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1 McLellan, Bryan J (OGC) From:Schoessler, Allie M <aschoessler@blm.gov> Sent:Monday, March 17, 2025 12:02 PM To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC); Garcia, Stephen B Subject:Re: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Bryan, Please see the final updates for Knifeblade #1: 3/14/2025: P&A Crew spent the day continuing to rig down equipment. Cement in the 11-3/4” x 8-5/8” annulus had dropped over 12’ from the surface and will require a top-off when the casing is cut. Nippled down flow-pan from BOP stack. 3/15/2025: This morning P&A crew started up the D7G and skidded the rig off the well. After the rig was out of the way they were able to lift the flow tank out of the cellar and nipple down the BOPs. The 8-5/8” casing was cut off at the base of the cellar, an inch below the 11-3/4” casing. Cement had fallen 5’ below the cut depth inside the 8-5/8” casing and fallen >12’ in the annulus. Half a super sack (12.5 sxs) of AS1 dry blend was mixed with 1bbl of water in an IBC tote, yielding 2bbl of cement slurry for the top-off job. A sample was taken and weighed 16.0ppg. A submersible pump was used to pump the cement from the IBC tote into the surface casing and annulus and complete the top job. Cement was wet at 1100 and was in place by 1200, 1.5bbl of slurry was pumped. WOC time of 6-12 hours on the top job to confirm that the cement has not fallen down the casing or annulus prior to welding on the marker plate. 3/16/2025: Cement had set-up overnight and was still at the top of the surface casing and annulus. The ¼” thick marker plate was welded over the top of the cut-off 11-3/4” casing with the following information: KNIFEBLADE #1 50-119-10012 PTD#: 100-121 US NAVY The plate is located 6’ BGL at the cut-off depth. The well is now plugged and abandoned and coordinates for Knifeblade #1 wellbore are: 69° 08’ 35.48” N, 154° 41’ 35.47” W. The excavator remained on-site to finish work back-filling and cleaning location prior to demobilization. This will be the final report for Knifeblade #1. Please let me know if you have any questions. I will send the final sundry report once available. Allie 2 Photo from 3/15/2025 - wellhead cut-off Photo from 3/15/2025 - Top off cement 3 Photo from 3/16/2025 - cap in place after top-off and WOC. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, March 17, 2025 8:21 AM To: Schoessler, Allie M <aschoessler@blm.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: RE: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Allie, Do you have any photos of the well casing and cement after it was cut below ground level, and photos after the marker plate was installed? Thank you 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: Friday, March 14, 2025 1:23 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Bryan, 4 Update for 3-12-2025: Last night the 8-5/8” x 11-3/4” annulus was thawed and a capillary tube was run down the annulus to 50’ from the base of the cellar. The 11-3/4” conductor casing was only ran +/- 52’MD from ground level, so it is believed that the annulus is completely thawed all the way down to the conductor shoe and there is no cement present. This morning P&A crew started up rig and opened pipe rams, fluid level in well had dropped 3-5’ overnight. RIH dry from 900’-1000’ and stop to circulate. RIH dry to tag cement Plug #2 at 1018’MD . PU 10’ from TOC and CBU to displace entire wellbore with 9.8ppg KWB. Perform static test for 2 hours. Fluid level dropped 12” during the two hour span. Observed well for an additional 2.5 hours and observed 2” of fluid level drop. There is potential that there is communication between the 8-5/8” surface casing and 11-3/4” conductor casing now that the annulus is thawed allowing the fluid to migrate to the annulus then out the open shoe. The annulus was filled with 9.8ppg brine and was experiencing fluid loss out the open shoe. On the second fill the fluid level only dropped 2’ before stabilizing. Workstring was TOOH from 1008’ to surface. MU Arctic Cement Platform (ACP), RIH to 210’MD and set at same. ACP is set by dropping a ball down the workstring and pumping till shear pressure deploys the platform. While pumping pressure quickly built to 125psi and then broke over to 25psi, indicating the shear screws were sheared. TOOH to surface and confirm that the running tool was empty and the platform has been deployed. RIH to 190’ to stage for cementing surface plug. Closed circulating valve and pipe rams to secure well. Freeze protect equipment and hoses and shut down for the evening. Update for 3-13-2025: Started up rig and opened pipe rams, fluid level in well had dropped 1’ overnight, broke circulation with workstring at 190’MD and checked that all the hoses and valves were lined up to receive cement from the batch mixer. The KWB that had been pumped into the 8-5/8” x 11-3/4” annulus the day before was pumped out leaving the annulus dry and ready to receive cement. 