and 0 gal defoamer. Wet yield 0.93 ft3/sk, mix water 3.556 gal/sk Batch mix 87.5 sacks of ArticSet I Class 'G'cement and mix to 15.6ppg. Begin Batch Mixing at 3:10 PM. Pumped 14.0 bbls of 15.6 ppg cement down 2" wellhead at 1.0 bpm, 0-30 psi. Cement in place at 3:47 PM on 3/09/18. 16:00 18:45 2:45 Clean cement unit. Break Down lines, pum s, and batch tubs. Total Hours: 1145 Remarks: WC #1 DOR WC #1 DOR Daily Operations Report Well Name: Well Type: Wolf Creek Test Well #1 Operator: ELMReport Oil & Gas Exploration Well JAPI #: 50-119-10008-00-00 #: 3 Report Date: 1D -Mar -18 - Contract#: L16PC00005 Field: NPR -Alaska PTD#: 100-1170 Contacts Weather Supervisor: share Phone#: McGeehan 801-556-0946 Gen. Conditions: Clear 907-232-9952 Phase: Site Manager: lames Nunley Phone #: Proj Eng: Zach Sayers Phone #: 281-615-1408 Wind Direction: East BUM PI: Amanda Eagle Phone #: Wind Gusts (mph): 5-10 MPH Temp. (Low, High): -6 11 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 PBTD: _ RKB, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: _ Unknown OH ID, in: loll/8" Operation Days: 3 Last BOP Test: Last Safety Mtg: 3/10/2018 Last Evac Drill: _ Csg String OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: Conductor: 11-3/4 48 45 Surface: ---- Production: _ Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) Triplex Mud Pump W11 Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbls.) CLASS I Cement Rinsate N/A 7.86 Cumulative Volume (bbls): 7.86 �'RY, Operations Report 24 Hour Summary: Monitor Wellbore. Fill well with cold lake fresh water. 24 Hour Forecast: TIH, perform cement abandonment to surface. RDMO. HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00 - 6:00) 7:00 Check Well for Gas. Still venting gas to surface registering an atmosphere concentration above 100 % of the lower 8:00 1:00 explosive limit (over 50,000 ppm CH4). Drop Plumb Bob down wellbore. Reach a depth of 708' MD and still unable to tag. 8:00 Discuss findings with BLM. Develop Plan Forward. Verbal Sundry Change Approval Given by BLM representative Amanda 9:30 1:30 Eagle. 9:30 Using submersible pump and 3/4" hose, attempt to fill casing from surface through 2" tree. 12:00 2:30 A total of 48 bbis pumped. Visible Water level seen below surface. ^ 60-70' below wellhead. 12:00 12:30 0:30 Break for lunch 12:30 13:00 0:30 Transfer water from water car to cement unit. Using submersible pump and 3/4" hose, fill casing from surface through 2" tree. 14:00 1:00 A total of 14 bbls pumped. Visible Water level seen at surface. 13:00 14:00 17:00 3:00 Clean and Clear location. Discuss findings with BLM. Develop Plan Forward. 17:00 1 18:00 1:00 Move equipment over to nextwell. Total Hours: 11:00 ...:.':.a`�`'. . ^... -..--.`-.....t -..... Remarks: WC #1 DOR WC #1 DOR Daily Operations Report Well Name:Wolf Well Type: Creek Test Well #1 Operator: BLM Oil &Gas Exploration Well API #: 50-119-10008-00-00 Report #: Report Date: Contract#: 4 14 -Mar -18 L16PC00005 Field: NPR -Alaska PTD #: 100-1170 Contacts Weather Supervisor: Shane Phone M 801-556-0946 Gen. Conditions: Calm McGeehan Site Manager: lames Nunley Phone #: 907-232-9952 Phase: Proj Eng: Zach Sayers Phone #: 281-615-1408 Wind Direction: _ East BUM PI: Amanda Eagle Phone #: Wind Gusts (mph): 0-15 MPH Temp. (Low, High): -8 5 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 PBTD: RKB, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: Unknown OH ID, in: 30" / 8" Operation Days: 4 Last BOP Test: Last Safety Mtg: 3/14/2018 Last Evac Drill: Csg String OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: Conductor: Surface: 11-3/4 48 45 Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) FMC Triplex Mud Pump Wit Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) ' Cumulative Volume (bbls): Waste Fluids 0 Fluid Type Weight (ppg) Daily Volume (bbls.) CLASS I Cement Rinsate N/A 7.86 Cumulative Volume (bbls): 7.86 Operations Report 24 Hour Summary: Mobilize equipment from WC#3 to WC#1, NU Diverter. 24 Hour Forecast: RIH to depth, set ACP, complete surface cement job. HSE Summary: No Accidents, No Incidents, No Spills. From To Hours I Operational Details (6:00 - 6:00) 7:00 7:30 0:30 Fuel Equipment 7:30 Mobilize Equipment from WC#3 to WC#1. 10:30 3:00 Mob Fuel Sled, Water Hauler, ISO Tank #1, Heater. SIMOPS: Excavate Cellar. MobilizeCement Unit. 11:30 1:00 SIMOPS: Cut casing off. 10:30 11:30 12:00 0:30 Break for lunch 12:00 _ 13:30 1:30 Weld starting head on casing. 13:30 14:30 1:00 NU Diverter. MU Hardline for diverter line. 14:30 18:30 4:00 Spot Heater trunks, begin heating cement unit. Build scaffolding around well and tarp enclosure in. Total Hours: 11:30 ,;..,. . .. :. .._:.... ,,,.�.. .:.... ,-. Remarks: WC #1 DOR WC #1 DOR Daily Operations Report Well Name: Wolf Creek TestWell #1 Operator: BUM Report #: Well Type: Oil &Gas Exploration Well API #: 50-119-10008-00-00 Report Date: 15-Mar-18 Field: NPR-Alaska PTD#: 100-1170 contract #: L16PC00005 Contacts Weather Supervisor: Shane Phone M. 801-556-0946 Gen. Conditions: Calm McGeehan _. Site Manager: James Nunley Phone #: 907-232-9952 Phage: Proj Eng: Zach Sayers Phone #: 281-615-1408 lWind Direction: East BLM PI: Amanda Eagle Phone #: Wind Gusts (mph): 0-20 MPH Temp. (Low, High): -3 8 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 8-Mar-18 5 PBTD: RKS, ft: 4 Start Date: Fluid in Well: Unknown OH ID, in: 10" / 8" Operation Days: Last BOP Test: 3/15/2018 Last Safety Mtg: 3/15/2018 Last Evac Drill: Csg String OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: _ Conductor: 11-3/4 48 45 Surface: Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) FMC Triplex Mud Pump Wil Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbis.) Cumulative Volume (bbis): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbis.) CLASS I Cement Rinsate N/A 7.86 _-- Cumulative Volume (bbis): 7.86 Operations Report 24 Hour RIH to depth, set ACP, complete surface cementjob. Summary: 24 Hour Attempt to tag TOC. Develop plan forward. Forecast: HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00 - 6:00) 7:00 8:45 1:45 Take on freshwater to the boiler. Take on freshwater to the cement unit. Start mixing brine. _ Complete diverter function test. 8:45 9:00 0:15 Took 25 turns to the right to close, 45 seconds to close. 9:00 9:30 0:30 MU Antic Cement Platform and handling pup. 9:30 10:30 1:00 RIH w/ ACP from surface to 128' MD. Drop ball and set ACP. Drop 5/8" SS setting ball. Pump brine behind ball at 1/4 bpm till ball on seat. 10:30 11:25 0:55 Slowly begin pumping at 1/8 bpm attempt to pressure up to 1,000 psi. Pressure spike not observed. Returns noted at surface, indicating plug deployed. ACP plug top set at 123' MD, CBU. 11:25 11:35 0:10 9.7# NaCl Brine, 80°F. 11:35 12:05 0:30 POOH from 128' MD to surface. 12:05 12:10 0:05 Inspect ACP running sleeve. ACP deployed. Dump 10 gallons of sand from surface on top of ACP plug. 12:10 12:36 0:26 TIH from surface to 114' IV 12:36 13:00 0:24 Break for lunch _ RU for cementjob. Transfer Brine from active pit to ISO Tank#1(Green). Haul bulk cement on location. Take on mix water and rinsate water. Mix chemical additives for cementjob. 13:00 15:30 2:30 RU cement head. Line up cement hose and discharge hose. Prepare totes for excess returns. 15:30 15:45 0:15 PJSM for cement job. Perform cement abandonment in the 11.3/4" casing and 10" open hole from 123' MD to surface. Take on 7.4 bbis of fresh water, add 4 gal of retarder and 0 gal defoamer. Wet yield 0.93 ft3/sk, mix water 3.556 gal/sk Batch mix 87.5 sacks of ArticSet I Class'G' cement and mix to 15.4ppg. Begin Batch Mixing at 3:26 PM. 15:45 16:09 0:24 Pumped 14.5 bbis of 15.4 ppg cement down 1-1/4" workstring taking returns up the IA at 1.0 bpm, 0 psi. Cement returns not observed at surface. A total of 5.47 bbis loss circulation noted during cement job. Cement in place at 4:13 PM on 3/15/18. _ POOH from 114' MD to surface. 1609 16:40 0:31 No cement observed on workstring collars. Cement observed on joint #1. SIMOPS: Break down cement unit. Clean cement unit. Break Down lines, pumps, and batch tubs. 1640 18:40 2:00 Shut in well. Total Hours: 11:40 Remarks: WC #1 DOR WC #1 DOR Daily Operations Report Well Name: Wolf Creek Test Well #1 Operator: BLM Report #: 6 Well Type: Oil &Gas Exploration Well API #: 50-119-10008-00-00 Report Date: 16 -Mar -18 Field: NPR -Alaska PTO #: 100-1170 lContract #: L16PC00005 Contacts Weather Supervisor: Shane Phone#: 801-556-0946 Gen. Conditions: Windy McGeehan Site Manager: James Nunley Phone #: 907-232-9952 Phase: Proj Eng: Zach Sayers Phone #: 281-615-1408 lWind Direction: West BUM PI: Amanda Eagle Phone # lWind Gusts (mph): 0-20 MPH Temp. (Low, High): -5 -1 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 PBTD: RKB, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: Unknown OH ID, in: 10.1/8'. Operation Days: 6 Last BOP Test: 3/15/2018 Last Safety Mtg: 3/16/2018 Last Evac Drill: Csg String OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: Conductor: 114/4 48 45 Surface: Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) FMC Triplex Mud Pump W11 Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbls.) Brine / OEM Mix - Added to ISO Tank #1 22.00 CLASS I: Cement Rinsate 7.86 CLASS II: Cement Returns 7.86 Cumulative Volume (bbls): 37.71 Operations Report 24 Hour Tag TOC at 59' MD, Perform final P&A plug to surface, RDMO. Summary: 24 Hour Test cement compressive strength, Cap well and burry. Forecast: HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00 - 6:00) Open Diverter / BOP. Well on a slight vacuum. 7:00 7:30 0:30 Fluid level at 14'2". RIH and tag cement at 59' MD. Transfer brine from active unit to ISO tank. 7:30 9:30 2:00 Break down hardline, prepare location for demobilization. Wait On Water for cement job. 9:30 11:00 1:30 SIMOPS: Continue to prepare equipment and location for demob. 11:00 11:30 0:30 TIH from surface to 50' MD. 11:30 '12:00 0:30 CBU through flow line. Close pipe rams, CBU through flow cross. All flow paths clear.__ _ 12:00 12:30 0:30 Break for lunch. Perform cement abandonment in the 11-3/4" casing and 30" open hole from 59' MD to surface. Take on 7.4 bbls of fresh water, add 4 gal of retarder and 0 gal defoamer. Wet yield 0.93 ft3/sk, mix water 3.556Ill Batch mix 75 sacks of ArticSet I Class'G' cement and mix to 14.7 ppg. *Trouble with plugged suction line during batching process limiting ability to continue to take on dry blend. 12:30 13:39 1:09 Begin Batch Mixing at 12:49 PM. Pumped 12.4 bbls of 14.7 ppg cement down 1-1/4" workstring taking returns up the IA at 1.0 bpm, 0 psi. Cement returns observed at surface 4.5 bbls into job. A total of 7.86 bbls of pure cement returns taken. Cement in place at 1:39 PM on 3/16/18. 13:39 14:00 0:21 Open Pipe Rams, POOH from 50' MD to surface Break Down Cement Lines and Equipment. Flush BOP Stack and cycle BOP rams while flushing. 14:00 14:45 0:45 Flush flow cross, Drain stack. Breakdown Fluid Ends of Pumps and flush rinsate. Pull Flow Pan. 14:45 15:30 0:45 SIMOPS: Perform post -job maintenance on cement unit. NO BOP, cutoff wellhead 5' below surface level. 15:30 16:30 1:00 RU to transfer returns tankto ISO tank. Transfer Class II fluids (brine) to ISO tank #1 (Green) for re -use on next well. Prepare Equipment for demobilization. 16:30 18:30 2:00 Consolidate] ads. Load heaters on Taco sleds, mobilize water car. Mobilize Red ISO tank. Total Hours: 11:30 11iolfM Remarks: WC #1 DOR WC #1 DOR Daily Operations Report Well Name: Well Type: Field: Wolf Creek Test Well #1 Operator: BLM Report #: Oil &Gas Exploration Well API #: 50-119-10008-00-00 Report Date: NPR -Alaska PTD M 100-1170 Contract m 7 17 -Mar -18 L16PC00005 Contacts Weather Supervisor: Shane Phone #: 801-556-0946 Gen. Conditions: Cold, Slightly Windy McGeehan Site Manager: lames Nunley Phone #: 907-232-9952 Phase: - _ Proj Eng: Zach Sayers Phone #: 281-615-1408 Wind Direction: West BLM PI: Amanda Eagle Phone M. Wind Gusts (mph): 0-10 MPH Temp. (Low, High): -8 -4 Well Status TD: 1,500 GL, ft: 714 Planned Days: 4 li Surface RKS, ft: 4 Start Date: 8 -Mar -18 Fluid in Well: Cement OH ID, in: 101./8.1 Operation Days: 7 _ Last BOP Test: 3/15/2018 Last Safety Mtg: 3/16/2018 Last Evac Drill: Csg string OD (in) Depth (ft) Weight (#/ft) Integrity Issues Outer Most: Conductor: 11-3/4 48 45 Surface: Production: Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) FMC Triplex Mud Pump Wil Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bli Brine / OBM Mix -Added to ISO Tank #1 CLASS I: Cement Rinsate 22.00 7.86 7.86 CLASS II: Cement Returns Cumulative Volume (bbls): 37.71 Operations Report 24 Hour Summary: Test cement compressive strength, Cap well and burry. 24 Hour Forecast: Final Report HSE Summary: No Accidents, No Incidents, No Spills. - From TO : Hours Operational Details (6:00 -. 6:00) 700 8:00 1:00 Prepare additional well equipment for demobilization. Load Bulk Product onto Taco Sleds. 8:00 10:00 2:00 Inspect 11-3/4" casing cementjob. Complete 500 psi compressive strength test. Passed. Compressive strength test observed by Bi representative Rodney Brashear. Weld on marker plate leaving weep hole. OCS mobilizing equipment to next well. Wells group assist loading and strapping loads. 10:00 11:00 1:00 SLR and Excavator to continue soil remediation and final well burial through the afternoon. * Final Report for well Total Hours: 4:00 Remarks: WC #1 DOR i AOGCC Coordinate Conversion Check 26 June 2018 INPUT OUTPUT State Plane, NAD27 Geographic, NAD83 5005 -Alaska 5, U.S. Feet Accuracies of conversions from NAD 27 to NAD 83 are typically 12 to 18 cm. Wolf Creek 1 1/1 Northing/Y: 5622337.5 Latitude: 69.378220715 Easting/X: 563868 Longitude: 153.507910141 Convergence:0 27 48.19897 Scale factor: 0.999904634 Datum Shift (m): Delta Lat. = -45.705, Delta Lon = 118.745 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers NAD 27 State Plane AK Zone 5 I Fasting Northing 563,868.05 5,622,337.54 564,475.58 5,629,559.99 563,418.68 5,622,198.41 431,521.71 5,636,962.40 592,276.39 5,686,608.03 Wolf Creek #4 711.6 1 3326 1 3435 1 1954 1 1845 Sec 9, T1S, R6W 584,114 1 5,618,548 • C. NAD 83 (Decimal Degrees) NAD 83 (Degrees Minutes Seconds) NAD 83 State Plane AK Zone 5 Elevation Public Land Survey System (PLSS) Legal Description- Umiat Meridian Well N Latitu& I W Longitude N'Latitude W Longitude Northing: Easting (NAVD88) FWL FNL FWL FNL (township, range, section) Wolf Creek#1 69.3782208109 -153.507909785 69°22'41.5949" -153°30'28.4752" 5,622,057.689 1,703,893.602 669.5 3,766.21 4,734.94 1,513.79 545.06 TIS R7W S2SE WotfCreek #2 69.3979424615 -153.502746140 69°23'52.5929" -153°30'09.8861" 5,629,280.086 1,704,501.045 401.7 2,157.90 2,797.50 3,122.10 2,482.50 T1N R7W S36SW Wolf Creek #3 69.3778504919 -153.511401886 69°22'40.2618" -153°30'41.0468" 5,621,918.565 1,703,444.230 691.3 3,315.61 4,870.99 1,964.39 409.01 TIS R7W S2SE Titaluk #1 69.4180608533 -154.534897576 69°25'05.0191" -154°32'05.6313" 5,636,683.172 1,571,545.339 846.8 1,094.51 708.32 4,185.49 4,571.68 T1N R11W S26NW Square Lake #1 69.5530648998 -153.281853400 69`33'11.0336" -153"16'54.6722" 5,686,327.625 1,732,301.634 361.4 4,287.28 4,104.37 992.72 1,175.63 T2N R6W S2SE NAD 27 State Plane AK Zone 5 I Fasting Northing 563,868.05 5,622,337.54 564,475.58 5,629,559.99 563,418.68 5,622,198.41 431,521.71 5,636,962.40 592,276.39 5,686,608.03 Wolf Creek #4 711.6 1 3326 1 3435 1 1954 1 1845 Sec 9, T1S, R6W 584,114 1 5,618,548 • C. FORM RZU 0 V E D Form 3160-5 I TNITIWTATES • (June 2015)] OMB No.1004-0137 DEPARTMENT OF THE INTERIOR Expires:Janu ,211 2017 BUREAU OF LAND MANAGEMENT 5.Lease Serial No. N/A 1 SUNDRY NOTICES AND REPORTS ON WELLS 6.If Indian,Allottee or Tribe Nadk�`1 G O C Do not use this form for proposals to drill or to re-enter an ti`J abandoned well.Use Form 3160-3(APD)for such proposals. N/A SUBMIT IN TRIPLICATE-Other instnictions on page 2 7.If Unit of CA/Agreement,Name and/or No. 1.Type of Well N/A Oil Well 0 Gas Well m Other 8.Well Name and No.Wolf Creek Test Well#1 2.Name of Operator Bureau of Land Management 9.API Well No. 50-119-10008-00-00 3a.Address 222 W 7th Ave,#13 Anchorage,AK 99513 3b.Phone No.(include area code) 10.Field and Pool or Exploratory Area (907)271-4354 Wolf Creek,NPR-Alaska 4.Location of Well(Footage,Sec.,T,R.,M.,or Survey Description) 11.Country or Parish,State 4,735'FNL,3,766'FWL,T1S,R7W,S2,Umiat /Lat:69.3782208109,Long:-153.507909785 North Slope Borough,AK 12.CHECK THE 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 0 Alter Casing 0 Hydraulic Fracturing ID Reclamation 0 Well Integrity ❑Subsequent Report EICasing Repair ❑New Construction []Recomplete 0 Other ❑Change Plans ©Plug and Abandon Li Temporarily Abandon Final Abandonment Notice Ej Convert to Injection El Plug Back El Water Disposal 13. Describe Proposed or Completed Operation:Clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof.If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond under which the work will be performed or provide the Bond No.on file with BLM/BIA.Required subsequent reports must 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 must be filed once testing has been completed.Final Abandonment Notices must be filed only after all requirements,including reclamation,have been completed and the operator has detennined that the site is ready for final inspection.) Plug and Abandon the wellbore. Please see the attached procedures. i0 /06 7 Oki' /t 7 SCANNED yet ./ .)--v .,),szi I,1"w 14.I hereby certify that the foregoing is true and correct. Name(Printed/Typed) Zach Sayers Engineering Manager Title r l Signature ?4 Date 10/19/2017 % 0. SPACE FOR FEDERAL OR STATE OFICE USE Approved by ,.��_ ACT/f4 Eu�iQGY J / rf••/ Title ZRAuCt{ CH ICF Date )1(L!