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From:Schoessler, Allie M To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC) Subject:Re: [EXTERNAL] RE: BLM LW Knifeblade Project 2024-2025 Date:Thursday, September 5, 2024 9:28:14 AM 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 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 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 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 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' 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. 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> 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. 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. Hope this helps. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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 2 O 0 0 9 n N w n 0 o 3 3 4 F m n e c E o �. (') 0 n H n m� �• �° 6 � nf0 T 5r : 30 cgF o=G N 0 O� m W n� o• `� n OW c m A ff m o° 3 r o » c O n G C_ 6 O G m c 3, n G. N c E mo y' om m RM, °' ^ 3 m N jE n o m 0 A v G� i> n n D �"• ^ D 3 myv s>5 a m m F ^ F Q o p a $ n o n$ � S w e N C:) M Ill 77 ci M O-7 -1 o �O lV m c S G e (D 111 n� G art W N � 6 O � G p Er — N O 5 o rs m E ^ N � S ❑ © ❑ EL■■■■ 0 lb m o O O. 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O �+ A m C C C \ O N O\ b ° N m 6 O w =? m r N S S !^ .C. O> u �'f C y C G7 m '� N < O< M N ID < y D O : °- PWz c Oi Ot A (0 x 3°° — 3 N W O a c c n O w n $£ a eNi fD CF 0'/ 9 T > 7 fD, H :' '�'►, m m m C N n a n In T .Q Ol OJ 0 pN O C 7 a w o o m m x c a9—i m ma o m m 3 3 d ,mod. .� m O a fD l+ y �. � ► � 9 �_ b N p O = fy � ^ m m n c K g � o a z v 3 � d v T G � O N P — � Y Y From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Knifeblade 2A (PTD 100-123) wellfile Date:Tuesday, September 3, 2024 8:26:03 AM Attachments:Knifeblade #2A Sundry Packet.pdf Please include the attached in the wellfile. Note that this has a similar name to the last one I sent, but it is a different well. Thanks 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 16:58:43 -08'00' Bureau of Land Management CONDITIONS OF APPROVAL FOR SUNDRY NOTICE – NOTICE OF INTENT Olgoonik Oilfield Services (OOS) Plug and Abandon Knifeblade #2A USWN: 50-119-10014 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. 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 ________________________ ie Schoessler Olgoonik Oilfield Services | Plug and Abandonment Program Knifeblade #2A (PTD #: 100-123) 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 #2A 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 #2A ....................................................................................................................................... 5 Table of Figures Figure 1: Typical Surface Rig Up Layout ................................................................................................................ 4 Figure 2: Knifeblade #2A Current Completion Schematic ..................................................................................... 8 Figure 3: Knifeblade #2A Proposed Plugging Schematic ....................................................................................... 9 Version # Implemented By Revision Date Approved By Approval Date Reason 1.0 Zach Sayers, P.E. 8/19/24 2.0 Zach Sayers, P.E. 8/27/24 Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2A 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 #2A 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 #2A Well Olgoonik Oilfield Services | P&A Procedures 5 3 P&A Procedures 3.1 Knifeblade #2A Knifeblade #2A 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 16’7” using a plumb bob. 3.1.1 Well Assumptions: x Thermistors cables are not present. 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 #2A 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 The historical records indicate that no shows were present in either the Chandler or the Grandstand formation that were drilled. At a thawing depth of 150’ an ice plug from 150’ to an estimated 758’ exists. This well was bailed dry to 750’ with no flow (removed 750’ of hydrostatic head with no flow). There is a saltwater zone at 758’ in KB #2A that is believed to be the base of the Permafrost. Based on a review of the geologic studies, and attempted flow testing, no hydrocarbon bearing zones capable of flowing with an evacuated column exists. Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2A 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 5' 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 a. Plate to include required identifier markings. BLM representative to witness 19. 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 20. 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 #2A Well Olgoonik Oilfield Services | P&A Procedures 8 Figure 2: Knifeblade #2A Current Completion Schematic Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #2A Well Olgoonik Oilfield Services | P&A Procedures 9 Figure 3: Knifeblade #2A 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 \ / e STATE - .41,-j -7-3,1:t. ofALT A c K . tg- - Division of Spill Prevention and Response Contaminated Sites Program GOVERNOR SEAN PARNELL ® .` D 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 , 2 U J V m m N a) N N ca O. 73N - 13 N VN m CO m m CO m CO CO a m m m m m CO m m m =° c 73m 0 m m m m m m m is .N o) m m CO m m CO m TO. m C m °c O w 'O 'O U 'O "O 'O N -0 'O -0 'O "0 'O 0 0 "O a) " 0 0 0 0 0 0 0 o a) ` 0 0 0 0 0 0 0 0 0 > @ o Q C C C C C C C C .0 C C C C C C C C C t- U Z 0 o N C) a) a) T_L a) U) a) C) a) a) a) C) O O L oL L L t -0 3 m L O O O O O O O — .0 C2 .0 L -C L L .0 L m C C C C C C C C C C C C C C .0 C C) o m N C) a) N Q) O .N J a) @ N O N a) a) a) Q) _V N t a O N Cl) Cl) Cl) a C CO N Cl) N N Cl) N Cl) N N N - p N y o L o o 0 a a 0 E o 0 I > > 9 o o > 5 5 5 '5 S E -z U N :D C C C N -50 C m = C C C CO 0 '0 O 00 - - - - m J O E. m - - - =CO = _ = = C) > 0 < co C C a o` `o 0 3 co Q, a 0) o` a v c `o `o `o o a o a d c N m O II O C C C 0 0 C - O- Z 1' O -O m .O CD 7 CCI .D CO N 'O f9 'O .0 N lD .D N co lD .O N -O (D -O m il Z a• a - a - a a.— a_ 0 a) a•- a•- a - a a - a-- a -C..9 Q = > h a,— C Y C C C C C C 3 y C C , C ._ C C Y C Y C Y C Y Q- I' O (1) (7 = 0 = 0 - 0 = O = O = O - 4) = O = O = O = O (n = O = O = O = O N C 0 • IQ Q-0 3 0 3 -`0 3 -`0 3 -0 -`0 U E) w `0 -`0 v` 3 v Q-0 -`0 Q C CO r 0 m ry_ d .6 u 06 06 U 06 '6 .) 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Abreak-down of the 136 is as follows: • 39 are uncased core holes that did not penetrate oil and gas zone, have naturally collapsed, and have blended harmlessly into the landscape. • 33 were either transferred to the North Slope Borough through the Barrow Gas Field Act of 1984 or were conveyed to Arctic Slope Regional Corporation. • 20 wells are being used to by the United States Geological Survey (USGS) for climatic temperature and perniafrost 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 Nuigsut. 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 S~ ,\~ ~v' 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 Umiat Air Force Station. In Tune of aircraft. 1955 the Air Force returned the facility to the U.S. Navy. Since Umiat is a FornZerly 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. Arniy 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 Umiat area. Umiat #9 is located about half mile to the north-northwest of the Seabee pad. The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect future development. Surficial wastes around Umiat #9 could present an issue. As was common with early Navy drilling, a gravel pad was not created. Wooden debris exists around the wellhead and there is a pile of drilling muds directly to the north which is void of vegetation (Figure 12). Samples taken by the COE from around the wellhead detected elevated levels of diesel range organics (DRO), residual range organics (RRO) and PCBs (U.S. Army COE, 2003). 24 The wellhead is equipped with two bull plugs, a flange and a 2 3/-inch nipple. There are no fresh water aquifers in the area, but due to potential contaminants downhole and existing contaminants on the surface, the well does pose a risk to human health and the enviromnent in its cun•ent condition. Umiat #6 Umiat #6 was spudded August 1950 to test the southern limits of the Uiniat 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 ban•els 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 '/g-inch casing to the surface. It has no gauges, valves or a cover plate. Two thermistor protrude to the surface and rests on the lip of the casing. This well poses no threat to human health or the environment unless development occurs. Umiat #7 Umiat #7 was drilled in = ~ -~ -~ - 1951 to a depth of 1,384 feet, cased to 1,196 feet f and completed as a dry ~' , hole. It was the southern ~ most well drilled on the Umiat anticline. The ~ objective was to further delineate the southern extent of the producing Figure 13: Umiat #7 summer and winter photos. field. The well encountered residual hydrocarbons in the Chandler and Grandstand formations. Oil recovered in bailing tests was so minute that it was measured in gallons. The small amount of crude recovered in each test is indicative of residual oil staining. The sands encountered in Grandstand are downdip of the productive reservoir and are water bearing. Minor gas shows were encountered at 260 feet (Robinson and Bergquist, 1956). The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the 25 next 20 years but since the well is located below the oil/water contact it has less potential to be adversely affected or affect future development. The wellhead assembly consists of 7-inch casing (with collar) clamped inside 11 '/-inch casing at a total height of 30 inches (Figure 13). Surrounding the open hole is wet tundra with no indication of remaining debris or other surficial issues. The hole poses no threat to humans or the environment. The well location is currently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional 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 `~ ,:, I 4 g: ~~. x~~a~ ~ , r* ~ ~~~ . Figure 14: Photo of J.W. Dalton taken October 26, 2004. Soil cracking is occurring around the wellhead and the north and east side of the cellar is exposed. 26 Figure 15: J.W. Dalton wellhead with pilings. Photo was taken August 2000. to the edge of the Arctic Ocean. As a result, casing is now exposed to a depth of 15 feet on the present day beach (Figure 16). The top of the diesel is approximately 60 feet below the present beach level. The reserve pit has been breached on the northwest coiner from the advancing shoreline (Figure 17). The pit is known to contain clu-omium, 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 h•act currently closed to leasing. -~. ~ . ~ ~~ . _~ _~"`~"~ This well is in danger of Y °{ - becoming engulfed by the ocean. R,~ t ~ The diesel fuel in the well and ;~~w =-- ~_ Y' ~~ ~.., r a _ ~ reserve pit contaminants raises -~~ ~ ~'~ concerns. The concerns can be hT Yew ~µ > `~ ,~'~~"~ , ° ° ,; .' ~, ,-~ ~ eliminated by pumping out the ~1 ~ ~ -- diesel, or displacing the diesel _ ..rr --.~.a~ ~' . with water and adding a bridge .~~-=u _„~• ,.. ~ ~~ ~'` ~ ~ ~ ~ - plug and cement to close off the hole. The casing would be cut off xr'~....~..,K , .a • below surface. The diesel would - - ~ ~ ~ . ° - _ be disposed of at the nearest Figure 17: Aerial view of the breached reserve pit. facility. If necessary, the reserve pit could be excavated down to remove contaminated soils, which would be placed into Super-Sacks and hauled out by Cat-Train for grinding and injection into a Class II well or other approved disposal site. In its current condition, the well does not pose a threat to humans or the environment, but if the casing were to break in its exposed condition, the diesel fuel would, over time, leak into the ocean. The release of heavy metals from the reserve pit may pose an immediate risk to human health and the environment. The pit was sampled October 26, 2004, and results are pending. 27 Figure 16: J.W. Dalton with exposed conductor (left), and rat hole (right). The mouse hole (not pictured) is completely exposed. 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 banels 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 def-nes the area of active seepage. The orange color is oil-eating casing, a 2-inch line pipe, and four bacteria. wing valves and will likely flow oil if 28 the valves are opened. Access to the wellhead is limited by the depth of oily-water 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 oil. The scraped-up earth was oil seep. Depth of the oily-water prohibits access to the then used to build berms around wellhead. the depression. Light amounts of trash appear to have been buried in these berms. The Navy cleaned up the site in the late 70s, removing most of the drums and other debris, but solid wastes, including half barrels and other drums can be found in the wet tar that fills the depression. Simpson Core Test #31 Simpson Core Test #31 is a shallow core test drilled in 1951 to a depth of 355 feet and o 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- rigure 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 psi. The well also penetrated the Gubik and Seabee Forniations, which were unproductive (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. A drilling pad does not exist as the well was drilled in an active oil seep, which remains active today (Figure 21). The Simpson Peninsula contains few permanent settlements, but a multitude of summer camps. The well had been a source of fuel for the inhabitants as evidenced by a 10-foot extension pipe hooked up to the wing valve. The extension allowed for the oil to flow down the pipe and collect in a bucket. In 2000, BLM learned that oil was seeping out of a corroded swedge on the wellhead. The potential haini 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 cun•ent state, oil could flow to surface if the well is damaged, corroded, or the valves are opened. Additionally, concerns have been raised regarding the bubbling around the base of the casing. When the valve is opened, the bubbling subsides. This indicates a small leak around the base of the casing or through a hole in the casing. The gas was sampled by the USGS and has been identified as reservoir-produced biogenic gas. While the well does pose a risk, it is mitigated by the fact that the well is drilled in an active, natural oil seep. 30 Simpson Core Test #30 Simpson Core Tests #30 and #30A were drilled about 100 feet apart in the same oil seep. The seep is part of the same regime that contains Cores #26 and #27. These wells were drilled to gain an understanding of the producing field limits and to help determine underlying structure. Simpson Core #30 is an oil well drilled in 1951 to a depth of 1,500 feet. No plugs were set and the well was cased to 102 ft. The hole encountered the same formations as Cores #26 and #27; Gubik, Seabee, undifferentiated Ninuluk/Seabee, and the Grandstand with a few poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. Poor oil shows were also noted in the deeper Grandstand Formation. During production tests of the shallow oil sand the well was bailed at rates averaging 5 barrels of oil per day (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The well was left with sheared, open casing above ground. Even though the well produced oil 50 years ago, it is static today. This suggests the hole has collapsed below the shallow casing. There are no fresh water aquifers in the well, however, since the well was drilled to a reservoir with sufficient energy to flow oil to surface, the well should probably be considered a risk if left unplugged. This well would probably be plugged by placing a 100 foot surface plug downhole to eliminate risks to surface resources. The potential risk is alleviated by the fact that the well is drilled in an active, natural oil seep. There is no drill pad as the Navy drilled within the seep and camped on the tundra. Some light trash is present in the seep between the Core #30 and Core #30A, which may prove difficult to clean (Figure 22). The well lies three tenths of a mile from both Core #26 and #27 (Figure 18). Simpson Core Test #27 Simpson Core Test #27 is an oil well that was spudded February 1951 and completed one month later. Total depth of the well is 1,500 feet, with casing down to 102 feet. Oil was encountered at a depth of 380 feet and was bailed at a rate of 3 barrels per day. The core test encountered the same formations as Simpson Core Test #26, with a few very poor gas shows and one productive oil bearing sand in the Ninuluk/Seabee undifferentiated formation. Oil-based muds were used from the drilling depth of 325 to 661 feet. At that point the oil was displaced and the drilling crew resumed using water based muds. 31 Figure 22: Light trash is present in the seep between Cores #30 and #30A. Additional crude was added downhole at a depth of 1,320 feet. The drill pipe was stuck and the two front derrick legs collapsed below the four-foot extension in an effort to free the pipe. The drilling muds in place were re-circulated during the repair process. In an attempt to free the pipe, 73 barrels of crude and 23 barrels of diesel were used to replace the muds and the pipe was worked free. The oil was gradually replaced by mud as the drilling continued, however, some oil remained in the hole after completion. The crude used downhole came from Simpson Core Test #26 (Robinson and Brewer, 1964). There are no fresh water aquifers in the well so there are no risks to sub-surface resources but there are risks to surface resources if the well is left unplugged. Oil could flow to surface if the well equipment corrodes, the well is damaged, or left open. This potential risk is mitigated by the fact that the well is drilled in an inactive, natural oil seep. The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and. received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. There is no existing pad. The wellhead consists of 8 5/$-inch casing, a flange and a brass gate valve. The casing was set in a small inactive oil seep. It will flow oil to surface if opened. There is no surface debris present at Core #27 (Figure 23). The well poses little threat to human health and the immediate environment around it in its current condition. Simpson Core Test #29 Simpson Core Test #29 is a dry hole drilled in 1950 to a depth of 700 feet and cased to 152 feet. The purpose of the well was to determine the limits of the producing field encountered at Core #26. A very poor oil show was identified in the Seabee Formation. The productive sand present in the other Simpson Cores does not exist in this well. The test hole also penetrated the Gubik and Grandstand Formations. No oil was recovered from this well (Robinson and Brewer, 1964). The well is grouped higher on the priority list due to its close approximation to Simpson Cores #26, #27, #30 and #30A (Figure 18). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development if left unplugged since any development will likely target deeper, more productive formations. The well was left with 8 '/z-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables protrude from the casing. It is located in a four-by-four foot wooden 32 Figure 23: There is no surface debris present at Simpson Core #27. cellar filled with water. A drilling pad was never established. There is some light trash around the wellhead including drill pipe, and various sized wooden scraps. A small barrel pump and other small debris can be seen in the casing and within the cellar (Figure 24). Thrs well poses no threat to the human population or the environment. Umiat #1 ,~~> ~. : ,~: <. ,~ . ~ ~~ ~, -. .;ti; `~ a'> 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 (Figw•e 25). The well is located on an unleased tract at the crest of a hill that divides the north and south forks of Seabee Creek. Future development is unlikely because of its location outside the Umiat structure. Left unplugged, the well poses no threat to the environment and has no potential to adversely affect future development. 