5 supersacks (125 sxs) of Arctic-Set 1 dry blend were mixed with 10bbls of 70°F water, yielding 20.7bbls of cement. A sample was weighed at 16.3ppg and additional water was added to the cement slurry. A second sample was taken and weighed at 16.0ppg and cement was pumped downhole beginning at 1035. Cement was pumped in the 1.9” workstring with the pipe rams closed and returns taken up the annulus and out the casing spool valve below the BOP stack. When cement was observed in the returns the supply hose from the batch mixer was switched over to pump down the capillary tube in the annulus. Within a few seconds of pumping into the capillary tubing the tubing packed off, pressure climbed to 200psi and the valve fitting failed. At this point cement was top filled into the annulus until it was full. The capillary tubing was removed from the annulus. At 1100 cement was in place in both the surface casing and the annulus and P&A crew began TOOH from 190’ to surface. The remainder of the afternoon was spent cleaning up all the cementing equipment and beginning to rig down and prepare for de-mobilization. Shut down for the evening and WOC prior to cutting off the well at the base of the cellar. Please let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, March 12, 2025 9:14 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Bryan, 5 Update for 3-11-2025: Started up rig and opened pipe rams, strapped fluid level in well and found it had dropped 1’ overnight. Perform static test for 2 hours. No drop in fluid level was observed. TOOH with 1.9” workstring from 860’ to surface. MU tagging BHA. RIH from surface to 900’MD and displace well with 9.8ppg KWB. Fluid was 70°F going in and returns were 60°F coming out. Sample cup from Plug 2 cement job is still soft and has not fully set yet. Shut-off pumps, freeze protect equipment and hoses. Close pipe rams and circulating valve, securing the well. Shut down for the evening and continue to WOC. The shoe plug was tagged at 1018' this morning, withing the anticipated range. Fluid dropped a few feet overnight but there was significant cooling in the fluid temperature. The assumption is the fluid drop was from thermal expansion/contraction. A 2-hour static test is being performed prior to proceeding with setting the surface plug to ensure there are no other issues. If no losses then they will proceed with setting the ACP and pumping the surface cement plug today. Please let me know if you have any questions., Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Tuesday, March 11, 2025 1:01 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Bryan, Update for 03-10-2025: Started up rig and opened pipe rams, strapped fluid level in well and found it had dropped 10’ overnight. RIH dry from 1010’ and tag at 1217’MD. Began to circulate a bottoms up ~70 minutes with 9.4ppg KWB. Pump pressure remained constant at 50psi. No cement was observed in the returns. Pumps were shut off and fluid level was monitored for an hour. The level remained static for the hour observation period. At 1118 began batching cement for Plug 2. 