/7 Conditions of approval,i 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.0 Section 1001 and Title 43 U.S.0 Section 1212,make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false,fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) • • i TM Olgoonik Construction Services tic Plug and Abandonment Operations Program Wolf Creek Test Well #1 Wolf Creek Legacy Wells Remediation NPRA, Alaska October 2017 Prepared By: Zach Sayers, OCS Olgoonik Construction Services, LLC 3201 C Street,Suite 700 Anchorage,Alaska 99503 VERSION HISTORY Version Implemented Revision Approved Approval Reason By Date By Date 1.0 Zach Sayers 10/19/17 Oleoonik Construction Services I Ig®®nik • Plug&Abandonment Plan Construction BLM-NPRA Legacy Well Remediation Services LLC L17PD00146/MOD 1—Wolf Creek Cluster Table of Contents 1 General P&A Design 3 2 Equipment& Supplies 3 3 P&A Procedures 5 3.1 Wolf Creek#1 5 Table of Figures Figure 1: Alternative Diverter Diagram 4 Figure 2: WC#1 Current Completion Schematic 7 Figure 3: WC#1 Proposed Plugging Schematic 8 Olgoonik Construction Services I General P&A Design • Olgoon-k _ ! • Plug&Abandonment Plan Construction BLM-NPRA Legacy Well Remediation Services ticL17PD00146 MOD 1—Wolf Creek eek Cluster 1 General P&A Design The primary goal is to leave these wells abandoned as per the task order specifications and requirements while reducing the amount of waste generated.The following assumptions will be used for each wellbore in the Task Order: • All P&A procedures will be agreed upon and in accordance with BLM regulations prior to execution. • Forty-Eight hours prior to P&A operations commence, BLM representatives will be notified. 2 Equipment & Supplies OCS and its team will provide the following well specific equipment: • Boart Longyear LX10 Multi-Purpose Drilling Rig o 197hp multi-purpose drill rig o Dressed to handle%", 1-1/4", and 2-7/8"work strings o Standard Workstring: 2-7/8"w/external upset tool joints • Well Control Equipment: o 7-1/16" 3M Double Gate Manual BOP Ram • Upper Ram: 2-7/8" Pipe Ram • Lower Ram: 1-1/4" Pipe Ram o 7-1/16" 3M flow Cross • Portable Cementing Equipment Including o 28bb1 Cement batch mixing unit o Triplex Pump used for cement • Storage Tanks o 200 bbl (8,400 Gallons)of storage tank capacity to contain circulated well fluids. o 24 bbl Rig Tank/Mixing Pit o Waste/Slop Tank • Plug and Abandonment Marker o Each well shall be sealed with a metal %"thick metal plate,welded in place with well information inscribed on the plate. Each plate will have a weep hole and be sized for each casing. • Transfer pump, with Backup Pump, Heaters, Pipe, hoses,valves,fittings • Vacuum Unit • Boiler Unit • Track Loader • Excavator Olgoonik Construction Services I General P&A Design Olgoonik—vitt• Plug&Abandonment Plan ConstructionBLM-NPRA Legacy Well Remediation Services tic L17PD00146/MOD 1—Wolf Creek Cluster Tee *"'"--- p C:e to-Lr_". ti _Iiii IN s i C r ',D Pan • + Drip, Dar - —7-1116"Intel-v.rt Fa a Aa_a-r t j r— �_ i i fl-fl- ,..1, f ! E ., rt a a v o t 1 1I 0 li L.. 4 4 0006 . (" VS a a a a ( T-81 Style flfi li7? L d) 0 a a e ; •, MIMI `y W 2-1 16 15.Otif, Lc To-que S'a•,e: i rIII 1 1 I 4,...., ^1a - m .1;1 f,-.- vyt w tr 1111 ;a, 1L sr i FWIIIIANA Atr—,.;a: t .¢,--.A, 'nri er.7 i 7 T ( dr_t_h c.1 F.Et_ CES[3'.PTiU'J D:.7° 3 -.•I"' S OW:,..AL CRA:'. "d "CMSAYEAS 27 _S ig ns LS tea 3 Lp ' :ate to f ba a P tcye Nipple ,'21 1 L.5� �C+o traction C UG _t:e DS,L. 'L5,?.:1 IL 10'19':C.1' r f t s 'tin C L-F ate m 7-1:15'E^F 5;1712017 1.5 --:-t- TITh Gere-a"Update: 610712017 _..5 F ELJ +.l eraat--oe DsaerterPropo:al F Jpca.e C,e-te-L re 10:13,241- L_ 5c(lz.r :rc I: FE'—" --14 1011911017 Figure 1: Alternative Diverter Diagram Olgoonik Construction Services I Equipment&Supplies • ooi — • Plug&Abandonment Plan Construction �BLM-NPRA Legacy Well Remediation Services tic L17PD00146/MOD 1—Wolf Creek Cluster 3 P&A Procedures 3.1 Wolf Creek#1 Wolf Creek Test Well#1 was drilled by the U.S. Navy in 1951.The last site inspection was in August 2017.This well was drilled to a TD of 1,500' MD with the 11-3/4"casing string having been set at 48' MD.Slight gas shows were observed at 863'and 1,152' MD. No cement plugs were set and drilling mud was displaced with fresh water and left to freeze in the wellbore.A small gas leak was detected in the threaded wellhead flange in 2003, and repaired using a JB Weld patch since shoring up the leak. .1.1. Deviation Requests&Clarificatit 1. OCS wishes to highlight its intention to use a manually operated double gate pipe ram well control device for this well in place of a hydraulic operated annular well control device.This device will act as the secondary well control device(Diverter)for this well.This diverter system is depicted in Figure 1. a. Per BLM Onshore Order#2 i. OCS wishes to clarify that this operation (thawing out the inside and below the wells structural casing/conductor)does not necessitate the 00#2 III.A.2.a.ii, rather 00#2 III.A.2.a.i applies. 2. OCS wishes to clarify that no casing pressure test will occur.Specifically OCS will not perform a casing test as specified in 00#2 III.B.1.h. 3. OCS wishes to clarify that the planned plug(surface to 114' MD) is approved as final P&A plug for this well in variance with 00#2 III.G.1&2&5&8. 4. OCS requests variance for 00#2 III.C.6. OCS requests to use personal H2S monitors in lieu of the gas detection equipment due to the open air environment used for these P&A's. 5. OCS requests variance for 00#2 III.C.7. OCS requests to omit the use of an ignition system for the flare line/ diverter line. 3.1.2 Hole Size: Fluid Type: Density(ppg) 11.00" IDcsg/ 6-3/4"—9.875"OH NaCI Brine system 8.6—9.8 *Ensure sufficient material on hand to make contingency kill weight brine 3.1.3 Cementing Program: Conductor P&A Plug Cement Hole Size Csg Size Type Density Yield %Excess Volume Est.TOC 6-3/4"— 11.00" ID Class G 15.6— 0.93 ft3/sx 10 CH/ 14.3 bbl Surface 9.875" Artic Blend 15.8 ppg 30 OH BOPE/Diverter 7-1/16"3M Double Gate Manually Operated Rams Upper Ram—2-7/8" pipe ram; Lower Ram—1-1/4" pipe ram CHOKE MANIFOLD N/A ACCUMULATOR N/A Maximum Anticipated BHP 5.97 ppg x 0.052 x 863 ft=268psi Maximum Anticipated Surface Pressure(HASP) 268 psi—(0.22 psi/ft x 863 ft)=78 psi Planned BOP Test Pressure N/A—Function Test only of diverter Casing Test Pressure(11-3/4") none Olgoonik Construction Services I P&A Procedures • Olgoonik • • Plug&Abandonment Plan Construction BLM-NPRA Legacy Well Remediation Services L17PD00146/MOD 1—Wolf Creek Cluster 3.1.5 Site&Well Prep Operations: 1) Move in all support equipment and rig up. Prepare well site as necessary. Install starting head. 2) RU Diverter and function test to ensure operational. 3.1.6 Plugging Operations: 3) Pick up work-string and circulate with heated NaCI brine while slowly tripping in the hole to 48' MD as necessary. 4) Continue in the open hole to 114'while circulating with heated NaCI brine while slowly tripping in the hole. Contingency Procedure—Original Hole Collapse: If unable to enter past 48' MD: a. Attempt to get past obstruction for 30 minutes, if successful proceed to step 5. b. If unsuccessful, POOH, MU Drilling BHA including 6-3/4" bit, RIH to TD. c. PU, establish parameters and begin drilling down to 114'-128' MD. a. Consider drilling past 114' MD to allow for rat hole for solids drop out. d. CBU, POOH till bit inside casing. e. Circulate and monitor well for 5 minutes to ensure no flow. f. Once all cement equipment is ready, RIH to TD. g. Proceed with step 6. 5) Circulate and monitor well for 5 minutes to ensure no flow. 6) Rig up cementing equipment and cement to surface with permafrost cement through the work string pumping until clean cement is observed at surface. 7) Trip Out Of Hole(TOOH)and LD work string. 8) Wait On Cement(WOC) at least 12 hours. Meanwhile, rig down all mixing, pumping and related equipment and prepare them for moving to the next location. 3.1.7 Post Rig Operations: 9) Using excavator, excavate around the wellhead to a depth up to of 6-8'below tundra level. 10) After WOC period is finished cut all casing and tubing strings off to leave well severed>5' below tundra level. 11) Top off all annuli with cement if necessary. Weld a 1/4"thick, 11-3/4" diameter steel marker plate over the top of the cut-off well casing. a. Marker plate to have the following information bead-welded onto the top. i. Wolf Creek#1 ii. API#50-119-10008-00-00 iii. PTD#100 1170 12) Back-fill excavation with original soil.Top excavation with five yards of clean gravel, mounding it over the well to compensate for settling as soil thaws. 13) Clean location, obtain site clearance approval from BLM representative on location and prepare all personnel, equipment and materials for demobilization. Olgoonik Construction Services P&A Procedures • Plug&Abandonment Plan Construction 6LM-NPRA Legacy Well Remediation Services LLC L17PD00146/MOD 1—Wolf Creek Cluster Location of Well Bucyrus-Armstrong Cable Rig isoremmentSection: 4735'FM,3766'FWL. TISit7W52,UmiotMeriadns Spud:A,r'29'',i95i State Plane Coordinates:X.563 868.05 is 5.522,337$4 done 59VA112;j Completed:larne4th,i95: Lobe'dE'LOny i!sne: 09°22'41 59"t:'153'30'28.48'W(WAo 83) 4` MD/TVD L ritual Grourd Level) • Frozen der"'inc fluid I water left in wellbore 13-1/2"OH to 48'MD;TJD*assumed size Conductor 11.-5f4",45#4-55 CSG to CS'tsDITVD * *10'Off most Lke, collapsed;crawn as open' (MOO"in,16.&i"Drift,3,070 Burst,1,510 collapse)• *Assumed specs(nearest design 479) Cemented with 21 as of cal-seal(Poured) Expected-0C at surface 10'OH 1/48'MD t/940'MD/TVD =is.'at 149+: P..?iC-ire Barrel Stuck in Mole) S' Oh ti 940`MD tj 1,500'MDt VD Wolf Creek Test Well#1 Current Completion Schematic TO:1,500MD/TVD wolf geek Exp'oration Asea Ofgoortik POP&Alaska API#50-119-10008 PTD#100-1170 " :ir rtua:,_•. it L�;2c,, Elevation KB:71+' RKB—GL:w` Figure 2:WC#1 Current Completion Schematic Olgoonik Construction Services ( P&A Procedures Plug&Abandonment Plan Construction• BLM-NPRA Legacy Well Remediation Services L17PD00146/MOD 1—Wolf Creek Cluster Location of Well Bucyrus-Armstrong Cable Rig :3Cue.'!`lnent Section_ 4,735'F&,3765'FWL, T2s 1#714'S2,Um'ot Merv:-17n Spud:Aar•: 2y'',1951 stare Plane Cccrdinotes:X:563,855.65 f:5.622,33754 Zone 3('NAD27 Corrpleted:lane 4',1951 totinMeAnngi:•oe: 59'2242,59'',N'/2.53•30'25.49"W f."44xD 83) - 4_M_fiNpLiiprs nal Ground Levei,3 5'Below C-*ourd Leve! s,s - - 15-112"O-±tc 4E'MD/TVD*assL-nev s.e bh. Conductor 11-3/4",45#,3-55 CSG to 48'MD/TVD (11.00"10,10.B4"Drift,3,070 Burst,1,510 Collapse) 'Assumed specs,nearest design 47 Cemented with 21 sx of Cal-Seal(Poured) Extracted TQC at surface P&A Cement Plug Cement circulated up IA 114'MD-Ground Level 143 bbls total cement pumped(returns taken to surfac 86A sac Class'G'Artic Grade cmt 0.93 ft3/sk yield,15.6 ppg ozen drilling fluid/water teft in wellbore below cement clue _:J OH f/48'MD t/940'MO '1rC Fish at 1,490 MD(Cor_?erre Stu:k;n Hole) 8. OH 1/943'MD 111,503'MD/TVG Wolf Creek Test Well#1. Proposed Plugging Schematic TD:1,500'MD/TVD Wolf Creek Exp oration Area Olgoonik lab -STD:su face MPRH,Alaska a4 Cure+r um( API it 50-119-10008 PTD#100-1170 SerNME 10/13!2017 Elevation KB:714' RKB-GGL,4' Figure 3:WC#1 Proposed Plugging Schematic Olgoonik Construction Services J P&A Procedures e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 Q 0 - 1 L 7- Well History File Identifier D Two-sided II 111111111" 111111 Organizing (done) o Rescan Needed /I 111111111" 11/1/1 RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 4-þ;;,/oG Date LJ/¡:¡-/ D (, o Other:: BY: ~ 151 û1P Scanning Preparation BY: Date: + 11111111111111" III 151 VVt-P = TOTAL PAGES L¡.. (Count does not include cover sheet) 151 Project Proofing BY: ~ Production Scanning 11111111I11111 "III Stage 1 Page Count from Scanned File:.5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date¡¡./,gjDb If NO in stage 1, page(s) discrepancies were found: YES NO 151 Mf NO BY: Stage 1 BY: Maria Date: 151 11/11111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 1/1 111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 11/111/111111111111 10/6/2005 Well History File Cover Page.doc Explanation Page Permit Number 100-117 These well numbers (typically beginning with 100) precede the beginning of the Commission. No permits were issued and no formal folder of record (information) created. Information known to the Commission through other agencies, journals, reports, news or additional historical means has been collected and entered into a database of Well History information. If specific information exists, these pages may be filed in this folder. Occasionally, the information has been obtained from a report that may deal with a general area and many wells. If or when possible, we may be able to 'point' the person interested in this specific well to one or more of these information sources. However, at best, this will be incomplete and independent research should be conducted to locate, if available, further information about a particular well site. o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 BGG 4)- \\ 11/7700 OF ric e THE STATE i�` �° L^� iTL cf awrzCL1:_",er ai Conservation ofALAsKA _ Division of Spill Prevention and Response -== �� Contaminated Sites Program 610 University Ave. GOVERNOR SEAN PARNELL = �. . ALAS4 Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Q ED- APR 0 8 2014 Wayne Svejnoha 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 utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi-site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. n•\CA A R\re\FnA....d t~.,,a:t;Pc\(';..;t;,n FPiiProt A oenriec\DOT\RT.M\Projects\Leeacv Wells\7 11 13 Letter to BLM on Legacy Wells.docx Wayne Svejnoha 3 July 11, 2013 Please review the attached list of specific sites. if you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreernan@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G:\SPAR\CS\Federal Facilities\Civilian Federal Agencies\DOI\BLM\Projects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx � - - • O 2 co T,w m T5 la t �0 w ' a) `) 7 (n 0) = -0 CO CO U a CO CO -0 c 0 N CO ca CO CO CO CO CO CO CO CO m m CO a) CO CO CO _c CO 0 w fO CO CO CO CO CO _ a) CO(O coa) N O (O 0 C to 0 c0 C CO CO 0)�' CO C w 'D '0 '0 'o "0 d a) -o -o p in "O -a -o -o 'O 0 -' 0 0 0 0 0 0 0 0 0) > 0 0 0 0 0 0 0 0 0 > CO O Q N C C C C C C C C -o I- C C C C C C C C C 00 Z .N a) a) a) a) >, E a) 0) 0 O 0 0 0 a) 0 U O 0 0 0 0 0 � '3 m 0 0 0 0 0 0 0 0 - -C o c 0 03 " - 0 -C L .0 `) .0 L -C t _C .0 .0 - C C C C C .D N . 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Abreak-down of the 136 is as follows: • 39 are uncased core holes that did not penetrate oil and gas zone, have naturally collapsed, and have blended harmlessly into the landscape. • 33 were either transferred to the North Slope Borough through the Barrow Gas Field Act of 1984 or were conveyed to Arctic Slope Regional Corporation. • 20 wells are being used to by the United States Geological Survey (USGS) for climatic temperature and permafrost studies (see Appendix B). • 7 wells are plugged (6 at Umiat, Square Lake #1). • 37 wells that require further evaluation. Following the 2003 field season, members of the legacy well team met to determine criteria for evaluating the risks associated with the above mentioned 37 wells and ranking each well based on these risks. For consistency purposes, the group devised a series of questions to assist in the process: • What is the condition of the existing pad and pits? (e.g. any indication of contamination?) • Is there any solid waste (old equipment, piping, barrels, etc.) or potential hazardous material conditions? • Did the hole penetrate known oil or gas stratigraphy? • Did the well have oil or gas shows, and if so, is the well capable of flowing? • Is the well near human activity, and if so are there conditions present that pose a risk to people? • What is the condition of the wellhead? Have there been any previous problems or repair work? Does the well (in its current condition) pose a risk? • What is the surficial condition of the existing pad and pits? Is contamination a possibility? • Does the presence of unplugged wells have the potential to negatively impact anticipated development? Each of the 37 wells are described in the following pages. Descriptions are ordered in terms of the ranked priority based on the above stated criteria and the concerns identified. Umiat Wells The early Navy wells in Umiat rank at the top of the list. Umiat is located on the north bank of the Colville River 60 miles upstream from the village of Nuiqsut. Natural oil seeps were discovered at Umiat by early explorers. This discovery, along with the detection of seeps at Cape Simpson, motivated the U.S. Navy to conduct a drilling program. Umiat and the Simpson Peninsula were the primary exploration targets in the mid to late 1940s. The Umiat seeps are still visible today. Their locations tend to shift over time. The seeps are currently active in Umiat Lake, just off the northeast portion of the airstrip and in a channel of the Colville River. ~ ~ ~\ 22 ~~ The 11 Umiat wells were drilled from 1945 to 1952. These wells are a concern for BLM due to their close proximity to human activity. IJmiat is not a village, but serves as a camp for seismic crews: Umiat is also the primary hub for recreational activities in eastern NPR-A and western CAMA (Central Arctic Management Area). It has one of the few airstrips on the North Slope maintained year-round and is a popular location for purchasing aircraft fuel (Figure 10). The 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. Arnry COE, 2003). Contamination levels were compared to the Alaska Department of Environmental cleanup standards and were used as a screening level. The COE has conducted site remediation at two well locations, Umiat #2 and #5 (Figure 11), and has plans to continue the surface clean up. To facilitate site remediation, the COE plugged wells #2 and #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 thee- potential Figure 11: Umiat #2 and #5 prior to removal and historic value. The Alaska Heritage remediation. Photo taken August 2001. Resources Survey (AHRS) included the Umiat wells in an inventory of all reported historic and prehistoric sites within the State of Alaska. This inventory of cultural resources includes objects, structures, buildings, sites, districts, and travel routes generally more than 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 Topagoruk formations. Multiple sands were perforated and tested. Production exceeded 217 barrels per day, thus seemingly showing the benefit of using an oil-based mud. However, the muds did Figure 12: Aerial view of Umiat #9. 