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Home My WebLink About100-122 Explanation Page 100-122/' Permit Number 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. 1 Gluyas, Gavin R (OGC) From:Schoessler, Allie M <aschoessler@blm.gov> Sent:Thursday, September 5, 2024 9:28 AM To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC) Subject:Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan, The P&A of Knifeblade 2 & 2A has been completed. Operations for 9/3 Knifeblade #2 & #2A  Hand dig around wells  Cut off wells at 3' BGL  BLM witnessed hard cement at surface for both wells  Weld on marker plates The Subsequent reports should be in next month, I will send them along once received along with some photos. Please let me know if you have any questions and I will be in touch about Knifeblade #1 in the next week or two. Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, September 3, 2024 10:43 AM To: Schoessler, Allie M <aschoessler@blm.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Thanks for keeping us in the loop. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 2 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Tuesday, September 3, 2024 8:09 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan, Operations for 9/1 and 9/2: Knifeblade #2: 9/1/2024  conducted several more hours of circulation and clean out.  Circulation fluid going in at ~200 Deg F and returning at 75 Deg F  no footage gained, max depth still 39'  conversation with BLM  Request approval to cement  Cement to surface 9/2/2024  Begin RD  Excavate around the well head  Stage Debris for removal Knifeblade #2A 9/1/2024  conducted several more hours of circulation and clean out.  Circulation fluid going in at ~200 Deg F and returning at 75 Deg F  stop circulation, evacuate well and investigate hard tag  find mixture of materials potentially containing concrete/cement, barite and LCM or other materials has formed a hard barrier in the well  conversation with BLM  Request approval to cement  Cement to surface 9/2/2024  Begin RD  Excavate around the well head  Stage Debris for removal 3 Please let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Sunday, September 1, 2024 2:45 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan, Operations on 8/31/2024 are as follows: Knifeblade #2  performed additional cleanout of well  max depth still 39'  conversation with BLM about depth and circulation Knifeblade #2A  tag at 18' and continued thawing out the well  thaw to 19' - returns are rusty colored and a fibrous material is coming back in returns.  Circulation fluid going in 220 Deg F and returns at 76 Deg F  conversation with BLM about depth and circulation  continue to circulate getting continuously diluted rusty colored returns with some fibers  Max depth still 19' with hard tag when at bottom Plans for Sunday will be to continue circulation of wells for at least several hours each. If no progress is made the plan forward is to cement to surface. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Sunday, September 1, 2024 2:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan operations on 8/30/2024 are as follows: Knifeblade #2  began thawing out the well  achieved maximum depth of 39' from top of casing  circulated multiple wellbore volumes 4  Circulation fluid going in at ~200 Deg F and returning at 44 Deg F  conversation with BLM about depth Knifeblade #2A  began thawing out the well to 18'  end of day will resume thawing 8/31/2014 Allie Apologies this was stuck in my outbox. From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Saturday, August 31, 2024 8:14 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan, Attached are the final approved sundries for Knifeblade 2 & 2A. Operations started yesterday afternoon. I will follow up with the report today. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, August 28, 2024 5:08 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Bryan, We have reviewed the comments from AOGCC and have made some changes to the Knifeblade 2 & 2A P&A plans. Attached are the updated plans that are scheduled to start over the weekend. We will circle back to Knifeblade 1 a bit later (in the next few weeks) as the P&A work wont begin until February or March of 2025. In response to your comments: Descriptions of the well drilling history and formation data can be found in this report: USGS, 1959. Geologic Survey Professional Paper 305-A. Test Wells, Titaluk and Knifeblade Areas, Alaska 5 Were any hydrocarbons encountered in any of the wells. Depths of hydrocarbons and freshwater will dictate needed plug depths, but I didn’t see either of those depths mentioned in the proposals.  Knifeblade 1 – Dry and abandoned, some brackish water encountered as described in the Navy 305G Report, Oil and Gas shows were negligible, one show of gas at 1795 while drilling.  Knifeblade 2 – Junked and abandoned, never made it out of the permafrost zone, well was dry.  Knifeblade 2A – Dry and abandoned, some brackish water encountered, described as saline water in Navy 305G Report, Light oil staining on some samples, a small amount of gas from one core sample, Hydrocarbons considered negligible.  For Knifeblade 2 & 2A: 1. Consider going deeper if the well is unobstructed below. o Based on the age and lithology of the well there is a likelihood that the wellbore has naturally filled in below the casing for both wells, however the contractor will attempt to reach a depth of 150' o 2. Is there freshwater in either well? What is the depth? This could influence the depth required to get cement. o No water in Knifeblade 2, some brackish water in Knifeblade 2A at multiple depths. o 3. Does thermistor cable act as a fluid conduit through the cement? Knifeblade 2: Try to recover thermistor cable. It is only 205’ long. - the contractor will attempt to remove thermistor as deep as reasonably/safely possible - Back up plan to cut and drop so as not to interfere with cement plugs.  The thermistor step was missed in this version for #2 but has been addressed. 4. Sections 3.2.5 and 3.3.5 indicate BOPE will be used, but there is no mention of rigging up BOP in the procedures for these 2 wells. - see updated sundries 5. There are two procedures for both wells, one where cement will be placed from base of conductor 45’ and 38’ respectively. The other describes placing cement from 150’ to surface. What determines which version will be used?  the primary approach is for summer rig less summer operations  the secondary approach is the contingency approach if for some reason the primary doesn’t work as anticipated  both approaches will attempt to get to 150’ of depth Please let me know if you have any questions or additional comments, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, August 8, 2024 9:29 AM To: Schoessler, Allie M <aschoessler@blm.gov> 6 Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. Hi Allie, A few comments/questions from Mel and I, based on what you sent us earlier. I won’t have time to look at the additional attachments until next week as I’m out of office and on the slope the next few days, but I want to send you what we already have now: Were any hydrocarbons encountered in any of the wells. Depths of hydrocarbons and freshwater will dictate needed plug depths, but I didn’t see either of those depths mentioned in the proposals. Regarding Knifeblade 1: 1. The BOP stack is manually controlled and doesn’t contain an annular preventer. AOGCC would require a waiver in both cases. Can the manual BOP be closed from a safe area if the well is flowing gas or liquid? 2. BOPs should be pressure tested to assure they will work when needed. 3. Marker plate should include the name of the operator. 4. What is the estimated TOC outside the 10-3/4” casing? 5. Is there any freshwater here? 6. Consider going deeper if unobstructed. For Knifeblade 2 & 2A: 1. Consider going deeper if the well is unobstructed below. 2. Is there freshwater in either well? What is the depth? This could influence the depth required to get cement. 3. Does thermistor cable act as a fluid conduit through the cement? Knifeblade 2: Try to recover thermistor cable. It is only 205’ long. 4. Sections 3.2.5 and 3.3.5 indicate BOPE will be used, but there is no mention of rigging up BOP in the procedures for these 2 wells. 5. There are two procedure for both wells, one where cement will be placed from base of conductor 45’ and 38’ respectively. The other describes placing cement from 150’ to surface. What determines which version will be used? 6. Knifeblade 2A: Consider going deeper. This well has a lot of open hole TVD. Hope this helps. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 7 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, August 8, 2024 7:34 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: BLM LW Knifeblade Project 2024-2025 Bryan, I was checking in to see if you had any comments and it appears that the document I sent did not fully load. Here is the P&A Plan for Knifeblade 1, 2 & 2 A. Allie From: Schoessler, Allie M Sent: Wednesday, July 24, 2024 8:57 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: BLM LW Knifeblade Project 2024-2025 Bryan, This year the BLM has awarded a contract to Olgoonik Oilfield Services for work at the Knifeblade 1, 2 & 2A wells. Phase I will occur late this summer and consist of reconnaissance for sampling and debris as well as rig less P&A of Knifeblade 2 & 2A. Phase II will occur January -April and consist of the P&A of Knifeblade 1 and backhaul of debris. Attached are the proposed P&A plans for this work. Please let me know if you have any questions, Allie Allie Schoessler Petroleum Engineer / Inspector Legacy Well Contract Office Representative Office: 907-271-3127 Cell: 907-202-2445 222 W 7th Ave Stop 13 Anchorage, AK 99513 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Fortin 3160-5 UNITED STATES FORM APPROVED OMB No. 1004.0137 (June 2015) DEPARTMENT OF THE INTERIOR Expires: January 31, 2018 BUREAU OF LAND MANAGEMENT S. Lease Serial No. NIA SUNDRY NOTICES AND REPORTS ON WELLS 6. If Indian, Allonce or Tribe Name Do not use this form for proposals to drill or to re-enter an abandoned well. Use Form 3160-3 (APD) for such proposals. N/A SUBMIT IN TRIPLICATE- Other instructions on page 2 7. If Unit ofCA/Agrcement, Name and/or No. I. Type of Well NIA ❑ Oil Well ❑ Gat Weil m Other 8. Well Name and No. Knifeblade #2 2. Name of Operator Bureau of Land Management 4 9. AN Well No. 50-119-10013.00.00 3a. Address 222 W 7th Ave, #13 Anchorage, AK 99513 3b. Phone No. (include ama code) 10. Field and Pool or Exploratory Area (907) 271-4354 National Petroleum Reserve, Alaska 4. Location of Well (Footage, Sec. T.,R.,M, or Sarver Descnption) 11. Country or Parish, State Latitude: 69.13107 N, Longitude:-154.70854 W (WGS 84) North Slope Borough, AK 12. CHECK THE APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA TYPE OF SUBMISSION I TYPE OF ACTION ❑ Notice of Intent U Acidize U Deepen U Production (StaruResume) ❑ Water Shut -Off ❑ Alter Casing ❑ Hydraulic Fracturing ❑ Reclamation ❑ Well Integrity © Subsequent Report ❑ Casing Repair ❑ New Construction ❑ Recomplete ❑ Other ❑ Change Plans © Plug and Abandon ❑ Temporarily Abandon ❑ Final Abandonment Notice ❑ Convert to Injection ❑ Plug Back ❑ Water Disposal 13. Describe Proposed or Completed Operation Clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereof If the proposal is to deepen directionally or reeomplete 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 riled within 30 days following completion of the involved operations If the operation results in a multiple completion or recompletion in anew interval, a Form 31604 must be riled once testing has been completed. Final Abandonment Notices must be filed only after all requirements, including mlamalton 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 8/30/2024 and were completed 9/0312024. Please see attached reports for in depth details The IA was cemented from 385to surface (GL measurement). The existing casing at surface was cut oft after cement to surface was complete. A marker plate was welded on S below ground level. The well was backfilled with native material. RECFlx/Fn OCI 29 2024 Lo i.t IC?,.11 _ilia"y and Minerals 14 1 hereby certify that the foregoing is We and correct. Name (Pnnre&71prd) Zach Sayers. P.E Title Petroleum Engineer Sigtuature �,��G's!3': !r ., Date 09/04/2024 THE SPACE FOR FEDERAL OR STATE OFICE USE fL�rc7`CuYI 1 Ul r ln,t. 12- 10 ------•----- - L-'---=----------------------•------------------- Conditians of val, if any, are attached. Approval of this notice does not wartan[ certify that the applicant holds legal or equitable title to those rights inthe subject lease FOfflc. tl�y� _\, _ L�1 _ _J.,,, �� •�� which would entitle the applicant to conduct operations thereon Title 18 U S. C 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, ficttnous or fraudulent statements or representations as to any matter within its jurisdiction (Instructions on page 2) From: Zach Sayers Date: Jctcl)er I", 2J24 • • • • RE: Knifeblade #2 Executive Summary • • • • „ Well Background The Knifeblade #2 was drilled by the U.S. Navy in 1951. This well was drilled to a TD of 373' MD with the 11-3/4" casing string having been set at 45' MD. The BHA became stuck in the well and the well was re - drilled (2A). The Navy did not set any cement plugs prior to moving off of the well. The well was left full of the water -based fluids and allowed to freeze. No wellhead was installed on this well, and the casing was left open to atmosphere. Operations Summary: OOS began the rig up on location on 8/30/2024. This was the first for Olgoonik to complete an entire P&A in the summer time using helicopter support only. The previous summer P&A was the 2016 Barrow program supported by barge and aircraft. OOS set up a base camp in Umiat, AK where it flew large equipment in using the Umiat runway. All equipment was slung to the Knifeblade location using a helicopter. Willows were minimally cleared to allow for site equipment rig up. The modular design of the summer P&A spread allowed for creative equipment placement utilizing natural willow clearings. All well equipment was spotted into place to include a cement unit, steam boiler, fresh water tanks, tools bins, hose bins, pit, and other hand tools. Thawing operations inside of the IA began on 8/30/2024. Thawing operations could not get past an obstruction at 36.5'. An additional day of attempts were made to get past the 36.5' with no success. It is assumed that with the RKB measurement and the reported conductor length, that thawing went down to the end of the 11-3/4" conductor and stopped at the transition to open hole. On 9/O1/2024 cement was pumped from 36.5' to surface inside the 11-3/4" IA. 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 3' below ground level. The surface equipment was rigged down and removed from location. The well cellar area was back filled with native soils and all surface debris was cleaned from location. Operations were completed on 9/03/2024. Sincerely, Zach Sayers Engineering Manager r L Bucyrus Armstrong Spudder BLM Location of Well Government Section: US R12W S2,Umiat Meridian Mud: odel W-4, 1951t Spud: Jullul y 26'", 1951 Latitude/Langitude: 69.13207 N/- 154- 70854 W(WGS 84) Completed: April 50, 1951 3' Below Ground Level -------------------- OH f/ surface to 45' MD 10-3/4" OH f/ 45' MD to 373' MD/TVD Knifeblade #2 Knifeblade Area NPBA, Alaska AN # 50-119-10013 PTD # 100-222 • o a 2 o ate• ova • 0 4 ;Q. • ;Q. • ;Q. ; ;Q. 11-3/4" Marking Plate welded on with 1/8" weep hole ----------------------------------- Balance Plug from V to 36.5 MD 4.3 bbls total cement pumped 25 sx Arctic Blend Class'G' cmt, 0.93 U/sk yield,15.8 ppg Conductor Casine 11-3/4", 45#', CSG to+/-45' MD/TVD • M nAPI fpec fasln� Cemented with 11 sx of Cal -Seal Expected TOC: Unkown As -Plugged Wellbore Schematic Under Contract To- w,wn By. as Olgeenik Z 9/04/2024 TD: 373' MD / TVD PBTD: Surface KB: 876' RKB — GL: S' Daily Operations Report Well Name: Knifeblade N2 Operator: US Navy Report M. 1 Well Type: Exploration Core Test API R: 50.119-10013 Report Date- 30-Aug-24 Field: NPR A PTD M 100-122 Contract if: 140L0621D0011 Contacts Weather Supervisor. Zach Sayers Phone ft: 281.615-1408 Gen. Conditions: Foggy In AM, Clear Skies Petr. Eng.: lachsayers Phone K: 281-615.1408 Wind Direction: West BLM PM: Allie sshaessier Wind Gusts (mph): 1017 MPH BUM PI: aW"risawyn ITemp. (tow, High): 36 44 Well Status TD: 373 GL, ft: 871 Planned Days: 3 PBTD: 373 RKB, ft: 5 Start Date: 30-Aug-24 Fluid in Well: frozen water based fluid OH ID, in: 1075 Operation Days: 1 Last BOP Test: Last Safety Mtg: 8/30/2024 Last Evac Drill: Csg String OD (in) Depth (ft) Welght 18/ft) Integrity Issues Conductor: 11.75" 45 45 Surface. Production- Parameters Pe Pump R Type Model Rate BPM Pressure (psi) Mud / Brine Properties Fluid Type Weight ( Volume bbls Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight Daily Volume bbls.) CLASS 1: Cement Rlnsate CLASS II: Cement Returns Cumulative Volume (bblsl: 0.00 Operations Report 24 Hour Thaw well, hit obstruction. Unable to thaw deeper. Summary: 24 Hour Continue to attempt to thaw past obstruction. Cement well. Forecast: No Accidents, No Incidents, No Spills. HSE Summary: Good communication, Unloading helicopter loads, Pinch points, Stay clear of mov ng equipment From To Hours Operational Details 6:00-6:00) 7:00 13:45 6:45 Morning was spent waiting on better weather conditions and on mob l zing equipment Show up on location and prepare equipment for thawing. Work began on the southern most well of the Knife Blade 2 / 2A cluster. 13A5 14:45 1!00 This well has a full casing collar looking up that has not been torch cut, No thermistor cables present at or near surface. Reconfirm Initial tag depth of Ice. Tag ice at 16'11". 1445 15:15 0:30 All depths are in reference to the casing ca8ar of the 11-3/4" rasing. RU to circulate heated well fluid Thaw from 17' to 36.5' 15:15 1&00 2:45 In temps: 200 deg F, returns 44 deg R Returns are a di rty rust colored water based fluid. Take sample per 3.8.4 Make several attempts to clear past 36.5'. Unsuccessful with getting past 36.5' 18:00 18:30 030 The workstring can gain —6' if left in stationary position but then has a large overpuil to pull up. After gaining the 6" and pulling up, the tag depth remains 36.5'. Stop thawing operations to discuss progress with BUM P.E. 28:30 18:45 0:15 Decision made to move operations to Northern well to allow for further Investigation of wegbore assignment and historical records. Total Hours: 1145 Remarks: Daily Operations Report Well Name: Knifeblade k2 Operator. US Navy Report K: 2 Well Type: Exploration Core Test API * 50-119-10013 Report Date: 31-Au_g-24 Field: NPRA PTO k: 100-122 Contract N! 140L062100011 Contacts Weather Supervisor zacn sayers Phone K: 281.615.1408 Gen. Conditions: Foggy Petr. Eng.: Len sayers Phone R: 283.615.1408 Wind Directlon: West BLM PM: Am.smocssic, Wind Gusts (mph): 9-12 MPH BLM PI: QuinnbwPor ITemp. (Low, High); 37 43 Well Status TO: 373 GL, ft: 871 Planned Days: 3 PBTO: 373 RKB, ft: 5 Start Date: 30-Aug-24 Fluid in Well: frozen water based fluid OH 10, in: 10.75 Operation Days: 2 Last BOP Test: Last Safety Mtg: 8/31/2024 Last Evac Drill: Strin OD (in) Depth (k) Weight (g/R) Integrity Issues Conductor: 11-75" 45 45 Surface: Production: Pump Parameters Pump g Type Model I Rate IGPM) Pressure(psi) Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Dalk Volume bbis.) CLASS 1: Cement Rinsate CLASS il- Cement Returns Cumulative Volume (661s): 0.00 Operations Report 24 Hour Attempt to thaw past obstruction. Unable to gain further depth. Summary; 24 Hour Continue to attempt to thaw past obstruction. Cement well. Forecast: HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00. 6:00) 9:45 15:15 5:30 Work on Northern well (KB 2A) Confirm tag depth. Tag at 36.5'. 