4 supersacks (100 sxs) of Arctic-Set 1 dry blend were mixed with 8bbls of 70°F water, yielding 16.5bbls of cement. A sample was weighed at 16.7ppg and cement was pumped downhole beginning at 1156. Cement was pumped in the 1.9” workstring with returns taken up the annulus between the workstring and 8-5/8” surface casing into the flow tank. The tank was strapped prior to cementing so that returns for the job could be calculated. There were returns for the duration of the cement job. At 1220 cement was in place and P&A crew began TOOH to 860’, pipe was dry as cement had already begun to U-tube. Flow tank was strapped after the job and calculations showed 11.25bbls of returns for the cement job. With workstring at 860’, KWB was circulated in the string to clean out cement. The remainder of the afte rnoon was spent cleaning up all the equipment and occasionally circulating the well with 70-75°F KWB to keep everything at a constant temperature and thawed. Well was secured with pipe rams and the circulating valve. Shut down for the evening and WOC. Plan for today: RIH and tag TOC late afternoon /early evening. Please let me know if you have any questions, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, March 10, 2025 11:15 AM To: Schoessler, Allie M <aschoessler@blm.gov> 6 Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: RE: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Thanks for the update. 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: Monday, March 10, 2025 10:23 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates Good Morning Bryan, The plug was tagged at 1217' this morning. They are gearing up to pump another cement plug at the shoe. Based on time for the first plug we will monitor for 24hrs before going in to check TOC. Please let me know if you have any additional questions, Thanks! Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, March 10, 2025 9:45 AM To: Schoessler, Allie M <aschoessler@blm.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: [EXTERNAL] RE: Knifeblade # 1 P&A Daily updates This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. 7 Allie, Since the cement wasn’t tagged where it was expected, does BLM plan to pump an additional cement plug? Thanks 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: Sunday, March 9, 2025 6:15 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: Knifeblade # 1 P&A Daily updates Bryan, Update for 3-8 and 3-9: 03-08-2025: Opened up circulating valve and pipe rams and broke circulation. Hole took 5bbls to fill before getting returns. RIH to 1244’MD and tagged up at the same depth as yesterday. Reciprocated workstring while circulating KWB to condition hole. Cement head was made up to workstring and P&A crew began mixing cement. Cement was wet at 0955. 4 supersacks (100 sxs) of Arctic-Set 1 dry blend were mixed with 8bbls of 70°F water, yielding 16.5bbls of cement. A sample was weighed at 15.4ppg and cement was pumped downhole beginning at 1038. Cement was pumped in the 1.9” workstring with returns taken up the annulus between the workstring and 8-5/8” surface casing into the flow tank. The tank was strapped prior to cementing so that returns could for the job could be calculated. There were returns for the duration of the cement job. At 1056 cement was in place and P&A crew began TOOH to 850’, pipe was dry as cement had already begun to U-tube. Flow tank was strapped after the job and calculations showed 22.75bbls of returns for the cement job. With workstring at 850’, KWB was circulated in the string to clean out cement. Well was secured with pipe rams and a valve on the circulating line. Shut down for the evening and WOC. 03-09-2025: Fluid level dropped roughly 54 feet overnight. Fill hole. RIH and no tag by 1200'MD. Circulate, get some cement returns but only a small amount and then back to normal brine density. Circulate at 1200' for bottoms up with no further cement returns. Let hole remain static for 1 hour while monitoring. Fluid level dropped 8 inches. Hole is fairly stable, decide to give cement more time to set up. Plan for tomorrow: check fluid levels, RIH for tag, add cement. 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. 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Friday, March 7, 2025 2:01 PM To:Schoessler, Allie M Cc:Rixse, Melvin G (OGC); Garcia, Stephen B; Chmielowski, Jessie L C (OGC) Subject:RE: Knifeblade # 1 P&A Daily updates Allie, I agree with BLM’s plan to place a 200’ cement plug from 33’ below the surface casing shoe, recognizing that further attempts to get deeper into the open hole have elevated risks of getting stuck. 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: Friday, March 7, 2025 1:51 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: Knifeblade # 1 P&A Daily updates Bryan, Update from this afternoon 3/7/2025 They are in OH tagging up at 1244' (33' below the shoe) and getting overpulls as they are attempting to get deeper in the well. Overall the well has taken 1.4 bbls from surface to 1244' but has otherwise remained very steady. Right now they have pulled up into the shoe at ~1160' to await further direction. Recommended from onsite personnel to not go deeper and begin prepping for setting the shoe cement plug. BLM engineering staff agrees with the recommendation and will request that adequate clean-out and prep is conducted to ensure the best cement plug success. 