33 indication of stressed vegetation down-gradient from the drill muds. Additionally, solid waste in the foam of steel framing and scrap metal are near the wellhead. The solid wastes pose no threat but are unsightly. Umiat #11 Utniat #11 was spud June 1952 and completed two months later. The well reached a total depth of 3,303 feet with 486 feet cased. One cement plug was placed at 440 feet. The objective was to test production possibilities of the Grandstand Formation on a fault that parallels the Umiat anticline. The well encountered residual hydrocarbons in the Seabee, Ninuluk, and Grandstand Formations but no oil or gas was recovered during production tests. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are over one mile to the south. The well is located within the Northeast planning boundary (see Map 2). The tract is located on lease AA-084141 but there is little possibility of the well interfering with future development due to its location outside the Umiat structure. The well was drilled in the alluvial plain of Bearpaw Creek, 0.6 miles from Umiat #8. A drilling pad was never created as operations consisted of mounting the drill rig on a sled and then placing it on top of large timbers that were secured to pilings (Robinson and Bergquist, 1956). A pile of unvegetated drilling muds is present 30 feet west of the wellhead in between the wellhead and the creek. The wellhead consists of a 10 3/-inch open-ended casing with a collar sticking up inside a 30-inch conductor that is filled with water. Minor wood debris can be found around the wellhead. The well poses no risk if left unplugged. Wolf Creek Area Three test wells were drilled in the Wolf Creek area. The wells were drilled in the early 1950s with the intent of testing the northwest-trending Wolf Creek anticline structure. Wolf Creek # 1 and #3 (Figure 26) are located at the crest of a hill with about 250 feet of relief from the valley. Wolf Creek #2 is located about one and one- third miles north within the Wolf Creek valley. Wolf Creek #2 and #3 are open holes but Wolf Creek #1 is equipped with a wellhead. ;;~ _ ! ~ ,. Wolf Creek #1 Wolf Creek #1 is a gas well drilled in 1951 to 1,500 feet and cased to 48 feet. The well encountered very poor gas shows in the Killik Tongue and productive sands in the Grandstand Formation. The well produced at rates up to 881 MCFPD in open hole tests 34 Figure 26: Wolf Creek #1 after adding a new ball valve to the wellhead. August 2004. of the Grandstand. The well is equipped with a blind plate, a 2-inch nipple and a brass gate valve (Figure 26). There is a small gas leak in the threaded wellhead flange and, if the valve is opened, the well will flow about 10 MCFPD but the presstu-e is so low it does not register on a gauge. In its cun•ent condition, the well does not appear to pose a risk to surface or sub- surface resources. The drill pad is shared with Wolf Creek #3. Tlu•oughout the pad, there are some wooden pilings, metal anchors and scrap metal. The scraps should not be considered hazardous in this remote region. The leaking gas is of minor concern, however given the weak gas pressure and remote location; the overall risk is very minimal. Wolf Creek #2 Wolf Creek #2 is a dry hole. The well was drilled in 1951 to 1,618 feet and cased to 53 feet. It is located roughly 1 '/ miles north of the other Wolf Creek test wells. The purpose of drilling was to determine if the gas-bearing sandstone beds previously encountered in Wolf Creek #1 would contain any oil. The records indicate a very poor gas show was encountered in the Killik Tongue but no oil or gas was recovered in production tests (Collins and Bergquist, 1959). The hole also penetrated the Seabee, Ninuluk, Chandler, and Grandstand Formations. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The wellhead consists of a plate welded onto the 11 3/-inch casing cut off at ground level (Figure 27). There is no existing drill pad. Solid wastes consist of a few empty 55-gallon drums upstream along the upper floodplain of the creek. The well poses no tlueat 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 primacy purpose was to test the Grandstand Formation (the producing formation around Urniat, 35 miles to the west). The Grandstand Formation produced from four different sands. In 35 r figure 27: Wolf Creek #2 had casing cut off at ground level. open hole flow tests of the well produced at rates up to 445 MCFPD. The gas appeared to be sufficient to supply a small camp, but not of corrunercial proportions (Collins and Bergquist, 1959). Two plugs were set in the well above the Grandstand Formation. The top of the shallowest plug is inside the casing at 554 feet. In addition to the Grandstand, the hole penetrated the Ninuluk, Chandler, and Topagoruk Formations. Upon abandonment, the hole was filled with oil-based. drilling muds and left open to the enviromnent. A total of 103 barrels of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the Tune 2004 lease sale for the tract and near-term development is unlikely. The well poses no threat to surface or sub-surface resources and has no potential to adversely affect future development. The drill pad is shared with Wolf Creek #1. There is some minor debris at the site as noted in the Wolf Creek #1 description. The wellhead was cut off six inches from the ground surface. This allows seasonal precipitation to accrue in the hole and spill over the sides, but the well poses no threat to surface or sub-surface resources and has no potential to adversely affect future development. Fish Creek #1 Fish Creek #1 was drilled by the Navy in 1949 near an oil seep. Total depth of the well was 7,020 feet. The well was plugged back to approximately 2,550 feet, drilled to a new total depth of 3,018 feet and cased to 3,017 feet. The well was drilled to test a large gravity anomaly that suggested the possible presence of petroleum-bearing rocks and some structural anomaly that might be a trap for oil. Very poor oil shows were identified in the Topagoiuk Formation at depths from 5,550 - 6,000 feet and a productive sand was reported at 3,000 feet. The well is not a flowing well but was pump-tested at rates averaging 12 ban•els of oil per day through agravel-packed completion. It also produced a small amount of methane gas. The hole encountered the Gubik, Shrader Bluff, Tuluvak, and Seabee Formations. 36 producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infi-astiucture 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 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 fomations. 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. n,: _„< ~.~- u~z~ yf~ ~ : ~. 9~ti} =~' ;pct;` ~. •:, t 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 iun but the well was left with casing above ground open to the atmosphere. Its present day location lies within 1000 feet to the west of an active oil seep. The well was not drilled deep enough to encounter the hydrocarbon stained sands evident in the Simpson Core #14A well. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years. This shallow well did not penetrate any hydrocarbon bearing zones and poses no risk to surface or sub- surface resources, nor does it have the potential to adversely impact future development. 38 Simpson Core Test #14A Simpson Core #14A was drilled in 1949 to a depth of 1,270 feet and casing was set to a depth of 32 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand 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 $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. 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 d1y 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 infi•astructure 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 #i with cabin on the drill pad. shows in the Topagoruk Formation. Gas shows were attributed to association with the coal beds (Collins and Bergquist, 1958). Upon abandonment, no plugs were set and the hole was filled with heavy muds. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. Exploration and development in the area is a possibility within 40 "? Figure 31: East Simpson #2 is partially submerged during the spring thaw. Photo taken June 2003. the next 20 years, but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. There are no major surface issues. The working area is still visible due to a multitude of wooden pilings around the wellhead and a cabin on the north end of the pad (Figure 32). Off the pad, the area is clean. The wellhead is missing its upper components. All that remains is the top flange above the base plate and the casing spool, leaving 11 3/-inch casing open to the enviromnent. The well is left with a casing head and is open to atmosphere. The wellsite is 45 miles southwest Wainwright, which is the nearest community. There are no hazardous materials or anything that would pose a risk to the general health and safety of the land. The cabin may be a concern, but dealing with the situation is outside the scope of this report. Meade #1 Meade #1 is a gas well drilled to a depth of x,305 feet in 1950. The well was cased to 2,785 feet and two cement plugs were set, with the top of the shallowest plug tagged at 2,783 feet inside the casing. The well encountered some gas shows in one productive sand within the Grandstand Formation. The gas tested at rates up to 1.1 MMCFPD during openhole flow tests of the sand at 2,949 - 2,969 feet. The well is estimated to have gas reserves of 10 BCF. Gas pockets are relatively common in this portion of NPR-A due in large part to the underlying coal. At one point while conducting tests, some problems were encountered while attempting to pull a testing tool out of the hole; aball-peen hammer was inadvertently dropped downhole, causing the tubing to stick. The tubing could not be freed and as a result, it twisted off leaving tubing in the hole. When the lost tubing could not be pulled out, heavy muds were pumped downhole and the well was abandoned (Collins and Bergquist, 1958). The well is located within the Northwest planning area (see Map 2). The well is adjacent to a recently leased tract that received a high bid of $10.26 per acre during the 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years and has the potential to target the Grandstand Formation. If left unplugged the well has no potential to adversely affect future development. There is no pad present at Meade #1. Several pilings and light trash are present, but overall is pretty clean. The wellhead is at ground level and consists of an open flange ,~~~"`~ ~ bolted to the top of the casing (Figure 33). This `~ ~" ~ f~ ~ ? ~ differs from the Navy reports that indicate the ~~< ~`-' ~ l'~k. ~ `. }~ wellhead was abandoned in place. There is no "' ~ record as to why it was removed. A BLM field ~~ " ~ 1~~~, `"''" ~~~ crew bailed the hole and discovered a swedge ~~. and 2-inch needle valve junked downhole. This ,; ~" ° .=~." ~, ''~, ~ `~ site is very remote (30 miles south of Atqasuk) ,, and since the gas zones are currently isolated ~' ~ ~~, ; below the cement plugs there is a limited risk of ~*~~ _ ~Q' ~,:~ _ _ adverse impacts to surface or sub-surface resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 Titaluk #1 was drilled in 1951 to a depth of 4,020 feet and is a diy hole. The well was drilled on the end of an anticline to test the oil and gas potential of formations within the Nanushuk Group. A few very poor oil and gas shows were encountered in the Grandstand and Topagoruk Formations, but no oil or gas was recovered during multiple production tests. The Ninuluk and Chandler Formations were also encountered, but with no shows. One cement plug was set at 3,471 feet. The placement of this plug is curious since the shows (albeit poor) were reportedly discovered above this level. (Robinson and Bergquist, 1959). The well remains in a static condition. Titaluk #1 is located within the Northwest planning area (see Map 2) on an unleased tract. No offers were received in the June 20041ease sale. Near-term development is unlikely. Surficially, there are no to human safety or the environment. Skull Cliff Core Test #1 Skull Cliff Core Test #1 was drilled- in 1947 to a depth of 779 feet and is a dry hole. No shows of oil or gas were reported while drilling through the Gubik, Grandstand, and Topagoruk Formations. While drilling to the target depth of 1,500 feet, the drillstring was lost in the hole and fishing attempts were unsuccessful in recovering the lost drillstring. The drilling mud was bailed down to the top of the fish and the remainder of the well was filled with diesel to 54 feet to prevent the wellbore from freezing and facilitate downhole temperature measurements. It is plausible that the casing could corrode and the diesel fuel could seep into the sub-surface strata, but since there are no fresh water zones in the well it is not considered a risk that would adversely impact sub-surface resources (Collins and Brewer, 1961). The well is located within the Northeast planning area (see Map 2). The well lies adjacent to a recently leased tract that received a high bid of $10.77 per acre during the 20041ease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 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 d1d not encounter oil and gas Figure 35: Solid waste primarily in the form of empty formations and has no pressure at drums litter the area around Skull Cliff Core Test. The the surface, it is not considered a wellhead is in the upper left portion of the photo. risk to surface resources. The only potential risk is that this site lies near a popular winter route between Barrow and Wainwright and it is possible for a snowmachine to impact the solid waste. Barrow is approximately 30 miles to the northeast and Wainwright is about 60 miles to the west. Oumalik #1 Oumalik #1 was drilled in 1950 and is a dry hole. The well was drilled to a total depth of 11,872 feet and cased to 2,762 feet. It is the deepest well drilled by the early U.S. Navy program. The well location was positioned on the apex of the 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 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 hibutary of the Oumalik River. Topographic relief is approximately 100 feet. The drill site is highly remote as the nearest village (Atgasuk) is 65 miles away. The well was drilled in 1951 and reached a total depth of 6,035 feet and is cased to 1,100 feet. It is a dry hole. Very poor oil and gas shows were reported in the Grandstand Formation and very poor gas shows were reported in Topagoruk Formation. The well is located within the Northwest planning area (see Map 2) on an unleased tract that received no bids during the lease sale of 2004. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. The well was left with open casing below ground level and has thermistor cables protruding from inside the casing. The casing is marked by a 7-foot, 3/-inch pipe. The open pipe lies within awater-filled cellar. The standing water has produced numerous algae and other aquatic vegetation obscuring the wellbore. Surficial hazards ,consist of several 10-foot timbers and a few 4-foot pipes (probably rig anchors) sticking up out of the ground. The site is mostly overgrown with shrubs and appears to be relatively clean. The airstrip, incoming, and outgoing trail scars are obvious and can be used to navigate to the wellsite. There are no risks associated with the well in its current condition and was given this ranking due to its close proximity to Oumalik #1. Topagoruk #1 Topagoruk #1 was drilled in 1951 to a depth of 7,154 feet and is a dry hole. The intent was to test a small, buried anticline and the various formations associated with it. The well was cased to 6,073 feet, plugged back to 6,175 feet and then drilled to a new total depth of 10,503 feet. Prior to re-drilling to total depth, approximately 250 barrels of crude oil from Cape Simpson were added downhole to help offset lost circulation and caving. Additionally, 20 barrels of diesel were added downhole during the drilling phase. No plugs exist in this well. The well is left with open casing to the surface and thermistor cables protruding from the casing (Figure 36). The well encountered the following stratigraphic units while drilling; Gubik, Grandstand, Topagoruk, and Oumalik Formations, Middle and Upper Jurassic rocks, Shublik Formation (Triassic age), Permian rocks, and Lower-Middle Devonian rocks. Hydrocarbon shows were limited to a few very poor gas shows in the Oumalik Formation. No oil or gas was recovered during 44 multiple production tests (Collins and Bergquist, 1958). The well penetrated no flesh 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. v~,£9" Y3:e-~ -~~{ uTi - M.-~sq! Y ~;. 5r.+ -'f %3rt !i~'~" s, ..,~, ~- F ~, ~:, There is not a visible pad, but rather an area of ;~,~ ~ ~ {,~ -. t. ,~ " ~ ,fib fi ., . disturbance. Disturbance stretches i/4 mile in an Figure 36~: Topagoruk #l cacasing on its east-west direction and /8 of a mile 1n 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 (i/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. East Topagoruk #1 Topagoruk's wellhead consists of an open hole cut off at the b •ound surface with several thermistor cables. A thin piece of weathered metal fits around the cut-off casing to resemble a marker. The weathered metal has been smashed at the base and now lies bent in half on its side. Overall this site poses little hazard to the environment or human population. East Topagoruk #1 was drilled on top of a small ridge in the Chipp River delta in 1951. It reached a total depth of 3,589 feet and is cased to 1,100 feet. The purpose of the well was to test an anticline with closure as well as test the fluid content of the permeable Cretaceous sandstone (Collins and Bergquist, 1958). A very poor gas show in the Topagoruk Formation is the only reported hydrocarbons encountered in the well and no oil or gas was recovered during multiple production tests. One cement plug was set in the 45 Figure 37: Drilling muds and a wooden box that resembles a cellar are located about'/ mile east of the wellhead. well at 1,049 feet. The well is located within the Northwest planning area. (see Map 2) on a recently leased tract. The tract receiving a high bid of $84.99 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. A drill pad does not exist. There are a few rig anchors near the wellhead, but no other surficial debris. The current state of the wellhead is open-ended 10 3/-inch casing. Casing height is tlu•ee 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/ -inch Figure 38: Knifeblade #1 is located in a marshy area at collar. The plumb-bob hit solid at I2 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 three Knifeblade wells drilled and reached a total depth of 373 feet, cased to 45 feet, before being junked and abandoned. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). The well did not encounter any hydrocarbon shows. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Surficial issues are negligible. A drill pad does not exist and the wellhead consists of open-ended casing. There are approximately eight empty drums near Knifeblade #2 and #2A. The wells are highly remote and should not be considered a threat to the enviromnent or human activity. Knifeblade #2A Knifeblade #2A, also drilled in 1951,. reached a total depth of 1,805 feet and was cased to 38 feet. The well lies 28 feet to the north of Knifeblade #2A. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). Only very poor oil and gas shows were reported in the Grandstand Formation. The well was left with casing open to the atmosphere and poses no threat to surface or sub-surface resources in its current condition. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Simpson #1 Simpson #1 test well was drilled with a rotary rig in 1948 by the U.S. Navy. The well was drilled to a total depth of 7,002 feet and cased to 5,954 feet. The purpose of the well was to test the various formations of the Lower Cretaceous and Upper Jurassic rocks. The well encountered several very poor oil and gas shows and one productive gas sand in the Lower Jurassic at a depth of 6,183 - 6,193 feet. The well produced gas at rates up to 3.0 MMCFPD during open hole flow tests of this Lower Jurassic sand. The gas zones are currently isolated from other formations and the surface by two cement plugs set above the productive sand. The top of the shallowest plug is at 5,520 feet (Robinson and Yuster, 1959). The well is located within the Northwest planning area (see Map 2) adjacent to recently leased tract that received a high bid of $7.51 per acre during the lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years and this exploration has the potential to target the Lower Jurassic. Since the well is partially plugged, however, it poses little risk to surface or sub-surface resources and will not likely adversely affect any future development. 47 The pad is highly visible and was constructed in the same fashion as Fish Creek #1 in which concrete was used as a working pad. Concrete was poured over a landing mat which was placed on pilings. As a result of ground movement from perniafrost freeze/thaw cycles, the concrete has buckled in numerous places creating apartially- collapsed surface. This feature provides excellent shelter to small animals and rodents. Additionally, there is a small pile of drilling muds near the wellhead. The well was left equipped with a casing flange, spool w/ side bull plug, and another flange and nipple and is shut-in with no pressure at surface. The components past the flange have since been removed. Overall, the current condition of the site is non-threatening to the sparse human population and the surrounding environment. North Simpson #1 North Simpson #1 was drilled in 1950 to a depth of 3,774 feet and cased to 109 feet. No hydrocarbon shows were reported during the drilling of this well as no sandstone was encountered (Robinson and Yuster, 1959). Upon completion, no plugs were set and the hole was filled back with muds. The well is located within the Northwest planning area (see Map 2) adjacent to a recently leased tract that received a high bid of $12.76 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. 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 Ban•ow 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 Foi7nations. 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 silt which resulted in consequently burying the casing head. the burial of the casing head (Figure 40). Above the surface, the wellhead consists of a 4-inch line pipe and a master valve. The master valve is frozen in the open position. The needle valve previously located above the master valve no longer exists. Beneath the casing head the well is plugged to surface and has no potential to adversely effect surface or sub-surface resources. The wellhead stands about eight feet high. Aplumb-bob was dropped and hit solid at 8 feet and stuck. It was subsequently lost. An old, stripped snowmachine sitting next to the wellhead is the only sizable object that would be considered solid waste. Overall, there is no risk associated with this well. Inigok #1 Inigok #1 was drilled in 1979 to a depth of 20,102 feet and cased to 17,432 feet. The well objective was to test astructural/stratigraphic trap within the Sadlerochit and Lisburne Groups (Husky Oil NPR Operations for U.S. Geological Survey-Inigok, 1983}. Some very poor gas shows were recorded in the Sag River, Nanushuk, and Endicott Group. Poor oil shows were reported for the Kingak Shale and Lisburne Group. The best shows were found in the base of the Torok Formation at 8,852 feet. No oil or gas was recovered during multiple production tests. The wellhead consists of three spools, each with a gate valve, a master valve, and a needle valve. Ten cement plugs were set in the well and it is plugged to surface. The well is located within the Northeast planning area (see Map 2) on a recently leased tract that received a high bid of $20.34 per acre during the lease sale of 2002. Total E&P Incorporated drilled an exploratory well 15 miles north of Inigok #1 and used the gravel 49 pad and airstrip near the t ~ - ~,, r.....,... ,,~... well for staging areas and ~ ~ ,,~~ `,:~,~ ~~ -` r ~ t. ~~, a cam It would be ~ ~~ ~ ~'r ;,~,_. ~ ~, 7 ; ~ ~ ~ ~ ~: p ,~~ * :' r ,.,,, . ~ o-~, f,.., ~ _ ~. v ~ .moo „~ z, ,~ fairly simple to remove ~: '~~ ~ :; ~,.4 ~ '~ • ~- the wellhead but the well ~ ~ -- has no potential to ~~~ ~ '~ ~ ~ ~ < ~ -~°~~`- ` ~, r ~ ~ ~ w adversely affect surface x x~ ~Y~~ -r~ } ~ v cj~ a ~ -^ Y =~~ ~ ~ ~ ; or sub-surface resources. ~-'~ ~~h 1,' x~ ~,i-~ ~ ~~ ~ ~.. ~ '' ~=: '~'` °`- ~~ Additionally, the well ~ -~ ~ ~~~ ~ 1t .; ~_' 1 ~~ poses no threat to .~ `° ~- _ ~ ~ '~ rr> adversely affect future ~ ~ „ fi ~~ ~`-~ -~ ` ''~ ~ ~ ~`~ development. ~~~~ .- R ~~. _ ~' ~.~~ _ -` Inigok #1 is one of the few logistical Centers Figure 41: Aerial view of Inigok #1. The drill pad and reserve pit within NPR-A (Figure are visible in the top of photograph. A road leads from the apron of 41). The airstrip and pad the airstrip to the drilling pad. are maintained with no solid wastes present. The wellhead poses no risk, and with the plugs already in place, could be removed. Additionally, this well has ayear-round airstrip and serves as a logistical base to various NPR-A activities. USGS Monitored Wells The USGS has used wells drilled in the NPR-A for collecting temperature data to better understand both the global temperature pattern and its effects on the permafrost. The wells that are currently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is anon-corrosive agent, and even if the casing should corrode there would be no impact to the surface resources and minimal impact on the sub-surface resources as there are nb known fresh water aquifers in NPR-A. The following wells are monitor wells with surficial issues. It is difficult to establish a rank since the wells are sufficiently plugged. The cleanup priority is difficult to determine as the primary tlu•eat lies with wells having downhole issues. However, political concerns could influence the timing in which the surface issues are dealt. East Teshekpuk #1 East Teshekpuk #1 was spudded in March 1976. The well was drilled to a depth of 10,664 feet. It is an active USGS monitor well that was properly plugged. The top of the shallowest plug is located at 2,400 feet. From that point to the surface, the hole is filled with diesel fuel. With the well properly plugged and diesel fuel being anon-corrosive agent, there is no downhole issue with the well at this time but there are solid wastes buried on site that may wan•ant removal. 50 East Teshekpuk #1 was drilled on a small peninsula on the southeast side of Teshekpuk Lake. The southern shore of the peninsula is protected from the prevailing northerly winds, however the north shore doesn't have the luxury of a barrier and is subject to erosion. Unfortunately, solid wastes from the camp and drilling operation were buried on the northern portion of the pad, possibly in the old reserve pit. The northern shore has been battered by numerous storms which have eroded the shoreline and exposed the solid wastes. The wastes are unsightly and potentially hazardous. While the nearest village of Nuiqsut is 52 miles to the southeast, Teshekpuk Lake is rich in subsistence resources and numerous summer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of 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 extremely friable. It is likely that these uncased core holes have naturally collapsed and harmlessly blended into the environment. There is no surface indication of their location and BLM has been unsuccessful in locating them during several visits to their reported location. They do not pose any potential risks. Barrow Gas Wells The Barrow Gas Field Act of 1984 (P.L. 98-366, 98 Stat. 468, July 17, 1984) allowed the U.S. Navy to transfer several wells to the North Slope Borough. The Navy chilled 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 govenuent and any other interest therein, to the Arctic Slope Regional Corporation (ASRC). The BLM acknowledges the surface and sub-surface lands as conveyed and the Office of the Regional Solicitor has confirmed that the Transfer Act included the wells and well locations, and any liabilities associated with these wells are the responsibility of ASRC. 52 test, are stored in the Alaska Geologic Materials Center. Plugged Wells Square Lake #1 Square Lake #1 is a Navy well that was drilled to a depth of 3,984 feet. Its primary intent was to test the Cretaceous rocks in east-west trending anticline structure (305H pg 424). No significant shows of oil were found. Gas shows were encountered in various sandstone beds between 1,600 and 1,900 feet, but otherwise the hole was dry. Upon completion, four plugs were reported to be set with the upper plug at 728 feet, well above the gas shows. Two other plugs were reported to be set in the gas zone, spanning depths of 1,640 - 1,840 and 1865 - 1934 feet. In addition to the six plugs, water and mud fill the remaining distance to the surface (Collins and Berquist, 1959). Upon successive visits to the site, BLM field crews dropped aplumb-bob down the hole and hit a solid obstruction between 8 and 10 feet. Don Meares, Northern Field Office, visited the site in August 2003 with an underwater camera and determined the solid surface to be cement. The Square Lake area is clean of debris with a few deadmen pilings (anchors) near the wellhead that could pose a ground hazard. The wellhead is open casing cut off at ground level. Umiat #2 and #5 The Umiat #2 and #5 wells were plugged and abandoned in 2002 by the COE (Figure 44). The wells were drilled on a common four-acre pad in 1947 and 1951. The purpose of the wells was to test for producing lithologies and deternline petroleum quantities. Umiat #2 penetrated the Gubik Formation, Nanushuk Group (Chandler and Grandstand Formations), Topagoruk Formation and Oumalik Formation. Problems with the drilling muds were encountered while drilling Umiat #2. Analysts determined that the fresh water drilling fluid caused formation damage and the Umiat #5 well was drilled adjacent to the #2 with acable-tool rig. The well produced 400 barrels per day with the most productive sandstones in the lower Chandler and upper Grandstand. Below a depth of 1075 feet, 107 bai7•els 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. March 2002. from Umiat #5 were removed. Costs were approximately $25 million dollars due in part, to soil remediation. Approximately 30,000 tons of petroleum-contaminated soil was excavated. 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 Umia.t #3, also known as Umiat Core Test #1, was spudded in December 1946 and drilled to test some of the oil bearing zones encountered while drilling Umiat #1. The well was drilled on the northeast corner of Umiat Lake just below the hill from Umiat #4 (Figure 45). Umiat #3 penetrated the Gubik Formation and the Nanushuk Group. The Grandstand Formation within the Nanushuk Group is considered to be the primary source of oil between the depths of 258 and 514 feet. The hole produced 50 barrels per day prior to shutdown. The well was re- tested nine months later with production dropping to 24 barrels per day (Robinson and Bergquist, 1956). The wellhead consists of homemade components with a single water service type valve and is capped with a needle valve. There is no seeping present at this Figure 45: The view from Umiat #4 looking southwest site, however seeps are common in toward Umiat Lake and Umiat. Umiat #3 is located on the area, including an active seep in the near shore of Umiat Lake. Umlat Lake. An extensive piping system is still visible. The pipes probably supplied water during the drilling phase. They connect Umiat #3 to #4 which then follow the hill from Umiat #4 to aside channel of the Colville River. Their function was to either carry water to the drilling sites or assist during the well's production phase. The overall surficial conditions including the wellhead and piping, do not pose a threat to human health nor the environment. BLM plugged the well in May 2004. Umiat #4 After encountering relatively poor oil shows on the first three wells, operations were suspended until 1950. Cable tool drilling rigs were introduced to determine if the fresh water muds had hindered the oil production in the previous wells (Robinson and Bergquist, 1956). Cable tool wells did not require the excavation of a cellar; therefore Umiat wells #4-#7 did not have cellars. Umiat #4 is located on top of the hill to the northeast of Umiat #3 (Figures 45, 46). The well was drilled May 1950 to a maximum depth of 840 feet. The hole bored through the Ninuluk, Chandler and Grandstand Formations. Oil was found in the upper and lower 54 sandstone of the Grandstand Formation. Drilling encountered good oil shows around 300 feet with a total 500 barrels produced (Robinson and Bergquist, 1956). The wellhead consists of 11 3/-inch casing protruding 36 inches above the ground surface. The casing is capped with a steel plate. Upon removal of the cover, the hole was open to the envu•onment. No valves or gauges are present. The well was plugged by the BLM on May 9, 2004. The well poses no risk to humans or the environment. Umiat #8 Like the other wells drilled in the 1950s, Umiat #8 was drilled using cable tools. The well was spudded May 1951 and completed August 1951. It is located on top of a ridge that separates Umiat from the Bear Paw Creek valley. Drilling intention was to determine the quality and quantity of hydrocarbons in the Grandstand formation near the crest of the anticline structure. The hole encountered the Seabee, Ninuluk, Chandler, and Grandstand Forniations. The Grandstand Formation produced approximately 60-100 barrels per day of oil and more than 6 inillion cubic feet per day of gas. The well was shut in with a gas pressure of 275 pounds per square inch. The gas was analyzed by the Bureau of Mines and determined to be 97.3 per cent methane. Brine was mixed (35 lbs of salt per barrel of water) and used in the drilling fluid to prevent freeze up. Brine solution of approximately the same ratio of salt per barrel of water was used to kill the well and set the plug while cementing casing. A total of 21,695 pounds of salt were used in the well (Robinson and Bergquist, 1956). The well was plugged May 2, 2004. Prior to plugging, the well was nicknamed the ``Whistling Well" due to the gas of which was escaping through fittings and valves in the wellhead. The wellhead is easily the most complex of the 11 Umiat test wells. It consists of five valves and multiple gauges. It has several homemade components and reaches a total height of ten feet. After reporting the seeping gas in 1996, two new valves and gauges were installed in 1997. The new gauges have been checked regularly since 1998 and have consistently read 250 psi. Despite replacing the two valves and gauges, gas continued to leak from the wellhead. The largest of the leaks occurred just above the top flange where a 4-inch nipple and collar are welded together. Other leaking occurred at the fittings of some of the gauges. The wellhead is sited on a gravel pad. A series of piping extends from the wellhead to a small stock tank about 100 feet to the south. The tank probably was used as a holding tank for the oil while testing the production potential of the hole. The same style of stock tank is present in various old photographs found in the Umiat area and may be the same 55 Figure 46: Umiat #4 prior to plugging. The wellhead is located in the center of the photograph. tank. Oil from inside the tank was sampled in 2004 with test results positively identifying PCB contamination which is slightly below the level of concern. Umiat #10 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 Sis-inch casing is flared and open at the top. This well was plugged May 6, 2004 (Figure 47). with Aquagel and water (per bai•~•el) were used The surface near Umiat #10 is in good shape. There is no existing pad and no solid wastes. With the recent plugging of the well, it is not a risk to human health and safety or the environment. 56 Figure 47: Plugging operations at Umiat #10. May 2004. APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Ati garu Awuna* Drew Point East Simpson #1 East Teshekpuk West Fish Creek # 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 (ÀPril1952) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY CONSERVATION DIVISION * Sec. ______ , , : : : ~-- --or---·r-----:-----· · , ' , , ' I : _____.1_____1_____,.---- _ · , . : : : · . , -----.1------1·-----1------ · . , , , , , . , : t I T. ______________ R. ____________ INDIVIDUAL WELL RECORD _______________________ Mer. Plm'l.w>(~ J. P. R. 14- Land office _______________-- Date_____ JUDe 5, _~..9,_2______ Ref. No. ____________ State Alaska Serial No. __ Co\,:::ty Less -. Knifeblade Area ee _____________________________ Field ______ Operator __U. S. Navy District West Coast Region Well No. _____!C:niteb~~__~~~~__!!~g__'ª____ *subdivision _________________________________________________ * Location JJ~g.Q!"º'__..t_ª~Q!!lP.J.~_t~_____________________________________________________________________________________ Drilling approved__ Drilling commenced __ Aug. 6 ____, 19____ Well elevation _--ª. I. ___ feet Drilling ceased Oct. 7 52 lBoS _on, 19___ Total depth _____ , 19.1~__ Initial production __None __ feet Completed for production________, 19_____ Abandon~:.J~'~\.I...~ _____09t.!.....1__, 19-2~__ Geologic Fonnations SurJac6 LO'WØ8t t68ted Gravity A. P. I. Initial R. P. Productive Horizons .Depths Name ContB1&C8 ------------------...---- WELL STATUS ----------------------------------- ------------------------ YEAR JA.N. FEB. MAR. APR. MA.Y JUNE JULY AUG. SEPT. OCT. Nov. DEc. 1952 Drg. Irg. Abd. ---------- ----------- --------_..- ----------~ ----------- ----------- ---------- ----------... ----------- ---------- ---------- ----------- -------- ---------------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ---------- -------- --------------- ----------- ----------- ---------- ----------- ----------- ----------- ----------- ----------- ----------- ----------.. ---------- ....--- ---------------- ----------- --------..-- ----------- ----------.. ----------- ----------- ----------- ----------- ----------- ----------- ---------- --- -------------- ---------~- .-----------. ----------- ----------- ----------... ----------~ ----------- ----------- ----------- ----------- --------- -- RF.M AIl:f{~ _~!_"q~~_~~~________________________________________________________________________________________________ _________________1dloa.tJe.d_.a.8J..e.e.1Lfrnm ICnjf'eb 1 .de...I2-__________~___________________________________________________ -----------....------------------- ------------------------------------------------------..--------------------------------------- ------ aëõJ:ógJ~~.ïCSm-Vë¡~!i!~!!~~9~~~~~;;~J~~~~~~~~~~~~~~~~~===--------------------------------- ----------------------------------------------------------- --------------- 'l'\J"t);( u.s. &OYERNNENT PRINTING;; OFFICE 16-~1-4 was not detëñniñed by Mr.13rë. 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 ca~ " : ~ÉNlFEB~B TBST WELLS 1. ~..~~ XDlfebJadel: I Location: Lat .·08'OV' N.. IDDg lM-53'21" W. Jl3evatlOD: Gro1lDd, 993 teet: derr1ck 1Ioor, 999 feet. Spndded: Oc:tober 13, 19fiL Completed: December 22, 1961: dry aDd abandoned. Total depth: 1,805 feet. XDlfeblade 2: Location: !.at .-08'19" N.. long. lM-44'12'" W. Elevation: Gro1lDd, an feet: derr1ek 1Ioor. 878 teet. Spudded: J"1II7 28, 195L Completed : August IS, 1951: jUDked aDd abandoned. Total depth: 3'l3 feet. XDlfebIade 2A": - " -- . . Location: Lat .-08'19" N., long 1154-44'12" W. Elevation: Ground. 