15:15 15:30 0:15 All depths are in reference to the casing collar of the 11-3/4" casing. Circulate heated fluids around well to prepare for cement job. 15:30 17:15 1:45 In temps: 220 deg F, returns 30 deg F- Circulate heated fluids around well to prepare for cement job - 17:15 17:30 0:15 In temps: 220 deg F, returns 54 deg F. 17:30 18:00 0:30 RD circulating equipment and winterize. 18:00 18:15 0:15 RD cement unit and winterize Total Hours: 8:30 Remarks: Daily Operations Report Name: Krrifeblade q2 Operator: US Navy Report 4: 3 IWell Well Type: F xploration Core -rest API q: SD319-10013 Report Date: 1-Sep-24 1 Ffeld: NPRA PTDq: 100.122 Contract q: 140L0621D0011 Contacts Weather Supervisor: Iaeh S."n Phone q: 281-615-2408 Gen.Condltionv Partly Sunny, Overcast Petr. Eng.: Zach Sayers Phone Jr: 281-615.2408 Wind Direction: West, North-West BUM PM: she xhoessier Wind Gusts (mph): 5-13 MPH BLM PI: Auinn sawyer ITernp. (Low, High): 33 39 Well Status TO: 373 GL, ft: 871 Planned Days: 3 PBTD: 373 RKB, k: S Start Date: 30-Aug-24 Fluid in Well: frozen water based fluid OH ID, in: 10.75 Operation Days: 3 Last BOP Test: Last Safety Mill: 9/1/2024 Last Evac Drill: Csg String OD in De th ft Wef ht je Integrity Issues Conductor: 11.75" 45 45 Surface: Production: Pump Parameters purrsp It Type Model Rate [BPMj Pressure i Mud / Brine Pro erties Fluid Type Weight Volume bbls. Cumulative Volume bbls : 0 Waste Fluids Fluid Type WN ht Daily Volume bbls CLASS 1: Cement Rinsate CLASS II: Cement Returns Cumulative Volume hhls • 0.00 Operations Report 24 Hour Continue to attempt to thaw past obstruction. No progress made. Cement welt to surface. Summary: 24 Hour Dig out cellar area Forecast: HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00. 6:0(1) 9.30 11:30 200 Work on Northern well (K8 2A) Confirm tag depth. Tag at 36.5'. 11:30 11!45 0 15 All depths are in reference to the casing collar of the 11-3/4" casing. Clrculate heated fluids around welt to prepare for cement job. 11:45 13:45 2:00 In temps: 220 deg F, returns 36 deg F. Circulate heated fluids around well to prepare for cement job. 13:45 14! 15 030 In temps: 220 deg F, returns 74 deg F. RD thawing equipment and winterize. Transfer water to tanks near cement unit. 14!15 15:15 1:00 Filter fluids to 1 mlcron. RU cementing equipment while water circulates through filtration - Perform cement abandonment in the 11.3/4" casing from 36-5' to surface - Take on 2.2 bbls of fresh water, add 3.25 gal of retarder and 1.5 gal defoamer. Wet yield 0-93 h3/sk, mix water 3-556 gal/sk Batch mix 25 sacks of Arti6et I Ciass'G' cement and mix to 55.8+ppg. 15115 16:30 1:15 Begin Batch Mixing at 3:22 PM. Pumped 4.3 bbls of 15.8t ppg cement down 1.1/4" workstring taking returns up the IA at 0.5 bpm, 0 psi - Cement returns observed at surface. Cement returns weighed 15.6 ppg. Cement in place at 433 PM on 9/01/24. 1630 17:00 030 Suspend Operatlons in preparation for Northern Welt P&A. 17:00 17:45 0-45 Clean cement unit and blow down lines. Clean and clear location. Winterize all equipment as needed. 17:45 18:30 045 Daily Operations Report Well Name: Knifeblade N2 Operator: US Navy ReportN: 4 Well Type: Exploration Core Test API N: 50.119-20013 Report Date: 2-Sep-24 Field: NPRA PTO N: 100-122 Contract N: 140L0621DOO11 Contacts Weather Supervisor: zash sayers Phone N: 281-615-1408 Gen. Conditions: Clear Skies, Sunny Petr. Eng.: zach Sayers Phone N: 281.615.1408 Wind Direction: North, East, then North, North-West BUM PM: Awe SOcessier Wind Gusts (mph): 3-26 MPH BUM Ph ownn sawyer iTemp. (Low, High): 32 57 Well Status TO: 373 GL, ft: 871 Planned Days: 3 PSTD: surface RKS, ft: 5 Start Date: 30-Aug-24 Fluid In Well: cement to surface OH 10, In: 10.75 Operation Days: 4 Last BOP Test: Last Safety Mtg: 9/2/2024 Last Evac Drill: Csg string OD (in) Depth (ft) Weight (N/ft) Integrity Issues Conductor. 11.75" 45 45 Surface Production: Pump Parameters Pump N Type Model Rate [BPM) Pressure (psi) it Mud / Brine Properties Fluid Type Welght [ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight (ppg) Daily Volume (bbls.) CLASS 1: Cement Rinsate 9 2.00 CLASS II: Cement Returns 9.4 3.50 Cumulative Volume (hhls): 5.50 Operations Report 24 Hour Dig out cellar area Summary: 24 Hour Cut off casi ng stub and weld on P&A capping plate Forecast: HSE Summary: No Accidents, No Incidents, No Spills. From To Hours Operational Details (6:00 - 6700) Crew hand dug around wellhead. Found that the steel cables around the wellhead made progress difficult. Pulled up large pieces of wood and steel cables. Also found metal wheels that were dug up and pulled out. 10-45 12:45 2:00 Slow progress due to the debris. Pause well operations to work on demobilization work with helicopter. Transfer class 2 fluids into manageable flyable loads. Sling Air Compressor hack to Umiat L2AS 16:45 4.00 Sling Cement Unit back to Umiat Sling Misc. Tools paliet back to Um -at Sling 1/2 roads of Class 2 fluids to Knifeblade N3 Sling Class 1 fluids waster to Knifeblade p1 16.45 17AS 1:00 Walk through jobsite with BUM. 17-45 18:45 1.00 Fly back to camp Total Hours: 8.00 Remarks: Daily Operations Report Well Name: Knifeblade 42 Operator: u5 Navy Reportgr 5 Well Type: Exploration Core Test API M 50-119-10013 Report Date: 3-Sep-24 Field: NPR A PTDM 100-122 Contract 140L0621D0011 Contacts Weather Supervisor: z hsa"n Phone K: 281-615-1408 Gen. Conditions: Foggy Petr. Eng.: Z,h sayers Phone g: 281-615-1408 Wind Direction: North, North-West BLM PM: AleeSchaessler Wind Gusts (mph): 7-24 MPH BLM PI: Quinn sawyer fTemp. (Low, High): 46 52 Well Status TD: 373 _ GL, h_ 871 Planned Days: 3 PBTD: _ surface RKB, R: 5 Stan Date: 30 Aug-24 Fluid in Well: _ _ cement to surface _ OH ID, In: 10.75 Operation Days: 5 Last BOP Test: Last Safety Mtg: 9/3/2024 last Evac Drill: Csg String OD in h Weight a/ft) Integrity Issues Conductor 11.75" 45 45 Surface Production Pump Parameters Pump g Type Model Rate BPM Pressure (psi) Mud / Brine Properties Fluld Type Weight i Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight Daily Volume bbls. CLASS P Cement Rinsate CLASS II Cement Returns _= Cumulative Volume (bbls): 0.00 Operations Report 24 Hour Cut off casin stub and weld on P&A ca g pp�ng plate Summary: 24 Hour N/A Forecast: HSE Summary: No Accidents, No Incidents, No Spill 5. From To Hours Operational Details (6:00 - 6:00) Crew hand dug deeper around the well. Were able to get to 3' BGL. 13:45 15:00 1:15 Dress 113/4" casing and cement to allow for welding of Y," well cap plate. 15:00 16:30 1:30 Pause operations for work at Northern well. _ Cut well at 3' BGL with torch - Cement extremely hard at cut off depth (no top off rob needed). 16:30 18:00 130 Cut-off witnessed by BLM P.E. Allie Schoessler Dress 11-3/4" casing and cement to allow for welding of Y." well cap plate. Weld 11-3/4" diameter, Y." thick marker plate to 11-3/4" casing Capping plate read: Knifeblade g2 18:00 19:00 1:00 US Navy 50-119-10013 100-122 19:00 19:00 0:00 Leave she back to camp Total Hours: 5:1S Remarks From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Knifeblade 2 (PTD 100-122) wellfile Date:Tuesday, September 3, 2024 8:24:27 AM Attachments:Knifeblade #2 Sundry Packet.pdf Please include the attached file in the wellfile. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 Form 3160-5 (June 2015)UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to re-enter an abandoned well. Use Form 3160-3 (APD) for such proposals. FORM APPROVED OMB No. 1004-0137 Expires: January 31, 2018 5. Lease Serial No. (Instructions on page 2) 6. If Indian, Allottee or Tribe Name 7. If Unit of CA/Agreement, Name and/or No. 8. Well Name and No. 9. API Well No. 10. Field and Pool or Exploratory Area 11. Country or Parish, State SUBMIT IN TRIPLICATE - Other instructions on page 2 1. Type of Well 2. Name of Operator 3a. Address 4. Location of Well (Footage, Sec., T.,R.,M., or Survey Description) 3b. Phone No. (include area code) 12. CHECK THE APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Oil Well Gas Well Other Notice of Intent Subsequent Report Final Abandonment Notice Acidize Alter Casing Casing Repair Change Plans Convert to Injection Deepen Hydraulic Fracturing New Construction Plug and Abandon Plug Back Production (Start/Resume) Reclamation Recomplete Temporarily Abandon Water Disposal Water Shut-Off Well Integrity Other 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 WKH%RQGXQGHUZKLFKWKHZRUNZLOOEHSHUIRQQHGRUSURYLGHWKH%RQG1RRQ¿OHZLWK%/0%,$5HTXLUHGVXEVHTXHQWUHSRUWVPXVWEH¿OHGZLWKLQGD\VIROORZLQJ FRPSOHWLRQRIWKHLQYROYHGRSHUDWLRQV,IWKHRSHUDWLRQUHVXOWVLQDPXOWLSOHFRPSOHWLRQRUUHFRPSOHWLRQLQDQHZLQWHUYDOD)RUPPXVWEH¿OHGRQFHWHVWLQJKDVEHHQ FRPSOHWHG)LQDO$EDQGRQPHQW1RWLFHVPXVWEH¿OHGRQO\DIWHUDOOUHTXLUHPHQWVLQFOXGLQJUHFODPDWLRQKDYHEHHQFRPSOHWHGDQGWKHRSHUDWRUKDVGHWHQQLQHGWKDWWKHVLWH LVUHDG\IRU¿QDOLQVSHFWLRQ THE SPACE FOR FEDERAL OR STATE OFICE USE 14. I hereby certify that the foregoing is true and correct. Name (Printed/Typed) Title DateSignature Approved by Title Date 2I¿FH Conditions of approval, if any, are attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon. Title 18 U.S.C Section 1001 and Title 43 U.S.C Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency of the United States DQ\IDOVH¿FWLWLRXVRUIUDXGXOHQWVWDWHPHQWVRUUHSUHVHQWDWLRQVDVWRDQ\PDWWHUZLWKLQLWVMXULVGLFWLRQ ✔ %XUHDX RI /DQG 0DQDJHPHQW : WK $YH $QFKRUDJH $. /DWLWXGH 1 /RQJLWXGH : :*6 1$ 1$ 1$ .QLIHEODGH 1DWLRQDO 3HWUROHXP 5HVHUYH $ODVND 1RUWK 6ORSH %RURXJK $. ✔ ✔ 3OXJ DQG $EDQGRQ WKH ZHOOERUH 3OHDVH VHH WKH DWWDFKHG SURFHGXUHV 5.% IW =DFK 6D\HUV 3( 3HWUROHXP (QJLQHHU Branch Chief 08-30-2024 Alaska State Office WAYNE SVEJNOHA Digitally signed by WAYNE SVEJNOHA Date: 2024.08.30 16:20:24 -08'00' Bureau of Land Management CONDITIONS OF APPROVAL FOR SUNDRY NOTICE – NOTICE OF INTENT Olgoonik Oilfield Services (OOS) Plug and Abandon Knifeblade #2 USWN: 50-119-10013 Project Specific Requirements 1. At a minimum, the top 50 feet of annular space must be filled with cement in accordance with 43 CFR 3172.12(a)(5). 2. Mud or brine shall be placed between all plugs. The mud or brine shall be an equivalent weight of the mud used during drilling operations. 3. A well identification plate shall be welded into place in accordance with 43 CFR 3172.12(a)(10), however the identification shall be as follows: - Well Name - US Well Number (API Number) - Operator: US Navy - State of Alaska PTD Number 4. All tubing/drill pipe used for cementing operations must be removed from the well. No tubing/drill pipe may be cemented in the well. 5. Thermistor cables shall be removed or cut off as deep as reasonably possible. 6. Backfill of excavation may be completed with native soil. A mound of material must cover the excavation areas so there are no low spots. If a low spot or additional fill is needed it shall be addressed in the summer 2025 site visit. Reporting Requirements: 1. The Operator must submit a revised Sundry Notice (3160-5) for approval prior to deviating from the approved plan. An oral approval by phone may be given should circumstances warrant. However, this does not waive the written requirement which is to be submitted within 5 days of receiving verbal approval. 2. Within 30 days of the completion of operations, a Subsequent Report on Form 3160-5, Sundry Notice and Reports of Wells, shall be submitted to the BLM Alaska State Office, Branch of Energy and Minerals. Notification Requirements: 1. All notifications and changes to the submitted Notice of Intent must be reported verbally or in writing to one of the following contact listed below at the BLM Anchorage State Office, Branch of Energy and Minerals: Allie Schoessler Petroleum Engineer/Inspector 907-271-3127 aschoessler@blm.gov Stephen Garcia Sr. Petroleum Engineer 907-271-3159 sbgarcia@blm.gov After Hours Contact: Allie Schoessler 907-202-2445 _________________________________ Allie Schoessler August , 2024 ________________________ Date BLM, Petroleum Engineer __________________________ llie Schoessler Olgoonik Oilfield Services | Plug and Abandonment Program Knifeblade #2 (PTD #: 100-122) Knifeblade Cluster Well Remediation NPRA, Alaska August 2024 Prepared for: U.S. Bureau of Land Management National Operations Center Prepared By: Clear Creek Energy, LLC 13561 Kidd Road Conroe, TX 77302 Under Contract to: Olgoonik Oilfield Services, LLC 3201 C Street, Suite 700 Anchorage, Alaska 99503 Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | General P&A Design 2 VERSION HISTORY Table of Contents 1 General P&A Design .................................................................................................................................... 3 2 Equipment & Supplies .................................................................................................................................. 3 2.1 Surface Equipment ................................................................................................................................ 3 3 P&A Procedures ............................................................................................................................................ 5 3.1 Knifeblade #2 ......................................................................................................................................... 5 Table of Figures Figure 1: Typical Surface Rig Up Layout ............................................................................................................................ 4 Figure 2: Knifeblade #2 Current Completion Schematic ................................................................................................. 8 Figure 3: Knifeblade #2 Proposed Plugging Schematic ................................................................................................... 9 Version # Implemented By Revision Date Approved By Approval Date Reason 1.0 Zach Sayers, P.E. 8/19/24 Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | General P&A Design 3 1 General P&A Design The primary goal is to leave this well 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: x All P&A procedures will be agreed upon and in accordance with BLM regulations prior to execution. x Seventy-Two hours prior to P&A operations commence, BLM representatives will be notified. x All wellbore fluids will be sampled for PCBs per Performance Work Statement (PWS) Section 3.8.4. 2 Equipment & Supplies 2.1 Surface Equipment OOS and its team will provide the following well specific equipment: x Hand conveyed workstring o Scaffolding and temporary wooden work surfaces o 150’ 1.660” workstring o Portable generators for power supply x Portable Cementing Equipment Including o 5 bbl Cement batch mixing unit o Moyno PCP Pump x Fluids Tanks o 47 barrels of storage tank capacity to contain circulated well fluids. o Waste/ Slop Tank x Boiler Unit x Transfer pump, with Backup Pump, hoses, valves, fittings x Well Equipment Tools and Hose Parts Bins x Plug and Abandonment Marker The well shall be capped with a metal 11-¾” x ¼” thick metal marker plate, welded in place with the well information inscribed on the plate. The plate will have a weep hole and is sized for each production casing. o Well name and number o Operator o API Number o PTD Number Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | Equipment & Supplies 4 Figure 1: Typical Surface Rig Up Layout Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | P&A Procedures 5 3 P&A Procedures 3.1 Knifeblade #2 Knifeblade #2 has a 11-3/4” casing stump sticking up with no wellhead or other casing strings. The following is planned for summer time operations using a helicopter for transportation of equipment and supplies. On site facilities will not be provided. Final cut off and plate welding will occur during the summer visit. A summer visit performed by the BLM in 2024 found that the well was thawed down to 12’3” using a plumb bob. 3.1.1 Well Assumptions: x No plugs or debris have been placed in the well from surface to 150’. x The open hole portion of the well is still open and can be accessed using straight pipe with a mule shoe. 3.1.2 Deviation Requests & Clarifications: x OOS wishes to request that the depth of cutoff be at the depth of found rock. From review of the summer visit photos, OOS anticipates the rock to be ~3’ below ground surface. This is less than the planned 5’ below Tundra surface. Should the BLM require a 5’ cut-off, OOS will need to bring out a large excavator with a rock hammer. Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | P&A Procedures 6 3.1.3 Fluids Program: Hole Size: Fluid Type: 11” ID csg Fresh Water system Density (ppg) Funnel Viscosity PV YP 6 RPM Gel Strength Salinity PH 8.33 26 1.7 – 2.2 10 – – – 0,000 - 164,000 7-11 3.1.4 Evaluation Program: 11-3/4” Cased Section: Logging Suite: MWD/LWD: None. Open Hole Logs: None. Cased Hole Logs: None. 3.1.5 Cementing Program: P&A Plug Cement Job # Hole Size Csg Size Type Density Yield % Excess Volume Est. TOC 1 10.75” 11-3/4” Class G Artic Blend 15.4 ppg – 16.0 ppg 0.93 ft3/sx 10% CH 15% OH 19.4 bbl Surface Additives: Class G Artic Blend: 0.130 gal/sk retarder, artic blend yield of 0.93 ft3/sk at 15.7 ppg density. 3.1.6 Well Control Program: BOPE none KILL LINE none CHOKE LINE none CHOKE MANIFOLD none ACCUMULATOR none REMOTE BOP CONTROL none Maximum Anticipated BHP No pressure anticipated from 0-150’ Maximum Anticipated Surface Pressure (MASP) No pressure anticipated from 0-150’ Planned BOP Test Pressure 7-1/16” Rig BOP No BOP pressure testing to occur. Casing Test Pressure (7”) none Notes: Historical records show that the well was drilled to 373’ and lost the tools in the hole. It is specifically stated that the hole was still 100% in the permafrost and that the well was “completely dry”. Given the stratigraphic data available from the well only 28’ due North, it is clear that no oil or gas zones exist in the entirety of this wellbore. Further, at a thawing depth of 150’: An ice plug from 150’ to an estimated 373’ would still be in place. Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | P&A Procedures 7 3.1.7 Site & Well Prep Operations: 1. Notify the Contracting Officer’s Representative (COR) at least 72 hours prior to starting the P&A process to allow a BLM representative be present to witness the plugging operations 2. Fly in mobile cement unit and water storage containers to the wellsite. 3. Cut 11-3/4” surface conductor / casing as needed for access. 4. Installed pre-fabricated returns valve. 5. RU scaffolding and or stable worksite material to allow for well work. 3.1.8 Plugging Operations: 6. Lower workstring into place and circulate using portable triplex pump to +/-38’. 7. Verify current fluid depth in well. Collect fluid samples with a bailer per BLM TO requirements 3.8.4. 8. CBU x3 times to clean hole. 9. Make attempt to continue thawing existing wellbore to planned depth of 150’ MD into historic Open Hole (OH section). a. Should workstring not make progress below conductor casing shoe, contact COR immediately for plan forward. 10. Thaw down to 150’ MD. CBU x3. 11. Rig up cementing equipment and cement to surface with permafrost cement through the work string pumping until clean cement is observed at surface. It is expected to take a total of 30 sacks of cement to fill the conductor and 87 sacks to fill the open hole section for a total of 117 sacks. 12. TOOH and LD work string. 13. WOC at least 12 hours. o Break down all equipment and prepare for transport 3.1.9 Post Plugging Operations: 14. Using hand tools, excavate around the wellhead to a depth up to of 3' below tundra level 15. Cut surface jacket and conductor if present 16. After WOC period is finished and using a cutting torch or a casing saw, cut all casing strings off to leave well severed >5' below tundra level 17. Top-off cement as needed 18. Weld a 1/4" thick, 11-3/4” diameter steel marker plate over the top of the cut-off well casing 19. Plate to include required identifier markings. BLM representative to witness 20. 