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 chilling) 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 The wellhead is equipped with two bull plugs, a flange and a 2 '/-inch nipple. There are no fresh water aquifers in the area, but due to potential contaminants downhole and existing contaminants on the surface, the well does pose a risk to human health and the environment in its current condition. Umiat #6 Umiat #6 was spudded August 1950 to test the southern limits of the Umiat anticline. The hole was drilled to a depth of 825 feet. The well was cased to 35 feet and a 42-foot cement plug was placed on the bottom of the well in order to stop water influx from sands at the base of the permafrost. The well encountered very poor shows in the Killik Tongue (Chandler Formation) and a productive sand in the upper Grandstand Formation. Oil recovered in open-hole pumping tests was produced at rates averaging 53 barrels of oil per day. Insufficient energy exists in the reservoir for the well to flow to surface and there are no fresh water aquifers present. Major caving of the hole occurred and the well was backfilled with mud (Robinson and Bergquist, 1956). The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. The well lies about 500 feet to the northwest of a gravel spur road which connects the Colville River to the eastern edge of the Umiat airstrip. The well is located in wet tundra adjacent to an empty 55-gallon drum. The well is left open with 8 5/$-inch casing to the surface. It has no gauges, valves or a cover plate. Two thermistor prohude to the surface and rests on the lip of the casing. This well poses no threat to human health or the environment unless development occurs. Umiat #7 Umiat #7 was drilled in 1951 to a depth of 1,384 feet, cased to 1,196 feet and completed as a dry hole. It was the southern most well drilled on the Umiat anticline. The objective was to further y .. . , 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 tlu•eat to humans or the environment. The well location is cun•ently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional U~niat Work Umiat has been a site of recent cleanup projects. The cleanup process began in 1994 with the removal of about 1,000 drums, some containing petroleum and transformer oil with PCBs, from the main gravel pad. Another 200 cubic yards of PCB-contaminated soil was removed in 1998 along with 60 cubic yards of lead-contaminated soils. In 2001, 50 cubic yards of PCB soil was excavated with an additional 10 cubic yards removed the following year by the Corps of Engineers (U.S. COE, 2003). J.W. Dalton #1 J.W. Dalton # 1 was drilled in 1979 to a depth of 9,367 feet. It is cased down to 8,898 feet and plugged back to 1,530 feet. (Husky Oil NPR Operations for U.S. Geological Survey-J.W. Dalton, 1982). The primary objective of the well was to determine if hydrocarbons were present within the Sadlerochit and Lisburne Groups. Gas shows were encountered in trace amounts in the Ivishak Formation, and the Lisburne and Endicott Group. Poor to good oil shows were discovered in the Ivishak Formation and in the Lisburne Group. A drillstem test of the Lisburne Group recovered 22 barrels of oily water (Gyrc, 1988). This well has been a USGS monitor well since its completion in 1979. Approximately 230 barrels of diesel fuel were placed downhole to act as a neutral medium for collecting wellbore temperatures. In the summer of 2004, warmer temperatures, wind, and wave action eroded 200 feet of the coastline adjacent to the well (Figures 14, 15). This erosion placed the J.W. Dalton #1 well and reserve pit precariously close 26 Figure 14: Photo of J.W. Dalton taken October 26, 2004. Soil cracking is occurring around the wellhead and the north and east side of the cellar is exposed. Figure 15: J.W. Dalton wellhead with pilings. Photo was taken August 2000. to the edge of the Arctic Ocean. As a result, casing is now exposed to a depth of 15 feet on the present day beach (Figure 16). The top of the diesel is approximately 60 feet below the present beach level. The reserve pit has been breached on the northwest coiner from the advancing shoreline (Figure 17). The pit is known to contain chromium, cobalt, zinc, and barium. However, chromium, cobalt and zinc were detected in background levels, due to the east-west water movement into and out of the pit. Barium is a constituent of the drilling muds and is consolidated with other sediments (U.S. Bureau of Land Management, U.S. Geological Survey, 1992). The well is located within the Northeast planning area (see Map 2), on a tract currently closed to leasing. This well is in danger of becoming engulfed by the ocean. The diesel fuel in the well and In its cun•ent 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. wear t S . t ~ ~~ ~ ~ " ± ' \ , ~ aa i ~ ~~ r5 ~ f 2 i` ~~ tf e ~ A 1 t~ ~ ~ f ~ rr/~. ~' ~ J ,~-~. ~ ~ 1 ~~~. ixy S Sirt~~pson -- ., ~~~ ~~~^ r SI(I~QB~1 #?$ Minge~ s r peon#13 ~ ,? ~~ EaBt Sim~Oi'r12 ! ; n nlpap ~ pSOR11~148i 14A ~'" _ ~ v ~;~ O£impSpfaaKi1 ~~ a .Simpson t~30 & 3UA a.~Sl 5u~son #1 r -.:+ ~~p Figure 18: Simpson Peninsula showing well locations. Simpson Core Test #26 Simpson Core Test #26 was drilled in the middle of one of the larger, active oil seeps in NPR-A (Figure 19). The Navy described this location as Seep 3. The hole reached a total depth of 1,171 feet and was cased to 350 feet. The well encountered one very poor gas show and one productive oil sand in the Ninuluk/Seabee undifferentiated formation. In production tests, the well flowed at rates averaging 110 barrels of oil per day (Robinson and Brewer, 1964). Other formations encountered include the Gubik, Seabee, and Grandstand Formations. Gas bubbles have been observed around the base of the casing since the 2000 field season. Bob Burruss of the USGS, sampled and analyzed gas from Simpson Core #27 which is part of the same oil field, located less than half mile to the east. His findings showed the gas to be biogenic methane indicating that microbial alteration (breakdowns) of the hydrocarbons has generated the gas. Additionally, oil sampled in the well was extremely biodegraded. Simpson Figure 19: The wellhead is located in the center of Core #26 has a wellhead flanged to the the photo. The green color liquid defines the area of active seepage. The orange color is oil-eating casing, a 2-inch line pipe, and four bacteria. wing valves and will likely flow oil if 28 the valves are opened. Access to the wellhead is limited by the depth of oily-water sun•ounding its base (Figure 20). There are no concerns with contaminating fresh water aquifers if the well is left unplugged, but the well could potentially flow oil and cause damage to surface resources if the well equipment corrodes or, through human intervention, the well is opened or damaged. The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased, receiving a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. 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 h•act 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 sununer 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 halm 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 con•odes or if the well is left open. There are no solid wastes or hazardous materials (besides the natural oil) that would present a concern or pose a risk to the health and safety of the land and people. Simpson Core Test #30A Simpson Core Test #30A is an oil well drilled in 1951 to a depth of 693 feet and cased to 152 feet. The well encountered some very poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. The well was bailed and averaged oil rates of 6 barrels per day duuing 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 cw-rent 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 denick 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 banels 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 5/8-inch casing, a flange and a brass gate valve. The casing was set in a small inactive oil seep. It will flow oil to sw•face if opened. There is no surface debris present at Core #27 (Figure 23). The well poses little threat to human health and the immediate environment around it in its current condition. Simpson Core Test #29 Simpson Core Test #29 is a dry hole drilled in 1950 to a depth of 700 feet and cased to 152 feet. The purpose of the well was to determine the limits of the producing field encountered at Core #26. A very poor oil show was identified in the Seabee Formation. The productive sand present in the other Simpson Cores does not exist in this well. The test hole also penetrated the Gubik and Grandstand Formations. No oil was recovered from this well (Robinson and Brewer, 1964). The well is grouped higher on the priority list due to its close approximation to Simpson Cores #26, #27, #30 and #30A (Figure 18). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development if left unplugged since any development will likely target deeper, more productive formations. The well was left with 8 '/z-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables protrude from the casing. It is located in a four-by-four foot wooden 32 Figure 23: There is no surface debris present at Simpson Core #27. cellar filled with water. A drilling pad was never established. There is some light trash around the wellhead including drill pipe, and various sized wooden scraps. A small barrel pump and other small debris can be seen in the casing and within the cellar (Figure 24). This well poses no threat to the human population or the environment. Umiat #1 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 #i is located about 5 which is not surprising given that barite is a miles from the Umiat airstrip. common drilling fluid component. Through sampling, the COE determined the barium has not migrated down the hill and poses no danger to the Seabee Creek drainage (Ecology and Environment, 1999). There is no 33 Figure 24: Simpson Core #29 indication of stressed vegetation down-gradient from the drill muds. Additionally, solid waste in the form 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 current condition, the well does not appear to pose a risk to surface or sub- surface resources. The drill pad is shared with Wolf Creek #3. Tluoughout the pad, there are some wooden pilings, metal anchors and scrap metal. The scraps should not be considered hazardous in this remote region. The leaking gas is of minor concern, however given the weak gas pressure and remote location; the overall risk is very minimal. Wolf. Creek #2 Wolf Creek #2 is a dry hole. The well was drilled in 1981 to 1,618 feet and cased to S3 feet. It is located roughly 1 '/ miles north of the other Wolf Creek test wells. The purpose of drilling was to determine if the gas-bearing sandstone beds previously encountered in Wolf Creek #1 would contain any oil. The records indicate a very poor gas show was encountered in the Killik Tongue but no oil or gas was recovered in production tests (Collins and Bergquist, 1959). The hole also penetrated the Seabee, Ninuluk, Chandler, and Grandstand Formations. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The wellhead consists of a plate welded onto the 11 3/-inch casing cut off at ground level (Figure 27). There is no existing drill pad. Solid wastes consist of a few empty SS-gallon drums upstream along the upper floodplain of the creek. The well poses no tlueat to surface or sub-surface resow•ces 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 628 feet. It is deeper than the other two Wolf Creek wells because its primacy purpose was to test the Grandstand Formation (the producing formation around Umiat, 3S miles to the west). The Grandstand Formation produced from fow• different sands. In 3S Figure 27: Wolf Creek #2 had casing cut off at ground level. open hole flow tests of the well produced at rates up to 445 MCFPD. The gas appeared to be sufficient to supply a small camp, but not of commercial proportions (Collins and Bergquist, 1959). Two plugs were set in the well above the Grandstand Formation. The top of the shallowest plug is inside the casing at 554 feet. In addition to the Grandstand, the hole penetrated the Ninuluk, Chandler, and Topagoruk Formations. Upon abandonment, the hole was filled with oil-based drilling muds and left open to the environment. A total of 103 barrels of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-terns development is unlikely. The well poses no tlu-eat to surface or sub-surface resources and has no potential to adversely affect future development. The drill pad is shared with Wolf Creek #1. There is some minor debris at the site as noted in the Wolf Creek # 1 description. The wellhead was cut off six inches from the ground surface. This allows seasonal precipitation to accrue in the hole and spill over the sides, but the well poses no threat to surface or sub-surface resources and has no potential to adversely affect future development. Fish Creek #1 Fish Creek #1 was drilled by the Navy in 1949 near an oil seep. Total depth of the well was 7,020 feet. The well was plugged back to approximately 2,550 feet, drilled to a new total depth of 3,018 feet and cased to 3,017 feet. The well was drilled to test a large gravity anomaly that suggested the possible presence of petroleum-bearing rocks and some structural anomaly that might be a trap for oil. Very poor oil shows were identified in the Topagoruk Formation at depths from 5,550 - 6,000 feet and a productive sand was reported at 3,000 feet. The well is not a flowing well but was pump-tested at rates averaging 12 ban•els of oil per day tlu•ough 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 Figure 28: Fish Creek #1 with concrete cellar. producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infrastructure is established. Surficially, there are still some solid wastes present. The drilling pad and cellar construction consists of concrete reinforced with steel matting. The concrete, matting, and pilings are still in place today, albeit heaved by permafrost (Figure 28). Several 55- gallon trash drums filled with debris are located off the concrete pad. Other light debris is also present within 500 feet of the pad. The oil seep is located about 1.5 miles to the southwest of the well site and is inactive. The USGS 305-I reports the dimension of the seep as being 6' x 20' (Florence and Brewer, 1964), however, BLM personnel located the seep in 2001 and noted its dimension to be 3' x 6'. Simpson Core Test #28 Simpson Core Test #28 was drilled in September 1950 to a total depth of 2,505 feet and cased to 110 feet. Despite the depth, the hole did not encounter any hydrocarbon shows. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. A drill pad does not exist, however a large area of disturbance is visible. The wellhead consists of open casing inside a wooden cellar. There is considerable solid waste near the well. These include: numerous metal pilings, drill pipe, large wood fragments (spool, plywood, timbers), and some partially crushed drums. The solid wastes are unsightly, but pose no threat to humans or the environment. Simpson Core Test #13 Simpson Core Test #13 was drilled in the summer of 1949. It was a relatively shallow test and did not generate any significant oil or gas shows. The well encountered residual hydrocarbons in the Seabee and Grandstand Formations at depths of 1,079 - 1,084 and 1,138 - 1,148 feet (Robinson and Brewer, 1964). No oil or gas was recovered during production tests. The well is over three miles north of the Simpson Core wells that penetrated productive Grandstand sands. Total depth of the well reached 1,438 feet. The top 26 feet are cased and the hole was filled with water-based drilling mud. Fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. 37 A drilling pad does not exist. Seven-inch casing was cut off at ground level and is very difficult to locate. The well is open to the atmosphere. There is no solid waste, nor is there anything hazardous regarding this location. It should not be considered a risk to surface or sub-surface resources. Simpson Core Test #15 Simpson Core Test #15 was drilled in August 1949 near an active oil seep. The well was drilled to a total depth of 900 feet and cased to 18 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations (Robinson and Brewer, 1964). No oil or gas was recovered during well tests. Additionally, fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. There is no existing pad. The well was drilled about '/8 of a mile north of a natural seep. The well consists of open ended casing with a height of 18 inches (Figure 29). The area is clean with no solid waste. This well poses no risks to the environment or human activities. Simpson Core Test #14 Simpson Core Test #14 was drilled in 1949 to a depth of 290 feet. The records do not clearly state how much casing was run but the well was left with casing above ground open to the atmosphere. Its present day location lies within 1000 feet to the west of an active oil seep. The well was not drilled deep enough to encounter the hydrocarbon stained sands evident in the Simpson Core #14A well. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years. This shallow well did not penetrate any hydrocarbon bearing zones and poses no risk to surface or sub- surface resources, nor does it have the potential to adversely impact future development. 38 Simpson Core Test #14A Simpson Core #14A was drilled in 1949 to a depth of 1,270 feet and casing was set to a depth of 32 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations. No oil or gas was recovered during tests (Robinson and Brewer, 1964) and fresh water aquifers are not present. Present day location of the well is approximately 1000 feet to the west of an active oil seep. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. East Simpson #2 East Simpson #2 was drilled in 1977 to 7,505 feet and cased to 6,427 feet. Five cement plugs were set, with the top of the shallowest plug set at 1,997 feet. The primary objective of the well was to test the Ivishak Sandstone where it onlaps the Pre-Devonian age basement rock (Husky Oil NPR Operations for U.S. Geological Survey, 1982). Small scale faulting was found between the wells in the area, possibly accounting for the thin section representing the Sadlerochit Formation. The well encountered very poor oil shows at 6,000 feet in the Torok Formation and Endicott age sandstones were cored with poor porosity and dead oil shows. The well is officially listed as a diy hole. Upon completion of the production tests, the well was plugged back to 1,997 feet and filled with approximately 280 barrels of diesel to facilitate permafrost temperature measurements. However with East Simpson #1 less than five miles away, the USGS has no plans to use this well for temperature monitoring. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this 39 well will have an adverse impact on development. If this exploration and development establishes infrastructure nearby, it would greatly facilitate plugging this well and significantly reduce costs. The wellhead consists of a casing head, side gate valve, a master gate valve, and a needle valve. The drilling pad is of the thin pad variety and is slowly being reclaimed by natural processes. Exposed pilings stick up a height of two feet from the surface, but no other objects needing removal are present (Figure 31). The cellar is a wooden 12' x 12' with standing water. With the existing plugs and the static condition of the well, there is no risk to surface or sub-surface resources. Kaolak #1 Kaolak #1 lies in the northwest portion of NPR-A and is considered one of the more remote well sites within the reserve. Kaolak #1 was drilled in 1951 to a depth of 6,952 feet and casing was set to 1,000 feet. Drilling served two purposes, to determine the presence of any reservoir characteristics, and to determine if oil or gas shows were present in this remote portion of the reserve. The site was chosen based on a seismograph survey in 1950 that identified an anticline at this location. The intent was to drill to a depth of 8,000 feet, but a windstorm destroyed the derrick. After the storm, the hole was abandoned due to unsatisfactory oil and gas shows. Findings indicated some very poor oil and gas shows in the Chandler Formation and very poor Figure 32: Kaolak #1 with cabin on the drill pad. shows in the Topagoruk Formation. Gas shows were attributed to association with the coal beds (Collins and Bergquist, 1958). Upon abandonment, no plugs were set and the hole was filled with heavy muds. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. Exploration and development in the area is a possibility within 40 Figure 31: East Simpson #2 is partially submerged during the spring thaw. Photo taken June 2003. the next 20 years, but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. There are no major surface issues. The working area is still visible due to a multitude of wooden pilings around the wellhead and a cabin on the north end of the pad (Figure 32). Off the pad, the area is clean. The wellhead is missing its upper components. All that remains is the top flange above the base plate and the casing spool, leaving 11 3/-inch casing open to the enviromnent. The well is left with a casing head and is open to atmosphere. The wellsite is 45 miles southwest Wainwright, which is the nearest community. There are no hazardous materials or anything that would pose a risk to the general health and safety of the land. The cabin may be a concern, but dealing with the situation is outside the scope of this report. Meade #1 Meade #1 is a gas well drilled to a depth of 5,305 feet in 1950. The well was cased to 2,785 feet and two cement plugs were set, with the top of the shallowest plug tagged at 2,783 feet inside the casing. The well encountered some gas shows in one productive sand within the Grandstand Formation. The gas tested at rates up to 1.1 MMCFPD during openhole flow tests of the sand at 2,949 - 2,969 feet. The well is estimated to have gas reserves of 10 BCF. Gas pockets are relatively common in this portion of NPR-A due in large part to the underlying coal. At one point while conducting tests, some 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 Atqasuk) and since the gas zones are currently isolated below the cement plugs there is a limited risk of adverse impacts to surface or sub-surface resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 Titaluk #1 was drilled in 1951 to a depth of 4,020 feet and is a 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 di711string. The drilling mud was bailed down to the top of the fish and the remainder of the well was filled with diesel to 54 feet to prevent the wellbore from freezing and facilitate downhole temperature measurements. It is plausible that the casing could corrode and the diesel fuel could seep into the sub-surface strata, but since there are no fresh water zones in the well it is not considered a risk that would adversely impact sub-surface resources (Collins and Brewer, 1961). The well is located within the Northeast planning area (see Map 2). The well lies adjacent to a recently leased tract that received a high bid of $10.77 per acre during the 20041ease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 is unlikely this well will have an adverse impact on development since industry will likely target deeper, productive formations. An oil seep located at the base of Skull Cliff (land/ocean contact) was observed and documented in the 1940s, which influenced the Navy's decision to drill. BLM and USGS crews searched for the seep when they were in the area but nothing was found at the cliff/beach contact. However, another seep was reported in 1996 by a group from the Academy of Natural Sciences in a small gully about a mile to the east near the old radio tower site. This seep was never confirmed by BLM. Surficially, a drill pad was never established, but a large area of activity is defined by roughly 200 drums, metal tracks, wood debris and various other scraps that litter the site (Figure 35). Presently, the well consists of open casing with a wooden plug shoved into it. There does not appear to be any stressed vegetation that might indicate a hazardous situation. Since the well did not encounter oil and gas Figure 35: Solid waste primarily in the form of empty formations and has no pressure at drums litter the area around Skull Cliff Core Test. The the surface, it is not considered a Wellhead is in the upper left portion of the photo. risk to surface resources. The only potential risk is that this site lies near a popular winter route between Barrow and Wainwright and it is possible for a snowmachine to impact the solid waste. Barrow is approximately 30 miles to the northeast and Wainwright is about 60 miles to the west. Oumalik #1 Oumalik #1 was drilled in 1950 and is a dry hole. The well was drilled to a total depth of 11,872 feet and cased to 2,762 feet. It is the deepest well drilled by the early U.S. Navy program. The well location was positioned on the apex of the Oumalik Anticline and drilled with the intent of revealing the oil, gas, and water content of the penetrated stratigraphy. Two cement plugs were set, the shallowest of which is inside the casing at 2,543 feet. Very poor oil and gas shows were reported in the Grandstand Formation, and poor gas shows were noted in both the Topagoiuk and Oumalik Formations. Small undetermined volumes of gas were recovered during multiple production tests. It is believed that the gas encountered was large enough to furnish fuel to a camp but not large enough to become a commercial producer. The gas encountered during drilling showed high gas pressure, but the sandstones in which they were observed are thin with low porosity (Robinson and Bergquist, 1956). The gas zones are currently isolated by the cement plugs and pose no risk to sub-surface resources. The wellhead and a fabricated plate are below ground level. Two 2 '/z-inch nipples open to the atmosphere are above ground to allow thermistor cables to be run into the well. The well is located within the Northwest planning area (see Map 2) on unleased tract that received no bids during the lease sale of 2004. Near-term development is unlikely. If left 43 unplugged, the well has no potential to adversely affect future development. The existing pad contains piping from a ground refrigeration system similar to Topagoruk #1. The ground in this area is somewhat swampy with high susceptibility to permafrost melt. Circulating cooled diesel fuel in the pipes enabled drilling to occur without thawing the ground. The steel pilings were pulled from the ground to be reused at another site (Robinson and Bergquist, 1956). However, steel pipe filled with diesel fuel remains. A 6- inch circumference of stressed vegetation was noted around several of the low-cut pipes. Despite the diesel, the well does not pose a risk to any existing communities or habitation. It is in a remote location approximately 55 miles southeast of Atgasuk. Overall, the well poses no risk to people or the environment. East Oumalik #1 East Oumalik #1 was drilled on a ridge that overlooks an unnamed tributary of the Oumalik River. Topographic relief is approximately 100 feet. The drill site is highly remote as the nearest village (Atgasuk) is 65 miles away. The well was drilled in 1951 and reached a total depth of 6,035 feet and is cased to 1,100 feet. It is a dry hole. Very poor oil and gas shows were reported in the Grandstand Formation and very poor gas shows were reported in Topagoruk Formation. The well is located within the Northwest planning area (see Map 2) on an unleased tract that received no bids during the lease sale of 2004. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. The well was left with open casing below ground level and has thermistor cables protruding from inside the casing. The casing is marked by a 7-foot, 3/-inch pipe. The open pipe lies within awater-filled cellar. The standing water has produced numerous algae and other aquatic vegetation obscuring the wellbore. Surficial hazards consist of several 10-foot timbers and a few 4-foot pipes (probably rig anchors) sticking up out of the ground. The site is mostly overgrown with shrubs and appears to be relatively clean. The airstrip, incoming, and outgoing trail scars are obvious and can be used to navigate to the wellsite. There are no risks associated with the well in its current condition and was given this ranking due to its close proximity to Oumalik #1. Topagoruk #1 Topagoruk # 1 was drilled in 1951 to a depth of 7,154 feet and is a dry hole. The intent was to test a small, buried anticline and the various formations associated with it. The well was cased to 6,073 feet, plugged back to 6,175 feet and then drilled to a new total depth of 10,503 feet. Prior to re-drilling to total depth, approximately 250 barrels of crude oil fiom Cape Simpson were added downhole to help offset lost circulation and caving. Additionally, 20 ban•els of diesel were added downhole during the drilling phase. No plugs exist in this well. The well is left with open casing to the surface and 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 tlueat to surface or sub- surface resources. The well is located within the Northwest planning area (see Map 2). It is adjacent to a recently leased tract, receiving a high bid of $50.00 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. There is not a visible pad, but rather an area of disturbance. Disturbance sketches 1/4 mile in an Figure 36: Topagoruk #1 casing on its east-west direction and /s of a mile in a north- side. When the casing was pulled out of south direction. Solid wastes exist in the form of the ground, thermistor cables were piping remaining from a refrigeration system that discovered. circulated diesel to keep the permafrost frozen. A potential hazard exists because diesel still occupies the ground circulation lines. These lines stretch approximately 750 feet to the east, 250 feet to the north, and 100 feet to the south from the wellhead. Other debris on site include some large, partially-burned timbers, awater-filled wooden box (Figure 37) that resembles a cellar (t/4 mile east of the wellhead), and drilling muds. Atqasuk is the closest village approximately 30 miles to the southwest. The well is remote with the exception of a subsistence camp approximately one mile southwest of the wellhead along the Topagoruk River. East Topagoruk #1 Topagoruk's wellhead consists of an open hole cut off at the ground surface with several thermistor cables. A thin piece of weathered metal fits around the cut-off casing to resemble a marker. The weathered metal has been smashed at the base and now lies bent in half on its side. Overall this site poses little hazard to the environment or human population. East Topagoruk #1 was drilled on top of a small ridge in the Chipp River delta in 1951. It reached a total depth of 3,589 feet and is cased to 1,100 feet. The purpose of the well was to test an anticline with closure as well as test the fluid content of the permeable Cretaceous sandstone (Collins and Bergquist, 1958). A very poor gas show in the Topagoruk Formation. is the only reported hydrocarbons encountered in the well and no oil or gas was recovered during multiple production tests. One cement plug was set in the 45 Figure 37: Drilling muds and a wooden box that resembles a cellar are located about'/< mile east of the wellhead. well at 1,049 feet. The well is located within the Northwest planning area (see Map 2) on a recently leased tract. The tract receiving a high bid of $84.99 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. A drill pad does not exist. There are a few rig anchors near the wellhead, but no other surficial debris. The cun•ent state of the wellhead is open-ended 10 '/-inch casing. Casing height is three feet above the ground surface. It is housed in a small 9' x 9' water-filled cellar. The area is remote. and poses no health and safety risks to humans or the environment. Knifeblade Wells There were three shallow test wells drilled in the Knifeblade Ridge area. Knifeblade #1 was drilled on the ridge at the head of a small stream, with wells 2 and 2A drilled about a mile downstream. The wells are in a highly remote location with Umiat being the nearest settlement, 65 miles to the east. Knifeblade #1 Knifeblade #1 is a dry hole drilled in 1951. The well was drilled to a depth of 1,805 feet and cased to 1,211 feet. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). The well encountered very poor gas shows in the Killik Tongue of the Chandler Formation and very poor oil and gas shows in the Grandstand Formation. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. 46 Figure 38: Knifeblade #1 is located in a marshy area at the headwaters of a small creek. Knifeblade #2 Knifeblade #2 is another dry hole drilled in 1951. It was the first of the three Knifeblade wells drilled and reached a total depth of 373 feet, cased to 45 feet, before being junked and abandoned. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). The well did not encounter any hydrocarbon shows. The well is located on an unleased tract, in Southern NPR-A (see Map 2} where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Surficial issues are negligible. A drill pad does not exist and the wellhead consists of open-ended casing. There are approximately eight empty drums near Knifeblade #2 and #2A. The wells are highly remote and should not be considered a threat to the environment or human activity. Knifeblade #2A Knifeblade #2A, also drilled in 1951, reached a total depth of 1,805 feet and was cased to 38 feet. The well lies 28 feet to the north of Knifeblade #2A. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). Only very poor oil and gas shows were reported in the Grandstand Formation. The well was left with casing open to the atmosphere and poses no threat to surface or sub-surface resources in its current condition. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Simpson #1 Simpson #1 test well was drilled with a rotary rig in 1948 by the U.S. Navy. The well was drilled to a total depth of 7,002 feet and cased to 5,954 feet. The purpose of the well was to test the various formations of the Lower Cretaceous and Upper Jurassic rocks. The well encountered several very poor oil and gas shows and one productive gas sand in the Lower Jurassic at a depth of 6,183 - 6,193 feet. The well produced gas at rates up to 3.0 MMCFPD during open hole flow tests of this Lower Jurassic sand. The gas zones are currently isolated from other formations and the surface by two cement plugs set above the productive sand. The top of the shallowest plug is at 5,520 feet (Robinson and Yuster, 1959). The well is located within the Northwest planning area (see Map 2) adjacent to recently leased tract that received a high bid of $7.51 per acre during the lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years and this exploration has the potential to target the Lower Jurassic. Since the well is partially plugged, however, it poses little risk to surface or sub-sm•face resources and will not likely adversely affect any future development. 47 The pad is highly visible and was constructed in the same fashion as Fish Creek #1 in which concrete was used as a working pad. Concrete was poured over a landing mat which was placed on pilings. As a result of ground movement from pernlafrost freeze/thaw cycles, the concrete has buckled in numerous places creating apartially- collapsed surface. This feature provides excellent shelter to small animals and rodents. Additionally, there is a small pile of drilling muds near the wellhead. The well was left equipped with a casing flange, spool w/ side bull plug, and another flange and nipple and is shut-in with no pressure at surface. The components past the flange have since been removed. Overall, the current condition of the site is non-threatening to the sparse human population and the 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. South Simpson #1 South Simpson #1 was drilled in 1977. The purpose of the hole was to test the Sadlerochit Formation where it laps onto the south flank of the Barrow Arch. The well was drilled to 8,795 feet and cased to 7,206 feet. Reports show that poor gas shows were identified in the Nanushuk Group, Kingak Shale and Shublik Formation. Gas flowed at a rate. of 75 MCFPD between 6,522 - 6,568 feet within the Kingak Shale (Gyrc, 1988). The gas contained more than 70% nitrogen. The origin of the high nitrogen content is unknown, but appears to be a localized phenomenon (Burruss, 2003). Sandstone tongues 48 (Simpson sand) within the Kingak Shale in the Simpson and Barrow localities are known to display good gas reservoir quality (Houseknecht 2001). Poor oil shows were discovered in the Nanushuk Group and Shublik and Torok Formations. Drill stem tests did not recover any oil. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $5.01 per acre during the lease sale of 2004. Exploration and development is a distinct possibility in the near future since the well is properly plugged it will have no adverse impacts on development. Surficially, the pad and pits are in good shape. The cellar has been backfilled r~gure 4u: South Simpson #1 had its cellar backfilled with silt, with silt which resulted in consequently burying the casing head. the burial of the casing head (Figure 40). Above the surface, the wellhead consists of a 4-inch line pipe and a master valve. The master valve is frozen in the open position. The needle valve previously located above the master valve no longer exists. Beneath the casing head the well is plugged to surface and has no potential to adversely effect surface or sub-surface resources. The wellhead stands about eight feet high. Aplumb-bob was dropped and hit solid at 8 feet and stuck. It was subsequently lost. An old, stripped snow~machine sitting next to the wellhead is the only sizable object that would be considered solid waste. Overall, there is no risk associated with this well. Inigok #1 Inigok #1 was drilled in 1979 to a depth of 20,102 feet and cased to 17,432 feet. The well objective was to test astructural/stratigraphic trap within the Sadlerochit and Lisburne Groups (Husky Oil NPR Operations for U.S. Geological Survey-Inigok, 1983). Some very poor gas shows were recorded in the Sag River, Nanushuk, and Endicott Group. Poor oil shows were reported for the Kingak Shale and Lisburne Group. The best shows were found in the base of the Torok Formation at 8,852 feet. No oil or gas was recovered during multiple production tests. The wellhead consists of three spools, each with a gate valve, a master valve, and a needle valve. Ten cement plugs were set in the well and it is plugged to surface. The well is located within the Northeast planning area (see Map 2) on a recently leased tract that received a high bid of $20.34 per acre during the lease sale of 2002. Total E&P Incorporated drilled an exploratory well 15 miles north of Inigok # 1 and used the gravel 49 pad and airstrip near the well for staging areas and a camp. It would be fairly simple to remove the wellhead but the well has no potential to adversely affect surface or sub-surface resources. Additionally, the well poses no threat to adversely affect future development. Inigok #1 is one of the few logistical Centers Figure 41: Aerial view of Inigok #1. The drill pad and reserve pit within NPR-A (Figure are visible in the top of photograph. A road leads from the apron of 41). The airstrip and pad the airstrip to the drilling pad. are maintained with no solid wastes present. The wellhead poses no risk, and with the plugs already in place, could be removed. Additionally, this well has ayear-round airstrip and serves as a logistical base to various NPR-A activities. USGS Monitored Wells The USGS has used wells drilled in the NPR-A for collecting temperature data to better understand both the global temperature pattern and its effects on the permafrost. The wells that are currently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is anon-corrosive agent, and even if the casing should corrode there would be no impact to the surface resources and 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 tlueat 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 Nuiqsut is 52 miles to the southeast, Teshekpuk Lake is rich in subsistence resources and numerous summer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of 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, undernlining 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 athition 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 erOSlon 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 exhemely friable. It is likely that these uncased core holes have naturally collapsed and harmlessly blended into the environment. There is no surface indication of their location and BLM has been unsuccessful in locating them during several visits to their reported location. They do not pose any potential risks. Barrow Gas Wells The Barrow Gas Field Act of 1984 (P.L. 98-366, 98 Stat. 468, July 17, 1984) allowed the U.S. Navy to transfer several wells to the North Slope Borough. The Navy drilled six shallow wells between 1953 and 1974 to test the natural gas potential. Between 1974 and 1982, 10 additional wells were drilled to help supplement the local gas supply. The wells were developed for use by the local. government agencies and Barrow residents. The act conveyed the sub-surface estate, held by the federal government and any other interest therein, to the Arctic Slope Regional Corporation (ASRC). The BLM acknowledges the surface and sub-surface lands as conveyed and the Office of the Regional Solicitor has confirmed that the Transfer Act included the wells and well locations, and any liabilities associated with these wells are the responsibility of ASRC. 52 test, are stored in the Alaska Geologic Materials Center. Plugged Wells Square Lake #1 Square Lake #1 is a Navy well that was drilled to a depth of 3,984 feet. Its primary intent was to test the Cretaceous rocks in east-west trending anticline structure (30SH 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 #S 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 19S 1. The purpose of the wells was to test for producing lithologies and deterniine 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 #S 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 #S were removed. Costs were approximately $2S million dollars due in part, to soil Approximately 30,000 tons of petroleum-contaminated soil was excavated. remediation. The soil was S3 transported on an ice road to the Umiat camp where it was thermally treated in a rotary kiln to remove petroleum residues. Small quantities of PCB contaminants were unexpectedly encountered after the excavation was completed. The source of the PCBs has been linked back to the #5 well and the fluids used downhole. The ever-shifting Colville River continues to erode the north bank and is approximately 50 feet from the old wellbores. With the removal of hazardous soils, this site should not be considered a threat to humans or the environment. Umiat #3 Umiat #3, also known as Umiat Core Test #l, was spudded in December 1946 and drilled to test some of the oil bearing zones encountered while drilling Umiat #1. The well was drilled on the northeast corner of Umiat Lake just below the hill from Umiat #4 (Figure 45). Umiat #3 penetrated the Gubik Formation and the Nanushuk Group. The Grandstand Formation within the Nanushuk Group is considered to be the primary source of oil between the depths of 258 and 514 feet. The hole produced 50 barrels per day prior to shutdown. The well was re- tested nine months later with production dropping to 24 barrels per day (Robinson and Bergquist, 1956). The wellhead consists of homemade components with a single water service type valve and is capped with a needle valve. There is no seeping present at this Figure 45: The view from Umiat #4 looking southwest site, however seeps are common in toward Umiat Lake and Umiat. Umiat #3 is located on the area, including an active seep in the near shore of Umiat Lake. Umiat Lake. An extensive piping system is still visible. The pipes probably supplied water during the drilling phase. They connect Umiat #3 to #4 which then follow the hill from Umiat #4 to 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 Foienations. Oil was found in the upper and lower 54 sandstone of the Grandstand Formation. Drilling encountered good oil shows around 300 feet with a total 500 barrels produced (Robinson and Bergquist, 1956). The wellhead consists of 11 3/-inch casing protruding 36 inches above the ground surface. The casing is capped with a steel plate. Upon removal of the cover, the hole was open to the environment. No valves or gauges are present. The well was plugged by the BLM on May 9, 2004. The well poses no risk to humans or the environment. Umiat #8 Like the other wells drilled in the 1950s, Umiat #8 was drilled using cable tools. The well was spudded May 1951 and completed August 1951. It is located on top of a ridge that separates Umiat from the Bear Paw Creek valley. Drilling intention was to determine the quality and quantity of hydrocarbons in the Grandstand formation near the crest of the anticline structure. The hole encountered the Seabee, Ninuluk, Chandler, and Grandstand Forniations. The Grandstand Formation produced approximately 60-100 ban•els per day of oil and more than 6 million cubic feet per day of gas. The well was shut in with a gas pressure of 275 pounds per square inch. The gas was analyzed by the Bureau of Mines and determined to be 97.3 per cent methane. Brine was mixed (35 lbs of salt per barrel of water) and used in the drilling fluid to prevent freeze up. Brine solution of approximately the same ratio of salt per barrel of water was used to kill the well and set the plug while cementing casing. A total of 21,695 pounds of salt were used in the well (Robinson and Bergquist, 1956). The well was plugged May 2, 2004. Prior to plugging, the well was nicknamed the "Whistling Well" due to the gas of which was escaping through fittings and valves in the wellhead. The wellhead is easily the most complex of the 11 Umiat test wells. It consists of five valves and multiple gauges. It has several homemade components and reaches a total height of ten feet. After reporting the seeping gas in 1996, two new valves and gauges were installed in 1997. The new gauges have been checked regularly since 1998 and have consistently read 250 psi. Despite replacing the two valves and gauges, gas continued to leak from the wellhead. The largest of the leaks occurred just above the top flange where a 4-inch nipple and collar are welded together. Other leaking occurred at the fittings of some of the gauges. The wellhead is sited on a gravel pad. A series of piping extends from the wellhead to a small stock tank about 100 feet to the south. The tank probably was used as a holding tank for the oil while testing the production potential of the hole. The same style of stock tank is present in various old photographs found in the Umiat area and may be the same 55 Figure 46: Umiat #4 prior to plugging. The wellhead is located in the center of the photograph. tank. Oil from inside the tank was sampled in 2004 with test results positively identifying PCB contamination which is slightly below the level of concern. Umiat #10 Uiniat #10 was spudded September 1951 and completed January 1952. This well was drilled to test the Umiat anticline and is located about a half mile northwest of Umiat #8. Total depth of the well is about 1,573 feet. When the well was bailed, it produced 222 barrels of oil in a 24-hour time span. The most productive layers occurred at 980 feet and 1,095 feet, penetrating both the Ninuluk and Grandstand Formation (Robinson and Bergquist, 1956). Also encountered were the Seabee and Chandler Formations. The hole was somewhat problematic as it caved considerably during drilling. Operations consisted of a drill rig set on a foundation of 12" x 12" timbers with a thin layer of gravel in between. Twenty-five pounds of salt mixed 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). with Aquagel and water (per barrel) were used .~,~~. The surface near Umiat #10 is in good shape. There is no existing pad and no solid wastes. With the recent plugging of the well, it is not a risk to human health and safety or the environment. 56 Figure 47: Plugging operations at Umiat #10. May 2004. APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Ati garu Awuna* Drew Point East Simpson #1 East Teshekpuk West Fish Creek #l 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 U.S. Department of the Interior Bureau of Land Management BLM/AK/ST-05(004+2360+941 November 2004 ~gacy Wells Summary Rep Petroleum Reserve-Alaska Rob Brumbaugh ob- u9 • • J Cover Photos 1 2 3 4 9 5 6 7 8 • JW Dalton #1 100-202 ,~ Atigaru #1 100-104 3 Lisburne #1 100-149 y Wolf Creek #1 100-117 5 Gubik #2 100-222 ~ Awuna #1 100-151 ~ Seabee #1 100-223 Umiat #10 100-218 1 - J W Dalton #1 after- considerable beach erosion during the summer of 2004. 2 -Atigaru #1 is a coastal USGS monitor well. 3 -Lisburne #1 is the southernmost of the legacy wells. It cw•r•ently lies outside the NPR-A boundar7~ due to a lawsuit in the early 1980s that forced the boundary to be moved several miles to the west. 4 - GI'olf Creek #1 during the summer of 2004. ~ -Alone drill rig, remnant from the U. S. A'avy exploration days, sits abandoned at the once proposed Gubik #3 drilling location. 6 -The drill pad at Awuna #1 has experienced erosion fi•onz the reserve pit, exposing pilings arzd Styrofoam to the elements. 7 -Seabee #1 is a USGS monitor well located at Unziat. 8 - Umiat #10 prior to plugging during May of 2004. 9 -The background image is of the rolling foothills of the Brooks Range near- N'olf Creek. Disclaimer The mention of trade names or commercial products in this report does not constitute endorsement or recommendation for use by the federal government. Authors Rob Brumbaugh is a Minerals Specialist with the Alaska State Office, 222 West 7`h Avenue #13, Anchorage, AK 99513. Stan Porhola is a Petroleum Engineer with the Alaska State Office, 222 West 7"' Avenue #13, Anchorage, AK 99513. Open File Reports Open File Reports Issued by the Bureau of Land Management-Alaska present the results of inventories or other investigations on a variety of scientific and technical subjects that are made available to the public outside the formal BLM-Alaska technical publication series. These reports can include preliminary or incomplete data and are not published and distributed in quantity. The reports are available while supplies last from BLM External Affairs, 222 West 7'~' Avenue #13, Anchorage, AK 99513 and from the Juneau Minerals Information Center, 100 Savikko Road, Mayflower Island, Douglas, AK 99824. Copies are also available for inspection at the Alaska Resource Library and Information Service (Anchorage), the USDI Resources Library in Washington D.C., various libraries of the University of Alaska, the BLM National Business Center Library (Denver) and other selected locations. A complete bibliography of all BLM-Alaska scientific reports can be found on the Internet at http:/haw`>tv.ak.bhn.gov/affairsisci mts.html. Related publications are also listed at http://juneau.ak.blm.gov. The BLM Mission The Bureau of Land Management sustains the health, diversity, and productivity of the public lands for the use and enjoyment of present and future generations. i Cover Photos 1 2 3 4 9 5 6 7 ,, 8 C~ i - ~. n~. Barron rt a~rer consiaeraote neacn erosion aur•mg the summer oy wv4. 2 - Atigaru #1 is a coastal USGS monitor well. 3 -Lisburne #1 is the southernmost of the legacy wells. It currently lies outside the NPR-A boundary due to a lawsuit in the early 1980s that forced the boundary to be moved several miles to the west. 4 -•GI~olf Creek #1 during the summer of 2004. S =Alone drill rig, remnant from the U.S. lUavy exploration days. sits abandoned at the once proposed Gubil,: #~ a drilling location. 6-'The drill pad at Awuna #1 has experienced erosion from the reserve pit, exposing pilings and Styrofoam to the elements. 7 -Seabee #1 is a L'SGS monitor well located at Umiat. 8 = Umiat #10 prior to plugging during May of 2004. 9 -The background image is of the rolling foothills of the Brooks Range near ld~olf Creek. Disclaimer The mention of trade names or commercial products in this report does not constitute endorsement or recommendation for use by the federal government. Authors Rob Brumbaugh is a Minerals Specialist with the Alaska State Office, 222 West 7`'' Avenue #13, Anchorage; AK 99513. Stan Porhola is a Petroleum Engineer with the Alaska State Office; 222 West 7`h Avenue #13, Anchorage, AK 99513. Open File Reports Open File Reports Issued by the Bureau of Land Management-Alaska present the results of inventories or other investigations on a variety of scientific and technical subjects that are made available to the public outside the formal BLM-Alaska technical publication series. These reports can include preliminary or incomplete data and are not published and distributed in quantity. The reports are available while supplies last from BLM External Affairs, 222 West 7`h Avenue #13, Anchorage, AK 99513 and from the Juneau Minerals Information Center, 100 Savikko Road, Mayflower Island; Douglas, AK 99824. Copies are also available for inspection at the Alaska Resource Library and Information Service (Anchorage), the USDI Resources Library in Washington D.C., various libraries of the University of Alaska, the BLM National Business Center Library (Denver) and other selected locations. A complete bibliography of all BLM-Alaska scientific reports can be found on the Internet at http:/hvww.ak.blm.gov/affairs/sci rpts.html. Related publications are also listed at http://juneau.ak.blm.gov. The BLM Mission The Bureau of Land Management sustains the health, diversity, and productivity of the public lands for the use and enjoyment of present and future generations. Background and History Two U.S. Government exploration programs focused on the petroleum reserve. The U.S. Navy began the first exploration program in 1944 and drilled a total 91 holes in the Reserve. The Navy focused on Cape Simpson (Figure 1) and Umiat (Figure 2), the two most prominent oil seeps. Navy contractors drilled 11 test wells at Umiat and another 34 on Cape Simpson. Overall; the program located eight oil and gas fields (Fish Creek, Gubik, Meade, Simpson Peninsula, South Barrow, Square Lake, Umiat and Wolf Creek). Following the conclusion of the Navy program in the mid-1950s, focus began to shift eastward toward what were to become State lands. Exploration activities in the petroleum reserve between 1953 to 1975 were limited to 9 wells in the Ban•ow area until interest increased following the 1973 Arab oil embargo. The U.S. Navy and the USGS contracted with Husky Oil Corporation to drill 9 and 27 exploratory wells respectively from 1975 to 1981 with one new discovery in the Walakpa Gas Field. The National Petroleum Reserves Production Act of 1976 (NPRPA) changed the name of the Reserve from NPR4 to the NPR-A and transferred administration to the U.S. Department of the Interior (USDOI). ;~~,_ €(~~~~ MAC ~ ~ Z01~ 3 1~,s J ti. ~, \! 