869 feet ¡ derr1ek 1Ioor. 874 feet. Spudded: August 8, 19G1. Completed: October 7, 18IS1¡ dry ancI ,h_"(WI~ Total depth: 1,805 feet. The Knifeblade test wells were drilled to test the oil and gas possibilities of the Grandstand and Tuktu formations. ". Knifeblade test wells 1,. 2, and 2A are 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 lqlra. (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 òn. clear days. The name "Knife- b)ade" was given to the sharp-crested ridge by a pilot Hying 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 pIs. 21B and 28.) The test well on the south side of the main thrust fault (see Structure) was thought to oft'er 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 con.:fasion in the records, although it was actually the first hole drilled. Knife- blade test well 2 was drilled to a depth of 313 feet, at which point the hole was junked when the drilling tools were lost and not recovered; at this depth the hole was still in permafrost and was completely dry. The formations drilled in this and the SQ~ing Knifeblade tests are as follows: IØD ,...,.. of ,.. ~ 0AtJ..n.. t_.... øtJruJ.... (""'1'1 fa fHl) (11.'1'1 ... feet) 8-820 820-1, SOCS T. D. _ ~IOG 1Oð- 873 T. D. u-eo ~1. SOCS T. D.'" ~ ~~, $4~ I 9"1 f ~~ The rig was . 28 feet due no~ and Knife- blade test well 2A was drilled to a depth of 1,80lS 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 dift'erent 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 negligibJe. 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 well 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 1. The grain size of the Grandstand formation 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- eV8l', it is very nn liqly 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. None is described by C. L. Whittington (oral communication) from the outcrop nearby. Elevations in the Knifeb1ade area were determined by recoJlnlt.iRRAnœ altimeter traverses by C. L. Whit- tington and have been tied to the Umiat datum. (See page 381.) The well elevatioDS are 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. STBt1CT17BB 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 Dilles 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 appro-nml\te1y parallel to the u:is 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 B1U'faœ this fault is marked by an abrupt change in strike be- IlkF ¿J.4 - ...... II 398 BXPLORATJON 01' NA. PBTROLE11M RESEBV1i: NO.4, NOaA ALASICA, 1144-63 = - --- ---- "'-.., --------_ -.........~ l.J ¡,..... ...... ------------- ........... KIlIFEIILADE'TarWELLI '- ?- ...........,.:, , -:::.. -i-~_I I· KNIFEllLADE TEST WELLS , D -__ 2ANDZA u_..- -----------------~-- Ie- 154-50' I 40' I ~ Ai-"''' ! i ~.' ... ,Sf ~ ¡ ~ (oj ~ ~""N .... DCCLI1IA~ .... ( \ ~ 155- I 154-50' EXPLANATION --$--- Axis of anticline D U Fault U. uplhrown side; Q. dawrrUufllftn side t- Thrust fault r. ufJPfJ' p/Ide ---------- Outline of anticline -9- Dry hole _8!r' 10' o I 'h I I I Scale In miles 1 I Geologic structure by C. L. Whittington, 1955 I 40' I'IGUIUI 32.--()uWne of part of tile KDlteIJlade antteUne. ahowIDC the e10nre on _ ImqInU7 bOrUoD In the Cb_dler formation and the relation of tile felt wella to Important faDlta. The wat ead of the _tleUne. DOt ahOWD on thla _P, .. eomplul,. fftuJtt'd. 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, o1fsets 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- sure, but surface exposures are not sufticient to permit a definite interpretation. No geophysical wo\'k was done in the area. Knifeblade test wens 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, A~'ming 1 hole is directly down dip from the other. A dip measured on the surface nearby is 19°5. 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 it) to 20:» or less in c.õ deepest cores. The 1,805 feet of beds driUed in test well 2A represents an actual thickness ~f appru:å- mate1y 1,625 feet because of the inclined beds. Knifeblade test well 1 was located on the north 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 weIJ site it is 18°NE, Dips measured on cores range from 5° to 15°, much less than in Knifeblade 2A. There is no e'ridence of faulting in Knifeblade test well I, The top of the Grandstand formation in Knifeblade test wf'J11 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 paJeontologica11y after tsa Iring into con- sideration differences in thickness due to dip. The test wella 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 bistory. 406 On => 75-85 ~ ---- 85-95 :~ ---- 9&-105 105-145 ~ 205-210 216-225 22õ-235 23&-245 ---- 245-:-250 250-265 EXPLORATION OF &. PETROLEUM RESERVE NO.4, NORL ALASKA, 1944-63 LiDuiloøic duerip'icm-Continued ø.m.rb Lilholot1ic clucriptiøn-Continued Core Depth (teet> Bemarb Bandatone, light-gray, fine- to medium- ¡rained, salt and pepper, 80ft; 75 percent white and olear quarts; also coal particles, dark chert and mica (muøcovite or sericite). Clay aba1e, medium- to medium-dark-gray, 40 percent; 40 percent øand 88 above; re- maiDder is black sbiny coal. Siltstone, 50 percent; and 40 percent light- tomedium-light-gray very fine-grained øandstone; trace of clay shale. Sandstone, very light- to light-gray, medium- to coarse-graiDed' 8< and pepper, soft to hard; grains subangular to øubrounded; 80 percent white and clear quartz, 10 pèrcent ooal particles, 10 percent mica (muscovite or sericite); light-eolored slightly calcareous cement; carbonaceous plant. impressioDB and light-olive-gray clay ironstone. The to~ of the Gva.ndAtand formation is placed at 105 ft. 14&-155 CIay AhAle, medium-gray, 60 percent; 20 per- cent aiItstone, and about 20 percent mica- ceous øandstone. 155-165 Sandstone, light-gray, medium-grained, 80ft; grains øubanguJar to øubrounded; 70 percent white and clear quartz; remainder is dark chert, ooaI particles, rock fragments,. and mica; Blightly calcareous. 165-185 Clay shale, medium-gray; also 40 percent aai1dstone 88 below in the lower half of the . interval; trace olive-gray ironstone. 185-205 Sandstone,medium-light.-gray, medium- grained, rare fine-graiDed, aalt. and pepper, very soft to medium-eoft.; grains øubangular; 60 percent white and clear quarts; re- mainder mostly dark chert with abundant coal particles in placea, some coaly partings; noncalcareous; trace of clay ironstone at. 185-190 ft. Siltstone, medium-light-gray, noncalcareouø; . carbonaceous partings; trace of sandstone. Clay shale, medium-light- to medium-dark- gray, aiIty near top; trace of coal, pyrite, and olive-gray ·clay ironstone. Clay shale, medium- to medium-dark-gray; 1&-30 percent black shiny to dull coal. Clay shale, medium- to medium-dark-gray, slightlyaiIty, micaceous. Siltstone, and ømall 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-graiDed in the lower; 75 percent white and clear quartz; remaiDder is dark chert, coal particles; sericite in matrix; Blightly calcareous. 265-280 Clay shale, medium-light-· to medium-gray, trace of finely micaceous siltstone. 280-295 Clay aha1e, medium-dark- to medium-gra)'; trace of pyrite, coal, and bJ'01rJÚllh-gray clay ironatone. 295-300 No sample. 1 3DO-303 Recovered 1 ft: MicrofoøaiIa abundant. Clay aha1e, medium- to medium-dark-gray, medium-bard; ¡ood cleavage; one IJ'in. t.hick bard slightly browniah-gray clay ironstone concretion at the oottom of the interval; shale contains pyrite nodules; dip undeterminable. 303-305 Coal, black, shiny, 50 percent; and dark- . gray to grayish-bJack clay shale. 305-316 Clay shale, medium- to dark-gray; 5 perœnt coal at 306-310 ft. 316-320 Clay shale, medium-gray; and 30 percent very fine-grained argillaceous slightly calcareous øandstone; bit.umen in sandstone. 320-370 Clay shale, medium- to medium-dark-gray; 10 percent. medium-light-gray very fine- grained ~dstone at 3S5-36O ft. 370-373 No sample. (f' ..!!'.;..'..""_'.... ?..J The well cuttings from e e test well 2A were of good quality to a depth of 1,500 feet. Below this ^Ì". depth there appeared to be a considerable amount of I....l/ loose sand contamination. No samples were taken from 190 to 335 feet as the section was duplicated by nearby Knifeblade test well 2. M. M ~1&oZogú: clucrip&itm ~ On Depth (feet) BemBrb 6-5 6-15 16-20 Height of derrick floor above ground. No sample. Clay ahale, medium- to dark-gray; 5 per- cent coal and moderate yellowish-brown clay ironstone. Clay ahale, medium- to medium-Ught- gray; aløo 16-20 percent medium-light- gray medium-grained very tight sand- stone; browniah aideritio matrix; also some mica; 20 percent moderate ye1Iow- ish-brown DOncalcareous clay ironstone; trace of coal. Clay ahale, medium-light-gray, øIightly aiIty; trace of sandstone. Sandstone, medium- to medium-light- gray, fine- to medium-grained; 70 per- cent white and clear quarts; remainder is rock fragments, dark chert, coal par- ticles, and mica; trace medium-pay clay ahale. 20-30 30-47 47-49 -~ ~~ ~~ J~ ~ ---- Core Depth (teet) 4~56 56-61 61-64 64-69 6~75 75-80 80-87 87-90 90-113 113-123 123-128 128-130 130-137 137-144 144-148 148-152 152-168 168-171 Lithologic dØ8cripti.COntinUed RemMD Coal, black, shiny to dull, and clay shale, medium- to dark-gray, 40 percent; 10 percent of the clay shale is light brownish gray. Clay shale, medium-light-gray, slightly silty and sandy; trace to 10 percent coal. Siltstone, medium-light-gray, and clay shale; trace of dirty sandstone. Clay shale, medium-light-gray. Coal, black, shiny; 10 percent grayish- black clay shale. Clay shale, medium- and dark-gray; 15 percent coal; trace of ironstone. Clay shale, medium-light-gray, very silty; 5 percent dark-gray clay shale. Sandstone; as below but some with yel- lowish sideritic cement; 15 percent black dull to shiny coal, 5 percent moderate yellowish-brown clay iron- stone. Sandstone, light-gray, probably quite soft; medium grained with scattered coarse grains; subangular grains; 85 percent white and clear quartz; re- mainder is coal particles and dark chert, some mica7ghtly calcareous in part; trace of_at 97-99 ft, trace of iron- stone at 108-113 ft. The top of the Grandstand formation is p!àced at 90 ft. Clay shale, medium- to medium-light- gray; some sandstone; trace of light- olive-gray clay ironstone. Sandstone, tine-grained, slightly calcar- eous, 60 percent; also medi~y clay shale; trace of clay ironstone. Siltstone, light-gray, and medium-gray clay shale. Clay shale, medium-light-gray, silty and slightly sandy. . Sandstone, medium-light-gray, very tine- to rarely medium-grained, very dirty, silty, composed of 70 percent white and clear quartz, some coal, chert, mica (sericitic); as much aŠïo percent clay ironstone particles; trace of clay shale. Clay shale, medium-gray; trace sand- stone; 5 percent light-olive-gray clay ironstone. Sandstone, . medium-light-gray, silty to tine-grained, slightly calcare01J!l, hard; 75 percent white and clear quartz; 20 percent dark chert, coal particles, some mica, ironstone particles. Clay shale, medium- to medium-light- gray; trace of siltstone; trace of pyrite. Sandstone, as·in core below; 10 percent medium-light-gray clay shale, 5 percent dark-yellowish-brown clay· ironstonèö Core Depth (teet) 1 171-174 ø 174-185 185-190 190-335 335-355 355-365 2 365-368 @ 368-370 370-375 375-385 385-455 455-464 3 464-467 _lOgiC d~criPtion-ContùÌued RemMD Recovered 2 ft 9 in.: Microfossils absent. Sandstone, light-gray, medium-grained, salt and pepper, medium-hard; platy fracture; subangular grains; 75 per- cent white and clear quartz; remain- der is mostly dark-gray and black chert, very rare white chert and rare coal particles; argillaceous cement; =calcareous; carbonaceous partings with 40° dip; sand contains very rare , blebs of bitumen. At 172 ft effective porosity 16.0 percent, and air perme- ability 41 millidarcys. Sandstone, as in core above. Clay shale, medium-light-gray. No samples were taken in this interval. See Knüeblade test well 2, 210-355 ft. Clay shale, medium- to medium-light- gray, medium-dark-gray; carbonaceous partings at 340-345 ft. Sandstone, medium-light-gray, fine:. to rare medium-grained; 65 percent white and clear quartz; black ~ particles common; dark chert; as much as 10 percent interstitial sericite; slightly ~- careous; also as much as 40 percent medium-light- to medium-dark-gray clay shale. Recovered 1 ft 6 in.: Microfossils absent; Siltstone, medium- to medium-light- gray, argillaceous, medium-hard; poor to fair shaly cleavage; many partings contain black carbonaceous plant impressions; some streaks of very fine sand; noncalcareous; some indi- cation of dip as much as 40°. Siltstone, medium-gray, 80 percent,' and medium-gray clay shale or claystone; with conchoidal fracture. . Clay shale, medium- to medium-dark- gray. . Clay shale, dark-gray, clÎrbonaceous; 5-10 percent black shiny coal; some medium- light-gray ·clay shat;;" as much as 20 percent medium-dark-gray siltstone. . Clay shale, medium~ to dark-gray, rarely medium-light-gray; carbonaceous at 405-410 ft, silty and sandy at 430-435 ft, trace of pyrite at 445-455 ft, one shell fragment at 420-425 ft. Sandstone, medium-gray, medium- to coarse-grained; grains .. subangular to subrounded; 50 percent white and clear quartz, 40 percent dark-gray chert and black· coal; noncalcareouÌJ; bitumen in sand; mõ some clay shale in upper 5 ft of this interval. Recovered 9 in.: Microfossils absent. Sandstone, light-gray, medium-hard, fine- to medium-grained, salt· and 408 ÉxPLORATtON' ÓF NA. :ÞETBot.EUM RESERVE ~O, 4, NORA ALASKA, 1944-58 ConI Depth (feet) 467-470 470-546 545-560 560-570 570-645 645-85ð 655-665 4 665-667 667-670 670-705 705-730 LilAolO( ic tlucription-Continued Bemarb pepper; angular to subangular grains; 60 percent white and clear quartz; remainder almost entirely dark-gray and black chert; argillaceous cement; in some fragments the interstices are filled with a dark-brown tarry mate- rial; noncalcareous; dip undeter- mined; at 465 ft effective porosity 10.07 percent and the sample is impermeable. Sandstone, light-gray, as in core above; also 15 percent medium-dark-gray clay shale. Sandstone, light- to medium-gray, salt and pepper, rather soft except for cal- careous streaks; fine grained at thebüå õ1ttië interval becoming coarse near the top, a few of the coarse grains are rounded, the rest are subanguIàr to subrounded; 40 percent white and clear quartz, 30 percent .G2II. particles. and dark chert; about 30percent of total rock is øericitic material-probably in matrix-which gives a sheen to rock chips. V erycalCáreous in interval at 495-500 it, slightly to moderately S!J- careous at 505-515 ft. Traces of bitu- "men throughout. Siltstone, medium-light-gray;· sandy near top of interval, argillaceous near base. Clay shale, medium-gray; as much as 10 percent medium-light-gray siltstone. Sandstone, light- to medium-light-gray, fine- to medium-grained, mostly rather soft; 75 percent white and clear quartz; remainder is dark chert, rock and ~ particles; øericitio material in matrix; noncalcareous except for very· oalC&{&- ous at 580-585 and 615-620 ft. '.æe- ~mUl prisms at 570-580 ft. Traces of bitumen throughout. Siltstone, and very fine-grained sandstone, medium-light-gray, 60-80 percent; and medium- to medium-dark-gray clay sha1e. Clay shale, medium-gray, silty in upper 5 ft. lnoceramUlprisms. Recovered *" in.: 1\bcrofossils absent. Clay shale, medium-gray, slightly to moderately calcareous, hard; fairly good cleavage. - Clay shale interbedded with siltstone, dark-gray, hard, mOderately to highly calcareous. Cür.y 8hale~ medium- to medium-dark- gray, aiÌty; trace of very fine sandstone toward the base of the interval. Ðitrupa, at. 695-705 ft. SandstOne, medium- to medium-dark- gray, medium-grained; subangu1ar Core Depth (feet) 730-750 750-755 5 755-758 (tJ 758-771 6 771-773 @ 773-789 7 789-792 ® 792-805 8 .805-807 Lithologic de,cription--Continued Bemarb gi'aÏns; 70 percent white and olear quartz; remainder is dark chert arid quite a large amount of carbonaceous material. Clay shale, medium- gray, silty. Trace 735 ft. Sandstone, light- to medium-light-gray, . fine- to medium-grained; grains sub- angular, SO percent white and clear quartz; remainder is rock fragments, dark chert, = particles, some mica and pyrite; noncalcareo~; some bitu- men in siltstone. Recovered 2 ft 10 in.: Microfossils absent. Sandstone, medium-light-gray, fine- to medium-grained, salt and pepper, me- dium-hard; grains, subangular; 60 per~ cent white and clear quartz; remainder is dark-gray and black chert; other minerals rare; noncalcareous; dip un- determined; no shows. At a depth of 758 ft effective porosity 10.25 percent. The pieces of core were too smaIl to drilI a plug for permeability. Sandstone, as in core above; some coarse grains; trace of bitumen. Recovered 10 in.: Microfossils absent. Sandstone, medium- to medium-Ught- gray, medium-hard, fine- to medium- grained; some coarse grains; 80 per- cent white and ,clear quartz; re- mainder mostly dark chert and some coal partioles; rare partings of angu- lar black clastio coarse-grained coal particles; very. slightly caloareo~ dip undetermined; no shows. Sandstone, as in core above, medium- grained, slightly calcareous. Recovered 1 ft 10 in.: Microfossils absent. Sandstone, medium-light-gray, me- dium-grained, salt and pepper, me- dium-hard; subangu1ar grains; 70 percent white and clear quartz; re- mainder is dark chert, coal particles, other minerals rare; argü1aceous ce- ment; noncalcareous;dip undeter. mined; no shows. At 792 ft effective porosity 14.2 percent, and air perme- ability 1.3 millidarcys. Sandstone, medium-light-gray, salt and pepper; grains subangular to sub- rounded with some ooarse rounded dark chert; 70 percent white and clear quartz; remainder is mostly dark-gray and black chert; pyrite common; trace of dark-gray clay shale and coal toward the base. _. No recovery. to medium-dark- of coal at 730- - , J t ~ Oore Depth (reet) 9 807-809 ØJ 809-815 815-825 825-835 835-840 840-845 $" 10 84&-846 846-850 850-860 860-893 11 893-894 Lithologic de8criPI.:ont::e~-~~-- -"-'-HI .uU~""Dl"A.lJ.I!i A.tU!j1:::S:riPlion_ContinUed 409 Bemarks Oore Depth (reet) Bemarks Recovered 10 in.: Microfossils absent. Sandstone, medium-light-gray, me- dium- to coarse-grained, salt and pepper, medium-hard;' composition essentially the same as in core 7 above; 65 percent white and clear quartz; very slightly calcareous to noncaIcareous; no shows. At -807 ft effective porosity 20.9 percent, and air permeability 325 millidarcys. Sandstone, light-gray, medium-grained, as above; trace of clay shale. Siltstone, medium- to medium-light-gray, as much as 20 percent noncalcareous to very calcareous sandstone. Clãy shale, memum-gray; 5-25 percent moderately calcareous siltstone. Siltstone, and very fine-grained sandstone,. medium-light-gray, moderately calcare- ~ and medium-gray clay sh~ Sandstone, light-gray, fine- to medium- grained; 85 percent white and clear quart2s; remainder is dark chert, coal' particles, and rare rock fragmén~ ;, very calcareous; also as much as 25 percent medium-gray clay shale. Recovered 1 ft: Microfossils absent. Siltstone, light-gray, hard; some fine- grained sandy laminae; also about 40 percent medium-gray silty mod- erately to very calcareous hard clay shale with fair cleavage; possible dip of 18°. Siltstone, medium-light-gray, moderately calcareous; carbonaceous partings; trace of very á~e-grained sandstone. . Sandstone, light-gray, very fine-grained. hard; grades to siltstone; 85 percent white and clear quartz; very æ- careous; also as much as 50 percent medium-gray clay shale. Clay shale, medium- to medium-dark-: gray; trace to 20 percent siltstone at 860-865 and 880-893 ft j slightly to moderately calcareous at 880-893 ft; Recovered 7 in:: Microfossils very rare. Sandstone, light-gray, very silty, hard; grades to fine-grained argill~ ceous siltstone with irregular frac- ture; primarily white and clear quartz; some slightly carbonaceous and micaceous dark chert; one very small fragment of a mollusk shell. Very slightly calcareous; dip about 200¡ no odor, DO cut (well geologist reports slight fluorescence) ; slight greasy stain in evaporating dish of sample ftóm 893 ft. At 893 ft effective porosity 8.93 percent and sample is impermeable. 