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. 2 16.2 bbls of cement will still be pumped resulting in at least a 200' plug. Please let us know if you have any questions or concerns by COB today March 7th, 2025. I have attached the P&A plan for convenience. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Friday, March 7, 2025 7:23 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: Knifeblade # 1 P&A Daily updates Bryan, Report for 3-6-2025 - Batch additional kill weight brine (KWB) to 9.5 ppg in flow tank. Hole fill was calculated to take 18.5-19.0 bbl to fill the ~300’ of evacuated casing. Cracked open choke/divert line to check for trapped pressure prior to opening pipe rams, no pressure was observed. Filled hole with KWB and got returns at 0945. Returns had chunks of ice that were circulating up-hole. RIH and tagged up at 390’ (previous tag from last evening was at 352’). Circulate KWB and thaw in hole, fluid was 80°F going in and returns were 60°F. Ice became intermittent between 600’- 700’. At 700’ workstring RIH free. Made hole to a depth of 810’, circulated KWB 100°F in and 70°F out – returns appear clean. Freeze protected equipment and tied down loose items/tarps as wind is picking up. Closed circulating valve and pipe rams to secure the well for the evening. Todays operations will continue with thawing/circulating towards planned depth of plug #1. Please let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, March 6, 2025 9:38 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: Knifeblade # 1 P&A Daily updates Bryan, Yesterday was the first day of well work: 3/5/2025 - This morning the iso tank filled with pre-mixed brine was brought over near the cellar to transfer from the iso into the flow tank. The water trailer was brought down to the wellsite and water was transferred into the flow tank and mixed with salt to achieve a 9.5 ppg kill weight brine (KWB). Flow pan was nippled up to the BOP stack completing the rig up on the well. An accumulator drawdown test was performed and the pipe rams, blind rams, and choke HCR were all functioned to ensure operability. The accumulator unit is set to kick on the charge pump at 2200psi and shuts off at 2700psi. A safety meeting was held to discuss roles in the event of a well kick incident and operation of the BOPE. 1.9" workstring was then RIH with a mule shoe on the bottom string. KWB was circulated at 80F in and 80F out for the 3 first 45' of hole. At 45 the first ice plug was thawed through and KWB began flowing out of the well. The pipe rams and circulating valve were closed to shut in the well. The choke/divert line was then slowly opened to bleed off any potential trapped pressure on the wellbore, but no fluids flowed into the divert tank. After confirming there was no trapped pressure, pipe rams were opened, and operations resumed RIH. Workstring was RIH to a depth of 352' where it tagged up. The circulating hose was hooked back up to the workstring. Lines were freeze protected, the circulating valve was closed, and the pipe rams were closed securing the well for the evening. Please let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, March 5, 2025 12:18 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Re: Knifeblade # 1 P&A Daily updates Bryan, 3/2/2025 - continuation of set up, BOPE, flow tank and diverter in place 3/3/2025 - build up the area around well for the rig 3/4/2025 - Skid Rig in-place and set up I flew out to site and took a look at everything on 3/4. Everything was looking great and met what was approved. Well work should start today so reports will be daily. Let me know if you have any questions! Allie From: Schoessler, Allie M Sent: Saturday, March 1, 2025 7:00 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Garcia, Stephen B <sbgarcia@blm.gov> Subject: Knifeblade # 1 P&A Daily updates Bryan, 2/28/2025 - excavation completed. Casing measurements confirmed: conductor 11-3/4" and surface casing 8-5/8" 3/1/2025 - starting head welded on. Water/ ice was in the annular space resulting in some damage to the surface casing. 