3 Figure 2: Oil seeping in Umiat Lake. in remote areas of the leased acreage. These staging areas have the potential to aid BLM's future remediation work associated with the legacy wells. Map 3 shows the relationship of usable airstrips to legacy wells. BLM efforts 1976-1982 The USGS initiated cleanup of the early Navy wells in 1976 and contracted Husky Oil NPR Operations, Inc. to manage the project. The NPR-A was divided into four quadrants; Arctic Coastal Plain, Northwest; Southwest and Southeast. The cleanup effort focused on the solid and hazardous materials that were abandoned in place by the Navy and was carried out during two phases. After the spring thaw, crews would travel by helicopter to new sites to break down and transport the wastes to an accumulation site. If a suitable site was located, non-combustible solid wastes were buried. While the ground was still frozen in the spring, aCat-Train crew retrieved wastes from storage sites established the previous summer. When hazardous materials (explosives and full drums of barite) were found they were transported to the storage site and hauled out the next spring. There is no evidence of anything hazardous remaining on site. In 1978, an extensive cleanup occurred at East Ou~nalik, East Topagoruk, Knifeblade, Ikpikpuk (explosives), Skull Cliff, Square Lake, Titaluk; Topagoruk, and Wolf Creek. A ---- __ total of $1.87 million dollars was spent and 7.2 million pounds of solid wastes were handled, stockpiled or burned. During 1979, cleanup occurred at Fish Creek, Grandstand, Gubik, Oumalik,~and several other areas in which a well was planned but not drilled. Approximately $1.85 million dollars were spent and 24.1 million pounds were handled, stockpiled or burned. Field work for 1980 consisted of cleaning up what had been stockpiled and over-wintered from 1979. There is no recorded summar}~ of cost or amount of wastes handled past 1979. In 1981, Husky discharged itself as contract operator and put out an invitation for bids. While waiting for bids, Husky continued its scheduled spring cleanup work at East Oumalik (Figure. 5), Wolf Creek, Fish Creek, Kogru River, Meade,_Oumalik, Square Lake~and Titaluk. The USGS did not fund additional work at Skull Cliff. The contract received no bids and Husky did not return. The USGS drilling program ceased in 1982. ~~ .. ~ ~ ~ I~ 7 is void of sur6cial debris. The cellar is visible in the mid- right portion of the photo. 9 NOTE TO FILE Wolf Creek # 1 100-117 Recommendation for Well Status Change It is recommended that the status of this well be changed from plugged and abandoned ("P&,A") to a shut-in completed oil well (1 -oil). Wolf Creek # I is one of a number of legacy wells drilled in Alaska prior to statehood. This well was drilled in 1951 and while the current status is shown to be P&.A, no cement has ever been placed in the wellbore to plug the well according to either State of Alaska or Bureau of Land Management ("BLM") regulations. Accordingly the presently carried P&A status is not correct and should be changed to 1 -oil. em f Thomas E. Maunder PE Sr. Petroleum Engineer ,�-k 1;) %� —(3 (:� Stephan F. Davies Petroleum Geologist 'j" 2�0 - 6 (. "NED JAN 19 2007 1.-.(;. UllUCLl e e Subject: Re: Umiat From: Stan_Porho1a@ak.b1m.gov Date: Wed, 21 Ju12004 15:46:12 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Umiat #8 was plugged with a downhole plug through the tubing across the active reservoir. A surface plug was set in both the annulus and tubing, with the top of the plug at 73' and 0' respectively. Umiat #10 was plugged with a bridge plug and 100' of cement above. Umiat #4 was plugged with a fluid level at 201', followed by water to 101', a gel pill to 70' and a surface plug to 11'. Tubing and rods were cut and left in the well. Umiat #3 was plugged with a fluid level at 118', followed by a gel pill to 93' and a surface plug to 66' (after falling 60'). Tubing was cut and left in the well. Work scheduled for winter 2005 includes topping off the surface plug for Umiat #3 and setting surface plugs for Umiat #6, #7 and #9. Previous plans to plug Umiat #1 and #11 have been put on hold. Work scheduled for summer 2004 includes PCB testing Creek #3 and possible wellhead improvements to Wolf of well fluids for Wolf Creek #1. l,,\~-:\ \ '" The next likely target for plugging efforts by BLM (pending additional funding) would be the Wolf Creek area (wells 1,2,3). Stan porhola BLM - Alaska Petroleum Engineer 267-1469 (.tÀ' i:.\.",,~~¥.ë:.\~ ~\oI~"""\._' "í c) ..s 6,¡ 7/'1 1/'1{\'I A ., ~/1 n~" 11)" Hole Depth: 857' ·855' 8" Hole Depth: 1152'-1175' 5" Hole Depth: 1490'·1500' TD::: 1500' PSTD::: 1500' Max ::: Mcf/d =53 psi ::: 33° Wolfcreek #1 Current Well Cement show Cement show NaGI Gal-Seal Wolfcreek#1 Surface Diagram \ Gas leak coming from weld on casing! Well Head Description (3' stick up): 11 3/4" casing with collar with leaking weld below coHar 11 3/4" casing Welded on þlind plate 2" nipple 2" gate valve (water-type) . operational . . WOLF CREEK TEST WELL NO. 1 CRETACEOUS Nanushuk Group: Ninuluk Formation: 10'-455' Chandler Formation, Killik tongue: 455'-1350' Grandstand Formation: 1350'-1500' /<:'0 -I t 1- . . Form. 9-683 (Apri11962) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY CONSERVATION DIVISION * Sec. __________ , , : I · , ' ~---_·I·----I·--___I-----. · . ' · . ' · , ' -----1-----:------1---- . · , , · . , ------L----J-----'.----- i i : : 1 ; T. _________________ R. _________ INDIVIDUAL WELL RECORD _______________________ Mer. ~ 1f. P. R. 1ft. Land office __________"':_- Date_________Iune _2..t_J~,9.s9__ Ref. No. ________ State __ ~aska Serial No. _______~_________ C~lIJlt,' Lessee __________ Field_J!.o~_J:reek_~~~__________ Operator --Y.LS, J&:yL District West leaat.légtÓÐ -..-..------ Well No. _!!>!;'__£~~.:....f~!I_~_!~!~_ .!___________* Subdivision ______________________________________________ *' Location .RecQrtLi.n~~ej¿~-----------------------------------------______________________________________________ Drilling approved ________, 19___ Well elevation Drilling commenced __~il~_____, 19-2!__ Total depth __1;0º-_________ feet If. J. ______ feet Drilling ceased ____ June 1 ____, 19 5~_ Initial production none Completed for production _________, 19_____ ed Abando~~~__~ J"uue:-'l_, 19-51._ Geologic Formations Surface L01D68t tested Gra.vity A. P. I. Initial R. P. Productive Horizons .Depths Name C07&tmt8 ------------.. ~-------------- ------------------------ ----------------------- -~--------- WELL STATUS ----------------------------- ------------------------- - Y mAR JAN. FEB. MAR. APR. MAY JUNE JULY AUG. 8mPT. OCT. Nov. D:mc. 1951 --~~-~- --~~-~ ADd. --------- ----------- ----------- ----------~ ------.---- ----------- ---------- ----------- ---------- ----------- -------- --------------- ----------- ----------- ----------- ----------- --------- ----------- ----------- ----------- ----------- ---..------- ---------- ------- --------------- ----------- ----------- ---------- ----------- ---------- ----------- ---------- ----------- ----------- ----------.. ---------- -..--- --------------- ------..-.._- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ---------- ----- --------------- ------.._--- ----------- ----------- ----------- --~ -------- ----------- ----------- ----------- ----------- ----------- ---------- -- '0""".0 ...._.. * Unsurveyed . ~---------------------------------------------------------------------------------------------------------------- ---------------------------------------------------------------------------------------------------...-------------------~ ----------...------------------------------------------------...---------------------------------------------------- -------------------------------------------------------------------------------------..---------------------------- _~J.W~_I~_¥~-lmä.ii.cœ.l._!a.p~r--30.L------------------------ --------------------------..-..------------------------------------------- ¡f/A f£f( u. s. GOY!INMI :NT PRINTINII O,.,.ICE 16--~7-4 . . L~__ G ~,ffr.~i) ~- " .~~_._~";",,,,_~c~____~ . ________' ~ ~...~.--~.__.~...._-,---~._- -Ä--J¿~.. -- ____:_~___c~ Zf~J--¡5-:i.. ..tð~.... ~'. . JI!~,?, >< . ~æø--t~A~~. ·_··'·,.oL~S.~~(!¡.·.~~<~ .....;:¿.~. --..-~-_-_~~~-_~/:, ~~-~;i_l1¥ >.' ~... ~~ì.){:¡;fii2t¿'. ~1;/.u ~_____~_-.~~-.._--~..cJ . ,_,__' _. / ~~~:~._~.. 7 (A1,~~~~,~> ..___...__~...~lP:J?/l'-ll. .It.. It - (I 11 f~ -:" . ~-_. . --~-~- -.. '-~---::"'----:-:-' --~~-'~-.-"'-"~-'-----'--"~-~- , ¿ d?3 -.C "/ X-------I~~--·~-1~7---c-~··-~~;~-··;.;---··.. ...----..~ u:-·~I'~~.;.;;:~"tF~?5l+ ~~____~-_.l~7Þ " t1 -------~~.-~ ~ ~~~ C~~) '. . · ". y . k__ c-( . c-:' ~.( ~~.~.._~.___. 'On ~.____._'________ -- -------~ --- -- ~ -~---- fA!.£_2-___2Ja__.___..z()~~?:Î. ' Q _._~_~__...~----2£if~-t- (L L¡ __.~.___.~___.?~~_~._Ë~-- ________li_ ____~. - -_-.-__ _....._:'-__._.._2_~..?_·__.12._. _~__-z;;~~,_. _._ -..,,------~.--~f f£:-;;A._..._~~__._....,. t( (¡ . (¡ -----~_._--_.._-,.-'-'--- -<--,--~---,--.,--.~-"--.,-- ._~-- - -,.,._-'.----_._-_.~_.__. DriUing-mud characteristics and additifJ8II, Square Lake test welll-Continued VJscœ. Water Tem- :~ Weight It,- loss pera. Aqua- Que- Depth ijbper (Marsh (co per ture lIeI bracho pbates Other addltl"'i!S eo rt) runnel 30 CO F) (sacks) ijb) ijb) see) min) - - - - - - - 3, 776 91 ISO 4.2 70 ------- ------- ------- 3,826 93 IS8 4.4 76 ------- ----...-- --...--_... 3,846 91 ISO 6.0 72 ----_...- ...------ -----...- 3,860 91 iiI 4.8 64 ------- ------- ------- 3,882 91 49 4.8 64 ------- ------- ------- 3, 910 91 1i7 6.0 65 ------... 325 190 100 lb Drlscose, 16 lb canst1c soda, 10 sacks Barold. 3,923 91 ISIS 4.0 65 -..----- ------- ------- 3.960 92 60 4.0 68 ------- ------- ------- 3, 1187 91 64 4.0 66 ------- ------- ------- HOLE DEVUTXON Deviation from vertical in Square Lake test weIll ranged from 0°15' to 2°00' and averaged approximately 0°50'. The greatest deviation occurred between 1,100- 2,100 feet; above and belöw that interval the hole was rarely as much as 1° from vertical. Deviation measure- ments were made with a Totco (Techanical Oil Tool Corp., Ltd.) recorder and are shown on the graphic log (pL 29). ELECTRIC LOGGING Electric logs were made in several runs between 110 and 3,984 feet by Schlumberger Well Surveying Corp. Runs 5 and 6 duplicated part of the earlier runs, in order to record the curves on different scales. On the graphic log (pI. 29), run 6 is used in place of runs 2-5. The depths recorded in each run are given below: Run Dep'h (lee') Run Dep'h (Ieet) L______________ 110-728 5_____________ 1, 500-3, 389 2______________ 728-1,675 6_______________ 728-3,752 3_______________ 1, 67~2, 664 7_______________ 3,'150-3,875 4-_____________ 2,664-3,062 8_______________ 3,875-3,984 WOLF CREEK AR In 1951 and 1952 c c on actors drilled three holes to test the oil-producing possibilities of the Wolf Creek anticline, a structural feature with a northwest- ward trend about parallel to the other anticlines in the northern foothills section of -the Arctic foothills province. The northern foothills section of the province in the vicinity of the Wolf Creek tests has a maximum relief of about 1,000 feet. Northwestward-trending escarp- ments parallel the Wolf Creek anticline to the north and south, although the anticline follows a lower less rugged ridge. There is about a' 250-foot difference in the elevation between Wolf Creek test wells 1 and 3 on the crest and Wolf Creek test well 2 in the creek valley on the north flank. · /ÝI ().EMIr 4, ALASKA, 1944-53 Wolf Creek anticline, first mapped by a Geological Survey field party in 1946, was studied in more detail in 1941. It was further defined in 1949 by photogeo- logic mapping by WÎlliam P. Brosgé who also drew the structure-contour map of the area shown in figure 36. This narrow anticline is about 30 miles long, and a pos- sible western extension may add another 25 miles to its length. Two hundred feet of proven closure encom- passes an area 5 miles . long, near the east end of the anticline; maximum closure of 600 feet, enclosing an area 16 miles long, is possible but cannot be proved (Brosgé, written communication, 1956). The 3 wells were drilled in Cretaceous rocks : Wolf Creek test wells 1 and 3, 485 feet apart on the crest of the anticline; penetrated rocks of the Nanushuk group (Lower and Upper Cretaceous): Wolf Creek test well 2, a mile and a third away down the north flank, drilled through 130 feet of the Seabee formation (Colville group, Upper Cretaceous) before entering older beds. Wolf Creek test wells 1 and 3 found a small amount of gas which has no present commercial value. The highest rate of flow, measurea in Wolf Creek: test well 1, was 1,304,900 cubic feet per day at 8 pounds pressure through a llh-inch orifice, 'with shut-in pressure build- ing up to 60 pounds in 30 minutes. Wolf Creek test well 2 had only a faint show of gas and produced. some salty water. STRATIGRAPHY A small amount of alluvium, which mantles the Cre- taceous rocks, was drilled in Wolf Creek test wells 1 and 2; in the latter test, located near a small creek:, the drillers reported penetrating gravel, underlain by olive- . gray clay, before reaching Cretaceous rocks 40 feet below the derrick floor. SEABEE FORMATION Ninety feet of the Seabee formation (Colville group, Upper Cretaceous) overlie rocks of the Nanushuk group (Lower and Upper Cretaceous) in Wolf Creek: test weIl 2. These beds consist of olive- and mOOium- gray siltstone, with a small amount of gray sandstone and clay shale, some cIa ironstone, and a small amount of light-yellowish-gray bentonite containing abundant euhedral biotite flakes. NINULUK FORMATION Beds of the marine Ninuluk formation (Upper Cre- taceous), uppermost part of the Nanushuk group, are the youngest Cretaceous rocks found in Wolf Creek test wells 1 and 3; the following description is based primarily on information from those wells. In these wells the Ninuluk formation consists of 200 feet of 69· 25 8000 I o I 8000 Feet I -1100-- Structure contour. ,dashed where approximate. Con- tour Interval 100 and 200 feeti datum Is mean sea 69· level' 20' 153·40' 30' 153·20' ~ ~ . !fJ m C e 69· S 25' ~ ~ ~ ~ t!!1 Þ1 - ~ Ë ~ 69· 20' FIO'OBII 8Ø.-Structure-contour map of the Wolf Creek anticline. The contours are on a horizon 800 feet above the base of the Seabee formation. ~ . 448 . EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, ALASKA, 1944-53 GRANDSTAND FORMATION The Killik tongue (Lower Cretaceous) of the non- marine Chandler formation (Nanushuk group), is about 900 feet thick and is composed primarily of clay shale, with some thin beds of sandstone, siltstone, and coal. The clay shale is medium dark gray, and is silty and micaceous in part. A little black clay shale is asso- ciated with the coal. The thin sandstone beds differ from those of the Ninuluk formation in being very fine grained, very argillaceous and silty, and slightly to very micaceous j some of the lower beds, which are 10 to 20 feet thick, produced & small amount of gas in Wolf Creek test well 1 and water in Wolf Creek test well 2. The base of the formation cannot be determined ex- actly, but the approximate division between the Killik tongue and the underlying Grandstand formation is placed below the lowest J!?entoni~and above a common occurrence. of specimens of Vemøuüinoidea bore<ilis Tappan, although a few Foraminifera occur, probably in thin interfingering beds of marine sediments, just above the base of the Killik tongue. (See p. 481) t 1\ (,,0 C t __ . ~ ~ 11 ) sandstone separated into beds 20 to 50 feet thick by beds of clay shale. The sandstone is commonly light medium gray, fine to medium grained, friable, and slightly silty and argillaceous, with a salt and pepper appearance; none of the beds contained oil or gas. The rock is composed of angular to sub angular clear and white quartz grains with some gray chert and dark rock fragments. Clay shale, which makes up a little less than half of the formation, is medium to medium dark gray, and is rarely very silty. Siltstone, present in thin beds, is medium gray, argillaceous, and slightly micaceous in part. A minor amount of shaly coal, clay ironstone, and white' bentoni~ are also present, al- though the last is rare and is limited to the upper part of the formation. Å distinctive microfaunal assem- blage, the Gaudryina7Trochammina fauna, is present in this formation. (See p. 480-4:81.) The drill in Wolf Creek test well 2 penetrated similar rocks, but the lithologic units described above vary considerably in thickness, or disappear entirely befo~ reaching this northern test. Some of the sandstone beds can be correlated in the three wells. The upper- most 50 feet of the Ninuluk formation, not present in the other wells, was found to be similar to the rest of the formation, except for a slightly greater amount of bentonite. The base of the formation is found at the bottom of the thick sandstone beds and below the lowest occur- rence of the Go:udryina-TrochammimD, microfauna. The formation is approximately 420 feet thick. 'RTT.T.T'R' TONGUE OF THE CHANDLER FORMATION ? " .-C~,1q (~. ~!) - Only the uppermost part of the Grandstand forma- tion was penetrated by Wolf Creek test wells 1 and 2 (150 and 60 feet, respectively). The description below is based on the 1,360 feet drilled in Wolf Creek test well 3. The formation (Lower Cretaceous) is the lowest part of the Nanushuk group in this area. The rocks are marine and consist of about 1,350 feet of alternat- ing sandstone and clay shale with rare siltstone beds. The upper 125 feet consist of medium-dark-gray non- calcareous silty Clay shale. This is underlain by 60 feet of medium-light-gray fine-grained slightly· silty very slightly micaceous sandstone that is composed of sub- angular clear and white quartz with rare chert and rock fragments. A few thin beds of clay shale break the con- tinuity of the saiulstone. A show of gas and a faint cut of oil in CC!. were obtained from this bed. Lower sandstones are very fine to fine grained, range from 15 to 100 feet in thickness, and alternate with 10- to 100- foot beds of clay shale or claystone; sandstone makes up approximately half of the sequence. Two of the sandstones gave slight indications of oil or shows of gas. Porosity of the sandstone beds range from 0.3 to 16 percent and permeability from impermeable to 32 millidarcys, except for a bed at 1,553 feet which had 19 percent porosity and 305 millidarcys permeability. The base of the formation is arbitrarily placed at the bottom of the lowest thick bed of sandstone. TOPAGORUK FORMATION The Topagoruk: formation (Lower Cretaceous), pen- etrated on the anticline only by Wolf Creek test well 3, is a sequence of marine rocks differing from the over- lying Grandstand formation only by the lack of thick, . massive sandstone beds and the greater proportion of fine clastics; the microfauna and cha.racteristic rock types encountered are the same. The formation is com- posed mostly of medium-dark-gray clay shale, with some beds of medium-light-gray very fine-grained ar- gillaceous silty sandstone and medium-gray argilla- ceous siltstone. No shows of oil or gas were noted in the 1,000 feet of the Topagoruk formation penetrated by the well. As the base of the formation was not reached, its total thickness in the area is unknown. ~LF CREEK TEST WELL lJ Location: Lat 69°23'11" N., long 153°31'15" W. Elevation: Ground, 712 feet; derrick Boor, 714 feet. Spudded: April 29, 1951. Completed: June 4. 