894-903 Sandstone, light-gray, very fine-grained to silty; 90 percent white and clear quartz; also dark chert, rare rock fragments; 10-50 percent medium-gray clay shale. 903-905 Recovered 1 ft 4 in.: Microfossils com- mon. Siltstone, medium-light-gray, argil- laceous, very hard; streaks of sand; recovery consists mostly of flat chips up to 1 in. in diameter; about 40 percent of these chips are medium- gray non calcareous clay shale; dip 27°; no shows. 90&-915 Siltstone, medium-light-gray, 50-60 per- cent, and clay shale, medium- to medium-dark-gray; some very slightly calcareous very fine-grained sandstone. 915-920 Sandstone, light-gray, very fine-grained to silty, moderately calcareous, 80 per- cent; primarily white and cleàr quartz; also 20 percent medium-dark gray clay shale. 920-950 Siltstone and sandstone, in varying amounts; moderately calcareous at 92&-930 ft, very slightly caIcåreous at 935-940 ft; as much as 50 percent medium-gray clay shale. lnoceramuø prisms at 930-940 ft. - 950-1,000 Clay shale, medium- to medium-dark- gray, rarely medium-light- and dark- gray; very silty and moderately cal- careous at 950-960 ft, silty at 99if- i,õõnt. D;"ru};, fragments at 955- 960 and 99 1, 0 ft, Ditrupa and lnoceramuø at 970-975 ft. - , 1, 000-1, 010 Siltstone, medium-gray; and very fine- grained sandstone, slightly calcareous to noncaIcareousj 5 percent medium- gray clay shale. 1,010-1,035 Clay shale, medium-dark- to dark-gray, silty; trace of very ~careous silt- stone at 1,020-1,025 1t. 5 percent medium-light-gray very slightly cal- careous siltstone at 1,030-1,035 ft. - - 1, 035-1, 040 Sandstone, light-gray, very fine-grained hard; 85 pèrcent white and clear quartz; remainder is dark chert and coal particles; slightly calcareous; some iñëdium-gray clay shale. 1,040-1,042 Recovered 2 in.: Microfossils very rare. Sandstone, light-gray, very fine-grained, hard; grains subangular¡ 80 percent white and clear quartz; remainder mostly dark chert, carbonaceous pa r- ticles, and some biotite; very slightl y calcareous; dip undetermined; exceed_ ingy faint odor (1). Well geologist reports cores 13-15 bled gas. 12 13 w C;I'-'4 11' /0 -0 /6 ~ ~ ~7 /~ Æ"'} ...:::.v.... ~ ¡ Ã4' 1"~¥:/ 0Q. ~ ~4 U..J44fl~'lkrdrl- $>'1.7 - '1 410 EXPLORATION OF .AL PETROLEUM RESERVE NO.4, NOR!RN ALASKA, 1944-53 Core Depth (feet) 1,042-1,066 14 1,066-1,070 1, 070-1, 084 15 1,084-1,086 1,086-1,095 1,095-1,100 1, 100-1, 120 1,120-1, 150 1, 150-1, 155 1, 155-1, 160 1, 160-1, 185 1,185-1,200 1,200-1,210 1,210-1,220 1, 220-1, 245 1,245-1,265 Lithologic description-Continued Remarks Core Deptb (feet) Sandstone, as in core above; 5-15 percent medium-gray clay shale. Recovered 9 in.: Microfossils very rare. Sandstone, light-gray, very fine-grained to silty, very slightly calcareous, hard; composition as iñ core 13 above; dip approximately 23°; very faint odor; very pale-yellow cut and greasy residue in evaporating dish. At 1,066 ft effective porosity 9.45 percent, and the sample was imper- meable to air. Sandstone, as above; trace of clay shale at 1,080-1,085 ft. Recovered 9 in.: Microfossils very rare. Siltstone, medium-light-gray, hard; Ír- regular fracture; scattered sand grains; rare black carbonaceous plant impres- sions; very slightly to moderately 2!:!- careous; dip undetermined. Sandstone, very fine-grained, and slightl:r calcareous siltstone; 15 percent me- (hum-gray clay shale. Siltstone, medium- to medium-dark-gray; 40-60 percent clay shale. Clay shale, medium- to medium-light- gray; as much as 40 percent noncalcar- eous siltstone. Siltstone, medium- to medium-light-gray, argillaceous; 10-50 percent medium- to medium-dark-gray clay shale; plant im- pressions at 1,140-1,145 ft. Clay shale, medium-dark-gray. Silty clay shale, and argillaceous siltstone, medium-light- to medium-dark-gray. Ditrupa fragments and Inoceramus prisms. Clay shale, medium-dark-gray, trace of siltstone at 1,165-1,170 ft. One piece of t,rae;onite stained with bitumen at 1,180-1,185 ft. Siltstone, and very fine-grained sandstone, medium- to medium-light-gray, non- calcareous to moderately Ç.alcareous; also 10-30 percent silty clay shale. Sandstone, medium-gray, very fine- grained, hard; composed of 70 percent white and clear quartz; many carbona- ceous particles; some black chert and mica; argillaceous, silty, slightly to very calcareous; some interstitial bitumen present. Siltstone; some very fine-grained sand- stone and clay shale. Clay shale, medium-dark-gray, silty. Sandstone, medium- to medium-light- gray, very fine grained to silty, hard; grains subangular to subrounded; pri- marily white and clear quartz; also dark 1,265-1,270 1,270-1,281 16 1,281-1,283 1,283-1,305 1,305-1,310 1,310-1,325 1,325-1,335 1,335-1,340 1,340-1,355 1,355-1,400 1,400-1,415 1,415-1,420 Lithologic discription-Continued Remarks chert, coal particles; very calcareous in interv';t;! 1,260-1,265 ft. Siltstone and sandstone, medium- to medium-light-gray, slightly calcareous in part. Clay shale, medium-dark-gray, very silty; some siltstone and sandstone. Recovered 8 in.: Microfossils absent. Siltstone, medium-gray, argillaceous, hard; fair shaly cleavage; also some very fine-grained sand; carbonaceous micaceous partings; pyrite has re- placed the matrix through one-half inch of the core; small amount of brownish crystalline calcite in part- ings; slightÌy calcareous; dip 27°. Sandstone, medium-light-gray, silty to fine-grained, rather soft; 85 percent white and clear quartz; remainder is rock fragments and dark chert; 5-15 percent medium-dark-gray clay shale. Clay shale, medium-dark-gray, 70 percent; and very fine-grained sandstone and siltstone. Sandstone, medium-light-gray, very fine- grained, very soft; grains subangular to subrounded; 90 percent white and clear quartz, also dark chert, coal fragments; trace of clay shale. - Siltstone, medium- to medium-light-gray, non calcareous to slightly calcareous; mostly white and clear quartz, rock fragments; also 20 percent medium- dark-gray clay shale. Ditrupa frag- ment. Sandstone, light- to medium-light-gray, very fine- to fine-grained; mostly white and clear quartz, rock fragments; slightly calcareous in part; also 20 per- cent medium-dark-gray clay shale; crinoid stem ossicles and Dztru1J(J. Cl~e, medium- to medium-dark- gray; 20-50 percent sandstone in the lower part of the interval; very tine- to fine-grained; sandstone is moderately ~alcareous at 1,350-1,355 ft, trace of S2!!. at 1,345-50 ft. Sandstone,light-gray,fine-grained,proba- bly rather soft; subangular grains; 75 percent white and clear quartz; œ!!. particles, rock fragments; noncalcare- ous to moderately calcareous; as much as 20 percent medlUm-dark-gray clay shale. Inoceramus prisms at 1,395- 1,400 ft. Clay shale, medium- to medium-dark- gray, silty; as much as 40 percent medium-gray siltstone. Siltstone, medium- to medium-light-gray, sandy; 10 percent black shiny coal. - f _ . ____, _...~v..,. AJ...u AJ...u~J!<.öLAV.I!i A.KE~8KA Lithologic discriPtioantinUed L2giC díscription-Continued 411 Core Depth (teet) 1,420-1,425 1,425-1,445 1,445-1,460 1,460-1,465 1,465-1,479 17 1,479-1,481 ~ 1,481-1,495 1, 495-1, 505 1, 505-1, 507 18 1,507-1,510 ® 19 1,510-1,517 1,517-1,521 tv Remarks Clay shale, medium-dark-gray, 80 per- percent and light-gray very tine- grained sandstone; 5 percent coal. Inoceramus prisms. - Saiuistone, light-gray, tine-grained; 85 percent white and clear quartz; mod- erately to very calcareous at 1,430- 1,440 ft; 20-50 percent medium- to medium-dark-gray clay shale. Clay shale, medium-dark-gray; 5 percent .e at 1,445-1,455 ft. Siltstone, medium-light-gray, argillace- ous, 60 percent; and medium-dark-gray clay shale. Clay shale, medium-dark-gray, 70-90 percent; some medium-light-gray silt- stone and very fine-grained sandstone; moderately calcareous at 1,465-1,470 ft, trace of coal at· 1,470-1,475 ft.· ~ Inoceramus pnsms at 1,475 and 1,485 ff. - Recovered 9 in.: Microfossils absent. Clay shale, medium-dark-gray, non- calcareous, hard; fair cleavage; rare micaceous partings; very rare slightly silty lighter colored laminae; dip un- determined, possibly 25°1 Clay shale, medium- and medium-dark- gray, very silty. Sandstone (samples mostly loose sand), light-gray, fine-grained, non calcareous; 15 percent medium-dark-gray clay shale. Clay shale, medium-dark-gray, 60 per- cent; also light-gray slightly calcareous fine-grained sandstone. - Recovered 1 ft: Microfossils absent. Sandstone, medium-light-gray, fine- grained, massive, hard; subrounded to subangular grains; 90 percent white and clear quartz; remainder is dark chert, rock particles, mica, and other minerals rare; argillaceous ce- ment; brownish cast to some of the quartz grains; essentially nonca1- careous; dip undetermined. At 1,508 ft fleeting odor on fresh fracture; straw-colored cut; olive-yellow resi- due. At 1,508 ft effective porosity 11.45 percent, and sample is imper- meable. No sample. Recovered 2 ft 10 in.: Microfossilsabsent. Sandstone, as above, nonca1careous; 85 percent white and clear quartz; dip undetermined. At 1,521 ft effective porosity normal to bedding 9.7 per- cent, and sample is impermeable. Core Depth (teet) 1,521-1,557 20 1, 557-1, 560 ® 1,560-1,580 21 1,580-1, 584 (!) (~,.~. ,"tJ?A"'~ ~ n .:;> 1,584-1,590 1,590-1,607 22 1, 607-1, 610 ® (~ ("1/t-") 1 1,610-1,620 23 1, 620-1, 622 (j) Remarks Sandstone (samples mostly loose sand), light-gray, very fine- to fine-grained; grains subangular to subrounded; 85 percent white and clear quartz; also dark chert, coal particles, rock frag- ments, rare i:iiicã; slightly calcareous; 30 percent medium- to medlUm-aarJ!:- gray clay shale at 1,545-1,550 ft, trace to 8 percent clay shale elsewhere; some siltstone in lowest part. Recovered 2 it: Microfossils absent. Sandstone, medium-light-gray, silty to· very fine-grained, hard; grains sub- rounded to subangular; 90 percent white and clear quartz; remainder is dark chert and coaly particles; argil- laceous cement;ñõncalcareous; dip undetermined, suggestion of 50-15°; fleeting odor; no cut; very pale-yellow residue from 1,557 ft. At 1,557 ft effective porosity 11.56 percent, and the air permeability < 1 millidarcy. Sandstone, as in the core above. Recovered 3 ft 6 in.: Microfossils absent. Siltstone, argillaceous, and some clay shale, medium-gray, hard; fair to poor cleavage; rare streaks of fine- grained sandstone; coarser-grained material occurs toward bottom of core; noncalcareous; dip 18°-23°; no shows. Siltstone, medium-light-gray; some loose sand; 5 percent clay shale. Sandstone (mostly loose sand), light-gray, very tine- to medium-grained; grains subangular; 75 percent white and clear quartz; some dark-gray and black chert, rock fragments, coal particles; non- calcareous; .trace of clay shale. Recovered 2 ft 10 in.: Microfossils absent. Siltstone, clay shale, and some very fine- grained sandstone, medium-light- to medium-dark-gray. Sand is 75 per- cent white and clear quartz; many of the grains are stained brown; re- mainder of grains are dark carbona- ceous material and some dark chert. Sandstone is slightly to moderately calcareous or D08sibly dolomitic, as rock reacts slowly with acid; dip undetermined; faint oily odor, dull- yellow cut and brown residue from 1,608 ft. Loose sand, tine- to medium-grained. Recovered 1 ft 4 in.: MicrofossiIs absent. Sandstone, light-gray, fine-grained with very rare medium grains, hard; fair . cleavage parallel the bedding; sub- rounded to subangular; 85 percent white and clear quartz; remainder is 412 . . EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 Core Depth (feet) 1,622-1,661 24 1,661-1,664 ($J I, 664-1, 690 1,690-1,725 I, 725-1, 730 .. 1,730-1,755 1,755-1,765 I, 765-1, 770 1,770-1,775 1,775-1,780 1,780-1,785 1,785-1,790 25 1,790-1,802 1,802-1,805 Œ) Lithologtc description-Continued Remarks mostly dark chert, some carbonaceous particles and mica, other minerals rare; rare argillaceous partings; non- calcareous; dip 8°-19°; some cross- bedding; no shows. Loose sand, 85 percent fine-grained, rarely very fine- or medium-grained; white and clear quartz. Recovered 1 ft 9 in.: Microfossils absent. Sandstone, light-gray, fine-grained, hard; 90 percent white and clear quartz; remainder is dark chert, coal, and rock particles; argillaceous cement; one black carbonized-coaly plant fragment 2* in. long and one quarter inch wide; noncalcareous; dip 8°-12°; no shows. At 1,661 ft effec- tive porosity 6.13 percent, and sample is impermeable to air. Loose sand, very fine- to fine-grained; 85 percent white and clear quartz; one clay chip at 1,680-1,685 ft. Sandstone chips, light-gray, very fine- grained; trace to 8 percent siltstone and trace of clay shale; much very fine loose sand. Siltstone, medium-light-gray, sandy; much loose sand. Sandstone, light-gray, fine-grained; mostly loose sand; trace to 20 percent clay shale at 1,730-1,740 ft. Clay shale, medium-dark-gray, silty. Loose sand, light-olive-gray, very fine- grained to silty; grains subangular; mostly white and clear quartz. Siltstone, medium-light-gray, sandy, non- calcareous. Loose sand, very fine-grained; some silt- stone. Siltstone, medium-light-gray; loose sand; some clay shale. Clay shale, medium-gray, silty; rare medium-dark-gray chips. No sample. Recovered 2 ft 9 in.: Microfossils very rare. Claystone, closely interbedded, with siltstone, with all gradations of each, medium- to medium-dark-gray, non- calcareous, hard; irregular fracture; dip 21°. OOBE ANALYSES Effective porosity, air permeability, and carbonate content analyses were made in the Fairbanks laboratory of the Geological Survey on core samples shipped from the test well sites. Porosity and permeability were de- 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 imperme.able fragments for analysis. The results given in the following table were obtained on samples from Knifeblade test well 1. All plugs were cut normal to the bedding. Core analyses, Knijeblade test well 1 Core, Depth (feet) Effective AIr permea- =y bility (mll- t) lIdarcys) 4.42 0 5.29 0 10.58 0 11.50 <1 13.06 <1 8. 16 0 4. 58 2.72 6.08 2. 66 11.10 <1 2____________________________ 3____________________________ 7____________________________ 13_______~___________________ 141__________________________ 15_ _ _ _ _ _ _ _ - - - - - -.- - - - - - - - - - - -- 16___________________________ 17___________________________ 18___________________________ 267 314 828 1,162 1, 269 1,297 1,377 1,394 1,486 I Carbonate·mIneral content 19.64 percent by weight, 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 analyses, Knijeblade test well SA Depth Effective AIr permeability Oore (feet) =r, (mIllidarcys) 1__________________ 1 172P 16.00 41. 3__________________ 465P 10.07 O. 5__________________ 758P 10.25 Sample too small to drill plug. 7__________________ 792P 14. 20 1.3. 9__________________ 807P 20.90 325. 11_________________ 893P 8. 93 o. 14_________________ 1, 066P 9.45 O. 18_________________ I, 508N 11.45 O. 19_________________ I, 521N 9.74 o. 20_________________ I, 557N 11.56 <1. 24_________________ I, 661N 6.13 O. I P Is para\Jel to the bedding. N Is nonnal to the bedding. BEAVY-MINEILU.. ANALYSIS Robert H. Morris examined (see p. 392) 5 heavy- mineral samples from 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 well 1 the zoned zircon zone ranges from 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 AND GAS SHOWS No good oil or gas shows were found in the Knile- blade test wells although many of the sandstone and silt~ --- 378 . ,'/ - --", '- ' EXPLORATION OF N" PETROLEtJ)( RESERVE NO. ., NORTHERN ALASKA, ""-'3 ,.. ,... '80" 'iii" ,.. U.. . ¡¡- EXPLANATION C . C l' ...- It ,10 + ""..- - + 10"\. ø.., _ ,... , . a _ ~ I,., 190 ....u. ,.. ø) ..,. I SOUTH u.IIO.TDT WILL I 2 SOUTH U._TDTWILL 2 · SOUTH U.IIOW TDT WILL . 4 SOUTH UUOW TDT WILL 4 · AVAK TDT WILL , · .OIl11lSlIlPSOIITDTWILL , 7 '''PSCIIITDTWILL' I _80_ TDT anu. , I USI' TOPA8O.UK TDT anu. , II FISK can TDT WILL , "ItAIIUICTDTWlLLI 12 lllAKTDTWILL , ,. OIIllAUIt TDT WILL , '4 USI' OUllAUIt TDT anu., II SOUA.I Ultl TDT WILI.., II nTALUKTDTanu. I 17 -.. CUD TDT anu. , II -.. CIIUII TDT trILL . II ....C.aac TDT WILL . . _K TDT IIILL.' 2' IIUIlIt TDT WIU. 2 :a KIIIFDUK TDT WII.I. , D KIIIFDUDI TDT trIU.S . AIIDIA 24 lIIAllmAIID TDT WILL , as UIIIAT TDT WILLS I_II =fi.l~-"'"( Jf 4/... . ~ Flllvu 28.~IadU map of DOrthenl AJaùa .IIhoWÚIg loeaöOD of test we1Ja aDd oU ðelds. The . United States Bureau of Mines at Bartlesvi)le, Okla., analyzed a gas sample from Titaluk tešt wen 1. . The·assistance of the Personnels of the above organi- zations is gratefully acknowledged. - . . STRATIGRAPHY '- \~'¡&1~"~f. ~1\>enetrated the Ninuluk, Chand- ler, Graudstan!,' and Topagoruk fonnati.;¡~ taceous age (fig. 29). The much shallow . _~~ IK:netrate~ only ~e Chandler a.Î11t _ sf:õñe fo~atIons. LIthologIcally, however, the section drilled in the Knifeblade test wells is similar to the same . formations in Titaluk test well 1. :! en D- III III ::) ... æ 0 ~ III It en en C) FORMATION a: .... A. A. ::J NINULUK KILLIK TONGUE en ::J ~ ::J OF THE % CHANDLER N.ANùIUl.UA GROUP o .... u C f- W a: u en ::J a: z .... c at 0 Z ...I GRANDSTAND BOOD OPOBBTAOBOt1B AGB BIlr1JI.n: 1'0aJU.'1'I0. The Ninuluk formation of Late Cretaceous age is· the youngest formation drilled 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- TOPAGORUK FIGuar; 29.-Roekl of Cntaeeoul age penetrated by Tltaluk test well t. ..onchoidal fracture or breaks irrAarly along bedding planes but is finely laminated w!lre interbedded with coal, carbonaceous shale, or bentonite. The sandstone is light gray, hard, and massive where cored near the base of the formation; it is very fine to medium grained, and 80 percent of the grains are white and clear quartz, and the remainder are coal particles, dark chert, white chalky material (weathered feldspar or chert'), and rare mica. The siltstone is similar to the sandstone-medium light gray and hard. The sandstones and siltstones are slightly to mod- erately calcareous. The cementing ma~rial is partly argillaceous, partly calcareous, and probably partly sideritic. The effective porosity in the sandstone beds near the base of the formation is 11.7-12 percent, and the beds are impermeable. Coal beds as much as 5 feet thick are present at the top and at about 250 feet below the top of the Ninuluk formation. The coal is soft, shaly, dull to shiny, and black. In a few places it grades into dark-gray carbonaceous cla.y shale that contains black pla.nt fragments. Bentonite is interbedded with the coal but is rare elsewhere in the· Ninuluk formation. The bentonite is light gray to white and contains some brown biotite plates. Yello,vish-brown clay ironstone concretions are . present in the Ninuluk,· although they are not nearly as common as in the underlying· Killik tongue of the Chandler formation. The shallowest sample in Titaluk test weIll examined by the Fairbanks laboratory was from a depth of 40 feet. This· was from the Ninuluk formation and is ßSSentially the top of the formation. (See p. 383.) The total thickness of the formation in the Titaluk area is about 550 feet. The Ninuluk formation was not found in the Knifeblade test wells, as older formations only are exposed along the axis of the Knifeblade anticline; the Ninuluk formation is present off the north flank of the anticline, according to C. L. Whitting- ton (oral communication, 1956.) Despite the presence of coal and carbonaceous beds, the Ninuluk formation is primarily marine as indicated by the repeated occurrence of marine microfossils. A few pelecypods were also found. The few nonmarine beds associated with the Ninuluk formation are fingers of the Niakogon tongue of the Chandler formation. uu.