4 Wellhead prep will continue tomorrow along with rig up operations. 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 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 T %UDQFK&KLHI(QHUJ\ 0LQHUDOV )HEUXDU\ $ODVND6WDWH2IILFH WAYNE SVEJNOHA Digitally signed by WAYNE SVEJNOHA Date: 2025.02.28 12:30:05 -09'00' Bureau of Land Management CONDITIONS OF APPROVAL FOR SUNDRY NOTICE – NOTICE OF INTENT Olgoonik Oilfield Services (OOS) Plug and Abandon Knifeblade #1 USWN: 50-119-10012 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. BOPE systems shall be in place and function tested when appropriate, if removal of BOP stack is necessary prior to the approved procedures plan, the BLM P.E. shall be notified for approval. 3. 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. 4. A well identification plate shall be welded into place in accordance with 43 CFR 3172.12(a)(10), however the identification shall include the following: - Well Name - US Well Number (API Number) - Operator: US Navy - State of Alaska PTD Number 5. All tubing/drill pipe used for cementing operations must be removed from the well. No tubing/drill pipe may be cemented in the well. 6. Backfill of excavation may be completed with native soil. A mound of material must cover the excavation areas so there are no low spots. If a low spot or additional fill is needed it shall be addressed in the summer 2025 site visit. Reporting Requirements: 1. The Operator must submit a revised Sundry Notice (3160-5) for approval prior to deviating from the approved plan. An oral approval by phone may be given should circumstances warrant. However, this does not waive the written requirement which is to be submitted within 5 days of receiving verbal approval. 2. Within 30 days of the completion of operations, a Subsequent Report on Form 3160-5, Sundry Notice and Reports of Wells, shall be submitted to the BLM Alaska State Office, Branch of Energy and Minerals. Notification Requirements: 1. All notifications and changes to the submitted Notice of Intent must be reported verbally or in writing to one of the following contact listed below at the BLM Anchorage State Office, Branch of Energy and Minerals: Allie Schoessler Petroleum Engineer/Inspector 907-271-3127 aschoessler@blm.gov Stephen Garcia Senior Petroleum Engineer 907-271-3159 sbgarcia@blm.gov After Hours Contact: Allie Schoessler 907-202-2445 February 28, 2025 _________________________________ ________________________ Allie Schoessler Date BLM, Petroleum Engineer _______________________ e Schoessler Olgoonik Oilfield Services | Plug and Abandonment Program Knifeblade #1 (PTD #: 100-121) Knifeblade Cluster Well Remediation NPRA, Alaska February 2025 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 #1 Well Olgoonik Oilfield Services | General P&A Design 2 VERSION HISTORY Table of Contents 1 General P&A Design......................................................................................................................................... 3 2 Equipment & Supplies ..................................................................................................................................... 3 2.1 Surface Equipment ................................................................................................................................... 3 3 P&A Procedures ............................................................................................................................................... 5 3.1 Knifeblade #2 ............................................................................................................................................ 5 Table of Figures Figure 1: Proposed BOP Drawing ............................................................................................................................ 4 Figure 2: Knifeblade #1 Current Completion Schematic ........................................................................................ 9 Figure 3: Knifeblade #1 Proposed Plugging Schematic ......................................................................................... 10 Figure 4: Knifeblade #1 Annuli Diagram ............................................................................................................... 