1951; junked and abandoned. Total depth: 1,500 teet. The fust of 3 wèns drilled on the Wolf Creek anti- cline was planned to penetrate the Grandstand for- . . 449 TEST WELLS, SQUARE LAKE AND WOLF CREEK AREAS, ALASKA Lithologic descripti01l-Continued mation, which contains the oil-producing sandstone _ beds of the Umiat oil field about 35 miles to the east, to determine its petroleum content and reservoir pos- sibilities in the Wolf Creek area. The well is about 1,500 feet south of the axis of the anticline. (See fig. 36.) It drilled through a few feet of soil before pane· trating rocks of the Nanushuk group. The Ninuluk formation is present from 10 to 455 feet and is under- lain by nearly 900 feet of the Killik: tongue of the Chandler formation (455 to 1,350 feet). The Grand· stand formation was penetrated in the bottom 150 feet of the hole. No shows of oil were noted, but minor amounts of gas flowed from sandstone beds in the Killik: tongue; the bottom 10 feet in the well produced 1,304,- 900 cubic feet of gas per day from the only massive sandstone bed of the Grandstand formation that was reached by the test well. The well was abandoned at 1,500 feet when a core-barrel assembly was lost and could not be recovered. from the hole. The electric log from this well (see pI. 30) reflects the lithology rather poorly; intervals of high resistivity and spontaneous potential on the log rarely correspond with the sandstone beds as indicated by bit cuttings brought up in the bailer and in the cores that were recovered. DESCRIPTION OF CORES AND CUTTINGS @ Descriptions of the rocks penetrated in Wolf Creek test well 1 are based. on an examination of cores and cutting samples. Composition as shown on the graphic log is determined in part by interpretation of electric log and may düfer slightly from the written descrip- tion. The material was described dry, and colors were determined by comparison with the Rock: Color Chart (Goddard and others, 1948). The depths were meas- ured from the top of the derrick :floor. Abundance of microfossil specimens mentioned at the beginning of each core description is defined as fol-' lows: 1-4, very rare; 5-11, rare; 12-25, common; 26-50, abundant; more than 50, very a.bundant. r-~ Lithologic de8cription [Wbere no core Is listed, description Is bued on cutting samples) Core Deptb (feet) Remarks 0-4 Derrick fioor to ground level. The inter- val between ground level and 50 ft is described from Arctic Contractors driller's log; no samples were taken. Surface soil. Sandstone. Top of Ninuluk formation at 10 ft. . G;;ÿã'hale. 4-10 10-20 ~ t 20-32 ~ 't ~ :s .", ~ ~ ~ Core Deptb (feet) 3Z-40 40-50 5~5 65-90 90-92 92-115 115-125 125-155 155-165 165-180 180-200 200-240 240-270 270-280 280-295 295-301 301-307 307-330 330-360 360-380 380-405 405-410 410-415 415-420 Remarks Clay. Shale, blue, sticky. Clay shale, medium-light-gray, slightly micaceous, calcareous; with abundant grayish-yellow hard clay ironstone. Clay shale and clay ironstone, as above; and medium-light-gray very calcareous siltstone with carbonaceous flakes; and medium-light-gray very fine-grained cal- careous sandstone consisting of suban~ gular white and clear quartz with some dark rock grains and some carbonaceous streaks. Coal, black, subvitreous; with blocky frac- ture. Clay shale, siltstone, and clay ironstone, as above. Coal, with a minor amount of sandstone, as above. Clay shale, as above; coal in upper 10 ft. Sandstone, medium-light-gray, fine-grain- ed, friable; some clay shale and siltstone. Sandstone, as above. Clay shale, as above; with clay ironstone. Sandstone, light-gray, fine- to medium~ grained, friable; composed of angular to subrounded clear and white quartz, some subhedral; gray chert and black rock fragments are numerous, pyrite rare, glauconite and mica absent. The lower 10 ft is calcareous. Siltstone, medium~light-gray, slightly sandy in part; rare clay shale. Sandstone, light-gray, argillaceous; some gray shale. Clay shale, medium-light-gray, very slightly micaceous; siltstone as above in upper 10 ft. Clay shale and siltstone, as above; and black carbonaceous shale with coal laminae. Clay shale, medium-gray, hard; very fine laminae of medium-light-gray clay. Sandstone, medium-light-gray, very fine- grained, very silty, noncalcareous; be- comes fine grained and less silty at the base. Siltstone, interbedded with medium-gray clay shale; laminae of medium-light-gray clay. Clay shale, with streaks of coal and clay ironstone in upper part. Sandstoue, medium-light-gray, very fine- to fine-grained, noncalcareous, slightly silty and argillaceous. Siltstone, interbedded with sandstone, and clay shale. No sample. Sandstone, with some siltstone, and shale. 450 Con r ---- ---- \'¡ ~__u "" ~~ ~ ~ ---- ~ ~ ---- ~ ..: u__ .~ .,; ~ t~ ~.~ ---- ~ ~ Depth (feet) 420-437 437455 455-460 460-495 495-530 530-540 540-545 545-550 550-555 555-560 560-565 565-568 568-575 575-580 580-585 585-590 590-595 595-615 1 615-620 620-625 625-629 629-634 634-650 650-655 655-662 662-685 685-690 690-695 695-725 725-745 . . LUÃOlol1W tluoriplion.-Oonttnued EXPLORATION OF NAVAL PETROLEUM: RESERVE NO.4, ALASKA, 1944-53 Lithologic tle8cription.-Oonttnued Remarks Clay shale, medium- to medium-da.rk-gray, silty, slightly micaceous; and medium- light-gray slightly micaceous argillaceous siltst()ne. Sandstone, as above. Sandstone and clay shale. Top of Killik tontrne of Chandler formation at 455 ft. Clay shale, medium- to medium-dark-gray, nonmicaceous, noncalcareous; a small amount of clay ironstone and 52!l in bottom 15 ft. Clay shale, as above; and medium-light- gray siltstone; some clay ironstone at 515 ft. Siltstone, as above; some clay shale, and a minor amount of coal. Siltstone, clay shale~d coal. Clay shale and siltstone; me sandstone, clay ironstone, black clay shale, and a minor amount of coal. Clay shale, with soIDëšntstone. Coal, with a minor amount of siltstone. Clay shale, siltstone, and coal. Sandstone with some cOal.- Clay shale and siltstone, ëalcareous. Limestone, bluish-gray, slightly ....argilla- - ceous, very finely crystalline. Clay shale, medium-gray; a small amount of limestone as aoove. Siltstone, Wl~h small amounts of gray and black clay shale, coal, and sandstone. Clay shale, and siltstone with a small amount of clay ironstone. Clay shale, medium- to medium-dark- gray; some siltstone at the top and the base of the section. Siltstone and clay shale. Siltstone, with some clay shale. Sandstone, with some siltstone. Recovered 10 in.: Microfossils absent. Clay shale chips, medium-gray; some 1Iakes of carbonized plants; two frag- ments of medium-light-gray sandy siltstone. Clay shale and siltstone, with a small amount of clay ironstone. Sandstone, with a small amount of silt- stone. Clay shale, gray, and~o&!¡ with a small amount of sandstone and black clay shale. Clay shale, with a small amount of coal. ~ and clay shale. - Clay shale, with some siltstone. Clay shale, with a minor amount of silt- stone in the lower part. Sandstone, carbonaceous; a small amount of siltstone and clay shale in the upper 10 ft. Core () (/) ~ Depth (feet) 745-750 750-765 765-775 775-780 780-785 785-789 789-794 794-798 798-815 815-840 840-850 850-857 857-865 3 865-870 870--885 885-890 890-900 Remarks Siltstone. Siltstone and clay shale. Siltstone, with a minor amount of sand- stone. Sandstone, with a minor amount of silt- stone, clay shale, and clay ironstone. Clay shale, with some siltstone and sand- stone. Siltstone, light-gray, noncalcareous; with some medium-gray clay shale. Recovered 5 ft: Microfossils absent. 2 ft 2 in., clay shale, medium-dark- gray; numerous fine laminae of medi- um-gray slightly micaceous noncal- careous siltstone, lenticular or cross- bedded in part. Grades into unit below. 2 ft 10 in., claystone, medium-dark- gray, very silty, very micaceous, noncalcareous; some fragments of carbonized plants. Clay shale. Clay shale, very silty; some black carbo- naceous clay, shale and a small amount of sandstone; clay ironstone in lower half of section. Clay shale and sandstone, medium-light- gray, very fine- to fine-grained, very argillaceous, slightly calcareous in part, slightly glauconitic; carbonaceous patches. Clay ironstone and siltstone also present in lower 10 ft and a few pieces of reddish-brown sandy ~ stone at 820-825 ft. CIåÿšhaIe, with some clay ironstone in upper 5 ft. Clay shale and cQJ:!; a minor amount of black clay shale. Sandstone, as above; some clay shale and siltstone. Recovered 3 ft: Microfossils absent. Sandstone, light-gray, fine- to medium- grained, argillaceous, noncalcareous. It is composed of subrounded grains of white and clear quartz and numer- ous dark grains. Streaks and frag- ments of carbonized plant remains are scattered throughout. It grades into sandy shale and sandstone at base. Permeameter indicated a sample from 867 ft to be impermeable to air. Effective porosity of the same sample by the Barnes method 5.31 percent. Clay shale, with some coal, especially in the bottom 5 ft. - Shale, gray .and black; with siltstone and coal. Clay shale, with clay ironstone in the top 5 ft and coal in the bottom 5 ft. · . TEST WELLS, SQUARE LAKE AND WOLF CREEK AREAS, ALASKA Lithol.ogic tle,cription-Continued Core Depth (feet) Remarks 900-925 925-930 930-935 4 935-940 940-945 945-950 950-995 995-1,010 1,010-1,020 1,020-1,025 1,025-1,073 5 1, 073-1, 077 6 1,077-1,080 t 1,080-1,084 ~ ~ 'l"" tr>\..- 1,084-1,090 1,090-1,120 1, 120-1,140 1, 140-1, 150 1,150-1,160 ---- 1,160-1,170 8 1, 170-1, 174 (Î, 9 10 1, 174.-1, 175 1,175-1,178 1,178-1,225 Clay shale, medium- to medium-dark-gray, noncalcareous; a minor amount of coal in the upper 10 ft, some clay ironstoñë in the bottom 15 ft. Siltstone, with some clay shale, and a minor amount coal. Clay shale. - No recovery. Clay shale, with some siltstone. Clay shale, sandstone, and siltstone. Clay shale, with a minor amount of clay ironstone, and some siltstone at the base. Clay shale, with sandstone in the upper 5 ft, and clay ironstone in the lower 10 ft. Sandstone and clay shale, a minor amount of clay ironstone. Clay shale and siltstone. Clay shale, with siltstone streaks. No recovery. No recovery. Recovered 3 ft 3 in.: Microfossils rare. Claystone, medium- to medium-dark- gray, nonmicaceous, noncaloareous; some medium-light-gray slightly silty lam- inae, commonly crossbed.ded. A olay ironstone lens one-half inoh thick is pres- ent 1 ft above the bottom of the core. Clay shale, black and gray; some sand- stone. Clay shale, with small amounts of clay ironstone, siltstone, and sandstone in the upper 10 ft. Clay shale and sandstone. Clay shale. Sandstone, light-gray, very fine- to fine- grained, argillaceous, micaceous, non- oalcareous. Sandstone, light-gray, medium- to fine- grained, slightly argillaceous; but with many dark rook grains. Recovered 6 in.: Microfossils absent. Sandstone, light-gray, fine- to medium- grained, argillaceous, noncalcareous; patohes and fragments of carbonized plants. The sand grains are sub- angular white and clear quartz, com- monly frosted, with gray chert and some dark rook fragments. Mica, pyrite, and glauconite are very rare or absent. No recovery. , No recovery. Clay shale, light- to medium-gray; a minor amount of siltstone. Sandstone, very fine- to fine-grained, argillaceous; with clay shale. Siltstone, medium-gray,' very sandy, slightly argilla,?eous, micaceous, noncal- careous; a small amount of olay shale. fVÆ- a- LJ WCt-IdJo ~,1) 1, 225-1, 235 1,235-1,250 466290-:19-5 451 Lithologic tle,cription-Continued Core Depth (feet) Remarks 1, 250-1, 270 11 1, 270-1, 273 1,273-1,278 Sandstone, fine-grained; with gray clay shale and siltstone in upper 10 ft. No sample. Recovered 2 ft 6 in.: Microfossils absent. Siltstone, medium-gray, argillaceous, slightly sandy, very slightly mioaceous, noncaloareous. The silt grains are sim- ilar in composition to the sand grains of core 8, but are more angular and have a larger percentage of dark rock fragments. Grades into silty clay- stone at base. Sandstone, with some clay shale and clay ironstone in upper 7 ft. Recovered 2 ft 6 in.: Microfossils absent. Sandstone, as in core 8. At 1,292 ft the rook has a porosity of 7.02 peroent and is impermeable. ctJëtom~ white to yellowish-white; abun- ant rounded grains of a yellowish translucent material and rare euhedral ~!~~!~ plates. Clá.y'shâ1e. Clay shale, with a small amount of )benton- itel and sandstone; medium-gray very Mltdy slightly argillaceous noncalcareous micaceous siltstone in upper 10 ft. Clay shale, medium-gray; a minor amount ___ of clay ironstone. Top of Grandstand ~ formation at 1350 ft. \( Siltstone, medium-gray, very argillaceous. 1 Clay shale, medium-dark-gray, very silty; 1 carbonaceous streaks and streaks of l::: siltstone; a small amount oftbentoniteJat ~ 1,435-1,445 ft. ~ Siltstone, with sandstone, and some ;;: J~tonite~ ~ o samp1é. Arctio Contractors' well \:1 geologist, Marvin Heany, described the interval as sandstone. LOGISTICS A drilling foreman and a geologist supervised the drilling of Wolf Creek test well 1. The drilling crew included 2 drillers, 2 tool dressers, 1 fireman, 1 heavy- duty-equipment mechanic and welder; 5 other men-1 cook, 1 kitchen helper, 1 janitor, 1 Caterpilla.r-tractor operator, and 1 warehouseman-timekeeper-were also permanently employed at the site. Electricians, addi- tional tractor operators, and the electric-log operator came from Barrow or Umiat as they were needed. Housing consisted of 15 waniga.ns; 2 were used for dormitories, 2 for water storage, and the others for 1 galley, 1 messhall, 1 radio room ànd store, 1 food ware- house, 1 generator and boiler room, 1 geological and ~- ~A..t/.¿ J /7 I, [bPI? f1:; I, / // tJ f- /'.J.. ... - ¡r -II d /I.. f'(;.., V'i ".."', ~ 1,278-1,290 12 1, 290-1, 293 ~ 1,293-1,300 1,300-1,310 1,310-1,350 ¡--- 1,350-1,400 1,400-1,420 1,420-1,485 1,485-1,492 1,492-1,500 CORE T. AND TEST WELLS, OUMALIK AREA, .K..-\. Simpson Seeps: 34 core tests; a shallow oilfield was defined by the series of core tests. Square Lake: 1 test well; a prospect northwest of Umiat defined , by seismic and photogeologic techniques. Titaluk River area: 1 test wen; located on an anticline mapped primarily by field and photogeologic methods. Topagoruk River area: 2 test wells; in the central part of the coastal plain; a deep test penetrated rocks ranging in age from Devonian to Pleistocene. Umiat: 11 test wells; many produced oiL Wolf Creek area: 3 test wells; relatively shallow tests; shows of gas. The test holes range in depth from 47 to 11,872 feet, and the drilling penetrated rocks of Paleozoic, Mesozoic, and Quaternary age. Most of the footage was drilled of Cretaceous rocks, and all the oil-bearing beds found are in this age. Figure 3 shows diagram- matically the relationships of the Cretaceous rocks. Paleozoic, Triassic, and Jurassic sedimentary rocks were penetrated in the drilling of a few holes in the northern part of the Reserve, but only a small amount a: L/J ... ... ::J <1'1 ::;) 0 L/J U < -1- I- L/J a: a: a: ......... ~=.. 0·" u .. " -?-- a: .... :;: o -' FORTRESS MouronAIN TOROK FORMATION FORMATION -----------------------1 1------------- LOWER CRETACEOUS <?)AND UPPER JURASSIC(?)ROCKS, UNDIFFERENTIATED OKPIKRUAK FORMATION -1 UNITS OF JURASSIC AGE .. Not known \ of gas was found in these older rocks. Oilfields' discovered at Umiat and Simpson seeps and gasfi at Barrow and Gubik. Some shows of oil or gas "__ also noted in other holes. The United States Geological Survey participated in the program as a cooperating agency. Drill cores and cuttings from the tests were shipped from the reserve to the Suryey laboratory in Fairbanks where they were processed, described, and analyzed. De- tailed subsurface information based on laboratory studies and analyses by the authors has been compiled by groups of related wells; in addition, logistic, engineer- ing, and drilling operational data have been abstracted from the files and reports made to the Navy by Arctic Contractors, United Geophysical Co., Inc., the Schlumbèrger Well Surveying Corp., the U. S. Bureau of Mines, and the National Bureau of Standards. These data as well as a geological interpretation of the sub- surface information constitute this paper. ARCTIC COASTAL PLAIN PROVINCE Sentinel Hill member SCHRADER Barrow Trail member BLUFF --------- FORMATION Rogers Creek member Ayiyak member SEABEE FORMATION NINULUK FORMATION GRANDSTAND FORMATION TOPAGORUK FORMATION 1---------'----- OUMAlI K FORMA nON Relationship of these rocks to those to the south is unknown Predominantty merlne PredominantJy nonmanne FlOURS 3.-Nomenclature of the Cretaceous rocks of northern Alaska. t\ _ .. ,..., I. J. ¡ A ¡ 1-'- V"-' f-I _of I . d-. . f~e- . ..1.. ~ Sft-- l¡Jc~J -?,S9 ~e 7 S'C;Z,-J3 .2 s·~t'--G.·. ? 3y~ JJ .~~'67~A 3bS~ß-:« g c.:~I)"~ c: ,. /ð 80-~' ß I¿Y:5 0- j) I . . ...., " C r¿ßf1 K'" wf' LL" ,if;: , , V(S"'\...V\ L E- s-7ìMA te 6> c.\ ,..J . , p L./} G:.- ~ ~ """ . !6 --;70+ ,)( --v ¡;¡.f- :.-"'.. K ·x ., '....-+ ó- X..', 7' j ".~ ....--. . ' / ¡flteE -x' x , 7!¿¥B < .X- '~ x·' , . '7'7fiJ;~c.B.. ' ..L. : 1- L .., /:J. '93-- 1ft 7f¿éJ 7J /ð+ y. _ /C.'4 ."1 M.~c~.~: Ii . j '7'\ 'X' x x Ro Co (! )G+~¡~.. ..... . . ct- I{ ( t x .. 5::.;; (j'þ1 ~<,-4 .' ¡ I i I --I , i .-1 ..J I I j I I i I I , )J /{J'\e)¡-'ry I I i ,~ _x ~x x, x- x. )'S'-f:/lb'-!,,¡J e >;5' / 0.':"i~~'f~;':CL~~{7Y - - . 1 , j"S' (t-( "J' ". . / .5s {;, 0"J·.' . , .-. . . .S'5 55' '( ;~¡J¡;~) 'K,' !} $ (SùWc~po~,~~rI-'() , . (;0 0 L-r cl¿£lß.J( WelL-'#: SfL.' IJSC.L- I d ~3,-ß ("d. 73 -c _ /2 r8·~A -.,;:-~ -- " J ,/ {)'c s-'-~ L, g S1¡ rVt,4 C æ i? c.\ ,..J . if?) -7 {tY\..::¡ - , P LA G:.