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 21. Clean location, obtain site clearance approval from BLM representative on location and prepare all personnel, equipment and materials for demobilization. Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | P&A Procedures 8 Figure 2: Knifeblade #2 Current Completion Schematic Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2 Well Olgoonik Oilfield Services | P&A Procedures 9 Figure 3: Knifeblade #2 Proposed Plugging Schematic 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 • \Vc.) r 11-2 a>F pkv of r A 'E12aIrtl' t cf L:TM��i':�:'.'"cL1i'^ ere a l THE STATE asK 133,.. Conservation -:—_ . s }�_____. Division of Spill Prevention and Response itiContaminated Sites Program GOVERNOR SEAN PARNELL O, 610 University Ave. ALAS Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage,Alaska 99513 SCANNED APR 2 5 2014 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. Wayne Svejnoha 3 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G.\SPAR\CC\Federal Farilities\Civilian Frrieral Aat,riec\DOT\RT.M\Prnierts\I Fogey Welk\7 11 11 Tetter to BIM on Legacy Wells.docx r� { U G 2 Ca > ,- Cb a a 'C O N 0 E 7 a C N m 0 d = 0 U N CO 0 0 CO 0 Cs co a"° CO CO CO R CO (6 O CO t0 co C C U • N CO o Y CC CO m m 0 CC 0 CC .'n rn CO as co CO as CO m CC m o)‘,0 CO C a a a a a a a a) a a a C a` a a a 0 a) O o 0 0 0 0 0 0 o o > 0 0 0 0 0 0 0 0 0 0 CCs �' < Cn c c c c C C c C a . c c C C C c c c C O Z 'W a) a >,E o m a) C) 0 C0 a) 0 0 0 o a) O O O 5 '3 O O O 0 -5 O o 5 O - .0 O` L c.1 .0 .0 L .0 0 .0 a) .0 .0 .0 .0 .0 L .0 CC C - C " C C C C "00 0 -� C t. 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J o 0 0 0 0 U) U) U) re M d -1 C C C 0 C CO M M 0 0 0 0 0 :--' m m J 2 7 Z Z Z -I SL- 0 2 0 Q Z Z 2 2 Z 0 O 0) > > > j > > > U) n 4 M t() 0) O_ NIa 46 a) C N o 0 0 0 O O t E •c Z d aa)) 0 co m co m m m 0. 3 r r t t t .0 ca a) a) N 7 7 7 7 J 7 @ $ 0 w - in cooco in in in • Well Ranking ,. ~ ;~ » ~~~ ~ {~ x ~ ~~~' ~: Before identifying the risks associated with the legacy wells, the BLM reviewed the list of wells to determine ownership and well status. Abreak-down of the 13b 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. • ZO wells are being used to by the United States Geological Survey (USGS) for climatic temperature and permafrost studies (see Appendix B). • 7 wells are plugged (6 at Umiat, Square Lake #1). • 37 wells that require further evaluation. Following the 2003 field season, members of the legacy well team met to determine criteria for evaluating the risks associated with the above mentioned 37 wells and ranking each well based on these risks. For consistency purposes, the group devised a series of questions to assist in the process: • What is the condition of the existing pad and pits? (e.g. any indication of contamination?) • Is there any solid waste (old equipment, piping, barrels, etc.) or potential hazardous material conditions? • Did the hole penetrate known oil or gas stratigraphy? • Did the well have oil or gas shows, and if so, is the well capable of flowing? • Is the well near human activity, and if so are there conditions present that pose a risk to people? • What is the condition of the wellhead? Have there been any previous problems or repair work? Does the well (in its current condition) pose a risk? • What is the surficial condition of the existing pad and pits? Is contamination a possibility? • Does the presence of unplugged wells have the potential to negatively impact anticipated development? Each of the 37 wells are described in the following pages. Descriptions are ordered in terms of the ranked priority based on the above stated criteria and the concerns identified. Umiat Wells The early Navy wells in Umiat rank at the top of the list. Umiat is located on the north bank of the Colville River 60 miles upstream from the village of Nuiqsut. Natural oil seeps were discovered at Umiat by early explorers. This discovery, along with the detection of seeps at Cape Simpson, motivated the U.S. Navy to conduct a drilling program. Umiat and the Simpson Peninsula were the primary exploration targets in the mid to late 1940s. The Umiat seeps are still visible today. Their locations tend to shift over time. The seeps are currently active in Umiat Lake, just off the northeast portion of the airstrip and in a channel of the Colville River. ,..~ ~ ~~ 22 \~~ • The 11 Umiat wells were drilled from 1945 to 1952. These wells are a concern for BLM due to their close proximity to human activity. Umiat is not a village, but serves as a camp for seismic crews: Umiat is also the primary hub for recreational activities in eastern NPR-A and western CAMA (Central Arctic Management Area). It has one of the few airstrips on the North Slope maintained year-round and is a popular location for purchasing aircraft fuel (Figure 10). The 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 _ _ . , o , Umiat Air Force Station. In Tune of aircraft. 1955 the Air Force returned the facility to the U.S. Navy. Since Umiat is a Fornierly 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 their potential Figure 11: Umiat #2 and #5 prior to removal and historic value. The Alaska Heritage remediation. Photo taken August 2001. Resources Survey (AHRS) included the Umiat wells in an inventory of all reported historic and prehistoric sites within the State of Alaska. This inventory of cultural resources includes objects, structures, buildings, sites, districts, and travel routes generally more than 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 Uiniat area. Umiat #9 is located about half mile to the north-northwest of the Seabee pad. The drill hole penetrated several known oil and gas formations; Ninuluk, Chandler, Grandstand and Topagoruk. Hydrocarbon shows were prevalent within both the Grandstand and the Topagoruk formations. Multiple sands were perforated and tested. Production exceeded 217 barrels per day, thus seemingly showing the benefit of using an oil-based mud. However, the muds did not allow the different formations to be distinguished. Cement was used in an attempt to "plug back" and isolate individual formations. Samples were taken and sent to a Bureau of Mines lab where the chemical tracer (used during drilling) was measured and the various sandstone samples were examined. This allowed a study of the different lithologies be conducted. The tracer Aroclor used in the well has raised concerns about PCB contamination. However, the well was allowed to flow for seven weeks at 200 barrels per day (Robinson and Bergquist, 196) prior to shutting it in, possibly purging the potential contaminants. As it stands today, insufficient energy exists in the reservoir for the well to flow to surface and the wellhead has no pressure on it. The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. Surficial wastes around Umiat #9 could present an issue. As was common with early Navy drilling, a gravel pad was not created. Wooden debris exists around the wellhead and there is a pile of drilling muds directly to the north which is void of vegetation (Figure 12). Samples taken by the COE from around the wellhead detected elevated levels of diesel range organics (DRO), residual range organics (RRO) and PCBs (U.S. Army COE, 2003). 24 Figure 12: Aerial view of Umiat #9. • The wellhead is equipped with two bull plugs, a flange and a 2 %-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 enviromnent in its cun•ent condition. Umiat #6 Umiat #6 was spudded August 1950 to test the southern limits of the Umiat anticline. The hole was drilled to a depth of 825 feet. The well was cased to 35 feet and a 42-foot cement plug was placed on the bottom of the well in order to stop water influx fioin sands 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 banels 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 5~-gallon drum. The well is left open with 8 '/8-inch casing to the surface. It has no gauges, valves or a cover plate. Two thennistor protrude to the surface and rests on the lip of the casing. This well poses no threat to human health or the environment unless development occurs. Umiat #7 Umiat #7 was drilled in •~ 1951 to a depth of 1,384 ti .~,_~ ,~ ~ ~f~,~4t feet, cased to 1,196 feet ~' - ~ `~ ~' ; rs _: ~ , and completed as a dry ~~ ; r ~4 ,.,N.3 ~ .,~' hole. It was the southern f most well drilled on the ~ y ~°'-- Umiat anticline. The ~ y ~~4 ,. objective was to further '~ delineate the southern ~ :~: - a= 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 %-inch casing at a total height of 30 inches (Figure 13). Surrounding the open hole is wet tundra with no indication of remaining debris or other surficial issues. The hole poses no tlueat to humans or the environment. The well location is cun•ently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional Ufniat 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, wanner temperatures, wind, and wave action eroded 200 feet of the coastline adjacent to the well (Figures 14, 15). This erosion placed the J.W. Dalton #1 well and reserve pit precariously close ~.. ~' ~' ,~~~ _ . 1 _ -~` ~`~ »~~ ~°- Figure 14: Photo of J.W. Dalton taken October 26, 2004. Soil cracking is occurring around the wellhead and the north and east side of the cellar is exposed. 26 Figure 15: J.W. Dalton wellhead with pilings. Photo was taken August 2000. to the edge of the Arctic Ocean. As a result, casing is now exposed to a depth of 15 feet on the present day beach (Figure 16). The top of the diesel is approximately 60 feet below the present beach level. The reserve pit has been breached on the northwest coiner from the advancing shoreline (Figure 17). The pit is known to contain chromium, cobalt, zinc, and barium. However, chromium, cobalt and zinc were detected in background levels, due to the east-west water movement into and out of the pit. Barium is a constituent of the drilling muds and is consolidated with other sediments (U.S. Bureau of Land Management, U.S. Geological Survey, 1992). The well is located within the Northeast planning area (see Map 2), on a tract currently closed to leasing. ~,~~ ,-~-~ ~ ~~ ` ° This well is in danger of ~~" "'~' .,:. becoming engulfed by the ocean. _ _ ~ ~_ ~ -~ - ~ ~ ~ G ~"4 . ,~.IL-3b~ a~Y.c., ~ -. `~ ~ The diesel fuel in the well and '°` '~ • ;~ ~ reserve pit contaminants raises ~ ~~ ~~„ Y, P ~~" ~ concerns. The concerns can be ~~,~ ~."*~~:~ _ :.}; ~~, eliminated by pumping out the -- u ' ~ • ~ diesel, or displacing the diesel I~ ,,~~ ~ `~ ~, ~~, ~' ~ ~ ,--~--" "~`~'" `~" ~ ~~ ~* with water and adding a bridge -,~ . l `` ,r-,. lu and cement to close off the P g ~. ~' _ hole. The casing would be cut off ~'~ `' ~ below surface. The diesel would - - be disposed of at the nearest Figure 17: Aerial view of the breached reserve pit. facility. If necessary, the reserve pit could be excavated down to remove contaminated soils, which would be placed into Super-Sacks and hauled out by Cat-Train for grinding and injection into a Class II well or other approved disposal site. In its current condition, the well does not pose a tlu•eat 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 irrunediate risk to human health and the environment. The pit was sampled October 26, 2004, and results are pending. 27 Figure 16: J.W. Dalton with exposed conductor (left), and rat hole (right). The mouse hole (not pictured) is completely exposed. Figure 18: Simpson Peninsula showing well locations. Simpson Core Test #26 Simpson Core Test #26 was drilled in the middle of one of the larger, active oil seeps in NPR-A (Figure 19). The Navy described this location as Seep 3. The hole reached a total depth of 1,171 feet and was cased to 350 feet. The well encountered one very poor gas show and one productive oil sand in the Ninuluk/Seabee undifferentiated formation. In production tests, the well flowed at rates averaging 110 barrels of oil per day (Robinson and Brewer, 1964). Other formations encountered include the Gubik, Seabee, and Grandstand Formations. Gas bubbles have been observed around the base of the casing since the 2000 field season. Bob Burruss of the USGS, sampled and analyzed gas from Simpson Core #27 which is part of the same oil field, located less than half mile to the east. His findings showed the gas to be biogenic methane indicating that microbial alteration (breakdowns) of the hydrocarbons has generated the gas. Additionally, oil sampled in the well was extremely biodegraded. Simpson Figure 19: The wellhead is located in the center of Core #26 has a wellhead flanged to the the photo. The green color liquid defines the area of active seepage. The orange color is oil-eating casing, a 2-inch line pipe, and four bacteria. wing valves and will likely flow oil if 28 ~ s the valves are opened. Access to the wellhead is limited by the depth of oily-water surrounding 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 011. 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 Simpson Core Test #31 is a shallow core test drilled in 1951 to a depth of 355 feet and cased to 101 feet. The objective of drilling was to collect a core to view the material at the bottom of the seep. The well does not meet standard oil and gas exploration well definitions. The casing is not cemented in place and the well is probably not capable of holding substantial pressure. The well encountered a few sands with shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. In 65 hours of testing, this zone flowed oil to the surface at rates averaging 125 barrels and 2,000- r'igure 21: Simpson Core #31 is located within an 4,000 cubic feet of gas per day. active oil seep. Flowing pressure was measured at 60 29 i psi. The well also penetrated the Gubik and Seabee Formations, which were unproductive (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. A drilling pad does not exist as the well was drilled in an active oil seep, which remains active today (Figure 21). The Simpson Peninsula contains few permanent settlements, but a multitude of summer camps. The well had been a source of fuel for the inhabitants as evidenced by a 10-foot extension pipe hooked up to the wing valve. The extension allowed for the oil to flow down the pipe and collect in a bucket. In 2000, BLM learned that oil was seeping out of a corroded swedge on the wellhead. The potential harm was mitigated by the fact oil was seeping into a natural oil seep. In June 2001, BLM spent $35,000 to remove the old wellhead and install a new master valve and needle valve. Oil and gas samples were taken by the USES 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 during bailing tests (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The wellhead consists of casing swedge, a nipple, and a brass gate valve and will flow oil to surface if the valve is opened. There are no sub-surface fresh water aquifers at risk. However, if the well is left unplugged it could pose a risk to surface resources. In its current state, oil could flow to surface if the well is damaged, corroded, or the valves are opened. Additionally, concerns have been raised regarding the bubbling around the base of the casing. When the valve is opened, the bubbling subsides. This indicates a small leak around the base of the casing or through a hole in the casing. The gas was sampled by the USGS and has been identified as reservoir-produced biogenic gas. While the well does pose a risk, it is mitigated by the fact that the well is drilled in an active, natural oil seep. 30 Simpson Core Test #30 Simpson Core Tests #30 and #30A were drilled about 100 feet apart in the same oil seep. The seep is part of the same regime that contains Cores #26 and #27. These wells were drilled to gain an understanding of the producing field limits and to help determine underlying structure. Simpson Core #30 is an oil well drilled in 1951 to a depth of 1,500 feet. No plugs were set and the well was cased to 102 ft. The hole encountered the same formations as Cores #26 and #27; Gubik, - Seabee, undifferentiated Ninuluk/Seabee, and the Grandstand with a few poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. Poor oil shows were also noted in the deeper Grandstand Formation. During production tests of the shallow oil sand the well was bailed at rates averaging 5 barrels of oil per day (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51. per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The well was left with sheared, open casing above ground. Even though the well produced oil 50 years ago, it is static today. This suggests the hole has collapsed below the shallow casing. There are no fresh water aquifers in the well, houJever, since the uTell was drilled to a reservoir with sufficient energy to flow oil to surface, the well should probably be considered a risk if left unplugged. This well would probably be plugged by placing a 100 foot surface plug downhole to eliminate risks to surface resources. The potential risk is alleviated by the fact that the well is drilled in an active, natural oil seep. There is no drill pad as the Navy drilled within the seep and camped on the tundra. Some light trash is present in the seep between the Core #30 and Core #30A, which may prove difficult to clean (Figure 22). The well lies three tenths of a mile from both Core #26 and #27 (Figure 18). Simpson Core Test #27 Simpson Core Test #27 is an oil well that was spudded February 1951 and completed one month later. Total depth of the well is 1,500 feet, with casing down to 102 feet. Oil was encountered at a depth of 380 feet and was bailed at a rate of 3 barrels per day. The core test encountered the same formations as Simpson Core Test #26, with a few very poor gas shows and one productive oil bearing sand in the Ninuluk/Seabee undifferentiated formation. Oil-based muds were used from the drilling depth of 325 to 661 feet. At that point the oil was displaced and the drilling crew resumed using water based muds. 31 Figure 22: Light trash is present in the seep between Cores #30 and #30A. ~~ Additional crude was added downhole at a depth of 1,320 feet. The drill pipe was stuck and the two front derrick legs collapsed below the four-foot extension in an effort to free the pipe. The drilling muds in place were re-circulated during the repair process. In an attempt to free the pipe, 73 ban•els 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 surface if opened. There is no surface debris present at Core #27 (Figure 23). The well poses little threat to human health and the immediate environment around it in its current condition. Simpson Core Test #29 Simpson Core Test #29 is a dry hole drilled in 1950 to a depth of 700 feet and cased to 152 feet. The purpose of the well was to determine the limits of the producing field encountered at Core #26. A very poor oil show was identified in the Seabee Formation. The productive sand present in the other Simpson Cores does not exist in this well. The test hole also penetrated the Gubik and Grandstand Formations. No oil was recovered from this well (Robinson and Brewer, 1964). The well is grouped higher on the priority list due to its close approximation to Simpson Cores #26, #27, #30 and #30A (Figure 18). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development if left unplugged since any development will likely target deeper, more productive formations. The well was left with 8 '/z-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables prohude 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 i , +~ Y 4 K a~ `;. r ,l - ,~~ #"' ~"; Figure 24: Simpson Core #29 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 tlu•eat 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 riact 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. 33 indication of stressed vegetation down-gradient from the drill muds. Additionally, solid waste in the foirn 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. ,~ "~ ,~ rT: ~< ~~ ~ e~ ~j ~ r~~ ` ~` ~~~~~? Figure 26: Wolf Creek #1 after adding a new ball valve to the wellhead. August 2004. -~ ; , .