11 Version # Implemented By Revision Date Approved By Approval Date Reason 1.0 Zach Sayers, P.E. 1/13/2025 James Nunley 1/13/2025 Original permit submittal 2.0 Zach Sayers, P.E. 2/25/2025 James Nunley 2/25/2025 Revised permit submittal 3.0 Zach Sayers, P.E. 2/28/2025 James Nunley 2/28/2025 Revised permit submittal Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 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 Drilling Rig o Boart Longyear LX10 o Dressed to handle 1.900” work strings x Well Control Equipment: o 7-1/16" 5M Double Gate Hydraulic BOP Stack o 7-1/16” 5M flow Cross o 2” 15M Choke Manifold o Hydraulic Accumulator x Portable Cementing Equipment Including o 80 bbl Cement batch mixing unit o Triplex Pump used for cement x Fluids Tanks o 200 barrels of storage tank capacity to contain circulated well fluids. o 42 bbl Rig Cellar Tank o Waste/ Slop Tank x Boiler Unit x Transfer pump, with Backup Pump, Heaters, Pipe, hoses, valves, fittings x Track Loader x Excavator x Well Equipment Tools and Hose Parts House x Plug and Abandonment Marker o Operator o Well name and number o API Number o PTD Number Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | Equipment & Supplies 4 Figure 1: Proposed BOP Drawing Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | P&A Procedures 5 3 P&A Procedures 3.1 Knifeblade #1 Knifeblade #1 was drilled in October of 1951. After drilling and setting 52ft of 11-3/4” conductor casing the well was cored and drilled down to 1,211 ft. The well was drilled / cored down to 1,805’ before leaving the well as-is and moving to the Knifeblade #2. Based on the Summer 2024 site visit the well has a 11-3/4” casing stump sticking up with the 8-5/8” surface casing inside of it. The well has no wellhead installed and is open to atmosphere. No oil or gas leaks were noted during the 2024 site visit. 3.1.1 Well Assumptions: x Thermistor 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 clarify that it intends to make use of a BOP system for the thaw out of this wellbore to provide a safety barrier in the event a hydrate was thawed or a gas bubble was thawed up. Upon completion of the cement abandonment of the perforations and subsequent positive test, OOS wishes to clarify that the BOPs can be removed as needed as operations require. BOP stack removal shall not occur until any possible access to formation pressure has been confirmed to be sealed off and approval is given from the BLM P.E. x No pressure testing of the well over 250 psi will occur. The surface casing has a factory burst rating of 318 psi. Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | P&A Procedures 6 3.1.3 Fluids Program: Hole Size: Fluid Type: 8.017” ID csg NaCl Monovalent Brine system Density (ppg) Funnel Viscosity PV YP 6 RPM Gel Strength Salinity PH 8.6 – 9.8 26-30 1. – 2.2 – – – – 6,000 - 171,000 7.5 -9 3.1.4 Evaluation Program: 8-5/8” 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 N/A 8-5/8” Class G Artic Blend 15.4 ppg – 16.0 ppg 0.93 ft3/sx 10% CH 50% OH 16.2 bbl 1,111’ MD 2 N/A 8-5/8” Class G Artic Blend 15.4 ppg – 16.0 ppg 0.93 ft3/sx 10% CH 10.3 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 7-1/16” 5M Gate Rams Upper Ram – 1.900” pipe ram Lower Ram – blind ram Mud Cross, Single Gate KILL LINE 2” Line w/ 1 each 2” 5M Manual Valve CHOKE LINE 2” Line w/ 1 each 2-1/16” 5M Hydraulic Valve (HCR) CHOKE MANIFOLD 15M Choke Manifold, (x2) manual adjustable chokes, 2” Choke line w/ 2” inlet and 2” outlet, and 5 each 2-1/16” 15M valves (5 total) ACCUMULATOR 4 Station REMOTE BOP CONTROL none Maximum Anticipated BHP 781 psi* = 8.33 ppg x 0.052 x 1,805 ft (from formation testing) *assumes a 8.33ppg pressure gradient. From formation testing data available, the formation pressure looks to be less than 8.33, and no hydrocarbon zones were encountered. Maximum Anticipated Surface Pressure (MASP) 384 psi* = 781 psi – (0.22 psi/ft x 1,805 ft) *(should the full fluid column completely evacuated) Planned BOP Test Pressure 7-1/16” Rig BOP No BOP pressure testing to occur. Casing Test Pressure (8-5/8”) none Notes: Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 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. Excavate down 4-8' around casing to allow NU of wellhead. 