- ')<0 'X ' (iVl ,'ê...r. b ,~1";' tAt! ?J " ¿\ , X' ,'v ^ 1C 1'" -L . ¿ C! '!~,. .."./ ~~---^.. ,.)1 -----..- ..-....- ,- \. " - . f~e- -« :~ L l '(b " Co I! x 5~ , Irs ~~1)tff5 -b.~è- >< SjitYH 55 ,- , .-- '- , - , - CORE a AND TEST WELLS, OUMALIK AREA, ~KA \ Simpson S~eps: 34 core tests; a shallow oilfield was defined by of gas was fmind in these older rocks. Oilfields the senes of core tests. . discovered at Umiat and Simpson seeps and gas , Square Lake: 1 test well; a prospect northwest of UIDlat defined t B d G bik: So sh f il \ by seismic and photogeologic techniques. a arrow ~ u . me ows 0 0 or gas 1_ 'Ì'italuk River area: 1 test well; located on an anticline mapped also noted m other holes. \ primarily by field and photogeologic methods. The United States Geological Survey participated Topagoruk Riv~r area: 2 test wells; in the central p.art ~f the in the program as a cooperating agency. Drill cores coastal plaIn; a deep test penetrated rocks ranging In age d tt" fro th t ts shi d f m th from Devonian to Pleistocene. an cu mgs m e es wer~ ppe ro e Umiat: 11 test wells; many produced oil. reserve to the Suryey laboratory m FaIrbanks where Wolf Creek area: 3 test wells; rela.tively sha.llow tests; shows of they were processed, described, and analyzed. De- gas. tailed subsurface information based on laboratory The test holes rarige in depth from 47 to 11,872 studies and analyses by the authors has been compiled feet, and the drilling penetrated rocks of Paleozoic, by groups of related wells; in addition, logistic, engineer- Mesozoic, and Quaternary age. Most of the footage ing, and drilling operational data have been abstracted was drilled of Cretaceous rocks, and all the oil-bearing from the files and reports made to the Navy by beds found are in this age. Figure 3 shows diagr8.IÎl- Arctic Contractors, United Geophysical Co., Inc., the matîcally the relationships of the Cretaceous rocks. Schlumbèrger Well Surveying Corp., the U. S. Bureau Paleozoic, Triassic, and Jurassic sedimentary rocks of Mines, and the National Bureau of Standards. These were penetrated in the drilling of a few holes in the data as well as a geological interpretation of the sUD- northern part of the Reserve, but only a. small amount surface information constitute this paper. 0:: ... ... ... ::> U1 ::> 0 ... u -< I- ARCTIC COASTAL PLAIN PROVINCE Sentinel Hill member SCHRAOER Barrow Tr.U member BLUFF --------- FORMATION Rog.rs Creek member Ayiyek member SEABEE FORMATION NINULUK FORMATION ... 0: 0: a: ~gt u ... :J GRANOSTANO FORMATION TOPAGORUK -?-- FORMATION 0:: ... 3: o ...J FORTRESS MOUNTAIN TOROK ?---------'---- FORMATION FORMA TrON OUMALI K FORMATION -----------------------? ?------------- -? Relationship of these rocks to those to the south is unknown LOWER CRETACEOUS (?JANO UPPER JURASSIC(?)ROCKS, UNOIFFERENTlATEO OKPIKRUAK FORMATION UNITS OF JURASSIC AGE Not known Predominantly marine Predominantly nonmann. FlOURS 3.-Nomenclature of the Cretaceous rocks of northern A.IaBka. ,/ t, t.· \ .1\" \ > . E§T~rêTê:O Fa OFFICIA.L USE ONLY COP y NO .....<-3.......:: ,. U Q s~ G72Ç'.J.¡OG·¡Cit& i5URv.:~ Navy Oil Uni J; l.a.bora.tory Fairbanks, Ala..!$:ä rJOLF CRF...1?iK TE;~T WJ.ilï:~ nQ ~ 1. Wol:t' Creek :¡;ast Well Uo" 1 (Lat<, 69° 235 18" No 6 l,ongo 1530 31" 3211 í( 0 Qµ.a.drangle 1=136 elevaUon '71411) is locat'ld on a northltJsst=eoutbeast trending anti,· oline defil1ed by surface and photogsolog1~ mapping" ¡ t spudded on April 2" 1951" with a BucTrus ca.ble tool rig" No oil shl.)wa I¡mz's noted.~ but gas sands wre encoWl~' tared at 863=·8681¡ ~ 1152=1175°0 and 1491') to th'B total depth of 10005,; The 863~868 ú sand flo'wed 116 l'leF of ga.S through a 3/S(1 orif:i.cÐo and built up 40 1b" psi smt=:l.n pressure in õ minute So ~he sand :trom 149:L iì to total depth produced 1304..9 MCb' through a liØ orifice, building up 60 lbs psi shut=in pTßssure in 30 minutes" As a result of an W'lf.lt.Lccesøful fishing operation~ drilling waß stopped at lOOO~ 0 the hole was filled wi th water and shut in on June 5. 1961" The test penetra.ted a.l tema:ting sand1toneo ail ts'ton8 and 5halØo with coal beds at gelJD 120-12030 365ije 555;)0 660'0 853'1 and 8ao" " YellO'.!1ish ",¡bite bentonite 1rl:th very rare biott te flakes and aÒUIldant X'ouxlded ri,'Tains 01 a yello\>1Ísh translucent material 1s present a.t 1293=1300@i a t:st1¡;:ky blue shale!! reported. by the driller at 4O=OOiJ Œ-"W a1 so be benton! tic" The sands vary from hard to friable and from calcareou.s to non-calca.reous~ and usually contain st::eaks and fragmentÐ of carbonized pla.n~ mate:rial~ aand beds ranging in thickness from· 2" to 30ð total a:pproximatsly 270g of the gection~ The best sands are med1um to fine grained) poorly to moderately induratedo w1 th minor aI1lounts ofargillaoeous cement~ Grains a;re angular to 8ubroundedr¡ $Xld are composed of clear and white quartz and gray chert wit}~ som,,) dark rock fragments" Pyrite 18 rare" mica and glauconite absent" Siltstone is similaT to the sandstone except for grain size; some V8'17 fine aand is included:in the uaual size range~ Shale 1s mediwu grt!JYÐ calcareou.s to non-calcareous, very sligbt:Ly and finely micaceotts. Cla"v ironstone com= poses s-"ICf$ of the individual 'bailer sam:¡;Ùes d(¡WJ, to 200a f, it averagee about fJJ, below that depth.. l'!lJ1or amounts of black: carbol1acQoTJ.a shale a1'0 associa:ted wi th tbe coaly interval!" T"l1e electric log :from this well refl.)cts the litholog V81:Y poorly~ intervals of high resistivity and self-potential only occasIonally correspond with the sand eection~ a.G logged from bailer and core samples" M1crofaunal studies by Harlan Eo> :Bergquist indicate thatQ beneath a th~.D. mantle of surface 8011 the well was drilled en ti;rely irl thin the Creta.ceous section" b u.pper 42õu contain a. uGaudI7ina. sp......~ocham!J1ina. F fau.nallo which is either uppermost Zone E (Nanuah~~ Group~ Lower (1) ~retaceous)Ð O~ Zonø F (Colville Groupo Upper Cretaceous) in ageo Below this 18 a relatively barren. intóJ:rvalo but at l075~ 0 a true Zone .E a.rena-~ C80U8 fa:ana (¡IVerneullino1dee F fau.na.!1) appearoØ and continues to t}-¡,8 total depth\) al though the foraminifera are common onJ.y beloH 145O! c On the ba.sie of paleontoloß1cg 11 tho:~og1cc and outcrop data,) t'lolf Creek Test Well Noo 1 is 400~ structurally higher thM 1'1Qlf' Cr€lek Teet Well Noo :ao a. test 6500fi to the ø.orth" \f>( \05\ . . ~tbo!9~i£ L~.l:1'OtioD. ~he folloÎlring description is òasf.)d on data from coresØ l>ailar sa.mples and well geologist's report, Core Deuth Recover): .QeBcr1ption 0-4B 4-10 Q Derrick floor to ground 1evel~ Surface BoiL (O~õOa from driller!! s logø as quoted in the well geologist~s Wsek¡Y Progress Report for May 7ø 1951. no sampl~s are available for this interval.) Sandstone G:rq shale Cla,y StiCky blue sbaleo . Clay sbale~ med1um light çayp calcareous" slightl;y micaceousø with abundant clay :1ronstonsp grayißh 78110wo :baret.. Cl3¥ Shcl0 and ironstone as a.bOV8ø and ail tsto~.', medium light g-¡¡a$p very calcareollso with cä:rbona." ceou.s flakesr. and sandstoneo very fine grained" medium light g:rS3o calcareoUth of eubangl11ar white and clear quartz with some dark rock grairu and some carbon~ceous streaks" Coal" bl ack 0 subvi treouso 'blocky fracturso Clay shale 0 sl1 tstone and clay ironstone as a.bov~o Coal. with minor amount sand as in sandstone a.òova., C1S3 f¡haJ.e as a.bove~ 1Id th coal in upper 10u ð Sandstone" fine grained. friableø medium light ça::fi) wi th some cleJ'" Elhale and 811 teton/!. Sandstone as aÌJove ~ Clay shale" as abovG~ with c1B3' ironstoneo Sand. loose~ fine to medium gra1nedo light gra~To compO' Bed of angular ta sub:round clear and whl t~ quart£o some subhedral; gray chert and black rock :f'ragmen ts are D.wneroue" PTr1 te ra.re~ glauconi ts and :nica 801>1'3&nt,, Sandstone in the lower 100 ia cal c¡3.reous~ 511 tstonee medium light ~'Ta;r 0 occasionally sllghUy sandy 0 Sandstonso light gr~. arg111aceou9o with some gra-¡- shale. Cla.v shalso medtwn light gray" very slightly m=.= CaCeouso ~nth siltstone as a.bove :LA upper 1090 Cl~ shale and 9il tstone as abov8o and bla.ck ca.rbonac.aou¡;¡ shale with coal laminae.. . C lay shale" mad1 um gra'l fJ hardo ï.d 1;h very fi ne laminae of med.:twn light gray claT~ Sand:3toneo V8l'"Y fine gra1nedo ver¡- sil ty 9 rned:h¡m light g;ray" non-calca.reouB9 grading to fine g;ra:irl.Ð(i.. and J.sse, en ty at the baseo In~erbsdded clay shal~ and siltstoneo lO~20ð 20-32[1 32-400 4O=5Ou 50-650 65- 90 I) 90-92U 92=115& 115-125 0 126-1550 155-165 t\ 165-180· 180....200u 200-240 6 .240=2706 270...280 u 280-295Q 395-3019 301-307° 307=3306 ð30-360 0 :a . Co:r~~ ' De"p~ Recove~ 360=3803 380=405~ 405=410 q 4l0-415~ 4l6-4a)~ 420~437ù 43?-453~ 463-,460' 460-495Q 495=530" 530-540 ~ 540-545Q 54&-550° 55Q...S55 Q 55&,.560° 560~5650 565-5683 568=5150 515-5800 580=5859 585-590& 590-5953 595-615Q 615=6~1 620...625Q 625-629 ' 1 629~~6349 OQ lON . Ea~Jlr1nlli}l G1a..v f¡hala wi th st:r¡~aka coal an.d clay ironat,c!1e in u.pper part. S~ndstonßf' fine to Tory fine gralIled", medium 1:lght g;ra,;Vo nou"":Ca.lI:a:reous. alightly sllty. In tarbadded a11 tstoile€ sandstone and clay shB.la" No !Sample. Sgnda tono 0 with som~ siltstone and shale. C lay shale~ ail i1' n medium gray to medium dark graye alightlY,micaeeou$~ and s11~ßtoneð medium light ça;b G11ghtly micaceous" Sandstone as above> Sandstone and clay ßhaleo Cl,q shale. medium gra;¡ to medium dark gray r nolÞ, mica.eeous~ D.on-eaJ.oareotls~ wi th Bma.ll amount lrclQ.= 8 tone and coal in bo t tom 15 ~ . ' Clay shale as above" and med1wn light gra:¡- ail t= stone. eome clay lrcmstonÐ at 5159" SU tstone as above 1d th some clay shale and a minor amount of coa1.~ Siltstone~ Clay smù~e and coale Clay ßhale a...n.d 911 t~3tone wjfu some sa.ndston~ø C1..':1J' honst,'oneo black cll~ shale and a. m1!í.or a.mOU:'Q~t o:f coale Olay shale with some siltstoßÐo Coale with minor amount siltstone" Clay shales Ul tstone and coal. Sandstone" wi th som~ coalQ Clay shale &~d siltstoneo both calcareoua~ Limastonev bluish gr.aya slightly argil1acao~~o vary flnèly cTJstallinao Olav shale a medium gf'å3o wi th a mnall amount of 11msstone as abov6o 511 tstoneo \d. th smaJ,l amounts of gray and black ola"y shale!) coal and sandstone" Clay shale 0 and sUI.stone wi th a small amoUJl t of cla;r ironstone. Clay shalso medium græ;.:r to medium dark gra:¡ 0 wi th so:ne ail tstoue at the top and th,8 ba.se of thi~ Si'Jc= Uono Sit tstone and clay Hhaleo Siltstone with some cla¥ shala~ Saniatone with some s11tstone~ Chips of medium gra.,v clay shalae wi th oecasio~.al flakes of carbonized plant material; two fragmep.ti!) of medium light f!7~ sand¥ ail tstonso 111 orofo s'Sll e abssn"!;o 3 .Q£íI! ~~ 634=650~ 650-655 0 655=662~ 662-ô85Ð 685-690° 690=695° 695-7259 725-745t 745=750° 760=>765ª 165-775 I) 775-780(¡ 780~785ij 785=7883 2 789-7948 794--7988 798-8156 815-8403 840-8606 850-8576 851...865 ij 3 865-8708 . ~eCQva;:J: 51) 0" 3ª Ols . .!!~J~cr~_~:2!l C1S{ sbalo and e11 tstoneø wi th smell amaM t cl~ 1ronston80 Sandstone" wi tn a small .amOW'lt of 811 tetone~ Cla¡' ahaleo gray ø and coalø 16'1 th a. small POWl t at BaJldetone .and black cl8¥ shale~ Clq shale» with small amount coalo Coal and clay tthaleo C1BJ' shale wi th some ail tstoneo Clay shalso with minor amount siltstone in lower 'Dart, Sand~tone~ carbonaeeou.so wi th clay shale in upper lOG, and mall amount siltstone throughout 0 511 tstonoo Siltstone and clay ahalsn Siltstone with minor amo\1nt øandstoneo Sand.stone with memoX' amou.nts ~lltstonep claT ShalÐ and clay ironatone6 Cl~ al~e0 with some ~iltøtonø and land3tone~ S1ltstonsa 11~ht grayo non-calcaraousø with some med1UJIt grq clB3' shale. 262" Clay shale. med1œ dark gré!¥a with numerous :fine lamin.a~ of silt Bhalso medium gr27~ sllght17 mi caceouso non= cal careou8o 0 coasionally 1 en t1 cu.lar or oross"bedded. Gradel3 into 291CIt C1S¥s,\;oneo madit'Un dark gr8JT. ver.v silty,,· veq micaceous!! non=calcars()uso with occasional fra.g= men tB of carboni zed pl~m t remains" ' I'U,crofo5slls absent" 0183 shaleo Cla:¡ shal 80 ver;¡ ail ty e wi th some black carbona~ aeous cla¡- 'shal;~ and a small amount of sandstoneg clay ironstone in lower half of section" Cl,q shaJ.e and sandstoneo very fine to fine gra.ined, vsI7 argillaceous } medium light grq a non... to slightly calcareous" slightly g].atlconi UCe wi th carbonaceous patches. Clay ironstone and siltstone also present in loweu' 10ij I' and a few pieces of reddi$h brown sand¥ limeston.e at 800= 82.?u 0 Cl3¥ sbalea "/1 t.h soma :clay ironstone in u.pper Sa" Cl,q shale and coalo with minor a1llQunt of black clq sbaJ. e. Sandstone as abov8!> with a little cl~ shale and 811 tstone" Sandstonee finG to medium grained with argillac= SOU8 cementa light gr:sy~non~calcareouso Composed of su.brounded grains of whi 1;e and clear qua1"tz 4 Q.2.Æ! ~1t 87Qr..8S5tî 885-8908 890=900 0 9OO-925u 92t).., 930 G 930~935~ 4 935-940IÌ 940-945° 945-950' 950-995$ 995-10l0G 1010=10a:> ~ lO2Q=1025¡¡ l025...107:;~ 5 lO?3,",l077~ l077-10SO¡j l080<»l084~ 6 '( 1085"",1090° l090-112)~ 1120-1140 I} 1140-11501) 1150œ>ll60 t) ~J~Q.Y.!-11: 00 0" o~ Olf Of! 0" 3~ 3rt . . ~acr1v.~iºp. and numerous dark grains" Streaks and !:ragrn!$n h of ca,rbonhed plant remains scattered thrOUgho1:~:t" Gra.des into sandy shale and. sandstone.at base, Microfossils abÐent~ I'JtrW-.¥ 5" 3lji) 56?\¡ ~!"me~~l.!_Mx impermøable Cla¡- shalep with some coale especially in. bottom fii) 0 G:rq and black shale wi th a11 ts tone and coal 0 Cl8¥ ehaloq w1'th clay :!.ronstone in top sa 9 coal in bot'tom 51]" Clay shale a medium gr8'J' to medium dark gr8¥e non- calcaraouse with minor amount coal in upper 101)" some clay ironstone in bottom 15~ ð Sllt,stone 1.411 th some cl8¥ shale and minor amount eo,al" Clay shale, Clay shale", wi th some 911 tstous. Cl~ shale/) sandstone Md siltstone. Clay sha.lsø wi t.h minor alIlount cla,y ironstonea and a little el1 tstono at the base" Clay aÞ..ale., 1611 th sa.nd.ßtoOne in upper 59 ¡) and cla;; ironstone 1n the lowsr lOe D Sandstone and clS¡.v eha1.eø with minor amount clay ironstoneo Cl~ shale and 311 tston.9. Clay shaleQ t!li th streaks 911 tstoneo Cla;,rston80 medium gr83 to medium dark gra,vo non",. calcareouse non=m1ca.ceou.s/J with occasional mediUID li~~t gray sUght1¥ ail t:r lam1na.ih often cros:¡¡... bedded. Cla;¡ ironstone lens" tH thick a 1 ;foot s.bovebottom. of coreo M1crofoßsile rar~o BlaCk and gr~ cl~ abp~e with some sandstone~ Cl~ ahale@ with zmall amounts clq iron-atonal! siltstonao and sandstone in ttppe:r lOiÌ 0 0183' ¡f¡...a.la and sandeton,eo Cla;¡- ~hall&. Sands tone~ fine to very :fine grained!) arg1l1acao1.'i.ßn light #ei;/ø non~calca.rßou8o micaceous" 5 . . fº~. 12mt~ !.~~ver.Y: p.!! SCl"J':p'~iÇ1.R- 1160-1170\1 Sandaton~" medium to fine grainedo slightly argilla.ceouß9 light grayf) but with man,y dark rock: grain£>? 8 1170-1174° 09 6" Sand:atoneÐ :fine to medium grained, arg1l1aceo\!.:rJo 1 i¡gh t ua..Y Q nOIl- ca.l careou.sG wi th pa tche t'I and fra~enh of carbonhed plant remains" fhes,S;¡'1ó. grains are su.bangular white and clea.r qu.artz" oftGn fro3ted~ with gr~¥ obert and some dark rock :f::rag:m~ntß. H1ca.~ Wri fie and glauconite very rare to absent~ H1crofoa:Sils absent., 9 1174n-ll'fflS Oð 011 1176-1178 ~ 0° 0:1 1118=122.?~ 1225-123.~u 1235-1250 íi 1260,~12?O11 12'10....1 213q 1273=12789 20 6" Clqv $h.aleQ light gra;¡ to medium g:fS3" with mino;¡, aroOU4t siltsìaneo SandBton~" var,¡ fi1\8 to fine gra.1nede argillaceo'Q,s.; 1.!1:Ì th clay shale? Silt ston8. 'v-e'1:;l 8a.n~ & sl ighUy arg1l1acaoil5¡¡ medi~m ,gr2¥9'non~calcareouso m1caceou00 with :e.mall amoun:t clq sbale" S¿mdst,oAÐ~ :fine çained.¡) wi th gra..y s:hale and siltstone 1,n upper 100" No s,'9.1üpleo -- 10 11 S11tstonso argilla.ceoue¡1 slightly 9an~ø medium gr~" non=calcareoù.I!Q very s11gÞ.tl3' m1ca.Ceou,so ~he 811 t gains are simila.r in compos:!. tion to '&be sand gra1n5 of Core a a.bove" bu.: ; more angular and \td.th a. la:r~r percentage of dark rook; fragments" Grade'! into s11 ty cla-.vstone a.t base.. Microfossil3 absent" 127S...1290U SMdgtone" 'td. th Dome clay sha.le and clay 1ron= stona in upyer 760 12 1290-1293° 20 6" Sand3toue aß in Core 8 above~ Microfossils sbsexÜ" 12920 Porositx ,,/,,02$ ~!lrme~bll ~ 1mparm8abl~ 1293-1300 ~ Bentonite" white to yellowish white" with a.bundant rounded gra.ins of yellowisho tra..-:!.!r-< lucent. lnAte.r:i.al~ and rare euhad.ral b1ot1 ts plateB" Clq shale" J. 300",,1310 Î 6 . . ~ l2..aJl1h ~ pascri:RtiQ~ Clay sh.al6@ with amall amoun t of ben toni ta. and sandatoD.e; 911 tstone& very san~~ slightly a.rg111B.ceoua~ modium #B¥ u nOll-celca.reoua~ ¡;n1~ CaceousØ in upper lO~o 1310....13606 J. :300-1400 a Cla¡- swag medium grB¥, with minor amount clq 1rons;one. 511 tSt01180 va1:¥' argillªceouso medium grr!J3"o C1B,1 shaleÐ very silty, medium dark gI.'q" with carbonacoouB streaksø and streaks 811 tstone; emall aÞIOunt bentonite 1 436-1445 !j " 611 tstone 1d th sandstone and some benton! teo No ~ple", 1400-14206 14a>...14S5g 14S5-1492ij 1492-1500\) ~"Do ~~-L-~_~ Florence Rucker, Geo1og18'~ ÂUgU.si 10. 1951 '7 ! j 4 ¡ Well Name :"~'~:...:'" ......_~:.....~ . . "Old" ., ..a'-"}' \'Ìells (1944-S3) Avak -, 100-oa"?- South Barrow-l /00 -083 South Barrow- 2 I ()O -õ{}"! Sôuth . Barrow-3 ICD ~ö~ South Barrow-4 IOO~08' Fish Creek-lIDO -A,-ò j GJI'andstand-l 100 -<þ5"....3 , I Gubik-l fOb-/}:;) I ¡ I Gubik-2 1 DO -:;):) 6) ~ Kaolak-1 100 -9';)4( Knifeblade-l lðO - 1t91 '. ':i YJ1ifeblade-2 J bD - ~c9 Knifeblade-2A ì~ "'~t Klo\iPe.Jø~e 6- l1eaè.e-1 OU11,alik-l I DO-(Io/ Eas.t OUlnalik-l 100 -1I6- SÏJr\oson-l Il>£)-/G,.~ NIJ;/h S/R7p:;ÞI1-1 J(){)....DI'Y Squ"are Lake-1 J 00 _I{~ Titð.luk-l /bÖ-IQÖ ' Topagoruk-1 JOt) -,qf Ea'~t Topagoruk-l I. -I~ ~ Umiat-1 JDC -QoD, , I I 10Ö-Q.ID fOO-C}.( I Umiat-4 100 -81;) . Umiat-S I DC -:;)13 j -- J Umiat-6 100 -é}.II../¡ Umiat-7 If:)Ó -~/~:n I Umiat-8 IOf) -;) I" ì Umiat-9 JóD -Q/1- J Umiat-10 IDD-é)J "ð' Umiat-l.1 IDO ...Q/1 I. Wolf Creek-l I bO-~ I ~ Wolf Creek-2 JUD-:\IC?5 i Wolf Creek-3 1(1)-# IO¡ Urniat-2 UmÚlt-3 .t t J f . t I ..,-..- "..-.. '.,._,- _.-. ---- "~"-'-'--"'-'- ,.,.---. .--.-..,,--..-."'." ~ . "Intermediate" Wells at Barrow. (1955-1974) South Barrow-5 ¡t>Ò -b~t5 South Barrow-6 ì C5t> - 0;;,'1 'r South Barrow-7 16ö'-O'3D South Barrow-8 106!-031 South Barrow-9 IDD-t.:i32 South Barrow-10 /tÞ-033 South Barrow-ll ItP -63J..( I t ì South Barrow-12 160-ò~ ~ ... "--.---..---."--..-"--..---- Aft{'