ø: TORCltJ. or TO CKAB'DUK roUlATIOR 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 thick sandstone Are there is a diminution of micro- fossils which ma~ indicative of nonmarine beds. The Killik tongue is composed of 85 percent of clay- stone and clay shale, 10 percent of sandstone and silt- stone, and about 5 percent of coal, very carbonaceo113 clay shale, and clay ironstone. The claystone and clay shale are medium light to medium dark gray. The darker colors are more common. This rock has poor cleavage and subchoncoidal fracture, that is, primarily a claystone. Some of the carbonaceous beds are finely laminated. The sandstone is light to medium light gray, hard, and the beds are rarely more than 20 feet thick. The grains are subrounded to subangular and range in size from very fine to medium. They are made up of 75-80 percent white and clear quartz, and varying amounts of dark chert, rock fragments, and carbonaceous and ironstone particles. The matrix in Titalnk test well 1 is· slightly to moderately calcareous, whereas in the Knifeblade test wells· it is particularly argillaceous. . rhe siltstone is. similar to the sandstone but is mostly slightly darker. The sandstone, siltstone, and clay- . stone are gradational in places. Rare small-scale cross- bedding is present. The effective porosity of the sandstone and siltstone in both areas is low, ranging from 0.96 to 5.29 percent in the few samples tested. All plugs were impermeable. Except for a very small amount .of gas found while drilling at 640 feet in Knifeblade test well 1, no oil or gas shows were found in the Killik tongue of the Chandler formation. Coal, carbonaceous material, and plant fragments are scattered throughout the formation. The coal is black, shiny to dull, brittle, and thin bedded. Very rare small inclusions of clear greenish-yellow amber are present. Dark-gray carbonaceous shale is present above and below the coal and elsewhere in the section. Black, plant impressions are found in both the claystone and sandstone, being abundant at some depths. These imprèssionS are fragmentary, and the plants cannot be identified. . Very characteristic of the Killik tongue are clay iron- stone (sideritic mudstone) concretions and laminae, particularly in the Knifeblade test wells. The clay - ironstone is hard, has conchoidal fracture, and ranges from gray to yellowish bl'9wn. Brown dense dolomite (or siderite') laminåe as much as 2 inches thick are found near some of the thicker còal beds in Titaluk test well 1. Tiny vertical veins of· yellowish-gray dolomite crystals are rare. . In the Knifeblad~ ~ wells and the subsurface in other places in the Reserve, there is a great deal. of authigenic sericite in the Killik tongue. This mica 380 EXPLORATION OF .AL PETROLEUM RESERVE NO.4, NOR.RN 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. an exceptionally high reading that measured 30.4 per- cent by weight. Ordinarily the matrix of the sand- stone of the' Grandstand formation is argillaceous. A few feet of limestone (or possibly siderite or dolo- mite )-medium.:c¡ark-gray with a brownish east, hard, argillaceous, with white vein calcitAr-was found in The Chandler formation i!~des into the marine TitaIuk test well 1, but none was found in the Knife- Grandstand formation; the toIJÞ of the Grandstand for- blade test weDs. mation is placed at the first common occurrence of the Most of the oil-producing zones in the Umiat field V 81'1&eUilinoidea borealis marint~ fauna. This is also the are in the Grandstand formation (Collins, 1957). In approximate top of a very sandy section, the thickest the Knüeblade test wells this formation contains nu- sandstone bed of which occurs IlLbout 350 feet be10w the merous deposits of black bitumen or asphaltic residue faunal top, suggesting that at one time the fault blocks that were The Grandstand formation in TitaIuk test well 1 drilled (see p. 413) did contain oil. The light frac.. is 1,650 feet thick. About 1,7110 feet of this formation tions have long since escaped. The two deep Knife- was drilled in Knifeblade test well 2A, but this is at blade holes yielded brackish water on bailing tests. In least 10 percent in excess of thlB true thickness because TitaIuk test weIll, a little gas and a few oil shows wem of the steep dips. A comparison of thicknesses in the noted. two wells suggests that the boj~tom of Knifeblade test Siltstone in the Grandstand formation is light to well2A is near the base of the f()rmation. medium light gray, and hard and is made up primarily The Grandstand contains about 100 feet of sand- of white and clear quartz grains. It is generally grada- stone and siltstone in beds as ]nuch as 180 feet thick; tional with the sandstone beds and makes up less than the rest is clay shale and claystone. The sandstone is 10 percent of the sandstone-siltstone bulk. Some swirly light gray (rarely medium light gray), hard, and bedding and some small-scaJe crossbedding were noted massive. The grain size ranges from very fine to in the siltstone near the top of the formation in Titaluk medium in the Titaluk test weU and from very fine to . test well 1. very coarse in the Knifeblade test wells; grain size de-· The clay shale and claystone are medium to dark ereases with depth. A few thi~ be~ of .congl?merate gray and hard. The clay shale has fair to good cleav- were recorded at the top of the 1:ormatí~ m Knifeblade age, and the claystone has almost no cleavage but has test weD 1. The conglomerate contains subrounded irregular to conchoidal fracture. These clayey beds are and rounded granules and pebb.les of dark-gray, green- mostly noncalcareous but are very silty in places and ish-gray, and black chert, milkJr quartz, coal, medium- grade to siltstone. The clay shale has some micaceous- and medium-light-gray clay shlLle, yellowish-gray clay carbonaceous partüigs. Sericite is present but is not ironstone, and light-gray sandstone. common in the formation. As is usual in the sandstones t)f the Nanushuk group, There is considerably less coal and carbonaceous ma- the predominant mineral making up the sand is white terial in the Grandstand formation, particularly at and clear quartz, ranging in quantity from 60 to 90 Titaluk, than in the Chandler formation above. A few percent of the total The other grains are mostly dark coal beds are near the top of the Grandstand in the chert and carbonaceous particlel5 with a few rock frag- Knifeblade test wells, but these beds interfinger with ments. The proportion of dark grains is higher in the marine microfossil-bearing shales. The coal may rep- coarser standstone, which has a salt-and-pepper ap- resent nonmarine stringers of the Chandler formation. pearance. Most of the grains artuuba.ngular, and a few No thick coal beds were cored; the cutting chips are are subround; but the very cOaJl'Se grains are round. black and shiny to dull. Rare carbonaceous shale beds Where tested, the e1fective porosity of the Grand- and a few plant fragments in the shale partings were stand formation ranged from 4.li8 to 20.9 percent in the noted. Clay ironstone is less common in the Grandstand Knifeblaœ test wells and froln 0.56 to 12.45 percent formation than in the Chandler formation. in the Titaluk test well. The highest air permeabili- Marine microfossils (see p. 417) are present through- ties were 325 millidarcys and 11 millidarcys, respec- out the formation, as weD as IMceram'UI sp. (mostly tive1y, although most samples tested "impermeable." prisms in the cuttings), Ditnspa sp., and crinoid trag- The low range of porosity in til1e Titaluk test well is ments. The Knifeblade area was probably closer than . result of calcareous materia.l in the matrix. The the Titaluk to the source of the material that makes up content of carbonate minerals in the sandstone in Tita- the Grandstand formation as the sandstone is coarser luk test well 1 is higher than that in the Knifeblade grained, even conglomeratic, and there are more coaly test weIls, and 1 sampJs in the Titaluk test well had beds. GRA1IDBTAlI'D FODATIOll' TOPA.GORUK: FORMA.. Only 520 feet of the Topagoruk formation was pene- trated by Titaluk test well L The Knifeblade tests were too shallow to reach it. In Titaluk test weIll, the divi- sion between the Grandstand and Topagoruk forma- tions is a well-defined lithologic change. The base of the Grandstand (also the base of the Nanushuk group) is placed at the bottom of the thick: sandstone group. The Topagoruk formation is about 70 percent of clay shale and 30 percent of siltstone and a little sandstone. The clay shale is medium. to medium dark gray and hard. The cleavage ranges from very good to very poor, and some of the rocks can be classified as claystone. Some of the claystone is calcareous. The siltstone is light to medium light gray, slightly to moderately calcareous, hard, has fair to good cleav- age parallel to the bedding and some carbonaceous and micaceous partings. There are a few thin beds of very fine- to fine-grained quartz sandstone. Effective poros- ity in the coarsest siltstone beds cored. was between 4 and 6 percent, and the plugs tested were impermeable. A very pale cut of oil was obtained from one core near the top of the formation. The siltstone and the clay shale are interbedded, some 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. C TlTALUK TEST WELL 1 ) Location: Lat 69°25'21" N., long 154°34'04" W. Approxfmate elevation: Gromul, 822 feet; ke1I7 bushing. 840 feet. Spudded: April 22, 1951. Completed: ¡uly 6, 1951. dry and abandoned. Total depth: 4,020 feet. TiWuk 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 tlattens 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 reachiJig the capacity of the rig . (approxi~ mately 4,000 feet). The hole was diilled to 4,020 feet, at which depth it penetrated the Topagoruk formation '88811s-GD---I which underlies thAt,nushuk: group. Only a few minor shows of oil an~ were found. (See page 394.) The formation contacts as determined in this test ¡ are as follows: Ninuluk_h________h____ 40-590 feet. Chandler________________ 590-1,850 feet. Graudstand_______h_U__ 1,850-3,500 feet. Topagoruk_______________ 3,500-4,020 feet, total depth. Field investigations by W. P. Brosgé, C. L. Whitting- ton, and A. L. Kover, U. S. Geological Survey, show that the Seabee formation of the Colville group of late Cretaceous age is present on the surface at the rig site. Samples representing the top 22 feet of rock were not received by the Fairbanks laboratory, but W. P. Brosgé 1 believes that this interval of rock, based on the well geologist's· description, represents the Seabee formation. The uppermost sample from 40-50 feet received in the laboratory contained a few microfossils which are distinctive of the Ninuluk formation. The elevation of Titaluk test well 1 has been adjusted. by W. P. Brosgé to the Umiat datum.a All elevations and locations in the Umiat-Maybe Creek area are sub- ject to correction, pending the results of new topo- graphic surveys. BTBtICTt1BJl The TitaIuk 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 well! 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- . 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 well in excess of these figures. Conoours on figure 30 are projected over the. top of the anticline where the Seabee formation is eroded. Sur- face geological control is lactrlng 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 tlat 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 William Broqf. persoual comlllnnf_H~... . Datum uøecI OD the Umiat Sped&1 HaP. . to1JOCft9hlc dIeet paIÞo Uahed bJ'the U. S. Geolopca1 SUmlJ' In 1148. Simpson Seeps: 34 core tests¡ a ShaUo.eld was defined by the series of core tests. Square Lake: 1 test well¡ a prospect northwest of Umiat defined by seismic and photogeologic techniques. Titaluk River area: 1 test weD¡ located on an anticline mapped primarily by field and photogeologic methods. Topagoruk River area: 2 test welJs¡ in the central part of the coastal plain; a deep test penetrated rocks ranging in age from Devonian to Pleistocene. Umiat: 11 test welJs¡ many produced oil. Wolf Creek area: 3 test welJs¡ 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. lVIost of the footage was drilled of Cretaceous rocks, and all the oil-bearing beds found are in this age. Figure 3 shows dia.eoram- 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 smaIl amount SOUTH . ARCTIC FOOTHILLS PROVINCE II: ... Q. Q. :::I In :::I o ... ... .. .. .... .. ~ ~:¡~ -+- . of gas was fOlÙ1dAthese older rocks. Oilfields '. discovered at Um~ and Simpson seeps and gasn at Barrow and Gubik. Some shows of oil or gas ~__ also noted in other holes. The United States Geological Survey participated in the program as a cooperating agency. Drill cores and cuttings from the tests were shipped from the reserve to the Suryey laboratory in Fairbanks where they were processed, described, and analyzed. De- tailed subsurface information based on laboratory studies and analyses by the authors has been compiled by groups of related wells; in addition, logistic, engineer- ing, and drilling operational data have been abstracted from the files and reports made to the Navy by Arctic Contractors, United Geophysical Co., Inc., the Schlumbèrger Well Surveying Corp., the U. S. Bureau of Mines, and the National Bureau of Standards. These data as well as a geological interpretation of the sub- surface information constitute this paper. . NORTH ARCTIC COASTAL PLAIN PROVINCE SenbMII .... member SCHRAD£R 8."...· T,M. memlMlr BLUFF ----------- FOR_nON Ropra Ct_ ......._ A,.,..._ SEABEE FOR_noN ~ NINULUK FOR_nON GRANDSTAND FOR_noN GRANDSTAND R)RMATION TOPAGORUK FORMATION II: ... ~ o ~ FORT1I£SS TOROK - ---- -- ------.--? 1---------'----- MOUNTA'N FORMAnoN FORMATION ------------------------? 1------------- OKPlKRUM FORMATION --1 UNITS OF JURASSIC AGE - Mol __ OUMAUIC FORMATION LOWÐI R..._pof_ CRETAC£OUS(?'''''O ._ to.-. 1o.1te UPPER _"'1. __ JURA5SIC(!'lRot:ltS, UNDIFFIERIENnAT£O r..dc I_Ior__ F~,~ f~ . '''........".. -: l'Inuu J..-NCIIIUIIICIatIIn fJI. &be em- racb fJI. aœtbsD .AJ8Ib. -------- ------.. -.;--:12 /,(f . , . 7"- ~j 'f- , -,/0'< /0-1- !ÓÝf- /û"f- - /c) -1- /0 +- ~ /6 ý- / () --I-- . I, . . /r . 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"- x x >< ~ . . -~-,~,-- ~::'~, r . -" .,- - --- -~"'-' '. ( / ~\ 7>:~, . ) ( - ~ / --;-.0 ,'ß ¡jl .... /. /OJ.,.4.. '/ 4 --~ ~--~_-1._________/ ~___ t(~'P-,/-e~ Ct/ i¿j¿( P ex,/· .~ ~---- ~J.. I v.,-" . ') Li '\ ¡- -;/(/7- / ,9c3 .~ /:9û 3- ß 10 ~ .. Q ():f - c: !&,D 3' --;1> ~ j) jl\/Cì,A_Q C I). ~;'. v~ it Ii l¡ I( Ii' I; "~=------- - -- - :z ~ ."'.-- "> . . Cø~-~ ',1 eM ~ è.¿""',,,-..::I .1- '-".::t::i\iU¡ ? (¿J",._,-,~ /, II (", '~ t> (; t/ ú' Ii Ii 1'( // "'3 ~.,q:J .X- X X X :¡. Simpson Seeps: 34 core tests; a shalIOeeld was defined by the series of core tests. Square Lake: 1 test well; a prospect northwest of Umiat defined by seismic and photogeologic techniques. Titaluk River area.: 1 test 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: 1l test wells; many produced oil. Wolf Creek area: 3 test wells; relatively shallow tests; shows of gas. The test holes range in depth from 47 to 11,872 feet, and the drilling penetrated rocks of Paleozoic, Mesozoic, and Quaternary age. Most of the footage was drilled of Cretaceous rocks, and all the oil-bearing beds found are in this age. Figure 3 shows diagram- matically the relationships of the Cretaceous rocks. Paleozoic, Triassic, and Jurassic sedimentary rocks were penetrated in the drilling of a few holes in the northern part of the Reserve, but only a small amount II: "" "- "- :::J II> :::J o "" u < --?- I- '" '" '" a: ~~~ u ... ~ --?-- of gas was fOUJld aese older rocks. Oilfields· discovered at Umiat and Simpson seeps and gasfi at Barrow and Gubik. Some shows of oil or gas .. also noted in other holes. The United States Geological Survey participated in the program as a cooperating agency. Drill cores and cuttings from the tests were shipped from the reserve to the Suryey laboratory in Fairbanks where they were processed, described, and analyzed. De- tailed subsurface information based on laboratory studies and analyses by the authors has been compiled by groups of related wells; in addition, logistic, engineer- ing, and drilling operational data have been abstracted from. the files and reports m.ade to the Navy by Arctic Contractors, United Geophysical Co., Inc., the Schlumbérger Well Surveying Corp., the U. S. Bureau of Mines, and the National Bureau of Standards. These data as well as a geological interpretation of the sub- surface information constitute this paper. ARCTIC COASTAL PLAIN PROVINCE Senbnel Hill member SCHRADER Barrow TraH member BLUFF ----------- FORMATION Rogers Creek member Ayiyak member SEABEE FORMATION ----- NINUI.UK FORMATION GRANDSTAND FORMATION GRANDSTAND FORMA rlON TOPAGORUK FORMATION II: "" ~ o ...J FORTRESS MOUNTAIN TOROK -------------.--? ?---------'----- FORMATION FORMATION ------------------------? ?-------------- LOWER CRETACEOUS <?)AND UPPER JURASSIC<?JROCKS. UNDIFFERENTIATED DKPIKRUAK FORMATION --? UNITS OF JURASSIC AGE - Not known Predominantly marine FIt:11BB 3.-Nomenclature of the Cretaceous rocks of northern Alaska. Predominantly "onmann. OUMALI K FORMATION Relationship of these rocks to those to. the south is unknown ~ . . 378 EXPLORATION OF NAVAL PETROLEDM RESERVE NO.4, NORTHERN ALASKA, 1944-53 165' 164' 160' 156' 152' 148' . \ t;~9 EXPLANATiON C 0 C E . C l' A- N G.. w.n It }. + Abendoned _.11 + 70·.. Dry hol. B ROO 164' o I '~O '~O 29o"4ILE& 50 . , I SOUTH BARROW TESr WElL -I 2 SOUTH BARROW TEsT WELL :2 3 SOUTH BARROW rEST WELL 3 .. SOUTH BARROW TEST WELL" ! AVAK rEST WELl. , . ,. 6 NORTH SIMPSON TEST WELL 1 13 OUMAlIK TEST WELt. 1 14 EAST OUMAlIK TEST WEl.lI 15 SQUARE lAKE TEST WELL"' 18 TITALUK TEST WElL 1 17 WOLF CREEK TEST WElL 1 'I WOLF CREEK TEST WELL Z 7 SIMPSON TEST WELL 1 8 TOPAGORUK TEST WrLLI 9 EAST TOPAGORUK TE5T WEll I . '0 FISH CREEK TEST WELL I 11 KAOlAK TEST WELL I 12 MEADE TEST WELL 1 70' .. .... .. "~·~~TlO~··········G ~ .. .' ....... IC I II , l 0 68' ----- 152' 19 WOLf CREEK TEST WELL 3 zo GUBIK TEST WELL,' 21 GUBIK TEST WELL :2 zz KHIF£Blþ.oE TEST WELL I Z3 KHIFEBlADE T£S1 WELLS Z AND ZA 24 GRANDSTAND TEST WELL 1. 2!1i UMIAT TEST wElLS 1-11 FIGURE Z-8.-Index map of northern Alaska 'showing location of test wells and oil fields. The United States Bureau of Mines at BartlesviJIe, Okla., analyzed a gas sample from Titaluk tešt weIll. . The assistance of the personnels of the above organi- zations is gratefully acknowledged. STRATIGRAPHY Titaluk test well 1 penetrated the Ninuluk, Chand- , leI', Grandst.and, and Topagoruk formations of Cre~ c taceous age (fig. 29). The much shallower Knifeblade test wel1s penetrated only the Chandler and Grand- stone formations. Lithologically, however, the section drilled in the Knifeblade test wells is similar to the same formations in Titaluk test weIll. ~ tJ) 0- W W :) f- a= 0 tJ) >- w a= tJ) tJ) C> a: w a.. a.. ~ ~ VI ~ ~ 0 :I: VI W ~ U < a: z w < I- ~ 0 z W ..J a: u ROCKS OF CRETACEOUS AGE NANUSHUK GROUP NINULUK FORMATION The Ninuluk formation of Late Cretaceous age is· the younge.st formation drilled 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 THE CHANDLER GRANDSTAND TOPAGORUK FIGURE 29.-Rocks of Cretaeeol1S age penetJ'ated by Titaluk test well 1. j ~ :j '~ ~ ~ ·'"ELLS, TITALUK AJ.,;""D KXlFEBLADE AR.LASK..4.. is/\) conchoidal 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 sn.ndstone 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 n, and rare mica. The siltstone is similar to cle·a vage 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 sub rounded to subangular and range in size near the base of the formation is 11.7-12 percent, and fron~ 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 a.s 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, dun 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 interbedcledwiththe COit! 