~ _ 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 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 cuiz•ent condition, the well does not appear to pose a risk to surface or sub- surface resources. The drill pad is shared with Wolf Creek #3. Tln-oughout the pad, there are some wooden pilings, metal anchors and scrap metal. The scraps should not be considered hazardous in this remote region. The leaking gas is of minor concern, however given the weak gas pressure and remote location; the overall risk is very minimal. Wolf Creek #2 Wolf Creek #2 is a dry hole. The well was drilled in 1951 to 1,618 feet and cased to 53 feet. It is located roughly 1 '/a miles north of the other Wolf Creek test wells. The purpose of drilling was to determine if the gas-bearing sandstone beds previously encountered in Wolf Creek #1 would contain any oil. The records indicate a very poor gas show was encountered in the Killik Tongue but no oil or gas was recovered in production tests (Collins and Bergquist, 1959). The hole also penetrated the Seabee, Ninuluk, Chandler, and Grandstand Formations. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The wellhead consists of a plate welded onto the 11 3/-inch casing cut off at ground level (Figure 27). There is no existing drill pad. Solid wastes consist of a few empty 55-gallon drums upstream along the upper floodplain of the creek. The well poses no tlu•eat to surface or sub-surface resources and has no potential to adversely affect future development. Wolf Creek #3 Wolf Creek #3 is a gas well. The well was drilled in 192 to a depth of 3,760 feet and cased to 625 feet. It is deeper than the other two Wolf Creek wells because its primary purpose was to test the Grandstand Formation (the producing formation around Umiat, 35 miles to the west). The Grandstand Formation produced from four different sands. In 35 Figure 27: Wolf Creek #2 had casing cut off at ground level. a ~ 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 Foima.tions. Upon abandonment, the hole was filled with oil-based drilling muds and left open to the envirorunent. A total of 103 barrels of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The well poses no 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 banels of oil per day through agravel-packed completion. It also produced a small amount of methane gas. The hole encountered the Gubik, Shrader Bluff, Tuluvak, and Seabee Formations. 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 Figure 28: Fish Creek #1 with concrete cellar. Satellites EIS approves oil and gas development in this area. ConocoPhillips has proposed roads and a drilling pad less than eight miles from this well and will likely be 36 producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infiastiucture is established. Surficially, there are still some solid wastes present. The drilling pad and cellar construction consists of concrete reinforced with steel matting. The concrete, matting, and pilings are still in place today, albeit heaved by permafrost (Figure 28). Several 55- gallon trash drums filled with debris are located off the concrete pad. Other light debris is also present within 500 feet of the pad. The oil seep is located about 1.5 miles to the southwest of the well site and is inactive. The USGS 305-I reports the dimension of the seep as being 6' x 20' (Florence and Brewer, 1964), however, BLM personnel located the seep in 2001 and noted its dimension to be 3' x 6'. Simpson Core Test #28 Simpson Core Test #28 was drilled in September 1950 to a total depth of 2,505 feet and cased to 110 feet. Despite the depth, the hole did not encounter any hydrocarbon shows. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. A drill pad does not exist, however a large area of disturbance is visible. The wellhead consists of open casing inside a wooden cellar. There is considerable solid waste near the well. These include: numerous metal pilings, drill pipe, large wood fragments (spool, plywood, timbers), and some partially crushed drums. The solid wastes are unsightly, but pose no threat to humans or the environment. Simpson Core Test #13 Simpson Core Test #13 was drilled in the summer of 1949. It was a relatively shallow test and did not generate any significant oil or gas shows. The well encountered residual hydrocarbons in the Seabee and Grandstand Formations at depths of 1,079 - 1,084 and 1,138 - 1,148 feet (Robinson and Brewer, 1964). No oil or gas was recovered during production tests. The well is over three miles north of the Simpson Core wells that penetrated productive Grandstand sands. Total depth of the well reached 1,438 feet. The top 26 feet are cased and the hole was filled with water-based drilling mud. Fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. 37 A drilling pad does not exist. Seven-inch casing was cut off at ground level and is very difficult to locate. The well is open to the atmosphere. There is no solid waste, nor is there anything hazardous regarding this location. It should not be considered a risk to surface or sub-surface resources. Simpson Core Test #15 Simpson Core Test #15 was drilled in August 1949 near an active oil seep. The well was drilled to a total depth of 900 feet and cased to 18 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations (Robinson and Brewer, 1964). No oil or gas was recovered during well tests. Additionally, fresh water aquifers were not encountered. ,.,~r,~ . a ~;~~ e. ~ i f ~ ~ if .t `""i1 7 ~~ Figure 29: Simpson 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 `/s 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 Core #15 is open to the atmosphere. 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 Fomlations. 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 X21.51 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. Surficially, it is best to consider both Core # 14 and # 14A together. A drilling pad does not exist, the wellheads are non-threatening, and there are no solid wastes. There is some discrepancy between the USGS 305-L report and the BLM field findings in terms of the wellheads. According to the report, Core #14A was uncased and the casing for Core #14 was cut off at ground level. In 2002, BLM discovered both holes side-by-side with open casing Figure 30: Simpson Core Tests #14 and #14A. extending upwards 24 inches from the ground surface (Figure 30). The site was last visited in August 2002. This well does not pose any concern and should not be considered a risk to surface or sub-surface resources. East Simpson #2 East Simpson #2 was drilled in 1977 to 7,505 feet and cased to 6,427 feet. Five cement plugs were set, with the top of the shallowest plug set at 1,997 feet. The primary objective of the well was to test the Ivishak Sandstone where it onlaps the Pre-Devonian age basement rock (Husky Oil NPR Operations for U.S. Geological Survey, 1982). Small scale faulting was found between the wells in the area, possibly accounting for the thin section representing the Sadlerochit Formation. The well encountered very poor oil shows at 6,000 feet in the Torok Formation and Endicott age sandstones were cored with poor porosity and dead oil shows. The well is officially listed as a dry hole. Upon completion of the production tests, the well was plugged back to 1,997 feet and filled with approximately 280 ban•els 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 abandomnent, 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. ~ i 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 4~ 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 20041ease sale. Exploration and development is a distinct possibility within the next 20 years and has the potential to target the Grandstand Formation. If left unplugged the well has no potential to adversely affect future development. There is no pad present at Meade #1. Several pilings and light trash are present, but overall is pretty clean. The wellhead is at ground level and consists of an open flange `~` r~ ~~" bolted to the top of the casing (Figure 33). This :~, '~ ~ 4`" ~ ~~- , 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 ~'r _ ~~,. crew bailed the hole and discovered a swedge s..V and 2-inch needle valve junked downhole. This ' ~ ~., r. ~ - site is very remote (30 miles south of Atqasuk) `r ~` , ~' r x ~ and since the gas zones are currently isolated =~% ~ ` - ~ below the cement plugs there is a limited risk of ~~ '~`~ ~ adverse im acts to surface or sub-surface .. _ 'tea. ~~ >.~~-;~~'~ _.~; p resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 Titaluk #1 was drilled in 1951 to a depth of 4,020 feet and is a dry hole. The well was drilled on the end of an anticline to test the oil and gas potential of formations within the Nanushuk Group. A few very poor oil and gas shows were encountered in the Grandstand and Topagoiuk Formations, but no oil or gas was recovered during multiple production tests. The Ninuluk and Chandler Formations were also encountered, but with no shows. One cement plug was set at 3,471 feet. The placement of this plug is curious since the shows (albeit poor) were reportedly discovered above this level (Robinson and Bergquist, 1959). The well remains in a static condition. Titaluk #1 is located within the Northwest planning area (see Map 2) on an unleased tract. No offers were received in the June 20041ease sale. Near-term development is unlikely. Skull Cliff Core Test #1 Skull Cliff Core Test #1 was drilled in 1947 to a depth of 779 feet and is a dry hole. No shows of oil or gas were reported while drilling through the Gubik, Grandstand, and Topagoruk Formations. While drilling to the target depth of 1,500 feet, the drillstring was lost in the hole and fishing attempts were unsuccessful in recovering the lost drillstring. The drilling mud was bailed down to the top of the fish and the remainder of the well was filled with diesel to 54 feet to prevent the wellbore from freezing and facilitate downhole temperature measurements. It is plausible that the casing could corrode and the diesel fuel could seep into the sub-surface strata, but since there are no fresh water zones in the well it is not considered a risk that would adversely impact sub-surface resources (Collins and Brewer, 1961). The well is located within the Northeast planning area (see Map 2). The well lies adjacent to a recently leased tract that received a high bid of $10.77 per acre during the 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 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, 1t 1S 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 Ouinalik Anticline and drilled with the intent of revealing the oil, gas, and water content of the penetrated stratigraphy. Two cement plugs were set, the shallowest of which is inside the casing at 2,543 feet. Very poor oil and gas shows were reported in the Grandstand Formation, and poor gas shows were noted in both the Topagoiuk and Oumalik Formations. Small undetermined volumes of gas were recovered during multiple production tests. It is believed that the gas encountered was large enough to furnish fuel to a camp but not large enough to become a commercial producer. The gas encountered during drilling showed high gas pressure, but the sandstones in which they were observed are thin with low porosity (Robinson and Bergquist, 1956). The gas zones are currently isolated by the cement plugs and pose no risk to sub-surface resources. The wellhead and a fabricated plate are below ground level. Two 2 '/2-inch nipples open to the atmosphere are above ground to allow thernistor cables to be run into the well. The well is located within the Northwest planning area (see Map 2} on unleased tract that received no bids during the lease sale of 2004. Near-term development is unlikely. If left 43 i ~ unplugged, the well has no potential to adversely affect future development. The existing pad contains piping from a ground refrigeration system similar to Topagoruk #1. The ground in this area is somewhat swampy with high susceptibility to permafrost melt. Circulating cooled diesel fuel in the pipes enabled drilling to occur without thawing the ground. The steel pilings were pulled from the ground to be reused at another site (Robinson and Bergquist, 1956). However, steel pipe filled with diesel fuel remains. A 6- inch circumference of sh•essed 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 theimistor cables protruding from inside the casing. The casing is marked by a 7-foot, 3/-inch pipe. The open pipe lies within awater-filled cellar. The standing water has produced numerous algae and other aquatic vegetation obscuring the wellbore. Surficial hazards consist of several 10-foot timbers and a few 4-foot pipes (probably rig anchors) sticking up out of the ground. The site is mostly overgrown with shrubs and appears to be relatively clean. The airstrip, incoming, and outgoing trail scars are obvious and can be used to navigate to the wellsite. There are no risks associated with the well in its current condition and was given this ranking due to its close proximity to Oumalik # 1. Topagoruk #1 Topagoruk #1 was drilled in 1951 to a depth of 7,154 feet and is a dry hole. The intent was to test a small, buried anticline and the various formations associated with it. The well was cased to 6,073 feet, plugged back to 6,175 feet and then drilled to a new total depth of 10,503 feet. Prior to re-drilling to total depth, approximately 250 barrels of crude oil from Cape Simpson were added downhole to help offset lost circulation and caving. Additionally, 20 ban•els of diesel were added downhole during the drilling phase. No plugs exist in this well. The well is left with open casing to the surface and thermistor cables protruding from the casing (Figure 36). The well encountered the following stratigraphic units while drilling; Gubik, Grandstand, Topagoruk, and Oumalik Formations, Middle and Upper Jurassic rocks, Shublik Formation (Triassic age), Permian rocks, and Lower-Middle Devonian rocks. Hydrocarbon shows were limited to a few very poor gas shows in the Oumalik Formation. No oil or gas was recovered during 44 • multiple production tests (Collins and Bergquist, 1958). The well penetrated no fresh water aquifers and does not represent a tlu-eat to surface or sub- surface resources. The well is located within the Northwest planning area (see Map 2). It is adjacent to a recently leased tract, receiving a high bid of $50.00 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. .~.~. ~ - ! .. , ~. . ~,~~ There is not a visible pad, but rather an area of ``- r''` disturbance. Disturbance stretches '/4 mile in an Figure 36: Topagoruk #1 asing on its east-west direction and '%a of a mile in a north- side. When the casing was pulled out of south direction. Solid wastes exist in the form of the ground, thermistor cables were piping remaining from a refrigeration system that discovered. circulated. diesel to keep the permafrost frozen. A potential hazard exists because diesel still occupies the ground circulation lines. These lines stretch approximately 750 feet to the east, 250 feet to the north, and 100 feet to the south from the wellhead. Other debris on site include some large, partially-burned timbers, awater-filled wooden box (Figure 37) that resembles a cellar ('/4 mile east of the wellhead), and drilling muds. Atgasuk 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. 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 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 4~ Figure 37: Drilling muds and a wooden box that resembles a cellar are located about'/< mile east of the wellhead. n well at 1,049 feet. ~~ U The well is located within the Northwest planning area. (see Map 2) on a recently leased tract. The tract receiving a high bid of $84.99 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. A drill pad does not exist. There are a few rig anchors near the wellhead, but no other surficial debris. The cun•ent state of the wellhead is open-ended 10 3/-inch casing. Casing height is tluee 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. Surficially, there are no concerns associated with this well. A drill pad does not exist and the wellhead consists of open-ended casing (Figure 38). The wellhead is 8 s/8- inch pinup inside 11 by 12 1/a-inch Figure 38: Knifeblade #1 is located in a marshy area at collar. The plumb-bob hit solid at 12 the headwaters of a small creek. feet. Total height for the well is about three feet. If this well is left in its current condition, it poses no risk to adversely impacting the surface or sub-surface resources. 46 • Knifeblade #2 Knifeblade #2 is another dry hole drilled in 1951. It was the first of the tluee 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 h•act, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Simpson #1 Simpson #1 test well was drilled with a rotary rig in 1948 by the U.S. Navy. The well was drilled to a total depth of 7,002 feet and cased to 5,954 feet. The purpose of the well was to test the various formations of the Lower Cretaceous and Upper Jurassic rocks. The well encountered several very poor oil and gas shows and one productive gas sand in the Lower Jurassic at a depth of 6,183 - 6,193 feet. The well produced gas at rates up to 3.0 MMCFPD during open hole flow tests of this Lower Jurassic sand. The gas zones are currently isolated from other formations and the surface by two cement plugs set above the productive sand. The top of the shallowest plug is at 5,520 feet (Robinson and Yuster, 1959). The well is located within the Northwest planning area (see Map 2) adjacent to recently leased tract that received a high bid of $7.51 per acre during the lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years and this exploration has the potential to target the Lower Jurassic. Since the well is partially plugged, however, it poses little risk to surface or sub-surface resources and will not likely adversely affect any future development. 47 • • The pad is highly visible and was constructed in the same fashion as Fish Creek #1 in which concrete was used as a working pad. Concrete was poured over a landing mat which was placed on pilings. As a result of ground movement from pernlafrost freeze/thaw cycles, the concrete has buckled in numerous places creating apartially- collapsed surface. This feature provides excellent shelter to small animals and rodents. Additionally, there is a small pile of drilling muds near the wellhead. The well was left equipped with a casing flange, spool w/ side bull plug, and another flange and nipple and is shut-in with no pressure at surface. The components past the flange have since been removed. Overall, the current condition of the site is non-threatening to the sparse human population and the surrounding environment. North Simpson #1 North Simpson #1 was drilled in 1950 to a depth of 3,774 feet and cased to 1.09 feet. No hydrocarbon shows were reported during the drilling of this well as no sandstone was encountered (Robinson and Yuster, 1959). Upon completion, no plugs were set and the hole was filled back with muds. The well is located within the Northwest planning area (see Map 2) adjacent to a recently leased tract that received a high bid of $12.76 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. South Simpson #1 South Simpson #1 was drilled in 1977. The purpose of the hole was to test the Sadlerochit Formation where it laps onto the south flank of the Barrow Arch. The well was drilled to 8,795 feet and cased to 7,206 feet. Reports show that poor gas shows were identified in the Nanushuk Group, Kingak Shale and Shublik Formation. Gas flowed at a rate of 75 MCFPD between 6,522 - 6,568 feet within the Kingak Shale (Gyrc, 1988). The gas contained more than 70% nitrogen. The origin of the high nitrogen content is unknown, but appears to be a localized phenomenon (Bunuss, 2003). Sandstone tongues 48 • • (Simpson sand) within the Kingak Shale in the Simpson and Barrow localities are known to display good gas reservoir quality (Houseknecht 2001). Poor oil shows were discovered in the Nanushuk Group and Shublik and Torok Formations. Drill stem tests did not recover any oil. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $5.01 per acre during the lease sale of 2004. Exploration and development is a distinct possibility in the near future since the well is properly plugged it will have no adverse impacts on development. Surficially, the pad and pits are in good shape. The cellar has been backfilled Figure 40: South Simpson #1 had its cellar backfilled with silt, with s11t which resulted in consequently burying the casing head. the burial of the casing head (Figure 40). Above the surface, the wellhead consists of a 4-inch line pipe and a master valve. The master valve is frozen in the open position. The needle valve previously located above the master valve no longer exists. Beneath the casing head the well is plugged to surface and has no potential to adversely effect surface or sub-surface resources. The wellhead stands about eight feet high. Aplumb-bob was dropped and hit solid at 8 feet and stuck. It was subsequently lost. An old, stripped snowmachine sitting next to the wellhead is the only sizable object that would be considered solid waste. Overall, there is no risk associated with this well. Inigok #1 Inigok #1 was drilled in 1979 to a depth of 20,102 feet and cased to 17,432 feet. The well objective was to test astructural/stratigraphic trap within the Sadlerochit and Lisburne Groups (Husky Oil NPR Operations for U.S. Geological Survey-Inigok, 1983). Some very poor gas shows were recorded in the Sag River, Nanushuk, and Endicott Group. Poor oil shows were reported for the Kingak Shale and Lisburne Group. The best shows were found in the base of the Torok Formation at 8,852 feet. No oil or gas was recovered during multiple production tests. The wellhead consists of three spools, each with a gate valve, a master valve, and a needle valve. Ten cement plugs were set in the well and it is plugged to surface. The well is located within the Northeast planning area (see Map 2) on a recently leased tract that received a high bid of X20.34 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. ~> ~~"~~ ~ t ~: :t , , ?~ } i^x ~ , '~`~- ._ 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 pennafrost. The wells that are cun-ently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is a non-con-osive agent, and even if the casing should conode there would be no impact to the surface resources and minimal impact on the sub-surface resources as there are no known fresh water aquifers in NPR-A. The following wells are monitor wells with surficial issues. It is difficult to establish a rank since the wells are sufficiently plugged. The cleanup priority is difficult to determine as the primary tlu-eat lies with wells having downhole issues. However, political concerns could influence the timing in which the surface issues are dealt. East Teshekpuk #1 East Teshekpuk #1 was spudded in March 1976. The well was drilled to a depth of 10,664 feet. It is an active USGS monitor well that was properly plugged. The top of the shallowest plug is located at 2,400 feet. From that point to the surface, the hole is filled with diesel fuel. With the well properly plugged and diesel fuel being anon-con-osive 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 f { • 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 sununer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of Atqasuk. Awuna is the most remote well in the entire petroleum reserve. The well was drilled to a total depth of 11,200 feet. Drilling was conducted over two consecutive winters. Ice roads and an ice airstrip were constructed for logistical support. The project cost approximately $6 million (Husky Oil NPR Operations-Awuna, pg 5). Due to the orientation of the pad, the prevailing winds force wave action into the drilling pad, undermining the sands and silts which make up the pad. Below the sands and silts, Styrofoam was used to insulate the underlying permafrost. Wave action has eroded tens of feet into the drilling pad, exposing the Styrofoam, which consequently breaks loose and blows away. Wooden pilings exposed from erosion show how much attrition has taken place. Styrofoam can be seen all around the pad with pieces blown up to 5 miles away. Downhole, the well is in good shape with sufficient plugs. Diesel fuel fills the top 4,000 feet. The well is an USGS monitor well. Wellhead components are in working condition with no problems. The immediate concern with this site is the blowing Styrofoam, but as the years progress erosion could become a major issue (Figure 42). The loose Styrofoam should be cleaned Figure 42: Awuna wellhead with exposed wooden pilings and up and erosion progress Styrofoam. should be monitored on an annual basis. It is also worth mentioning that the same type of scenario is unfolding at Tunalik #1 (another USGS well}. Wave action from the reserve pit is beginning to 51 undermine Styrofoam from the drilling pad. Tunalik #1 differs from Awuna #1 in that prevailing wind direction does not force erosion in the direction of the wellhead. Uncased Core Tests There are thirty-nine uncased core test holes. These holes were typically left filled with drilling mud and abandoned without being plugged. Drilling depths ranged between 500 and 1,500 feet depending on the purpose of the test. By nature, core tests were drilled to test soils, permafrost, or lithologic units. They were not drilled for oil or gas exploration purposes and did not encounter hydrocarbons. Many of .the cores are stored in the Alaska Geologic Materials Center (Figure 43). The BLM has examined the cores and they are exri•emely 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 primacy intent was to test the Cretaceous rocks in east-west trending anticline structure (305H pg 424). No significant shows of oil were found. Gas shows were encountered in various sandstone beds between 1;600 and 1,900 feet, but otherwise the hole was dry. Upon completion, four plugs were reported to be set with the upper plug at 728 feet, well above the gas shows. Two other plugs were reported to be set in the gas zone, spanning depths of 1,640 - 1,840 and 1865 - 1934 feet. In addition to the six plugs, water and mud fill the remaining distance to the surface (Collins and Berquist, 1959). Upon successive visits to the site, BLM field crews dropped aplumb-bob down the hole and hit a solid obstruction between 8 and 10 feet. Don Meares, Northern Field Office, visited the site in August 2003 with an underwater camera and determined the solid surface to be cement. The Square Lake area is clean of debris with a few deadmen pilings (anchors) near the wellhead that could pose a ground hazard. The wellhead is open casing cut off at ground level. Umiat #2 and #5 The Umiat #2 and #5 wells were plugged and abandoned in 2002 by the COE (Figure 44). The wells were drilled on a common four-acre pad in 1947 and 1951. The purpose of the wells was to test for producing lithologies and deternline petroleum quantities. Umiat #2 penetrated the Gubik Formation, Nanushuk Group (Chandler and Grandstand Formations), Topagoiuk Formation and Oumalik Formation. Problems with the drilling muds were encountered while drilling Umiat #2. Analysts determined that the fresh water drilling fluid caused formation damage and the Umiat #5 well was drilled adjacent to the #2 with acable-tool rig. The well produced 400 barrels per day with the most productive sandstones in the lower Chandler and upper Grandstand. Below a depth of 1075 feet, 107 banels of crude oil from both Umiat and Simpson were used as a drilling fluid, as well as 11 barrels of diesel fuel (Robinson and Bergquist, 1956). In 2000, the Colville River threatened to erode both wellsites away. The COE took action under the FUDS program in the winter of 2001-2002 to plug, abandon and remove any surface features. The concrete lined cellar of Umiat #2 and wooden platform Figure 44: Plugging operations at Umiat #5. M from Umiat #5 were removed. Costs were approximately $25 million dollars due in part, to soil Approximately 30,000 tons of petroleum-contaminated soil was excavated. remediation. The soil was ~3 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 =~ t 2~~~~~ }mow - Formation within the Nanushuk ' K i'~ w a --a x' 3 {. 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 tlu•eat to human health nor the environment. BLM plugged the well in May 2004. Umiat #4 After encountering relatively poor oil shows on the first three wells, operations were suspended until 1950. Cable tool drilling rigs were introduced to determine if the fresh water muds had hindered the oil production in the previous wells (Robinson and Bergquist, 1956). Cable tool wells did not require the excavation of a cellar; therefore Umiat wells #4-#7 did not have cellars. Umiat #4 is located on top of the hill to the northeast of Umiat #3 (Figures 45, 46). The well was drilled May 1950 to a maximum depth of 840 feet. The hole bored through the Ninuluk, Chandler and Grandstand Formations. Oil was found in the upper and lower 54 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 n 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 Forniation 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 baiTel 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. s ~ 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 Umiat #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 5i8-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 Urniat #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. 1~ APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Ati garu Awuna* Drew Point East Simpson #1 East Teshekpuk West Fish Creek #1 Ikpikpuk Kugura Koluktak* Kuyanak Lisburne North Inigok North Kalikpik Peard Bay Seabee* South Meade South Harrison Bay Tunalik* Tulageak West Dease HOLE DEPTH(meters) 648 884 640 600 727 735 615 582 227 856 532 62~ 660 591 393 549 399 556 756 823 *Are also part of the CALM network (Circumpolar Active-Layer Monitoring). 57 . . Form. 9-593 (APriIl952) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY CONSERVATION DIVISION *Sec. , : ' , , ' -----------I·-----~----- , , ' . . ' , , ' I I : -----·¡----¡-----·r--- . i i I ----...-r----7-----'·----- , I ' I I ' I I ! T. _____________ R. _____________ INDIVIDUAL WELL RECORD _______________________ Mer. ~¡..wv1f\: If. P. R. #4 Land office __________..::=_ Da.te___l~e_~_1.929________ Ref. No. ___ State Alaska Serial No. _____ --- - Cv u.u...LJ' Lessee ________________.-:'-=--__________________ Field ________ Knit' eblade Area Operator_U. s. N~ District West Coast Region _____ Well No. __~1t'e blad.~__~~~~__~~~__~__________ * Subdivision ___________________________________________________ * Location ___BeJ::ord._.ing.Q.~l~~----------------------------------------------------------------------------------------- Drilling approved __ , 19____ Well elevation _____L__.I...._________ feet Drilling commenced __.J.uJ.y...~ , 19...22__ Total depth _ 373 h) Drilling ceased Aug. 5 ____, 1922 _ Initial production feet Completed for production ed Abando~______ A:ug. Geologic Formationø Surface Lowest tested __,19_____ Gravity A. P. I. 5 , 1922 Initial R. P. Productive Horizonø Name .Depths CcmteRts ---------- -----------------...----- WELL STATUS ------------------------------- ------------------------ YEAR JAN. FEB. MAR. ApR. MAY JUNE JULY AUG. SJilPT. OcT. Nov. D1ac. 1952 J)rg. Abd. ------------ ----------- ...---------- ---------. ----------- ----------- ---------- ----------- ----------- ...--------- ------...---- -..._-------- -----..-...- --------------- ----------- ----------- ----------- ----------- ---------- ----------- ----------- ----------- ----------- ----------- -...------- -------- ----------...---- ----------- ----------- ---------- ----------- ----------- ----------- ----------- ----------- ----------- -----..._---- ---------- -..---...- -----------...--...... ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ...--------- -- --------------- ---------- .--------...--. ----------- ----------- -...--------- ----------- ----------- ----------- ----------- ----------- ---------- --- * Unsurveyed REMARKS ___________________________________ --------------------------------------------------------------------- ______________nW~~_AÞ_ª..~ at 313 j'e!!t because of tiøhinp: .J~È___________________________________________ ----------------------------..- --------------------------------------------------------------..---...--------..-----...- ---------GëõlQi1M--~~ý~i~ij·()r!~!i~~~~~gi~-:jQl~~=~~~~~=~~--------------------------------- -..-------------.....--------------------------...-..-------------------------------- ¡Vv~ U. S. GOVDII"ENT PRINTING ~ICE IG-~ð7-4. TEST we, TlTALUX .AND XND'EBLADE AREAS,.ItA / r '" fAJ 1'1 /_ ,- 397 The rig was skidded 28 feet due north and Knife- blade test well 2A was drilled to a depth of 1,805 feet. Good shows were absent in the sandstones of the Grand- stand formation, although an asphaltic residue was noted. The hole produced. some brackish water. (See page 414.) Knifeblade test well 1 is 4,865 feet N. 23°13' E. of 2A in a bowllike depression that opens to the south near the top of Knifeblade Ridge. This test well was on a di1ferent fault block and started higher in the Chan- dler formation than the other two tests. Bitumen was also found in the Grandstand formation, but shows of oil or gas were negIigibls. This test well gave some brackish water. No pronounced lithologic change from sandstone to shale was noted- (possibly because of sand-contami- nated samples) near the bottom of Knifeblade test weU 2A, although the bottom of this test must be close to the base of the Grandstand formation, by comparison of thicknesses with Titaluk test well L The grain size of the Grandstand forma.tion sandstones becomes finer with depth and is very fine to silty near the bottom in Knifeblade test well2A. This may represent the transi- tion to the Topagoruk formation found in other test wells. The holes could not be drilled deep enough (the capacity of the drilling rig was 1,800 feet) to check for the presence of the Tuktu formation. How- ever, it is very nn libly the Tuktu formation would have been found here. The decreasing sand size near the base of the Grandstand does not preclude but sug- gests, that there is no thick underlying sandstone for- mation. Nons is described by C. L. Whittington (oral communication) from the outcrop nearby. Elevations in the KnifebJade area were determined by reconnAiR!Ønœ altimeter traverses by C. L. Whit- tington and have been tied to the Umiat datum. (See page 38L) The well elevatioDS a.re accurate with respect to each other, although they may not be ac- curate with reference to sea. level. Latitude and longi- tude are derived from planimetric maps compiled from trimetrogon aerial photographs. r - was not detërÏDii1eâ. oj -:Mr. "Brewer as thermal equi- librium had -not been reestablished when the last read- ings were obtained. The minimum temperature in the well could not be obtained because of the loss of the upper cables. : ~ ~ ~EBLADB TEST WELLS 1,(1)21. )) KDltebJade 1: LocaUOD: Lat .-oø"O¥' N., loDg W-53'21" W. Elevation: GroUDd. 993 teet: derrick - floOr. 999 feet Spudded: October 13. 195L Completed: December 22, 1951: dr7 aDd abandoned. Total depth: 1,805 feet. . XnftebJade 2: LocaUOD: Lat .-OS'19" N.. loDg. æ-44'12" W. ElevatioD: Ground, 871 feet: derrick 400r, 876 feet. Spudded: .Tull' 26, 195L Completed :Auguat ~ 1951: jUDked 8D4 abaDdoDed. Total depth: 81'S feet. XDUebJade 2A: - - -- - LocaUOD: Lat .-OS'10" N., 10Dg llK-4;4'12" W. ElevatioD: G1'01IDd, 869 feet: derrick floor. 874 feet. Spudded: August 6, 195L Completed: October 1. 1961; dry aDd ttb·ftc!oneo' Total depth: 1,805 feet. The Knifeblade test wells were drilled to test the oil and gas possibilities of the Grandstand and Toktu formations. -. Kni:febJade test wells 1,. 2, and 2A a.re on Knifeblade ridge, a prominent topographic and struc- tural high in the Arctic foothills province, about 3 miles north of the Colville River and 68 miles west- southwest of Umiat, A 111.$wJt.. (See fig. 28.) This structural feature is a little over 20 miles south of the Titaluk test well; the Titaluk rig could be seen from Knifeblade ridge on clear days. The name "Knife- b)ade" was given to the sharp..crested ridge by a pilot flying over the area. _ Knifeblade test well 2 and 2A are near the bottom of a shallow valley of an intermittent stream on the south side of the ridge. (See p1s. 27B and 28.) The test well on the south side of the main thrust fault (see Structure) was thought to offer the best possibilities for finding oil; so it was drilled first. The number previously assigned to this test was "2," and this number was retained to prevent confusion in the records, although it was actuaJly the first hole drilled. Knife- blade test well 2 was drilled to a depth of 373 feet, at which point the hole was junked when the drilling t001s were lost and not recovered; at this depth the hole was stilI in permafrost and was completely dry. The formations drilled in this and the succeeding Knifeblade testa are as follows: Jrma IoøøIIe 0' 'M ~ 0A&1IdI4Jr ,....... ~UorI (dep'_ ... ,..,) (IJeptA ... feet) 6-820 820-1. 80G T. D. ~105 lOG- oHS '.I:. U~ 16-80 --1, 805 ~. Ji. K'ftlfebl-de teat wen 1-- C 1iiilf4blade teat well 2 XDlfeb1ade teat wen 9.A _ 4eeaø-a8--f ~-1< ~~) STB.17CTU1I.B The following brief discussion of a structure in the Knifeblade anticline is based on the work of C. L. Whittington (written communication, 1956). The anticline is about 14 miles long and 4 miles wide, although it can be traced for many more miles as a low fold. A major thrust fault, thrust from the south, is north of and approximately parallel to the axis at the east end of the anticline. (See fig. 82.) Beds of the Chandler and Grandstand formations are pushed over strata of the Chandler formation. On the surface this fault is marked by an abrupt change in strike be- - . . 398 EXPLORATION OJ' NAVAL PBTlWLEUM RESERVE NO.4, NOBTHERN ALA8XA, UU-U - -1--__ -.. 10-- ___~' -........... ----- (J ..... .. --.... 0 ...... .......... KIIIIDLADt: ta-r WILL 1 ?- ....,. --.. " " , -!::.. -f- \/ I I XNIFEllLADt: TEST WILLS ---. \ . D ... ____aAIIDZA Y-,",4II' ------------------- ur 154-60' -----..----------------- 40' . I ~ ")--25'\. ! ~ ~.' ... ~ æ ¡ ... Qi ~ APNOaMATC ....... ........'ftO... .... ( ---\ 1&5- I 154-50" EXPLANATION --f-- Axis of anticline D U Fault U. upthtown side; D. rkNmtIItvwn side to- Thrust fault r, ufJPlJ' pIØ ---------- Outline of anticline ~ Dry hole -" 10' o I 'h I I Scale In miles 1 I Geologic structure by C. L. Whlttlngton.1955 I 40' lI'IG1JBII 32.