3. Cut 8-5/8” surface conductor / casing. Dress for starting head. a. Inspect 8-5/8” x 11-3/4” annulus for cement to surface. b. If cement not found at surface, use specialty built capillary tubing and lower to 50’ Below Ground Level (BGL). Keep capillary tubing suspended for future cementing. c. Micro string of capillary tubing shall have an OD no greater than 0.67” and preferably 0.50” d. All joint must be beveled and welded, then ground down to Flush Joint (FJ). e. Should tubing not make it to 50’, contact P.E. for modification to later procedure. 4. Weld on starting head. 5. RU BOP, function test to ensure operational. 3.1.8 Plugging Operations: 6. Skid rig in place. Raise mast. 7. Verify current fluid depth in well. Collect fluid samples with a bailer per BLM TO requirements 3.8.4. If fluids are frozen collect samples during circulation. a. If well not full to surface top off with Kill Weight Brine. 8. RIH with 1.90” workstring. Thaw as necessary to a depth of +/- 1,211’ (bottom of surface casing). 9. CBU at surface casing shoe prior to entering Open Hole (OH) section. 10. Circulate workstring down to target depth of 1,311’ MD. 11. CBU and pull into shoe 12. RIH open ended and place balanced cement plug from 1,311’ to 1,111’ MD 13. POOH to 900’, CBU to clear workstring 14. WOC until cement reaches compressive strength 15. RIH, Tag TOC 16. Spot 9.8 ppg KWM from 1,111 to 150’ 17. RIH with 8-5/8” cement basket and set at +/- 150’. 18. Cement using balanced plug from 150’ to surface. a. Ensure that multi-valve cement head is rigged up to allow flow separation to the IA and the OA. b. After completing IA cement job, divert flow to the OA through the capillary tubing and cement until clean returns are seen at surface. 19. ND BOPs, prepare to release rig 20. Release Rig 3.1.9 Post Plugging Operations: 21. Using excavator, excavate around the wellhead to a depth up to of 6-8' below tundra level 22. Cut surface jacket and conductor if present 23. 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 24. Inspect all annuli a. Top-off cement in annuli as needed Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | P&A Procedures 8 25. 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 26. 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 27. 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 #1 Well Olgoonik Oilfield Services | P&A Procedures 9 Figure 2: Knifeblade #1 Current Completion Schematic Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | P&A Procedures 10 Figure 3: Knifeblade #1 Proposed Plugging Schematic Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order - 140L0624F0011 – Knifeblade #1 Well Olgoonik Oilfield Services | P&A Procedures 11 Figure 4: Knifeblade #1 Annuli Diagram Explanation Page Permit Number 100-121 These well numbers (typically beginning with 100) precede the beginning of the Commission. No permits were issued and no formal folder of record (information) created. Information known to the Commission through other agencies, journals, reports, news or additional historical means has been collected and entered into a database of Well History information. If specific information exists, these pages may be filed in this folder. Occasionally, the information has been obtained from a report that may deal with a general area and many wells. If or when possible, we may be able to 'point' the person interested in this specific well to one or more of these information sources. However, at best, this will be incomplete and independent research should be conducted to locate, if available, further information about a Particular well site. o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 v/7,eTHE STATE °f\ A L-aisel:°vatLorr Division of Spill Prevention and Response Ifitt - Contaminated Sites Program GOVERNOR SEAN PARNELL ® 610 University Ave. ALAS V. 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 Re: BLM Legacy Wells Dispute ;� MINED APP 2014 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, deaned 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 O J 0 CO T.O• m V V t m •N 0) 0 CO N V O 03 07 O-. ' '0 O C o C1 m m CO 0 co 0 m CO a co 0 m m m m CO CO m as �° �CU _ as V 0 y m m CO is CO m CO CO O N 0) CO CO N 0) 0 CO CO co CO Q) 07 C O a0.. 