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 - Theeffectlve porosity of the sandstone arid siltstone plates. Yellowish-brown clay ironstone concretions in both at'eas is low, ranging from 0.96 to 5.29 percent are present in the Ninuhtk, although they are not in the few samples tested. All plugs were impermeable. nearly as common as in the underJying Killik tongue Except for a 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 Titaluk test weIll examined or aas shows were found in the Killik tongue of the . t:> . by the Fatrbanks laboratory was from a depth of 40 Chandler formatlOn. feet. ,This was from the Ninulu~ formation and is Coal, carbonaceous material, and plant fragments essentIally the top of the formatlOn. (See p. 383.) are scattered throuahout the formation. Thè coal is !he total t~ickness of the fo:'mation in the !italuk area black, shiny to dull, brittle, and thin bedded. Very rare ts abo~lt 5:>0 fe~t. The Nmuluk formatIOn was .not small inclusions of clear greenish-yellow amber are 10und m the K11lfeblade test wel~s, as older f;>r:natlOIls present. Dark-gray carbonaceous shale is present above - only are exposed along the aXIS of the K11lfebIade and below the coal and elsewhere in the section. Black' anticline j' the Ninuluk formation is present off the plant impressions are found in both the claystone and north flank ofthe anticline, according to C.L. ''''hitting- sandstone, being abundant at some depths. These ton (oral communication, 1956.) impressions are fragmentary, and the plants cannot be Despite the presence of coal and carbonaceous beds, identified. . the Ninuluk formation is primarily. marÏI.le as ÍIlc~icated Very characteristic of the Killik tongue are clay iron- by the repeated occurrence of marine mIcrofossIls. . A stone (sideritic mudstone) concretions and laminae, few pelec~pods »:ere also ~ouncl. The f~w nonmarme particularly in the Knifeblade test wells. The clay beds asso:rated wIth the Nmuluk forrnatlOn are ?ngers . ironstone is hard, has conchoidal fracture, and ranges of the NIakogon tongue of the Chandler formatlon. from gray to yellowish brown. Brown dense dolomite KILLIK TONGUE OF THE CHANDLER FORMATION (or siderite n laminàe as much as 2 inches thick are found near some of the thicker coal beds in Titaluk test well 1. Tiny vertical veins of yeIlowish-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 KiIIik tongue. This mica The Killik tongne of the Chandler formation, 1,260 feet thick, underlies the Ninuluk formation in Titaluk test well 1 j 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 I , . . 380 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, J 944-53 givcs a silky sl1et>n to fractured surfaces. The sericite is most common in the lower part of the Chandler for- mation although some is aJso 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 plaeed at tIle first common occurrence of the Verneni7inoides borealis marine fauna. This is also the approximate top of a yery sandy section, the thickest sandstone bed of which occurs about 350 feet below the faunal top. The Grandstand formation in Titaluk 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 we112A 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- creases with depth. A few thin beds of conglomerate were recorded at the top of the formation in Knifeblade test wen 1. The conglomerate contains s:.rbrounded 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 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 wens and from 0.56 to 12.45 percent in the Titaluk test well. The highest air permeabili- ties were 325 millidarcys and 17 milIidarcys, respec- tively, although most samples tested "imp.ermeable." The low range of porosity in the Titaluk test well 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 wells, 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 Grandstand formation is argiI1aceous. A few feet of limestone (or possibly siderite or dolo- mite)-medium-dark-gray with a brownish cast, hard, argillaceous, with white vein calcit.e---was found in Titaluk test well1, but none was found in the Knife- blade test we11s. Most of the oil-producing zones in the Umiat field are in the Grandstand formation (Collins, 1957). In the KnifebJade test wells 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 11ave 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 somesman-scale crossbedding were noted in the siltstone near the top of the fonnationin Titaluk : test wen 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 irreo-ular to conchoidal fracture. These clayey beds are b _ _ mostly noncalcareous but are very silty in places ~nd grade to siltstone. - The clay shale has some micac.eous~ 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 Titaluk, than in the Chandler formation above. A few coal beds are near the top of the Grandstand in the Knifeblade test wens, but these beds interfinger with marine microfossil-bearing shales. The coal may rep- resent nonmarine st.ringers 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, ~s well as I1wcermnu8 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 congl?meratic, and there are more coaly beds. TEST .S, TITALUK A...l'm :Ki'HFEBLADE AREAS, aKA TOPAGORUK FO~fATION Only 520 feet of the Topagoruk formation was pene- trated by Titaluk test weIll. The Knifeblade tests were too shallow to reach it. In Titaluk test weIll, the divi- sion between the Grandstand and Topagoruk forma- tions is a well-defined lithologic change. The base of the Grandstand (also the base of the Nanushuk group) is placed at the bottom of the thick sandstone group. The Topagoruk formation is about 70 percent of clay shale and 30 percent of siltstone and a little sandstone. The clay shale is medium to medium dark gray and hard. The cleavage ranges from very good to very poor, and some of the rocks can be classified as claystone. Some of the claystone is calcareous. The siltstone is light to medium light gray, slightly to moderately calcareous, hard, has fair to good cleav- age parallel to the bedding and soine carbonaceous and micaceous partings. There are a few thin beds of very fine- to fine-grained quartz sandstone. Effective poros- ity in the coarsest siltstone beds cored was between 4; -and 6 percent, and the plugs tested were impermeable. A very pale cut of oil was obtained from one core near _ the top of the formation. The siItstònè and the clay shale are interbedded, some 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. TIT AL UK TEST WELL 1 Location: Lat 69°25'21" N.,1ong 154°34'04" W. Approximate elevation: Ground, 822 feet; kelly bushing, 840 feet. 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 U mia t. 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 drilled to 4,020 feet, at which depth it penetrated the Topagoruk formation 466356-59---2 381 which underlies the Nanushuk group. Only a few minor shows of oil and gas were found. (See page 394.) The formation contacts as determined in this test are as follows: Ninuluk_____n__________ 40-590 feet. Chandler _ __ _ n u u _ C _ _ _ _ 590-1,850 feet. Grandstand_n_____n____ 1,850-3,500 feet. Topagoruk_u__u_uun_ 3,500-4,020 feet, total depth. Field investigations by W. P. Brosgé, C. L. Whitting- ton, and A. L. Kover, U. S. Geological Survey, show that the Seabee formation of the Colville group of late Cretaceous age is present on the surface at the rig site. Samples representing the top 22 feet of rock were not received by the Fairbanks laboratory, but W. P. Brosgé 1 believes that this interval of rock, based on the well geologist's description, represents the Seabee formation. . The uppermost sample from 40-50 feet received in the laboratory contained a few microfossils which are distinctive of the Ninuluk formation. The elevation of Titaluk test weIll has been adjusted by W. P. Brosgé to the Umiat datum.2 All elevations and locations in the Umiat-Maybe Creek area are sub- ject to correction, pending the results of new topo- graphic surveys. - - STRUCTURE The Titaluk anticline is a long and narrow structure extending from a point southeast ôf the Meade River at lat 69°35' N., long 157°05' 1¡V. 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 Brosgé 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 well in excess of these figures. Contours on figure 30 are projected over the top of the anticline where the Seabee formation is erocled. 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 drillecl near the apex to this depth at least. 1 William Bros-gé, personal communication. . Datum used on the Umiat Special Map, a topogracphic sheet pub- lished by the U. S. Geological Survey in 1948. I ,~_.,~- . RESTRICTED FOR 'FFICIAL USE ONLY t ,¥ COP Y NO ..---¿Cl.::_-: ,\ ì\ I ''L.;" Uo So GOOLOGICAL Su:a.VEY lia:v;¡ Oil Un! t La.boratory hi rbankSt Alaska UIF.BmL.ADE 1'EST w.ELL NOo 2J. The Kiga.lik-AWUDa Area. was first traversèd. bya U.. So Geo1ogicSl Surve:r par_ headed by Po S~ Smith in 1924 (Smith9 i'. Sop and 14ðrtie, .J. Bo. JrH Geolog and mineral resources of northwestern Ala.£kag U~ . S., Geol. Survq :Bull. > 815ø p. 140 1930).. In the sumlIler of 1947 tI.. S" Geological ·SurveYt) Naq Oil Uni tl) PutT No.. a (\'Jh1 t t1ngton~ C. Loe and Troyero .k.. 1;0 I) Stratigraphy' and structure of the area of' the K1ga.1ikand Awna Rivers. Alaska: Geologicål :Report No" 17) made a. recoDnais- sance survey in the a%'eai> In the :tall of 1950 thè Knifeblade Anticline was res~died frOm aerial photoso and two shallow holes to det&rmine sand conditions of the Nanushuk were recommended.. One hole, Knifeblade No" 2. waste be drilled south of the major ~w reverse fault to test the Zone B-C section aAdthe othero Xnifeblade No.1. to be drilled north of the t,3.ult waS to test younger beds. A. transverse normal fa,1Ù t W8St of the well locations further complicates the struc- ture G Kni:t'eblade Test Well No. 2ð the first 001[3 drilled, ran into technical dif:t1cul t1es and was abandoned at 3733 ø The rig was skidded 2B' north and Knife- blade Test Well No. 3A was 4%'11184 to a total de'Oth of 18058 with a Bucyrus-ir1e Cable Tool Rig. Knlfeblade No.. 2A is 18~ structÎ1rally higher tbân Bo.. 2. The well was located at Lat" 690 8.38 N and. Long" 1540 44t W. Qµadrangle J-14" Elevation of the derrick floor was a.pproximately 7669 . The rig floor was 58 above ground level. 11 3/4 inch surface Câs1ng waS :aet at 3a... The hole ~enetrated the typl0alVerneuilinoides F faunal sone of the Cretaceou.s Nanushuk Group from llad to totai depth. Dips as determined from the cores are qui t8 steep, 'therefore the seotion is thinner than the apparent th1ckness10gged. !he upper 4008 of the hole contains coal and a.bundant ironstone. The sandstones encoun- tered at 465· are medium to coar,se grained at the top ot the section and become tiner with depth" These sands, on the basis of both 11 tholo&\, and m1crðpaleontolog are believed correlative to those topping at .3200a in T1 taluk Test Well No" 1. Some streaks in the sandstone a%'e hard and are moderately to very calcareous" Sandstones in thé upper half of the hole contain much set'ici te. Cl~ ironstone concretions and coal are relatively t'S,1:'ð in the sandy section" No good shows of 011 or gas were fou.nd althoug.lJ. most of tbe sandstones and 811.. etoneB contain small amounts of intersti t1a.l b:7. tumen or aapha.l tic residUe wh1che wi th CC14. give a. blaokish-broWJ1 cut. The well geologist reports tÞat the cores from the sande tone at 1035-1086' bled ga.s. Water entered the hole while drilling at 758-171 f ~ Upon completion of the dril11ngo the bole was bailed for two days" The "volume óf water proved sufficient to render bailing at the rate at 30 barrels :pe~ hour insig- nifieant upon the fluid level in the holed (Well Geologist's Weekly Progress Report lio. 9L The fluid level was maintained around 250t. 2?he salinity a.veraged 4000- 5000 ppm sodiwn chloride., , /~ fOO~3 . . The followingporo8i ty and permea-bili ty determinations were made: Q5!re .De'Dth Effective Porosi t¡ .Air Permea,b11i__ 1 3 6 7 9 11 14 18 19 20 24 172P 4661' ?58!' 792P 807:P 893P 1066F 1508. 15211'1 15571i 166lN 1600% 10007 10,,25 1402 20.,9 8093 9045 11~45 9074 11,,66 6013 4J. md" impermeable sample too snall to drill plug 103 ad. 325 mdo impermeable impermeable impermeable impermeable le.ss tban 1 md" im"ÇIermeable The well cuttings are ot good qual! ty down to a depth of about 16001 ø Below this point there appears to be a. considerable ~ount of loose sand cOJ?,ta.m1na.tion" No samples were taken iu Knifebla.de No" 2A froJ!Ì 190-336 0.. The same section (210-3550) in nearby Kniteblade Noo 2 was subs?i tuted on the graphic log 01 No" 240 All cores and well cuttings are described ÇÙ7. :Paleontolo pcal determinations v were made by B. 11.. Bergquist", ' Core and Well Cutting Desc~ipt1on 15-a> Cl~ sbalep medium. gra;r to d.a~~ f!;87 p 5% coal and moderate yellow! øh brown clqirol1stone.. '. Clay shaleo medium light grfq ¡o medium grqo also 10-20% medium light gray sandstone, medium ~~1ned. very tightc brownish sideritic matrix, also some mica, 20% mqf~ra.te yellowish brown ironstone a tra.ce co41. non-calcareous. . . Clay shale. medium light gr8¥o sJ,.1ghtly aU ty. trace sandstone Sandstone. medium light. gray ~9 Jnedium gr~. fine to medium grainedo 7r:1/a whi ie and clear quarh. b~ance is rock: fragments. dark chert. . coal particles and m1.cae trac~ fIlE!d1.um gray clq shalèo Coal ~o shiny to dull black and clc9¥ shale. medium grq to dark grq. l()'-þ of clq shale is lißbt brownish qq. Clq shale. medium light grq~ .·trace to 1016 coal. slightly 8il W and '~ < 8an"'V ~ Silt shale. medium light grB3~4 clq shale.· trace "db"V" sandstone Clq shale!> medium light gray';: . Coal. shiny black. 10% grqis~b~aCk clq shale~. Clq shale. medium €Jra3 md ~lc: grq. 155& coal. trace ironstone Cla;r shale, medium light gr8T: ',.~r¡ 9il ty. f;fþ dark grtq cl~ shale. Sandstone as below but some wi th yellowi sh cast-sideri tic cement. l~ dull to shiDl' black coal. ~ moderate yellowish brown c1q 1ron~ stone. . A . Sandstone. light graTo probably quite sotto medium grained. occasional coarse grains 0 sub~ar. 861& white and clear quartz. balance is coal particles and dArk chert. some mica. slightly calcareous in part. trace- coaJ.-97:-99~. trace ironstone 108-1133 ~ ,- '.;~ 20-30 30-47 47-49 49-56 56-61 61-64 64-69 69-75 75-80 80-87 87-90 90-113 2 113=123 123-128 128...130 130-137 137-144 144-148 148-152 152--168 168-171 Core - De-oth 171~174 1 173-185 185-190 190...335 210-225 225-235 235-245 245-250 25(}-265 265-.280 . . Clq shale ) medium light gr217 to medium gr8¥o some sandstone!! tra.ce light olive grar ironstoneo Sandstone 60%, fine çained. slightly calcareous" also medium gray claf shaleo trace clay ironstoneo 6il t shale. light gray and medium grq clay sJJale. Clay shale. mecUum light grq. silty and slight17 sandT. Sandstone. .medium light €£r1?J3't very fine to rare medium grained, ver:r 1t411't#" 9 sil V. 7\IÞ white and clear quartz. some coal, chertø up to 10% ironstone particles. micaceous (seric1 te) ø trace clq shale . Clq shale. medium gr37. trace sandstone" fi/¡ light olive grq iron- stone . Sandstone. medium l1pt grq. hard. silty to fine grained. 75% white and clear quartz. 2d/ø dark chert., coal pa1"tlcles, some mica, iron- stone particles. slightl¥ calcareouso Cla.Y shale, medium light gr~ to medium gray. trace silt shale. traøe ~rlte. . Sandstone. a.s in core below. l~ mec1iwn light gra¥ clS3" shale 0 fIjJ dark yellowish brow. clq iron~tone!, Recover,v 2,9 9" Sandstone. light graTo medium hard, medium grained, platy fracture. subangÌ1la1'ø "salt and papper"" 7ff1¡ vb! te and clear quar ts. balance is mo stl1' dark: gray and black chert. verT rare whi t8 chert and rare coal particles, argillaceous cement; nop..~caloareous: carbonaceous partings wi th 400 dip; ~d contains very rare blebs of bitumen. Dspt.h Ett,C,th's foro~i t7 ..Air PeØ1eabil1t7 l72t .. .. ..i. ).6,,0% .. 41 mLt.. Microtose1J;1 absent" ':f¡: Sandstone as in core above Cla3" shale, medium light grq 10 samples were taken in this "nterval" The following descripUon is taken from the same stratigraphic interval (approxo 210-3558) in Knifeblade Test Well Nc_ 2 which is looated only 289 south of Knifeblade 2Ao Cl~ shale. medium light grq to medium dark t:rq~ silty near tOPø trace coal, pyrite and olive gray ironstone. Clq shale. medium gray to medium dark grrq, 15-30% shiDl'-dull black coal Cla.}" shale. medium gaT to medium dark gray. slightly- sil f¥ and mi ca.ceous 511 tstane and smaJ.l amount of verr fine sandstoneo light grq to medium light grSTo micaceous, plant impressions~ . Sandstone, light grq to medium light gray, very fine grained in upper part of interval and medium gra.ined in the lower, 75% wh! 1;e and clear quartz, balance is dark chert. coal particles;! sericite in matrixo slightly calcareous . Cla;r shale. medium light grq to medium grq. trace of siltstone. finely micaceou8o 3 280=-295 .Q.gn 1 300-305 305-315 315-320 320-355 335-355 355-365 Core - De'Ðth 2 365-368@ 368-370 370-375 375-385 385-455 455=464 2.9Æ! Devth 464-46 7 ~ 3 . . Clq shale!! medium dark gray to medium gr9'8 & trace pyri tee coal and browni sh grq 1ronstone. De'Oth ~_C?.oven: Cl~ sbaleo medium grs:y to medium dark gr8T~ medium hard, good cleavage. one lj-lnch thick hard. slightly brownish gr8¥ clay ironstone concretion a.t the very bottom of the interval. shale contains occasional ~ite nodules; non- calcareous; d1p undetarminableo A few microfossil species abundant Coal 50%. shiq black and clay shale. dark gray to grayish black Clq shaleø medium gray to dark gray, ~ coal 305-31~g Clav shaleg medium grq and 30% very fine argillaceous slightl¡- calcareous sandstoneø bi tumen in sandstone C~ shale. medium gray to medium dark grS7,. 300-3039 18 0" Clq sbale, medium light gray to medium gr;qe medium dark gray and carbonaceous partings 340-345 9 . Sandstonee medium light grS¥ * fine to occasional medium grained ) 65% white and clear quartz, black coal particles commonp êla.rk chert. u~ to 10% interstitial sericite. slightly calcareouso also up to 4DCP medium light grq to medium dark grq cl8¥ shale. RecoverY' 19 6" 5il t shale. medium light grS¥ to medium grq., medium hard\1 poor to fair cleavage. argillaceouso ~ partings containing black carbonaceous plant impreasionso some streaks of very fine sand; nOD- calcareous; some ind.ication of dip up to 40°" Hi crofo s811 sabseJ;1 to S11 t shale 8~c medium grq and ~lq shale or clq stone wi th conchoidal fracture!! medium gf'8¥" Clq shale. medium gray to medium dftrk grq Cla;y- shale. dark gr<3¥~ carbonaceous !) 5-1~ shinT black coal 0 some medium light grq slay abaleo up to 2dþ medium dark gr83 a11 t sbalso C¡q shale 0 medium grq to dark gray 8 rarely medium. llßht gray 0 carbonaceous 405-4100, ail t¡- and sanà;r 430-4358 0 trace Wri te 445-455'. one shell fragment 43)-4359 0 .. Sandstone 0 medium gra-go medium to coarse grainedp grains subaD.ßUlar to mbroundede 50% wi te and clear quartlo 40% dark grq chert and bla.ck coal. ,non-calcareous, bitumen in sando also some clB7 shale in upper five feet of thie 1ntervaln Becoven 09 9" 5andstoruh light ßrfJ¥. med1u:c hardQ angular to subanglÙar grains. fine to medium grainedu II sal t and pepper" II 60% whi t8 aJld clear quartzo balance 4 Co~~ 46'1-470 470-545 545-560 560-570 570="645 645-655 656-665 .Q~ 4: 670';"705 105-730 730-750 750-755 ]!:j) t;g De'P th 665=667 a . . ;Rec9ye1?[ slmo st en t1rel)~ da:.-k gray and black chert;) argil= laceous cemantD in certain fragments the inteZ'= sticee are filled with a dark brown tarr,r materialg llon=calcaraou3, dip undetermi!l~d~ blackish-brow.n cut from center of interval Detlth .Eff'e~tJ"e Po_:Z:()Si~ Air Pªrmea.bill~-z 465 u . 10 -0 071' impermeabl a Microfosails absent sandstor>.so light grayo as in cora abov80 cleo 15% medium dark grq clEl¥ shs.le Sandstonso light gray tomec1ium gra"¥a rather loft except for calcareous streaks. "sal t and pepper" t fine ça.ined at the ba.se of the interval becoming coarse near the topo a few of ~e cOaJ'se grainß are rounded the rest ars subangu1ar to subroundedp ~ white and dear qU41"tz)~ coal pa:rticles and dark colored charta about 3Cf; of total roCk is ser1c1 tic materia.l==pI'obably- in matri:z:--gives "sheen" to rock chipBo Very caJ.careous in tn·¡¡erval 495-500G r. slightJ.