~tUne of part of the KDtfeblade anttcUne. lI1ow1Dg the donre on _ JmacIDu7 bOrUon In the Chandler formatJon _d the reJadon of the test welltl to Important faale.. The west end of the _deUDe. not 111011'11 on tII18 _Po 18 eolØPlul,. flluUcd. tween the northeast and southeast blocks. Dips are very steep, as much as 70° on the north side in the vicinity of the fault. A major transverse fault, prob- ably older than the thrust fault, ohts the axis in the eastern third of the anticline. Other minor transverse faults are indicated. This anticline appears. to have a large area of clo- sore, but surface exposures are not sufticient to permit a definite interpretation. No geophysical wOt"k was done in the area. Knifeblade test wells 2 and 2A were located on the southeast block, on the hanging wall of the major thrust. There is no evidence in either of the two holes to suggest that they penetrated this thrust fault. Be· cause they are so close together, correlation between 2 and 2A is excellent. The top of the Grandstand forma· tion is at 766 feet above sea level in test well 2 and at 779 feet above sea level in test well 2A, a di1ference of 13 feet, indicating that the beds dip 25° on that zone, assuming 1 hole is directly down dip from the other. A dip measored on the surface nearby is 19°8. as the fault is approached. Dip measured on the cores in Knifeblade test well 2A decreases from about 40° in the upper 2 cores (171 and 365 ft) to 20::1 or less in t:¡ë deepest cores. The 1,805 feet of beds drilJed in test well 2A. represents an actual thickness ~f apprun- mate1y 1,625 feet because of the inclined beds. Knifeblade test well 1 was located on the nortb side on the footwall of the thrust fault. Original plans called for drilling this test well about 1,000 feet south of its actual location, but the plans were changed when it became apparent that this more southerly site was on or very close to the big thrust. A surface dip near the trace of the fault is 700NE., and near the well site it is 18°NE. Dips measured on cores range from. 6° to 15°, much less than in Knifeblade 2A. There is no evidence of faulting in Knifeblade test well 1. The top of the Grandstand formation in Knifeblade test well 1 is at 179 feet above sea level, or 600 feet lower than in Knifeblade test well2A on the overthrust sheet. Correlation between the two holes is good both litho- logically and paIeontologically after taking into con· sideration differences in thickness due to dip. . The test welJa are dry, possibly because they are too low on the anticline, but it is more likely that the cause is due to an unfavorable structural lústory. TES.LL8, TITALUX AND XNlFEBLADE ~Jt4 4Õ5 LiAoloøic ducriptúm-ContiDued LiAoloøic ducripticm-Continued Can Deptb (feet) a.a.rb ~--- 1,495-1,505 Siltstone, medium-Ught.-graYi and very fiDe light-gray IaDdøtone; very cal- careouaoement; aløo 30perœnt medium- gray clay shale. 1, 505-1, 510 Sandstone, medium-light-gray, fiDe- grained; graiDø aubangular to aub- rounded; 90 percent white and clear quans; ren\Ainder is dark chen and rook fr&pDentø, some sericite, car- boDaceoUS patches; moderately cal- careous cemen\. 1,510-1,515 SUtstone, and very fiDe øandatone; m0d- erately to very calcareous cemeu\. 1, 615-1, 550 Clay abale, medium-dark-gray; trace of medium-gray uoncalcareoua øiltstoue and very fiD&-paIned øandstone at 1,515-1,520 and 1,530-1,540 ft; 26~ cent very fiDe øandatone and ailtatone; Ditrvpø M 1,53õ-l,640 ft. 1, 550-1, 580 Sandatone, light- to medium-light-gray, very fiD~; graiDa aubangular to aubrounded; 90 percent white andJolear quans; trace of dark-yellowiah-browu clay iroDstone at 1,555-1,560 ft, trace of bitumen throughou\. 1, 580-1, 590 Siltstone, medium-light-gray; trace of clay 8b&Ie. 1,590-1,600 Sandatoue, light-gray, fiDe- to medium- grafned, salt and pepper, soft and friable; 65 pera8Dt white and clear quans; mbangular to rarely angular. 1, 600-1, 660 Sandstone, light-gray, mostly looøe aaud, fiDe-graiued, rarely medium-grained; 15-85 percent white and clear quarts; some ailtstone and clay abale; trace of carbonaceous abale at 1,615-1,620 ft, traoe of bitumen in eiltstone at 1,825- 1,680 It, Dilrapø at 1,606-1,820 it. IftOCØ"CUftUl prillma at 1,825-1,630 f\. 1,860-1,885 Clay shale, medium-dark-gray; 30-40 peroeut medium-gray øandy ailtstone at 1,660-1,675 ft; 30-50 percent aaud- atone at 1,875-1,885 ft. 1, 886-1, 710 Sandstone, light- to medium-light-gray, very flne-graiDed; graiDa aubangular; 90 percent white and clear quan.; dark abertandamiDoramountotheraûDeraJa; Blightly calcareous; trace medium-dark- clay abale. 1, 110-1, 112 R3oo".:red 8 iD.: Miorof08lli1ø very :rare. Bntatone,. medium-gray, very slightly calcareous, very hard; dip undeter- mined. 1, 112-1, 116 Bntatone, medium- to medium-light-gray, DDdy, DOncalcareous; trace medium- dark-gray clay ehal8. 1, 115-1, 130 Clay shale, medium- to medium-dark- pay, IIlty. , . --- 19 Can Depth (teet) Bemarb' - 1,730-1,735 Siltstoñe, medium- to medium-light-gray; 20 percent medium-dark-gray clay shale; rare bitumen coating. Clay øhaIe, medium- to medium-dark- gray, very silty. Siltstone, and very fiDe aaudatoue, me- dium-light-gray, alightly calcareous: 30 percent medium-dark-gray clayabale. Clayaha1e, medium-dark-gray, 15 percent; 30 percent medium-dark-gray slightly calcareous siltstone. Siltstone, mediuiu-light-gray, slightly cal- careous, slightly micaceous, 80 peraeut; also clay sbale; Dåtrupø. Sandstone, light-gray, very fiDe-grained to ailty; graiDa aubangular with BOme aub- rounded; 90 peraeut white and clear quarts; also carbonaceous and mica- ceous particIeø, dark chert and rook fragments; 10 perceut medium-dark- gray clay shale. Slightly calcareous. Slltatone, and very flue aaiulatone, alightly calcareous; trace of clay shale. Clay aha1e, medium-gray, ailty, trace of 00&1; Dilrapø at 1,780-1,790 It. No recovery.' No sample. Recovered 1 ft 2 in.: Mic..ofoaaila OOIDlDOD. Clay aha1e, medium-dark-gray, aDe17 mioaceous; DOnoalcareoua, mod... ately hard; fair cleavage; clip unde- termined. 1,735-1,750 1,750-1,755 1, 155-1, 760 1, 760-1, 765 1,765-1,770 1,770-1, 785 , ---- 1,785-1,795 20 1,795-1, 800 1,800-1,801 1. 801-1, 805 21 . . tr ~BTJrBTWBLL ~ ì The quality of wall cùtbñgs tram g---f.:t "was gÒod. LilAoloøic ducriptitm Can Dep&la (JIiI&) Jtemub ---- 0-6 5-16 " Heigh~ of derrick ðoor above ground. Clay abale, medi~-. to medium-light-pay, slightly øilty; carbonaceousplaDt imp~ aiOD; trace of dark-yellowiah-browu 'clay irODatone; trace of· black ahiDrooaL . Coal, black, ahiDy, 50 percent; and medium- to dark-sray caibonaceous ola7'_~; 6 percent olayiroDStone. Clay ahaIe, medium- to dark-gray; p1aD~ Im- preøaio~ 3-6 P8f08Dt coal in the upper 10 ft; trace to 20 percent siltstone at 40-66 fL. Coal, black, shiny. to dull, 35 percent; 35 percent dark-gray carbonaceous clay ahaIe¡ and medium-light-gray fiDe-paiDed IÏand- stone. 15-25 2õ-65 I ____ 65-76 406 Core Depth (In feet) 75-85 ~ ---- 85-95 ~~ 95-105 105-145 - ~ 205-210 210-225 225-235 235-245 ---- 245-,.250 250-265 . . LitÀologic description-Continued EXPLORATION OF NAVAL PETROLEuM RESERVE NO.4, NORTHERN ALASKA, 1944-53 Lithologic description-Continued Bemarb Core Depth (teet) Bemarb Sandstone, light-gray, fine- to medium- grained, salt and pepper, soft; 75 percent white and clear quartz; also coal particles, dark chert and mica (muscovite or sericite). Clay shale, medium- to medium-clark-gray, 40 percent; 40 percent sand as above; re- mainder is black shiny coal. Sütstone, 50 percent; and 40 percent light- to medium-light-gray very fine-grained sandstone; trace of clay shale. Sandstone, very light- to light-gray, medium· to coarse-grained, salt and pepper, soft to hard; grains subangular to subrounded; 80 percent white and clear quartz, 10 percent coal particles, 10 percent mica (muscovite or sericite); light-colored slightly calcareous cement; carbonaceous plant impressions and light-olive-gray clay ironstone. The ~ of the Grandstand formation is placed at 105 ft. 145-155 Clay shale, medium-gray, 60 percent; 20 per- cent sütstone, and about 20 percent mica- ceous sandstone. 155-165 Sandstone, light-gray, medium-grained, soft; grains subangular to subrounded; 70 percent white and clear quartz; remainder is dark chert, coal particles, rock fragments, and mica; slightly calcareous. 165-185 Clay shale, medium-gray; also 40 percent sandstone as below in the lower half of the interval; trace olive-gray ironstone. 185-205 Sandstone, medium-light-gray, medium- grained, rare fine-grained, salt and pepper, very soft to medium-soft; grains subangular; 60 percent white and clear quartz; re- mainder mostly dark chert with abundant coal particles in places, some coaly partings; noncalcareous; trace of clay ironstone at 185-190 ft. Siltstone, medium-light-gray, noncalcareous; . carbonaceous partings; trace of sandstone. Clay shale, medium-light- to medium-dark- gray, silty near top; trace of coal, pyrite, and olive-gray· clay ironstone. Clay shale, medium- to medium-dark-gray; 15-30 percent black shiny to dull coal. Clay shale, medium- to medium-dark-gray, slightly silty, micaceous. Siltstone, and small amount of very fine- grained sandstone, light- to medium-light- gray, micaceous; plant impressions. Sandstone, light- to medium-light-gray; very fine-grained in upper part of interval and medium-grained in the lower; 75 percent white and clear quartz; remainder is dark chert, coal particles; sericite in matrix; slightly calcareous. 265-280 Clay shale, medium-light- to medium-gray, trace of finely micaceous siltstone. 280-295 Clay shale, medium-dark- to medium-gray; trace of pyrite, coal, and brownish-gray clay ironstone. No sample. Recovered 1 ft: Microfossils abundant. Clay shale, medium- to medium-dark-gray, medium-hard; good cleavage; one 1* in. thick hard slightly brownish-gray clay ironstone concretion at the iiottom of the interval; shale contains pyrite nodules; dip undeterminable. Coal, black, shiny, 50 percent; and dark- . gray to grayish-black clay shale. Clay shale, medium- to dark-gray; 5 percent coal at 305-310 ft. Clay shale, medium-gray; and 30 percent very fine-grained argillaceous slightly calcareous sandstone; bitumen in sandstone. Clay shale, medium- to medium-dark-gray¡ 10 percent medium-light-gray very fine- grained s~ndstone at 355-360 ft. No sample. 1 295-300 300-303 303-305 305-315 315-320 320-370 370-373 . LAb~:~ / from Knifeblade test well 2A \ere of good quality 0 a depth of 1,500 feet. Below this M depth there appe ed to be a considerable amount of W loose sand cont . ation. No samples were take from 190 to 335 fee as the section was duplicat.e y nearby Kuifeblade tes well 2. . / A ¡fýl/~ ~ Core Depth (teet) 0-5 5-15 15-20 20-30 Fe' - ......<.:.... ... þ' t :~'-~ : 4 r" 412 . . EXPLORATION OF NAVAL PETROLEUK RESERVE NO.4, NORTHERN ALABltA, 1944-53 OlIn »-pili (feet) LitIaologk delCription-CoDtiuued Bemarb mostly dark chert, some earbouaceous particles and mica, other miDeralø rare; rare argiUaceoua partinp; DOD- calcareous; dip 8°-1sr'; lIOIDe cro8II-' beddiDg; DO ahowa. Loose BaDd, 8S perc8Dt fiDe-grained, rarely very fqae- or medium-¡raiDed; white and clear quart.a. Recovered 1 It 9 m.: Microfossi1s abøeDt. Sandstone, light.-gray, fiDe-graiDed, bard; 90 percent white and clear quart.a; remainder is dark chert, coal, and rock particles; argillaceous cement¡ ODe black carbonized-coaly plant fragment 2* m. long and one quarter inch wide; Doncalcareous¡ dip SO-I2"¡ DO ahOWII. At 1,661 ft effeo- tive porosity 6.13 percent, and aample is impermeable to air. Loose BaDd, very fiDe- to fiDe-grained¡ 8S percent white and clear quartz; one clay chip at 1,680-1,685 ft. Sandstone chips, light.-gray, very JiIle- grained; trace to 8 percent aDtstone and trace of clay ahale; much very fiDe loose aand. Siltstone, medium-light-gray, BaDdy; much 10088 sand. Sandstone,1ight-gray, fiDe-grained¡ mostly looøe BaDd; trace to 20 percent clay ahale at 1,730-1,740 ft. Clayahale, medium-dark-gray, ailty. I..ooae sand, light-olive-gray, very fiDe- grained to ailty¡ grains subangular; mostly white and clear quartz. Biltstone, medium-light-gray, aandy, non- calcareous. Loose sand, very fiDe-graiDed¡ some ailt- atone. Bntstone, medium-light-gray; loose BaDd¡ IIOme clay shale. Clay ahale, medium-gray, silty; rare medium-dark-gray chips. No aample. Recovered 2 ft 9 m.: MicrofOll8i1ø very rare. Claystone, closely mterbedded, with siltstone, with all gradations of each, medium- to medium-dark-gray, non- calcareous, bard; irregular fracture; dip 21°. COD ANALYSES Eft'ective porosity, air permeability, and carbonate content analyses were made in the Fairbanks laboratory of the Geological Survey on core samples shipped :hom the test well sites. Porosity and permeability were de- 1,622-1,661 24 1, 661-1, 8M 1, 6M-l, 690 I, 690-1, 725 1,725-1,730 . 1,730-1,765 1,765-1,765 1,765-1,770 1,770-1,776 1,776-1,780 1,780-1,786 1,786-1,790 26 1,790-1,802 1,802-1,805 termined on the type of equipment mentioned on page 392. In coring with the cable tool rig there was a tend- ency for the softer sandstones to disintegrate, leaving only hard imperme1J,ble :hagments for analysis. The results given in the following table were obtained on samples :hom KDifeblade test well 1. All plugs were cut normal to the bedding. Core øtllJl,l8Ø, Km/eb1.ll,à teal velll OlIn. = 2____________________________ 3____________________________ 7____________________________ 13_______~___________________ 141__________________________ 15_____________;_____________ 16___________________________ 17___________________________ 18___________________________ 267 314 828 1,162 1,269 1,297 1,377 1,394 1,486 B1reetIve =:; ttrwl;'<: JIcIIinJa) 4.42 6.. 29 10.58 11.50 13. 06 8.16 4. 58 6. 08 lL 10 o o o <1 <1 o 2.72 2.66 <1 I Oarbcmate-m1DenII 0IIDteD& 1I.M JIØI'CIIDt by Wlll¡ht. No analyses were made of Knifeblade test well 2. The following table gives the porosity and perme- ability determinations made on Knifeblade test well2A. Core ØtllJl,lIU, KRifeblode lut vell SA OlIn Depth (feet) B1recUve =:; 1__________________ 3__________________ 5__________________ 7__________________ 9__________________ 11_________________ 14_________________ 18_________________ 19_________________ 20_________________ 24_________________ 1 172P 465P 758P 792P .807P 893P 1, 066P 1, 508N 1, 621N I, 657N I, 661N 16. 00 10.07 10.25 14. 20 20.90 8. 93 9.45 11.46 9.74 11. 56 6.13 AJr permeabIII~ (DiJlUdareJa) 41. O. Sample too øma1J to drill plug. 1.3. 325. O. O. O. O. <1. O. I P Sa puaIIe1 w the beddlDc. N Sa Dœmal w the becIdJuc. BJU.VY.MINBIU.L ANALY8I8 Robert H. Morris examined (see p. 392) 5 heavy- mineral samples :hom Knifeblade test weIll and 8 from Knifeblade test well 2A. (See fig. 31.) No samples were prepared from Knifeblade test well 2. He de- termined that in Knifeblade test weIll the zoned zircon zone ranges :hom 1,290 to 1,490 feet. A sample at 1,160 feet is nondiagnostic. In Knifeblade test well 2A the zoned zircon zone ranges from 460 to 1,540 feet. One sample at 160 feet is nondiagnostic. OIL AND GAS OIL .AJO) GAS SHOWS No good. oil or gas shows were found in the Knife- blade test wells although many of the sandstone and silt, . . /J1 owllrr ----- 378 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 'III" ,litO '110" 'iii" '52" ,... . /1- EXPLANATION C 8 . C l' .. N ...- It ,/0 + "'.......... ... + 10" . 0", - ~- 10" ~ &.1- ,lit· t .. -., I~ '90 290..·...· 152" , IOIITII U"'O.TaTIrIU , 7 ..M_TaTIrIU' ,. OUMALlICTDTWIU.' ,. IIOU'CIIIDTØTWIU. . 2 SOUTIIUII_TaTIrIU 2 8 tWAtIOIIUlCTaTWIU.' ,. IASTOUMALlICTDT-.a.' . 8UetIC TaT IIIU.,' . SOUTII U"'O. TaT IrIU . 8 lAST TClPAtIOlIUIC TaT WIU. , 'II SQUAIII LAKI TaT -.a. " z, auetlC TaT IIILL 2 . SOUTII UII_ TDT -.a. & ,. FI511 CIIID TDT -.a. 1 '8 nTALUK TaT -.a. , .. ICIIIFIaADC TaT WILL , II AVAICTaTIrIU' IIUGLAICTaTWIU.' n IIOU'CIIŒICTaT-.a. , .. ICIlIFULADlTaTwa.LS aAIIDU ~IITIISt.PSOIITDT-.a. , '2 MUDCTDT-.a. , '8 IIOU'CIIIDTDT'ftLL 2 z. 811AIIÍIsI'AIIDTaTWIU' as UMIAT TEST.au '-II ~ ~....... ~ _.....-....... __ __ ................ oII.- The United States Bureau of Mines at BartIesvi)le, Okla., analyzed a gas sample from Titaluk teSt wen 1. - The -assistance- of the Personnels of the above organi- - zatioDS is gratefully acknowledged. ~ ~ STRATIGRAPHY r Tïtal~ well 1 )penetrated the Ninuluk, Chand- ler, GriihdBtand, and Topagoruk ~~ taceous age (fig. 29). The much shallow ~ ~.nUa. penetrated only the Chandler -- - -~fðññations. Lithologically, however, the section drilled in the Knifeblade test wells is similar to the same _ formations in Titaluk test weIll. ::I en a.. III III ::J I- æ 0 ~ III 0:: en en C) FORMATION a: ..., CL. CL. :J NINULUK KILLIK TONGUE en :III: -:J :J -OF THE o % CHANDLER :&00][8 Opt O:&BTAOBOl1B ABB ..., en :J a: z ..., ~ 3: 0 z -' GRANDSTAND N~8BUX GROUP 1IIJfvt.n I'OUUTIO. The Ninuluk formation of Late Cretaceous age is- the youngest formation drilled on both the Titaluk or the Knifeblade anticlines. In Titaluk test weIll, it is made up of about 65 percent of clay shale, 30 percent of sandstone and siltstone (primarily in 2 thick sandstone beds), and 3 percent of coal and carbonaceous material. The other 2 percent is bentonite and clay ironstone. The clay shale is medium light to medium gray but is darker gray where it contains an abundance of carbonaceous material. It is moderately hard to hard and has a sub- u ~ to- ..., a: u TOPAGORUK FIGUU: 29.-Rocke of Cn>ta~eoull age penetrated by Tltaluk test well 1. TEST ~, TITALUK AND KNIFEBLADE ~JS.A ..,. v ..onchoidal fracture or breaks irregularly along bedding thick sandstone where there is a diminution of micro- planes but is finely laminated where interbedded with fossils which may be indicative of nonmarine beds. coal, carbonaceous shale, or bentonite. The Killik tongue is composed of 85 percent of clay- The sandstone is light gray, hard, and massive where stone and clay shale, 10 percent of sandstone and silt- cored near the base of the formation; it is very fine to stone, and about 5 percent of coal, very carbonaceoU3 medium grained, and 80 percent of the grains are white clay shale, and clay ironstone. The claystone and clay and clear quartz, and the remainder are coal particles, shale are medium light to medium dark gray. The dark chert, white chalky material (weathered feldspar da.rker colors are more common. This rock has poor or chert t), and rare mica. The siltstone is similar to cleavage and subchoncoidal fracture, that is, primarily the sandstone-medium light gray and hard. a claystone. Some of the carbonaceous beds are finely The sandstones and siltstones are slightly to mod- . laminated. erately calcareous. The cementing material is partly The sandstone is light to medium light gray, hard, argillaceous, partly calcareous, and probably partly and the beds are rarely more than 20 feet thick. The sideritic. The effective porosity in the sandstone beds grains are subrounded to subangular and range in size near the base of the formation is 11.7-12 percent, and from very fine to medium. They are made up of 75-80 the beds are. impermeable. percent white and clear quartz, and varying amounts Coal beds as much as 5 feet thick are present at the of dark chert, rock fragments, and carbonaceous and top and at about 250 feet below the top of the Ninuluk ironstone particles. The matrix in Titaluk test well 1 formation. The coal is soft, shaly, dull to shiny, is· slightly to moderately calcareous, whereas in the and black. In a few places it grades into dark-gray Knifeblade test wells· it is particularly argillaceous. carbonaceous clay shale that contains black plant . The siltstone is similar to the sandstone but is mostly fragments. slightly darker. The sandstone, siltstone, and clay- Bentonite is interbedded with the coal but is rare stone are gradational in places. Rare small-scale cross- elsewhere in the· Ninuluk formation. The bentonite is bedding is present. light gray to white and contains some brown biotite The effective porosity of the sandstone and siltstone plates. Yellowish-brown clay ironstone concretions in both areas is low, ranging from 0.96 to 5.29 percent are . present in the Ninuluk,· although they are not in the few samples tested. All plugs were impermeable. nearly as common as in the underlying· Killik tongue Except fora very small amount .of gas found while of the Chandler formation. drilling at 640 feet in Knifeblade test well 1, no oil The shallowest sample in TitaIuk test weill examined òr gas shows were found in the Killik: tongue of the by the Fairbanks laboratory was from a depth of 40 Chandler formation. feet. . This was from the Ninul~ formation and is Coal, carbonaceous material, and plant fragments essentIally the top of the formatIon. (See p. 383.) are scattered throughout the formation. The coal is '!he total thickness of the fo~ation in the ?1ta1uk area black, shiny to dull, brittle, and thin bedded. Very rare 18 abo~t 550 f~t. The Nmuluk formatIon was .not small inclusions of clear ~sh-yellow amber are found m the Knifeblade test wells, as older formatIOns present. Dark-gray carbonaceous shale is present above only are exposed along the axis of the Knifeblade and below the coal and elsewhere in the section. Black. anticline; the Ninuluk formation is present off the plant impressions are found in both the claystone and north flank of the anticline, according to C.L. Whitting- sandstone being abundant at some depths. These ton (oral communication, 1956.) imprèssio:U; arè fragmentary and the plants cannot be Despite the presence of coal and ea.rbonaceous beds, identified. ' . the Ninuluk formation is primarily. mar~e as in~cated Very characteristic of the Killik tongue are clay iron- by the repeated occurrence of manne mtcrofossds. . A stone (sideritic mudstone) concretions and laminae, few pelec~pods w:ere also ~ound. The f~w nonmarme _ particularly in the Knifeblade test wells. The clay beds ~Iated Wlth the Nmuluk formation are ~rs ironstone is hard, has conchoidal fracture, and ranges of the NIakogon tongue of the. Chandler formation. from gray to yellowish brown. Brown dense dolomite ar.I.IE 'fonu. 01' 'I'D CBAlIDLD 1'0.XA'l'IOB (or siderite 1) laminåe as much as 2 inches thick are found near some of· the thicker cOal beds in TitaIuk test well 1. Tiny vertical veins of' yellowish-gray dolomite crystals a~ ~e. . In the Knifeblad~ test wells and the subsurface in other places in the Reserve, there is a great deal of . authigenic sericite in the Killik tongue. This mica The Killik tongue of the Chandler formation, 1,260 feet thick, underlies the Ninuluk formation in Titaluk test weIll; at the type section it is mostly nonmarine (Detterman, 1956, p. 237). In the subsurface there is no.good break between the two formations. The con- tact in the Titaluk test well is placed at the base of a . . 380 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 gives a silky sheen to fractured surfaces. The sericite is most common in the lower part of the Chandler for- mation although some is also found in the upper Grand- stand formation. Ø..urDBTAlI'D .OJtXATIOll' Thè Chandler formation grades into the marine Grandstand formation; the top of the Grandstand for- mation is placed at the first common occurrence of the Vern.euilÍ1&oide8 boreolÎ8 marine fauna. This is also the approximate top of a very sandy section, the thickest sandstone bed of which occurs about 350 feet below the faunal top. The Grandstand formation in TitaJuk test well 1 is 1,650 feet thick. About 1,710 feet of this formation was drilled in Knifeblade test well 2A, but this is at least 10 percent in excess of the true thickness because of the steep dips. A comparison of thicknesses in the two wells suggests that the bottom of Knifeblade test well2A is near the base of the formation. The Grandstand contains about 100 feet of sand- stone and siltstone in beds as much as 180 feet thick; the rest is clay shale and claystone. The sandstone is light gray (rarely medium light gray), hard, and massive. The grain size ranges from very fine to medium in the Titaluk test well and from very fine to very coarse in the ·Knifeblade test wells; grain size de- ereases with depth. A few thin beds of conglomerate were recorded at the top of the formation in Knifeblads test well 1. The conglomerate contains subrounded and rounded granules and pebbles of dark-gray, green- ish-gray, and black chert, milky quartz, coal, medium- and medium-light-gray clay shale, yellowish-gray clay ironstone, and light-gray sandstone. As is usual in the sandstones of the Nanushuk group, the predominant mineral making up the sand is white and clear quartz, ranging in quantity from 60 to 90 percent of the total. The other grains are mostly dark cbert and carbonaceous particles with a few rock frag- ments. The proportion of dark grains is higher in the coarser standstane, which has a salt-and-pepper ap- pearance. Most of the grains are subanguIar, and a few are subround; but the very coarse grains are round. Where tested, the eBective porosity of the Grand- stand formation ranged from 4.58 to 20.9 percent in the Knifeblade test wells and from 0.56 to 12.45 percent in the Titaluk test well. The highest air permeabili- ties were 325 millidarcys and 17 millidarcys, respec- tively, although most samples tested "impermeable." The low range of porosity in the Titaluk test wen is a result of calcareous material in the matrix. The content of carbonate minerals in the sandstone in Tita- luk test well 1 is higher than that in the Knifeblade test weIls, and 1 sample in the Titaluk test well had an exceptionally high reading that measured 30.4 per- cent by weight. Ordinarily the matrix: of the sand- stone of the' G-randstand formation is argillaceous. A few feet of limestone (or possibly siderite or dolo- mite )-medium-dark-gray with a brownish cast, hard, argillaceous, with white vein calcite-was found in Titaluk test well 1, but none was found in the Knife- blade test wells. Most of the oil-producing zones in the Umiat field are in the Grandstand formation (Collins, 1957). In the Knifeblade test weIls this formation contains nu- merous deposits of black: bitumen or asphaltic residue suggesting that at one time the fault blocks that were drilled (see p. 413) did contain oil. The light frac- tions have long since escaped. The two deep Knife- blade holes yielded brackish water on bailing tests. In Titaluk test well 1, a little gas and a few oil shows were noted. Siltstone in the Grandstand formation is light to medium light gray, and hard and is made up primarily of white and clear quartz grains. It is generally grada- tional with the sandstone beds and makes up less than 10 percent of the sandstone-siltstone bulk. Some swirly bedding and some small-scaJe crossbedding were noted in the siltstone near the top of the formation in TitaIuk . test well1. The clay shale and claystone are medium to dark gray and hard. The clay shale has fair to good cleav- age, and the claystone has almost no cleavage but has irregular to conchoidal fracture. These clayey beds are mostly noncalcareous but are very silty in places and grade to siltstone. The clay shale has some micaceous- carbonaceous partings. Sericite is present but is not common in the formation. There is considerably less coal and carbonaceous ma- terial in the Grandstand formation, particularly at TitaIuk, than in the Chandler formation above. A few coal beds are near the top of the Grandstand in the Knifeblade test wells, but these beds interfinger with marine microfossil-bearing shales. The coal may rep- resent nonmarine stringers of the Chandler formation. No thick coal beds were cored; the cutting chips are black and shiny to dull. Rare carbonaceous shale beds and a few plant fragments in the shale partings were noted. Clay ironstone is less common in the Grandstand formation than in the Chandler formation. Marine microfossils (see p. 417) are present through- out the formation, as wen as I MC8ramuø sp. (mostly prisms in the cuttings), Ditropa sp., and crinoid frag- ments. The Knifeblade area was probably closer than the Titaluk to the source of the material that makes up the Grandstand formation as the sandstone is coarser grained, even conglomeratic, and there are more coaly beds. TEST WE~ALUIt AND XNIFEBLADE AREAS, + 381 TOPA.GORUK FORMA.TION which underlies the Nanushuk group. Only a few Only 520 feet of the Topagoruk: formation was pene- minor shows of oil and gas were found. (See page 394.) trated by Titaluk test well L The Knifeblade tests were The formation contacts as determined in this test ¡ too shallow to reach it. In Titaluk test weIll, the divi- are as follows: sion between the Grandstand and Topagoruk forma- NinuIuk_________________ 40-590 feet. tions is a. well-defined lithologic change. The base of Chandler______'-_________ 590-1,850 feet. the Grandstand (also the base of the Nanushuk group) Grandstand______________ 1,850-3,500 feet. is placed at the bottom of the thick sandstone group. Topagoruk_______________ 3,500-4,020 feet, total depth. The Topagoruk formation is about 70 percent of clay Field investigations by W. P. Brosgé, C. L. Whitting- shale and 30 percent of siltstone and a little sandstone. ton, and A. L. Kover, U. S. Geological Survey, show The clay shale is medium to medium dark gray and that the Seabee formation of the Colville group of late hard. The cleavage ranges from very good to very poor, Cretaceous age is present on the surface at the rig and some of the rocks can be classified as claystone. site~ Samples representing the top 22 feet of rock were Some of the claystone is calcareous. not received by the Fairbanks laboratory, but W. P. The siltstone is light to medium light gray, slightly Brosgé 1 believes that this interval of rock, based on to moderately calcareous, ha.rd, has fair to good cleav- the well geologist's description, represents the Seabee age paraIlel to the bedding and some carbonaceous and formation. The uppermost sample from 40-50 feet micaceous partings. There are a few thin beds of very received in the laboratory contained a few microfossils fine- to fine-grained quartz sandstone. Effective poros- which are distinctive of the Ninuluk formation. ity in the coarsest siltstone beds cored was between 4 The elevation of Titaluk test well 1 has been a.djusted and 6 percent, and the plugs tested were impermeable. by W. P. Brosgé to the Umiat datum.- All elevations A very pale cut of oil was obtained from one core near and locations in the Umiat-Maybe Creek area are sub- the top of the formation. ject to correction, pending the results of new topo- The siltstone and the clay shale are interbedded, some graphic surveys. places in thin laminae. An inch-thick intraformational conglomerate made up of subangular clay shale frag- ments in siltstone was found 170 feet below the top of the formation. A small amount of swirly bedding and small-scale crossbedding is also present. The Topagoruk formation contains the same micro- fossils and megafossils as the Grandstand formation. / ~ TlTALUK TEST WELL 1 } Location: Lat 69°25'21" N.,long 1M-34'M" W. Appros:1mate elevation: Ground, 822 feet; kell7 bushlng, 840 feet. Spudded: AprU 22, 195L Completed: 1my 6. 1951. dr7 and abandoned. Total depth: 4,020 feet. Titaluk test well 1 is on the· Titaluk anticline about 62 miles west of Umiat. The test is on· the top of a ridge 7 miles northeast of the junction of Maybe Creek and the Titaluk River and about 650 feet above the streams. The area has rolling hills and intrenched streams near the north edge .of the Arctic Foothills province. Fifteen miles north of the test site the land flattens to the monotonous lake-covered Arctic coastal plain. The purpose of the hole was to test the oil and gas possibilities of the formations of the Nanushuk group to the extent· of completely penetrating the lowest sand-. stone or reaching the capacity of the rig (approxi~ mately 4,000 feet). The hole was cúilled to 4,020 feet, at which depth it penetrated the Topagoruk: formation 4888CS&-ð8---2 STB.11CTUB.B The Titaluk anticline is a long and narrow structure extending from a point southeast of the Meade 'River at lat 69°35' N., long 157°05' W. about 80 miles east to a. point near the headwaters of Maybe Creek a.t !at 69°20' N. and long 153°30' W. Near its midpoint the Titaluk anticline is crossed by the river from which it derives its name. Titaluk test well 1 was drilled on a local closure near the east end of the anticline. The minimum closure on top of the Seabee formation as shown by structure con- touring by Brosgé and Kover and by United Geophysi- . ca.l Co. (fig. 30) is about 180 feet, and the area covered is about 13 square miles. The actual closure on such a large anticline could be well in excess of these figures. Contours on figure 30 are projected over the top of the anticline where the Seabee formation is eroded. Sur- face geological control is Jacking on the northwest side but it has been supplemented by seismic lines (United . Geophysical Co., party 144, 1950) which indicate clo- sure at depth (phantom seismic horizon A in shallow rocks of CretaceouS age). . The test well is just south of, and 70 feet below, the apex of the anticline. The strata drilled in the test are flat lying to a depth of about 2,000 feet, indicating that : the test was drilled near the apex to this depth at least. I 1 WUlIam BrOQf, penIOual eO"....II"I.......1I. · Datum used 011 the Umiat 8pec:1a1 Map, . topocraphlc meet pabo Uahecl b)" the U. S. Geoloc1eal 8UrY.,. III 1948. COmeSTS A...'iD TEST WELLS, Ou:uALIK . ALASK.-\. 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. TitaIuk River area: 1 test well; 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; ma.ny 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 SOUTH . ARCTIC FOOTHillS PROVINCE II: .... ... ... ::::I on ::::I o .... '" '" II: .... ~ u ~=~ -+- \ of gas was found in these older rocks. Oilfields \, discovered at Umiat and Simpson seeps and gasti at Barrow and Gubik. Some shows of oil or gas i __- 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. . NORTH ARCTIC COASTAL' PLAIN PROVINCE s.n...... Hill _ SCHRAD£R Ban.. - r,aU rnemtNf' BLUFF ----------- FORMATION .....,. Cr_ _ A,.,... __ SEABEE FORMATION NINULUK FORMATION GRANDSTAND FORMAnoN GRANDSTAND FORMAnoN TOPAGORUK FORMATION TOROK - ---- -- ------"--? ?--------~----- II: .... ~ o ...J FORTRESS MOUNTAIN FORMAnoN FORMATION ------------------------? ?-------------- OKPlKRUAK FORMATION --? UNITS OF JURASSIC _ auMAUK FORMAnoN LOW£R __ip 01 _ CRETACEOUS(?)MD '_ to 1_ to llIe UPPE.. _tit I. un_ JURASSIC(?JROCKS, UNDIFFEItENTlATED - NoI_ I F,~ -.- 'Iy_ -,-lie E""'-I :'iif',ih':' - J'III1'UI.-N-.cIatun fJI. &be Cm- roca fJI. aœUIem AJub. I . 378 . EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 168' 164' 150' 156' 152' 148- , (:. EXPLANATION C C E . C l' A N G.. wen l ,. .. AbandoneCS well .. 70· _ Dfy hole 68'__ ..' '. '. .~ 164· o I '~O 290MIL~. 50 . , 'yo 1 SOUTH BARROW TEST WnL 1 2 SOUTH BARROW TEST WELL 2 3 SOUTH BARROW TEST WELL :3 .. SOUTH BARROW rEST WEll . 5 AVAK rEST WELL 1 6 NORTH SIMPSON TEST WELL 1 7 SIMPSON TEST WELL 1 8 TOPAGORUK TEST WELL 1 9 EAST TOPAGORVK TEST WEll 1 10 FISH CREEl( TEST WELL' 11 !CAOl"K TEST WELL I 12 MEADE TEST WELL 1 13 OUMALlK TEST WELL 1 ,.. [AST QUMALU( TEST WELL I 15 SQUARE lAKE TEST WELL '. 18 TlTAlUK TEST WELL' 17 WOLF CREEK TEST WELL 1 18 WOLF CREEK TEST WELL Z ìO· .' .,# .. '" ..' '.. ..;~~;;;~........,.(. ß .. . ........ 11 I II pllO -68. 152' 19 WOLF CREEK TEST WELL 3 20 GUBIK rEST WElL._ 21 GUBIK TEST WELL 2 22 KHIF[BlAD[ TEST WELL 1 23 KHIFEBlADE TEST WELLS 2 AND ZA 24 GRANDSTAND TEST WELL 1 25 UMIA.T TEST WELLS 1-11 - FIGURE 2K-Index map of northern Alaska showing location of test weIls and oil fields. The United States BureaU of Mines at Bartlesvi)le, Okla., analyzed a gas sa!llple from Tit.aluk test wen 1. . The assistaIlCe of the personnels of the above organi- zations is ~ratefuny àcknowledged. ~TRATIGRAPHY Titaluk test weI¡ ~ penetrated the Ninuluk, Chand- ler;. Grandstand,. and Topagoruk fonüatiöl~Š"of Cre- taceous age (fig. 29). The much shallower Knifeblade test wells penetrated only the Chandler and Grand- stone formations. Lithologically, however, the section drilIed in the Knifeblade test wells is similar to the same formations in Titaluk test well 1. ~ (J) 0- W w :J I- a:: 0 (J) >- w a:: (J) (J) ~ c: ..... 0.. 0.. :::J :¥:: I/) :::J :::J 0 :x:: I/) ..... :::J U < c: Z l1J < I- 3: 0 z ..... ..J c: U ROCKS OF .CRETACEOUB AGE NANUSHUK GROUP NmmUK FORMATION The Ninuluk formation of Late Cretaceous age is the youngest formation drilIed on both the Titaluk or the Knifeblade anticlines. In Titaluk test well 1, it is made up of about 65 percent of clay shale, 30 percent of sandstone and siltstone (primarily in 2 thick sandstone beds), and 3 percent of coal and carbonaceous material. The other 2 percent is bentonite and clay ironstone. The clay shale is medium light to medium gray but is darker gray where it contains an abundance of carbonaceous: material. It is moderately hard to hard and has a sub- FORMATION NINULUK KILLIK TONGUE OF TH E CHANDLER GRANDSTAND TOPAGORUK FIGURE 29.-Rocks of Cretaceous age penetrated by TitaJuk test well 1. · ,YELLS, TITALUK AND KNIFEBLADE A., ALASKA 379 conehoichl fracture or breaks irregularly along bedding thick sandstone where there is a diminution of micro- planes but is finely laminated where interbedded with fossils which may be indicative of nonmarine beds. coal, carbonaceous shale, or bentonite. The Killik tongue is composed of 85 percent of clay- The sandstone is light gray, hard, and massive where stone and clay shale, 10 percent of sandstone and silt- cored near the base of the formation; it is very fine to stone, and about 5 percent of coal, very carbonaceous medium grained, and 80 percent of the grains are white clay shale, and clay ironstone. The claystone and clay and clear quartz, and the remainder are coal particles, shale are medium light to medium dark gray. The dark chert, white chalky material (weathered feldspar darker colors are more common. This rock has poor or chert 1), and rare mica. The siltstone is similar to cleavage and subchoncoidal fracture, that is, primarily the sandstone-medium light gray and hard. a claystone. Some of the carbonaceous beds are finely The sandstones and siltstones are slightly to mod- . laminated. erately calcareous. The cementing material is partly The sandstone is light to medium light gray, hard, argillaceous, partly calcareous, and probably partly and the beds are rarely more than 20 feet thick. The sideritic. The effecti\"e porosity in the sandstone beds grains are sub rounded to subangular and range in size near the base of the formation is 11.7-12 percent, and from very fine to medium. They are made up of 75-80 the beds are impermeable. percent white and clear quartz, and varying amounts Coal beds as much as 5 feet thick are present at the of dark cherf, rock fragments, and carbonaceous and top and at about 250 feet below the top of the Ninuluk ironstone particles. The matrix in Titaluk test weIll formation. The coal is soft, shaly, dull to shiny, is slightly to moderately calcare-ous, whereas in the and black. In a few places it grades into dark-gray Knifeblade test wells' it is particularly argillaceous. carbonaceous clay shale that contains black plant The siltstone is similar to the sandstone but is mostly fragments. slightly darker. The sandstone, siltstone, and clay- Bentonite is interbedded with the coal but is rare stone are gradational in places. Rare small-scale cross- elsewhere in the Ninuluk formation. The bentonite is bedding is presè!1t. light gray to white and contains some brown biotite Thè efi'ecÜve porosity of the sandstone and siltstone plates. Yellowish-browriclay ironstone concretions in both area~;is low, ranging from 0.96 to 5.29 percent are present in the Ninuluk, although they are not in the few samples tested. All plugs were impermeable. nearly as common as in the underlying Killik tongue Except for a very small amount of gas found while of the Chandler format.ion. drilling at 640 feet in Knifeblade test well 1, no oil The shal.lowest sample in Titaluk test weIll examined or gas shows were found in the Killik tongue of the by the FaIrbanks laboratory, was from a depth of 40 Chandler formation. feet. . This was from the Ninulu~ formation and is Coal, carbonaceous material, and plant fragments essentIally the top of the formatIOn. (Seep. 383.) are scattered throuO"hout the formation. The coal is !he total t~ickness of the fO:'mation in the !italuk area black, shiny to dull, brittle, and thin bedded. Very rare IS abo~t 5::>0 !e~t. The Nllluluk formatIOn was .not small inclusions of clear greenish-yellow amber arE} found In the Klllfeblade test well.s, as older for:natIOns present. Dark-gray carbonaceous shale is present above only are exposed along the aXIS of the Kmfeblade and below the coal and elsewhere in the section. Black anticline; the Ninuluk formation is' present off the pLmt impressions are found in both the claystone and - . north flank of the ~nti:line, according to C. L. vV1Üttlng- sandstone, being abundant at some depths. These ton (or~l commumcatIOn, 1956.) impressions are fragmentary, and the plants cannot be Despite the presence of coal and carbonaceous beds, identified. the Ninuluk formation is primarily.marÍI:e as in~icated Very characteristic of the Killik tongue are clay iron- by the repeated occurrence of marme mIcrofossIls. . A stone (sideritic mudstone) concretions and laminae, few pelec~pods ~ere also }ound. The f~\v nonmarllle particularly in the Knifeblade test wells. The clay beds ass2?lated wIth the N llluluk fonnatlOn are ~ngers - ironstone is hard, has conchoidal fracture, and ranges of the NIakogon tongue of the Chandler formation. from gray to yellowish brown. Brown dense dolomite KILLIK TONGUE OF THE CHANDLER FORMATION (or siderite?) laminae as much as 2 inches thick are found near some of the thicker coal beds in Titaluk test well 1. Tiny vertical veins of' yellowish-gray dolomite crystals ar~ rare. . In the Knifeblade test wells and the subsurface in other places in the Reserve, there is a great deal of authigenic sericite in the Killik tongue. This mica The Killik tongue of the Chandler formation, 1,260 feet thick, underlies the Ninuluk formation in Titaluk test well 1; at the type section it is mostly nonmarine (Detterman, 1956, p. 237). In the subsurface there is no good break between the two formations. The con- tact in the Titaluk test well is placed at the base of a , , . . 