¡- to moderately calcareous 005=-515Q 0 tra.ces of bi tume.n throu8hout 'J Siltstone or silt shalel} medill'J1 light grayo sand¥ near top of interval 0 argillaceous near b,aseo Clay shale 0 medium gr870 up to 10% medium light grq silt shale" Sandstone 0 light gr~ to medi·~'J1 light gr~e mostly rather softø fine to medium gra.inedo 75% lI1hi te and clear quartzo balance is dark chertp rock: particles ani coal -particlsfh s8r101 tic materia.l in matrix@ non-calcareous except for very calcareous 580=585~ and 615-6;09" Inooeramus prisms 5'70-5S0~" Traces of bi tumen . throughout '.nterval" 511 tstone and very fine sandst £)n8 60-80%@ medium light gr.a,y and cl~ shale 0 medium ÇB3 to medium dark grq Olaf shalso medium grayg sil~, 1n upper five feet "Inoceramus prisms" Recovery o a ì" Clay shale,} medium ~ra¥f hardo fairly good cleavageg alightJ.¡- to moderately calcareous" Microfossils a.bsent. Cla,y shaleo medium grq to medium dark grqo ail tyo trace of very fine sandstone toward the base of the intervalø Laevidental1um 695-705G . ---- Sandstone!} medium grS¥ to medium dark grqo medium grainedo sub= angu.lal'ø 70% white and clear quartz, bal.ance j. s dark cht!rt S!.lld qui te a. large amount of ca.rbonaceous material" C1S¥ shale9 medium grB3 to med:tum dark gra;¡e ail tyo Tra.ce of coal 730=736 a " Sandstone, light gray to med1w:alight gr8¥o fine to med1um grainedø grains subangular; 80% whi te an.d claa.r quartzo balance is rock fra.gments~ dark chert, coal particlas.-'some mica and pyr1tep non.= calcareous. some bitumen in siltstone. 5 QH,!:~ 5 760-170 .£SJ r~ 6 773",,789 Co.!! '7 '7!~2--605 De1)tJ~ 755=7580 De'ÇI~~'1 771~773~ ~ 789=792' . R~~ 2~ J.O It . SandstOD,Sr medium 11ght gray 0 medium hard.ø grains aubangu.la.¡·, fine to· medium çainedo 11 sal t and pepper" Ð 6(~ '1ßhl ta a.ï.d clear qu.a.rtßø i;>alancÐ of dark gra.y £illd blac:kch13:rt; other minerals I'aJ.·e; non-calcar.eous~ dip ,xndetermined; no shows pe'!Jth l~ffsctive~_~osit;v.: .~i_r ;Perm_eª~~l.i tJr 7589 10" 2iJi'O. Sample too ameJ.l to drill plugo Ni crofe sail s abean to Sandstone as in core above~ some coarse grainsÐ trace of bitumen, 1ie~()ye~ o~ 10:1 Sanda ton'3 " medituD. light grs"y to medium f;B¥Ð medium har4~ fine to medium grainedp some coar~e grain,sp 8Cì5f> white an.d clear quartzc baJ.ance mostly ~ark colored chart and some coal part1cls~J rare parting~ of angular black clastic coarfiJe grained coal particles; vary slightly oalc~~eous; dip undetermined; no shows Microf'ossHs abaento .Recovery Sandston~ a.s '.n core aDOiTSo medium graineð.o slightly calcare oUSo lQ 10" Sands ton,! 9 medium light gr8¥o medium bardø sub= angular ø medium grained~ "sa! t and pepper" Po 70% whi te and clear quartzo balance dark chartp coal particles. occasional other rare minerals argil- laceous cement; non-calcareous; dip undeterminedo no sha we De~th ~ffective Porosity 792ulj.C2% ---- Micrafos~ils absento Air PS!'II1eabillty 10 3 md~ SandstoneD medium light gray Q If mal t and pepperd 0 grains su"bangular to eubrounded with occasional coarse rounded dark chert9 7~þ white and. clear Quartzo balance mO:$Uy dark gX83 and bla.ck cherta W;d te commoD,@ trãoe of dark gray cl~ shale and coal toward the base "f the inte:rvalo 9çn DeJ;!th Recove~ e 805=807¡¡ 0' 01'1 9 807=809' 0' 10'" No recovexy Sandstonf!o medium 11ght çqo mediwn hard-a medium to coarse gl'ainedo It sal t and pepper" 0 compo 61 tion essentially the same as in Core 7 above~ 65% 6 S::_Q;~k1 B10=8J5 815,~8~~5 €85,,,SZ5 E·35~~a{O €~D=845 _Q.t~ 10 B ;15=850 S 50=86) 8 &0=893 ~~9.r.e 1..}. Ofm~902) ..th~~h ~ìÈ 845·-846 Q ~E!h 893=ß9§!~ . . Ê:.9º02~:Œ".l 1.1hU.13 a:o.d elsaI' qU3Xt'Z, VSlY calca;;rt;¡ous: !Þ.O ShCtiS De"at) ,êíIectiY_!':L;PQrc.~1~ 80?) 20,,9% M1cX'o:;oBsila a"bs:ení~. slightly to nOVr Ai;:_;.perm!3~biJ"i ~ 325 mda Sandstoue. li¡ght g;r~..,p Jli9dhw.gl"'aiD.edo as e.Dovee trace clay shale Sil tston60 r.l$riium ligl'lt {?;l't.'!;! to) medium g;ra;{ø U:fi to 20% sand5tone~ non-ca.lc)a,reou.s to veTil calca,r8")uEo Clay sl~le0 medium grayø 5=25% mod$rat~ly calce~eous siltstone Sil tstone a.¡::¡.d yery fine ßandat)v'89 medium light gra:yg moderately calcaree,u.a and mediwu gr:2~ cla;;r shale" Sandstor~e. light gra;¡~ fine to medium grained9 85% white and claat' q~.1.al"tsø bala.'lce i 13 dark chfJrt3 coal particles and rare rock frag= mentsD ver.¡'· calcareOu'!3ø alßO T,lp ·to 25% medium i?7aJ" cIa;'!' shals. Rsco"y,ª,Ei: 19 Oil Silt~tcneD light gr~~ hard9 some fine grained sand,y lam:i.;ì.a:¡h also a.bout 40% medium gay eil ty clSlf shala, hard, fair cleavage; moderately to very calca~eous; pcsaiolÐ dip of lSo Microfossi¿$ absent. Siltston$& madiwn light gr~¥D carbonaceouz partingsg moderately c~~careouao trace very fine sandstone Sands tons 0 1 igh t ça-;¡ Ð hardD 'lory fine to eil t stone e 85% wh:1 te and clear qu.arh" ver¡ ca.lca.l'ecus~ also up to 50% medium gray 0183. shale. . Cl~ S~~lÐ. medium gray to medium dark gr~g trace to ~ silt= s~to.!le 860=855 íI and 880=892," Ð ßlightly ·to moderately calcareous 880=893 ,) " Racovl!I!ri{ 00 7ft Sandstonao light gZ8Yo hardo very 6ilty==g:!1:'ades to ailtstoI\eÐ argillaceous, irregular fracture~ ver,y fine to fine grainadn p~imarily ~it6 and cle~~ quartzp soma dark chertD slightly carbon= aceo"Q,s and mica.ceou.s" one very small fragment of s rnol1ue¡c shell~ very slightly oalcareollsg dip about ~'û0. no odor. no. cu.t (well geologist repo~tß slight fluorescønce)9 slight greasy stain in ßvaporating dish f~om 8930 De1,1th !iffec·Uva~9rosl~r Air]?ørmeab"Ui}~ 8930 6,,9~ impermeable MicrofossilB very raX80 Sa.':1dston()~ light gr~a very fin,@ to f!!ilty)9o% white and clear quaxtz. alao dark chert. rare 1'0'*;: fl"agmentË1o 10-50% medium grrq clay shaleo ? £:t?~ l2im!h 1" '>! 9O~,>f¡05J 905=915 9J.5=92) 9:aO=95) 9;;0= lO()O lOOO~~li)lÖ lOJ.O=1~);35 l035=liHD a C oJ:! ~ø~ 13 lO4D~1042!) lO~':O=l066 10.{'O=l066 .~~=~ P!~o th 14 JW66=1070~ 10'fO=1085 . . RecoiJ'ab1T ---"--.:;:",&, 'l'J ~~?t SiJ. htone: m~dium light grq~ veq ha.rd~ argil~ 12.èe.;m.sf,;r~r;3ak!J of sa.n.d.~ recovery cons! ate mostly of ::13:;; chips U:~ to one inch in d.iameter~ abou.~ 4!J% of '¡¡hase chins are medium D'f'>ay c1~V' . _" b'" """ shâl~; norl·~~9l.ca.re,ouí3; d.ip 27 : no showß Microfoas.ìl spec181i! ra.:rÐo specimens common 611 tstone 50-SQ%@ medium light gJ:ð¥ and. olåY shale@ medium grEJ;f to m~dium da.rk ç83'. some vary sl:lghtly calcareous ve1.7 fine sa.nèLstoI1.e. Sandstone 80%" light graYø ve!';;r fine to sil t,.~ primarilY' whi te at'.d c1ear qua.r~.z@ modera.tely calca::aouso a.lso :30% medium dark j£ra¥ clay s:halso Siltstone 8~d aandstone in va~ying amounts) moderately calcarao~Ð 985-930$ 9 ""ery slightly Oa,lca2'i)Q1.\S 93&=940'19 up to 50% medhun gray cla;y shals 0 l.~ÿ'E¡!!ra.mu.s p4'1 am;3 900-940 Ii . C1S¥ shaleQ með..1ùmçB3" to med:11J.IT1 dark grfJ;;f II rarely medium light g::tag and dark gra:¡" very all t¿r a,.¡..d mod~ra.taly calcareous 950-960ft 0 sil V 990-10008 9 }..aevidant?J.i~AQ fragmente :found 955-960¡ and. 995= lCOO, Laavt.9.eE~al~µm and ¡~Q.~'~~aJ~ found 970-9758 <> Siltstonar medium gr8¥, alno vor;! fine sat~dstone~ slightly tiO ncn-calCa.1"sOu'th f/þ medium gra;;'l cliZ11' shale" Clay shale 0 medium dark gr~~odark &:ay~ slltYotraca vary- cclcarsQuß £iJ.ts~one 1020-1025" ¡, EfI, medium light gray very slightly calcareous $Ill t9tona 1030-10351 0 Sé'.ndstone. light t¢ei¥ p h'lrdo 'm:r;¡r fine gra.inedo 85% whi te and clea.r quartz 0 ba.lance i 5 dark chert and. coal particlese sl!ßb.tly calca.r- eous. some medium gr~ cl~ s141l~o Recovey OQ 2" Sandstone., light g;¡:ay~ hardo very fine grained~ grains ßu1ì.flllgularð 80% w.hi te s,nd clear que..rtzo. balance mOßtly dark chertQ carbonaceous particles and some 1J¡.o ti t'8; 'ver-J slightly calcareous. d.ip undeterminod. sxce8ding~ faint odor (?)~ well geologist :i'aports Cores 13-15 bled ga.s" ~UcrQfo8sila ;fery Ji.'arøo S,e.:a.d.stOI1S as 1n core a.bove~ 5~oJ.5¡~ medium g::ay clay sha.le Recovs;rz o~ 911 Sand~tone0 light grayg hard~ vsr,r fine grained to silt Yo compo~ition aß in Cora 13 aboveø V6T,1 slightly G~~~areoua; dip approximately 230~ ver,y "Wary fain;.~ QdcI'o very very pale yellow cut an,d grea,9Y 1'98:tdtw in eva.porating dish DeTI~b, }1;.e:f.§cti'y"eF'o14os}~_~ ,~ir Pe~li:r 1066 9" 45% impermeable Hicr';:¡,foss:U.13 ver-;f l"arÐ,. Sandstone as abov6Q trace?! clad shale l080-1085Go <[) ~~~ QOI'! ~th 15 1084-1086g l085~lOS'5 1095=1100 110Q=11W llZ"J=llfO 115Q~1155 115-5<-1160 116fj=l185 :U8,'5=1200 1200=1210 1210=1220 1220,=1245 1245~1265 1265=1.270 1270=128:) :~or~ Ds'P !h ," ..'0 128l-1283~ 1285..,1306 . . ~ O' 91$ Siltstone, medium light gra7. hard & irregular tra.cturé~ occasional sand grait1Sø rare black: carbonaceoìJ.s plant impressions; vS'r'J slightly to moderately calcareous; dip undetermined. Microfossils Vèry rarso Sandstone a very tine to siltstone. slightly caloareousg 15% medium UEq clsy ßhale Siltstone, medium gray to medium dark çayQ 40-60% clay shale 0 Cl~ shale" medium light g;ra:¡ to mediwn (Çt!ilh up to 40% 1311 t ehaleg non-ca.l ca..reou s 0 Siltetone& medium light gray t~ mediuw'gra7ø ar~llaceous. 10=50% medium gZ'aJ' to medium dark gr3;l clay shale. plant impressions 114.0-·11t],5" D Clay s~J.eD medium dark gr~ Sil~ clay ßha.le and argillaceouß siltstone. medium 11gh~t gray to medium ds.:rk grr:qo !=a.av1d~t~lwn :f'raßlIlents and ID.oC~tTa.P~us pri sm$" Cla,y sÌ1£Ùap m:3dium dark gray & traœ s:J.lt s.ba.le 1165-117010 One piece of aragonite stained with bitumen 1180-11851. 511 tstone and very fine sands tons/> medium grBJ' to medium light ff:ray9 non-calcareous to moderately ,3aJ.aareouso also 10-30% silty cl~ shalso Sandstone~ medium gra::rø hardQ ·very :fine grained. 7C1/o IIh1 'lie and clear quarUo maDY carbonaceou.s particles and some black chert and mica" a.rgi11aceouGp si1tr. slightll to ver,y calcareous. some interstitial bitumen present. 3il tstonsQ some very fine sand.stone and ala¡- shale Cla,y shalef medium dark gray. silty. Sandstone. medium light gray to medium gray. ba.rdQ very fine grained toO 9n ty. gra.ins subangu.lar to su-õrounded. primarily ",hi t6 and clear quartze al so dark cher·to coal pa.!'ticles. very calcareous in interval. 1260-12651 c Sil tston.e at'\d sandstone. medium light gray to medium çaye sligh.tly to non~calcareouso Clay shale, medium dark grayQ ver,y si1tYD some siltstone and sandatoneo R,!co,very 0$ 8" 511 t shalt~o medium grave hardp fa.ir claa"Vageø arg111aceousD al so some ver:¡ :tine sand.) carbon- aceoua=mi <:acaous partingsg Wri te has replaced the mat::ri:t through t inch of the corei) small amount of hrownish crystalline caJ.ci te in partingst f31ightly calca.reous~ dip 2100 Microtossns absente Sandstone. medium light grayD rather softr silty to fine grained~ 8~ white and clear qua.rtz~ balance is rock: fra.gmsnte and dark cr.e:rt~ 5=1~ medium dark gr~v clay shalso 9 13C'5=13:.0 1310~1325 1325-1335 1335".13<;10 1340=1&15 1355=l4(:0 1400=1415 14150= 14;1) 1420= 14.."15 1426=144ß 1445=1480 1460=JA65 1465=14'('9 Co%'& Ds'P tl?- 17 1479~1'181 ! 14$1=1495 1495-1605 15.')6=1507 . . Cl~ shale 70%. medium dark gray and very fine sandstone and 1311 t= stone, Sandstone, Juedium light gray0 very soft, very fiJle ßl'aiJledt gra.ins subangular to subroundedb 90% 1.\1h1 te and. clear quartIc also dark che~. coal fragmenteß trace cle¥ shaleo Siltstoneo medium light gr~ to medium g;r~, mostly whits and claar quart~, roc~ fragments, non-ca~careous to slightly calcareous. also 2(}j'o medium dark: gray claJr shale" ~aevident$l1W11 fragment. Sandstonec1.ight grtð3 to medium light gr8l{ø very fine to fine grained" ¡¡¡oaUT white and clear quartz. rock fragmentso non- to slightly calcareous& also 2(1ß medium dark grq clay shaleD L~evident~ium and crinoid stem ossicles~ Ciq sba.le.; mèdium grq to mediu.m dark grq~ æ-5~ sandstone in the lo~r part of the interTal, vary fins to :fine grained" sandstone i:i mo dera hJ,y cal careous 1350-13550 e t 1'aC;¡; coal 1345-50 ~ ;) Sanda tone a light g'1:8i¥9 :tine grainede probably rather soft" sUbangalaro 7fJ{o wh1 te a'1d clear qu.artz~ coal particles. rock fragmentsøllon... calcareous to moderately calca~eous0 up to ~ medium dark gr~ ol$f sbale. Inocaramus 'Prisms 1395-1400iJ. . Clay shale) ~roedium- gra;¡ to medium dark gra.ys silVa up 'to 40Í medium grq ail t shale Silt ahale. medium light g'1:8¥ to med1wn Ça;¡D san.<\ve 10% shiny bla.ck COalð Clay sha.le. 80% medium dark g;r~~ sandstone" light gra::fp very fiu<8 grained" 5% ooal".In9'<:EJ~am~~ p1'1 UlSo Sandstone. light gray. fine grained. e~ ~hite and clear quartzr moderately to verycaloareous 1430-1440- ~ 20-50% medium gra,y to medium dark gray cla;y Cla,y shale. madium dark gra:yø5% coal 1445-14051 d Siltstone ô~o medium light gray. argillaceous and medium dark gra:y clay 3b.al e Cla;y sr.aJ.a 70-90%" medium gra;¡ and medium dark gra;yg some ail t ahale and v~ry fin.e sand.stone) med.ium light t:ra¥9 moderatel;:r calcar- eous 1465=1'17030 trace coal 1410""1475~. 1.noceramu$ prisms 1.475-148580 Raco'Ver,y 09 9" . Cla.v sha.l'3) medium dark gI'q. hard. fair claavagt\h rar-Ð mica~ðo'la partingsg ver:¡ rare slightly ail ty lighter colored laminae; non-oalcareous; dip undetermi~~d; possibly 250n Microfossils absent. Clay sÞ.a.la. medium {Ç8.'3 a.nd II1L,dium dark gr:iJ¥ ~ very eil ty Sandstone (samples mostly loo3a aand)e light gT~o fine graiAsdø non-calcareous" 155& medium da:rk grB3 clay shale. Cl2¥ shale ßQ7ba medium dark g;r8Y and. also light grB'3Ð slightly Calcareouso fine grainad sand~toneo 10 CQrs '~.. 18 151Do·1615 Q..Q!:! 19 1520...1557' f9.!.! 20 1560~"158:) . £.2L~ 21 peu ~~ :L507=1.5:!.O ij D~th 1-.511~1E>31! Depth 155'1-1-.560 ¡ De' ) th 1580=15846 ::R.ecovett l@ 0" ¡~ 0 eampl e -ªecove~ 28 10" . . SandstonG~ medium li~ht gr~~ hard. massive. fine gTa.inedg £ubrounded to subang¡..1laro 90% white and clear qu.artz~ bal.a.nce is dark chert~ rock pal"ticles., mica and rare minerals, argillaceous cement, browuish c~st to some of the quartz grains; ~ssen= tially non~calcareous; dip undetermined; ;fleeting odor on fresh fracture. straw-colored cut, olive ,-e1101ll: residue. Ae~th .Et'feètiye P()1'Osi'tY .6\11' Permea-þl).j. t,Y lSOaN 11~45% i~per~eable Microfossils abseni Sandstone, as above, 8~ whi ta and clear qu.a;rtz~ non-calcaraous;d1p undetermined ~'PthEffactl,vâ :Porosit;r Air"P~rl!;~ª,'21Hty l52l!:! . 9..7~ira:permeable Microfossi1a absent Sandstone (sa¡nples mostly looss sänd) , light gra:fø vary fine to fine grainedl1 grain.s su"bangt11ar to subroW1ded~ 85% whi te and clearqua..'!'tz. also dark chertß coal ~articl~s, rock fragmentso rare m1ca~ slightly calcareou.s. 30% medium - g-rq to medium dark grs;¡ clay shale 1545-1550 i ~ traCe to ~ clay shale éls8wh3ret some silt sþ.ale in lowest part of interval., Recover¥ ,2' 0" Sandstone) medium light gra:h ba.rd~ sn ty to very fina graiZ1,~d9 subr<fWlded to subangu.la.r¡) 90% white and clear quartz, balance is dark obert and. coaly particles8 argillaCèous cement; non-calcareou.s, dip undet~.rminedo suggestion of 5-15°119 fle8~ing odor~ no I:uto ve1:1' pale ;yellow residua from 1557') De-oth ]f':tect~ve Porod ty Air Permaabili tr 1557N -- 11~56í· les3 th2n·i~md~-- Microfossils absent. Sandstone as in. the cors abov() :E(e_c.o,,,er;r 3G· 5" ¿'\,rg:111ac6ous ail t shale sn.d so-me 0137 shaJ..s~ ¡¡1ediwn gr~þ hard" fail" to poor cleavage, oc:caBic',nal. streaks o~ fine sandø coar~er grained materi~l. oecarð toward bo-'·;,om of core, non-calcareol1.s~ dip 18-23°; no Bho 1ùiî . Microf'oss~,J.s absento 11 158,4-1590 1590~1607 Cor! De'Oth .- 22 1607-1610° 1610=1620 Q.Qri! Dept~ 23 lS2Q...16Z2~ 1625=1660 Cor€! Del)!h 24 liS61-1664' 166.<1-1690 1690.;.1725 . . Sil t shale" medium light gI't;q, soma loose sande fII, c1a,v shale Sandstone (mostly loose sandL light grq", ver:¡ :fine to medium gra1nedo g~ains subangularo 7$ light and clear quartso some dark grq and black chert~ %'oc11: fr~gmentaø coal partioleso no~ calcareousp trace ola1 shale Recover:{ 20 101f S11 t shal,~, 0181' shale and some ver:! fine sand= stone,. mediwn light grq to' medium dark gr3¥", Sand is 7~& white and clear quartz-maoy of the grains 111 th brown sta.in\) balance of grains are dark carbt)11a.ceol1s ma. terial. and some dark chert: sandstone :ls slightlT to moderately oalcareoue= or possi.b~r dolomitic a.s rock reach slowly with acid; dip undetermined; faint oily odor. dull yello'$' cu.t and brbwn residue from 1608' 0 Microfossils absento Loose sande :fine to medium gr~tnedo Recovery 1° 411 Sandstone 0 light gray 0 hard~ fair oleavage p2,rallel the bedd1l1t~, fine gra.ined wi th very rare medium grains" su.hrounded to subangtllarø 85% white and clear qua~"·¡;zo baJ.ance 1s mostly dark cherto some carbouac.aoue particles and mica., other minerals rare. rare argillaceous partings; non-calca.rsous~ dip ß.=.19° (' some cress-bedding; no shows Microfossils absento Sàmples mostly loose Sàndo 85% ~1ite and clear qUartzJ fine grainedp rarely very fine or madi urn !ì~9Q!~ry l~ 911 Sandstone9 light gra:.y, hard. :fine gra.in0d~ 90~ lmite Md claar quartza balance is dark chert~ coal and ?,C3ck particleso argillaceous csment~ oni9 'black barbonized=coaly plant :fragment 3'~ inchel'J long and 1/4 inch wide; non-caloareous; dip 8_H!0; no shows De~th !lfí~ct~7e1?Ol"osi~ Air Permeability . ~ l661N 6013,Tø impermeable ~HcrofoS5il3 absant~ Loose sand~ very fine to fine g:rainsde 85,r, whita and clea.r ,!ua.rt~@ oné chip clay l68o-l6S5~ Chips of sandstoneg light gra;;"f. 1191'7 :finee trace to a% ail t shale and trace clay ßhale. much Vêr,y fine loose sando 12 1'725-172'0 1730=1755 1755-1765 1765-17,(,() 1770-1775 1775=1780 1780-1785 1785-1790 1790-1803 Core - ~"pth 1803-1805 Q :::5 . . Silt she.J.ep m'3dium light, ga:j'g san~. inuch loose sand Sandstone!) light gra'!ø fine grainedo mostly 100M sando trace to ';JJ% cla¡- shale 1700-'174:)0 Clav shale v medium dark graT. a11~ Loose Band. light grq with o11ve cast. very fine to silty, gråins subangularc mostly white $1ld clear quartz~ $11 t shaler: medium light US¥g sandy. non-calcareou.s Loose sand. ver,r fine grained, some silt· Shale 511 t shaJ.sr medium light I!;rq~ loose sandø some cl~ shale C1a,y shale. mediwn grq, a11 t;r~ rare medium da1'lt itrSl' chipso No sample ,ª~COV8;ry. 2t 9" Closely i~terbedded claystone and siltstone with all gradations of ea.ch, medium grEfJ' to medium dark gr;q. hardo irregular fracture. non..calcareouB~ dip 21° . Mlci-ofoÌ!lsi1s very rarao -7: tJ ........, /) . _ J....u~ /t1;'J"fAf~jJ Florence Robinsonþ Geologist March 19ø 1952 13 ";. :,~. h...:'~ ,.. .__:...:::. . . "Old" , r.a\.')' \';ells (1944-S 3) Well Name Avak -, lOO-Oé}"?- South Barrow-l I()O -083 South Barrow-2 / ()O --oB(.f South' Barrow-3 laD "'76~ I south Barrow-4 I Ó 0 r- 08" i ~. F±sh Creek-l 'DO -t()ò j Glõandstand-l 100 -(þ5""3 . I i Gubik-l IOO-;},f) I Gubik-2 100 -:J:J;;) Kaolak-l 100 -GJ~ Knifeblade-l llJO - la./ YJ1:i:feblade-2 J OD - ~Q Knifeblade-2A Î:S "'ow K",,¡Þe. ol4.cJe 6- Ibb....td3 , ... . -,~ lo\eaåe-l Ou.'"I\alik-l IDO-f/</ Eas-t OUlnalik-l 100 -1/6- SimDson-l 1 ()Õ -I G, '3 Nð;fh S/",p~ø,.,-I 1(){)"OI'Y Squ'are Lake-l 100 _1.'(, Titaluk-l 10(;)- IQÖ Topagoruk-l JOÖ -1t16"' Ea~t Topagoruk-l I($J-tt16- Umiat-l 10D -Qo'ì umiat-2 /oD -QID Umiat-3 IOO-f}U Umiat-4 100 -(}I;). Umiat-S IDO -9/.3 Umiat-6 /00 -é)./I../¡ Urnia"t-7 If:)Ó -a/~:t¡ I Umiat-B /OD -;)1" ì Umiat-9 Jt; D -Q/1- . Umiat-lO ,()()". [)I 11 Umiat-l.l 100 -9/~ Wolf Creek-l J tp-11 ~ ). Wolf Creek-2 WO-:;l C'ð" ! Wolf Creek-3 '(i) -ì I&.) --.--.......-..-..- ¡.. \ .t : , 1 f , ì I , ·'1 j 1 , _"~ ._,"__._." ...._" -"0'_-'- .._",._~.__._._.~ . "Intermediate" Wells at Barrow. (l9SS-1974) ,. South Barrow-S 1(>6 -b~t5' South Barrow-6 , (ft) - ek;)o., .~ South Barrow-7 16D'-o'3D South Barrow-B /06(-031 South Barrow-9 16Ö"'ä3;). South Barrow-10 1t:D-033 South Barrow-ll ItP -63J.( ~ South Barrow-12 lóO-ò~ ~ , ... .^-.. .--..--.....--...--.....--".". ._·'_·..o~"·. ~ ....'~ . "15