380 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 gi ves a sjlky 8l1een to fractured surfaces. The sericite is most common in the lower part of the Chandler for- ma60n alt.hough some is also found in the upper Grand- stand formation. - GRANDSTAND FORMATION The Chandler formation grades into the marine Grandstand formation; the top of the Grandstand for- mation is placed at the first common occurrence of the 17 erne/l.ilinoides borealis marine fauna. This is also the approximate top of a very sandy section, the thickest sandstone bed of which occurs about 350 feet below the faunal top. The Grandstand formation in Titaluk test weIl 1 is 1,650 f,eet thick. About 1,710 feet of this formation was drilled in KnifebJade test weIl 2A, but this is at least 10 percent in excess of the true thickness because of the steep dips. A comparison of thicknesses in the two weIls suggests that the bottom of Knifeblade test weIl 2A is near the base of the formation. The Grandstand contains about '700 feet of sand- stone and siltstone in beds as much as 180 feet thick; the rest is clay shale and claystone. The sandstone is light gray (rarely medium light gray), hard, and massive. The grain size ranges from very fine to medium in the Titaluk test weIl and from very fine to very coarse in the Knifeblade test weUs; grain size de- creases with depth. A few thin beds of conglomerate were recorded at the top of the formation in Knifeblade test well 1. The conglomerate contains subrounded and rounded granules and pebbles of dark-gray, green- ish-gray, and black chert, milky quartz, coal, medium- aridmedium-light-gray clay shale, yeIlowish-gray clay ironstone, and light-:gray sandstone. As is usual in the sandstones of the Nanushuk group, the predominant mineral making up the sand is white and clear quartz, ranging in quantity from 60 to 90 percent of the total. The other grains are mostly dark chert and carbonaceous particles with a few rock frag- ments. The proportion of dark grains is higher in the coarser standstone, which has a salt-and-pepper ap- pearance. :Most of the grains are subanguJar, and a few are subround; but the very coarse grains are round. 'Where tested, the effective porosity of the Grand- stand formation ranged from 4.58 to 20.9 percent in the Knifeblade test weIls and from 0.56 to 12.45 percent in the Titaluk test well. The highest air permeabili- ties were 325 milIidarcys and 1'7 millidarcys, respec- tively, although most samples tested "imp.ermeable." TIle low range of porosity in the TitaIuk test weIl is a result of calcareous material in the matrix. The content of carbonate minerals in the sandstone in Tita- luk t.est weIl 1 is higher than that in the Knifeblade t.est weIls, and 1 sample in the Titaluk test weIl had an exceptionaIly high reading that measured 30A per- cent by weight. Ordinarily the matrix of the srmd- stone of the Grandstand formation is argiI1aceous. A few feet of limestone (or possibly siderite or doIo- mit.e)-medium-dark-gray wit.h a brownish cast, hard, aro-maceous with white vein calcite-was found in o· , Titaluk test weIl 1, but none was found in the Knife- blade tBst wells. Most of the oil-producing zones in the Umiat field are in the Grandstand formation (CoIlins, 1957). In the Knifeblade test weIls this formation contains nu- merous deposits of black bitun1en or asphaltic residue suggesting that at one time the fault blocks that were driIJed (see p. 413) did contain oil. The light frac- tions have long since escaped. The two deep Knife- blade holes yi.elded brackish water on bailing tests. In Titaluk test weIl 1, a little gas and a few oil shows were noted. Siltstone in the Grandstand formation is light to medium light gray, and hard and is made up primarily of white and clear quartz grains. It is generaIly grada- tional with the sandstone beds and makes up less than 10 percent of the sandstone-siltstone bulk. Some swirly bedding and some smaIl-scaIe crossbeddil).g were. noted in the siltstone n.ear the top of the formation in Titaluk test weIl 1. The clay shale and claystone are medium to dark gray and hard. The clay shale has fair to good cleav- age, and the claystone has almost no cleavage but has irregular to conchoidal fracture. These clayey be.ds are mostly noncaIcareous but are very silty in places and grade to siltstone. The clay shale has some micaœous~ carbonaceous partings. Sericite is present but is not common in the formation. - _ There is considerably less coal and carbonaceous ma- terial in the Grandstand fonnation, particularly at Titaluk, than in the Chandler formation above. A few coal beds are near the top of the Grandstand in the Knifeblade test weIls, but these beds interfinger with marine microfossil-bearing shales. The coal may rep- resent nonmarine stringers of the Chandler formation. No thick coal beds were cored; the cutting chips are black and shiny to duIl. Rare carbonaceous shale beds and a few plant fragments in the shale partings were noted. Clay ironstone is less COJllmon in the Grandstand formation than in the Chandler formation. Marine microfossils (see p. 41'7) are present through- out the formation, !!-s wen as Inoceramus sp. (mostly prisms in the cuttings), Ditrupa sp., and crinoid frag- ments. The Knifeblade area was probably closer than the Titaluk to the source of the material that makes up the Grandstand formation as the sandstone is coarser grained, even conglomeratic, and there are more coaly beds. - TEST .' TITALUK A1."\¡D &"\¡IFEBLADE AREAS, A~ 381 TOPAGORUK FOR:\UTIOX which underlies the Nanushuk group. Only a few Only 520 feet of the Topagoruk formation was pene- minor shows of oil and gas were found. (See page 394.) trated by Titaluk test weIll. The Knifeblade tests were The formation contaèts as determined in this test too shallow to reach it. In Titaluk test well 1, the divi- are as follows: sion between the Grandstand and Topagoruk forma- Ninuluk. _ _ _ __ __ _ __ _ __ _ _ _ 40-590 feet. tions is a well-defined lithologic change. The base of Chandler________________ 590-1,850 feet. the Grandstand (also the base of the Nanushuk group) Grandstand_ - -- - - - -- - - - - - 1,850-3,500 feet. is placed at the bottom of the thick sandstone group. Topagoruk_______________ 3,500-4,020 feet, total depth. The Topagoruk formation is about 70 percent of clay Field investigations by W. P. Brosgé, C. L. Whitting- shale and 30 percent of siltstone and a little sandstone. ton, and A. L. Kover, U. S. Geological Survey, show The clay shale is medium to medium dark gray and that the Seabee formation of the Colville group of late hard. The cleavage ranges from very good to very poor, Cretaceous age is present on the surface at the rig and some of the rocks can be classified as claystone. site. Samples representing the top 22 feet of rock were Some of the claystone is calcareous. not received by the Fairbanks laboratory, but "V. P. The siltstone is light to medium light gray, slightly Brosgé 1 believes that this interval of rock, based on to moderately calcareous, hard, has fair to good cleav- the well geologist's description, represents the Seabee age parallel to the bedding and some carbonaceous and formation. The uppermost sample from 40-50 feet micaceous partings. There are a few thin beds of very received in the laboratory contained a few microfossils fine- to fine-grained quartz sandstone. Effective poros- which are distinctive of the Ninuluk formation. ity in the coarsest siltstone beds cored was between 4 The elevation of Titaluk test wen 1 has been adjusted and 6 percent, and the plugs tested were impermeable. by W. P. Brosgé to the Umiat datum.2 All elevations A very pale cut of oil Was obtained from one core near and locations in the Umiat-Maybe Creek area are sub- the top of the formation. _ ject to correction, pending the reª-ults of new topo- The siltstone and the clay shale are interbedded, some graphic surveys.. - - ..:::~. places in thin laminae. An inch-thick intràformational STRUCTURE conglomerate made up of sub angular clay shale frag- ments in siltstone was found 170 feet below the top of the formation. A small amount of swirly bedding and small-scale crossbedding is also present. The Topagoruk formation contains the same micro- fossils and megafossils as the Grandstand formation. 'rITALUK TEST WELL 1 Location: Lat 69°25'21" N., long 154°34'04" tV. Approximate. elevation: Ground, 822 feet; kelly bushing, 840 h~ . Spudded: April 22, 1951. Completed: July 6, 1951, dry and abandoned. Total depth: 4,020 feet. Titaluk test well 1 is on the Titaluk anticline about 62 miles west of Umiat. The test is on-the top of a ridge 7 miles northeast of the junction of Maybe Creek and the Titaluk River and about 650 feet above the streams. The area has rolling hills and intrenched streams near the north edge of the Arctic Foothills province. Fifteen miles north of the test site the land flattens to the monotonous lake-covered Arctic coastal plain. The purpose of the hole was to test the oil and gas possibilities of ~he formations of the Nanushuk group to the extent of completely penetrating the lowest sand- stone or reaching the capacity of the rig . (approxi~ mately 4,000 feet). The hole was drilled to 4,020 feet, at which depth it penetrated the Topagoruk formation 466356-59-2 The Titaluk anticline is a long and narrow structure extending from a point southeast of the Meade River at lat 69°35' N., long 157°05' W. about 80 miles east to a point near the headwaters of Maybe Creek at lat 69°20' N. and long 153°30' W. Near its midpoint the Titaluk anticline is crossed by the river from which it derives its name. .--- .. Titaluk test weIll was drilled on a local closure near the east end of the anticline. The minimum closure on top of the Seabee formation as shown by structure con- touring by Brosgß and Kover and by United Geophysi- cal Co. (fig. 30) is about 180 feet, and the area covered is about 13 square miles. The actual closure on such a large anticline could be wen in excess of these figures. Contours on figure 30 are projected over the top of the anticline where the Seabee formation is eroded. Sur- face geological control is lacking on the northwest side but it has been supplemented by seismic lines (United Geophysical Co., party 144, 1950) which indicate clo- sure at depth (phantom seismic horizon A in shallow rocks of Cretaceous age). The test well is just south of, and 70 feet below, the apex of the anticline. The strata drilled in the test are flat lying to a depth of about 2,000 feet, indicating that : the test was drilled near the apex to this depth at least. 1 William Brosgé, personal communication. . Datum used on the Umiat Special Map, a topographic sheet pub- lished by the U. S. Geological Survey in 1948. , ...u..... 'lee' 1!elJ;' a.. 7& ...._ ft~' .f ,. te'¡" ài'l.'I.... ... lIP Wfeo1.eAe e__e. ¡to.... 'I.......~ at :¡.at. 6'f1' 6.:3 la. ¡,ørI&. U4: 4'1.' ..~e J-'l.4. .,uI. .... etaJ't.... on J!>i1J' 11/. '1.<;111). _ th .. ~..kte ~ - ài).).eð. to .. døP"' of !'It' ..t _lol1 ¡¡oint tIo& *" on _ ¡U"U'L e'''' -"..'L....i1>& - 01' ""II. -paJ't .f _ ... u.tIo& \1.;'1.8- 'f1At1i& at,..-,e_e ",,__eetul ... - 1ii>U .... jOJIIt.ð. on ~6. 'L~). at.d tIo& m ~ _. _1\Þrth te a ""v :1.<>_".... fO" ......- teet. , ._1ið.... .1 _ """"lei< n- ..... ~2i....."""'''a. · ' ." ..... fl"· feet ao...· ¡p:__~' U a/4 ,,- """,UOII .... ... .' 4f> f...t. _ ~. ~~t<I. e ->'L ¡¡ort'l.On of .. 11.......-· --.... ie tIo& ,,' f~ ....it. _ _""n te ~.loCJU-~- .,.,¡.J, _\II , . jØ.; 11'I .v. ~ __t.1iØ "..,1>\.-", - ....~ ie .. .."ð...,.... 1n ~. "A~s). $l~~.. '-k t""' - ,- ll')~ . U 0 50 G.~GIC~ ø:V1Ø }JaW 011. 'Un1 t,1øe.bol'&wn fa.irbankS, jJ.a~ . Ø1:rø.AJ)& US'! ~. 1iO 0 2 a1. ~).èS.:t· ittéej;'i~ð. ~. Ce1'e and *1.1 Cu.\ f¡;iJig ~~t.p'ioø 5-1.6 C1.àf ~.. _<U"'" 'L1~ gat t.o "",,",'" g1IfIIl' aL~ t41¡W'. ~011. J1.""" 1'"117........... ",,_ l.,n.-· aatI< 78'U"vt..... -- t.hoø 0\11"" blnck' f'Jf>. ~ bl.... ....,. ,,'l.eII "haLe. ....... fl'IIII to" ",.. \)iat,\er c$~' "" clSiJ t..........· ' ' m.... ~ '" .... ~". iHIIJ tIØIIoi 111 tbe ~ ' ,~ ~-' .__ t.o &IOU ~. ~ tffPJI ~ cIJ,IIiI -':" .. - þt. fF'ÞIII' n"" gr<diiiØ ' . t~ fIPIJ' ft"" IiI>...,t , ,"""' ",.t'" ~r·. \e .. 01""" 03.... ~ ~... /IIIdi 01P~ .....t - ~.... d è1- ' C:!.., geT iii> ........ ..... ..., -. ~...... .... I¥:ff. _ 'bWiIt $i:!.~ ...-._. 11-'" {ffIlfII io þU9 'l.i#' 1iIf'I'I' ..",q fiae. tr~ ~aJ .We Saad""'- ..,.¡q 1.1P' f!!I"'II te 'I.igh1> 1/FIff' tot' to 1iIoIf'l. ....- \It> eoar" g~' ~a!I ~"" \Ø ...o~ ..,.:!., -.~. - wII1'. ' ani!. ,,'I....... ~\.... lff#. ..,µ. p....ue1... _ - ,{__,ll'" of' øñ~ \e). 11gb1> ...10....,. oUgn'l¥ ~ __e. .....110......-· ~.-. anð. 1.1p1> oU"" tp!8 t......·t...8 elOif eÞal'" .....t... Il!l'at 6C#. .iHtII>e'I... .,¡. anð. ..-' - ............. ~ &WÐe Sa","to"". li~ 1l!l'0lI' ."ft. .,eM"'" ~ ge1e. ~ eo ........ ...caÞã. ?fA, wII1 ,. an'" 01..... CI!"""~' .....- i. ð¡Øk _0'" CO'µ' parei"'L' 0'.01< fr~ "",d lOiea. .ugñ8U e$.1~. 1.þ.>2t) 26-66 '5-~ 15-~ 8ñ..J~5 95-}.06 1.05-1.46 145-1..55 1..55-1.66 \óD...-'\~ 165-185 185-205 205-210 210-225 225-235 236-245 245-250 250-265 265-280 280=295 £2n 1 :300=305 305-315 315~320 320=370 . . Clay sha.l9" medium gr£'.;J" also 40% sandstone as below in the lower half of t.he 1ntarval, tra.ce olive grð¥ ironstone Sandstone.) mediUJD light gra;¡ p ver.,¡ 80ft to medium soft~ medium grainsd-. rare fine gra:lnedß grains euõangular, .. Sal t and pepperd 9 607-~ white and olear quartz, balance mostly dark chert wi th occasional abundant coal particles, some coaly partings. 1l1)u-caleareOuBp trace ironstone 185-190 5il tstons. medium 11gb'!; gray. c,ar"1)oDaceous parUngsiI non-calcareous. trace sandstone Clay shale. medium light gray to medium dark gray. silty near toPb trace coal. pYr1 te and olive gray iron.stons Clay shale. medium gray to medium dark grq. t5-3O% shin,y-dull black coal Clay shale. med"wn gray to medium dark gray, slightly silV and micaceous Sil t8tone and small amoun; of veri fine sandstone. Ught gray to mediUIII light ~-r33, micaceous~ plant impression$ Sandstone. light gray to medium.ligbt gray» very fine gra.ined in u:p-oeI' 1)&rt of interval and medium grained in the 10".1'. ?f:!þ white and clear quartz,) 'balance is dark charta coal -oarticles. serlcl te in matrix, slightly calcareous Clay shale. medium light 5r~ to medium gra;¡~ tr3.ce of slltston.e" fine17 micaceous Clay shale. medium dark gray to medium gray. trace Wr1 te. coal and 'browni ah gray ironstone ~ .F.aCOTer¡r 3OO-303Q p o· Clq shale. medium gray to medium dark gr~. medium haz'd, good clea.vage. one it inch thick hard. slii~tly brownish gr~ cl~ ironstone concretion at the vsry bottom of the interTal~ shale con'ta.ins occaaional 1>1'1'1 te nodule8¡ non- calcareoua; dip undeterminable. A fev microfossil species abun~t~ Zone D-E Coal 50%. shin,y black and c1a,y shale~ dark gray to grayish black Clay shale. medium Gray to dark. gra;¡o 5% coal 305-3103 Cls,y shale. medi~ grey and ~ very fine argilla.ceous slightly calcareous sandstone, 'bitumen in aandstone Clà.y shale. medium gray to medium dark gray" 10% medium light gra:¡u vary fine grained sandstone 355~360ft Jß#>.~ ïfrrt~ __ Florenca Robinson» Geologist Janu.a,ry 29~ 1952 2 .-- '. KN:tFFiBLADE TEST w'EU.. lifO, 2 The &ma¡l faunal' domine.'tsd by 'iJerí1êu11inoid.eß F and Miliammina Ac 18 onø tUat might range from zones :B thro~h Ee bU'f the-;:s¡;smblaga a.~å. -\h~ a,/.)t¡Ad.aJlce of certain species is characteristic of marg1.ual mariu.e ;¡:¡OAe l2i sediments logged in several of the test wellÐ of NPR4~ The similar1 t.Y of this fau.na. tot.hat of wslla li øted below 1nd1catefJ the sedimente of the :lùJ.i:føòlade struct1.1re must bil )"oWJ&er than prevlouslT believed. A comparison of the fauna. wi th that of Umiat 1'eat Well Boo 1 in41cate. a similar! V with the uppfEjrmoet part of Zone :a;~ a.bout; 400 feet below Zone F 0 whereEl.B there i;;l no ø1m13..arity- of tau.>1$.. wi tb tbs:t portion of Umiat fest Well No" 1 assigned 'kI beds older 'tr48.n Zone D" .t.wll_ to well compar1 son w1 th the EAifeblade fauna :1 s as follows; First abunclant occurrence of !!~~l1:1J,;lJ!Q~~~ F -Mili~ina A fauna Umiat !rest Well NoÞ 1 132&.,1335°001'e Oumalik !rest Well No.. 1 97° II kst Ownalik Test Well No" 1 720° dU.ch T1 taluk: !est Well No.. 1 1860~ It Wolf Creek Test Well Ho~ 1 1435ij i' Wolt Creek 2861; Wêll No <> 2 1550 0 (1 Iúiiteblade ~es1; Well No" to lOOP, core ~he 8Øe fauna. was found in abwl.dailce in 001'8$ at 7æ...733 teet 1n Oumalik Test Well No.. It at 750...755 fSGt and 1550---1560 fe.st in East Oumalik Test Well No. 10 and at 2378-2393 teet" 2670...Z516 :faat~ 3102...3137 f8et~ and 3289=3007 teet in 1'1 taluk !lest Well No" 1. In l.4ea.de Te~t Well Uo.. 1 the fau.r..a. begins around 1380 feet1l but was not fo'lJJld in any abundanceo In lCn1:teblade Test Well No.. 2 'the f1rBt occurrence of the fauna. is at 125 feet and gra.duaJ.1y increases 1n abundance of specimens to the f1r~t cored intervaJ. (300-3039) ~ in Wolf Creek: '1'e8t Well No" I the first appearance 1~ at 1080 teet~ in' Wolf Creek Test Well lio" 2 1 t 18 at 1300 1'8è1;0 This wgges'~s thê~t there 18 a section of 200 to 300 teet in which the fauna 18 sparlle above the inte1"'l1al ot a.bundance" Earlan R, Bergq'U.i s t :~~.~~.; "...._~::, . . "Old" .. ...a'\.")' \';ells (1944-~3) Well Name Avak -, 100-09-+ South Barrow-l /(JO -083 South Barrow-2 l()ö-ÕóJ"! South -Barrow-3 leD -;o~ i South Barrow-4 lOOt Oól" I Fl:sh Creek-l I DO -/ti:> i GJiandstand-l I DC> -46""3 . I Gubik-l lOb -;):;) I ¡ I Gubik-2 I DO -;)::J:;) . Kaolak-l 100 -t)~ Knifeblade-l ldO - 1à.1 Knifeblade-2 J bD - 1;;.(;) Knifeblade-2A Î:S r\OW J.(",,¡Pe.Jøl4òe 6- z.teaåe-l OU1'nalik-l IOO-f/</ Eas-t OU1'nalik-l ¡DD -1/6- Simpson-l I{)Ò-If¿,3, Nðrf, S/n,p::ðq-I }()O....OI'fj' Squ-are Lake-1 J 00 -Ill.- Tita.luk-l 100-11:)0 Topag6ruk-l Joe -Iq~ ; i Ea!#t Topagoruk-l lo:J -tCI6- Umiat-l IDC -Qöl1 ~ 1 .: Umiat-2 loO-QID Umiat-3 (OO-d( I Umiat-4 100 '91;). . Umiat-S /00 -9/3 -- J Umiat-6 IOD -a¡q¡ umiat-7 I()Ó _~I\J¡ I Umiat-8 IDP -:Ji~ ì umiat-9 tóö -Q/9 .1 Umiat-lO I{)()...é)i1f Umiat-ll 100 ..é)/,? \ Wolf Creek-l I (:j.)- t I ~ ¡- Wolf Creek-2 Juo-ht?5 ¡ Wolf Creek-3 I d) -I IC) ..._.._ __..n_.' ..._.' _._.._,._. .__.__._ ......~ ....---... .,. -_.__..-._"-'~- , . : I . t I . "Intermediate" Wells at Barrow.Cl9SS-l974) r .-.' j' , , .. South Barrow-S IbÒ -bd.15 South Barrow-6 '(Jl)-~'1 .~ South Barrow-7 16b'-O'3D South Barrow-9 106!-o3l South Barrow-9 IOD"'ä3;;). South Barrow-lO id:>-0'33 South Barrow-ll leÞ -63J.( . South Barrow-12 lðO"ò~ t » . . .. .._...__..___...___.... ___·n. .---,-..--........-- . 'i6