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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 stratigi•aphy? • Did the well have oil or gas shows, and if so, is the well capable of flowing? • Is the well near human activity, and if so are there conditions present that pose a risk to people? • What is the condition of the wellhead? Have there been any previous problems or repair work? Does the well (in its current condition) pose a risk? • What is the surficial condition of the existing pad and pits? Is contamination a possibility? • Does the presence of unplugged wells have the potential to negatively impact anticipated development? Each of the 37 wells are described in the following pages. Descriptions are ordered in terms of the ranked priority based on the above stated criteria and the concerns identified. Umiat Wells The early Navy wells in Umiat rank at the top of the list. Umiat is located on the north bank of the Colville River 60 miles upstream from the village of Nuiqsut. Natural oil seeps were discovered at Umiat by early explorers. This discovery, along with the detection of seeps at Cape Simpson, motivated the U.S. Navy to conduct a drilling program. Umiat and the Simpson Peninsula were the primary exploration targets in the mid to late 1940s. The Umiat seeps are still visible today. Their locations tend to shift over time. The seeps are currently active in Umiat Lake, just off the northeast portion of the airstrip and in a channel of the Colville River. ~\ ,~, 22 \~~ The 11 Umiat wells were drilled from 1945 to 1952. These wells are a concern for BLM due to their close proximity to human activity. Umiat is not a village, but serves as a camp for seismic crews: Umiat is also the primary hub for recreational activities in eastern NPR-A and western CAMA (Central Arctic Management Area). It has one of the few airstrips on the North Slope maintained year-round and is a popular location for purchasing aircraft fuel (Figure 10). The Umiat wells all lie within 2 miles of the camp, with the exception of Umiat #1, which is approximately 5 miles to the northwest. After the U.S. Navy completed drilling operations in 1952, the U.S. Air Force assumed custodial responsibility at Umiat and established the 8,000-acre Umiat Air Force Station. In Tune of aircraft. 1955 the Air Force returned the facility to the U.S. Navy. Since Umiat is a Fornierly Used Defense Site (FUDS), the U.S. Army Corp of Engineers (COE) is responsible for the reduction of risk associated with surficial hazardous, toxic, and radioactive waste. The COE has conducted extensive surface investigations in the area and has identified contaminants at several locations. Varying levels of barium, petroleum, pesticides, and polychlorinated biphenyl (PCB) were identified at the wellsites, the landfill, and the nearby slough (U.S. 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 drill hole penetrated several known oil and gas formations; Ninuluk, Chandler, Grandstand and Topagoiuk. Hydrocarbon shows were prevalent within both the Grandstand and the Topagoruk formations. Multiple sands were perforated and tested. Production exceeded 217 barrels per day, thus seemingly showing the benefit of using an oil-based mud. However, the muds did Figure 12: Aerial view of Umiat #9. not allow the different formations to be distinguished. Cement was used in an attempt to "plug back" and isolate individual formations. Samples were taken and sent to a Bureau of Mines lab where the chemical tracer (used during drilling) was measured and the various sandstone samples were examined. This allowed a study of the different lithologies be conducted. The tracer Aroclor used in the well has raised concerns about PCB contamination. However, the well was allowed to flow for seven weeks at 200 barrels per day (Robinson and Bergquist, 196) prior to shutting it in, possibly purging the potential contaminants. As it stands today, insufficient energy exists in the reservoir for the well to flow to surface and the wellhead has no pressure on it. The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the next 20 years and the well has the potential to leak to surface if development occurs and may adversely affect. future development. Surficial wastes around Umiat #9 could present an issue. As was common with early Navy drilling, a gravel pad was not created. Wooden debris exists around the wellhead and there is a pile of drilling muds directly to the north which is void of vegetation (Figure 12). Samples taken by the COE from around the wellhead detected elevated levels of diesel range organics (DRO), residual range organics (RRO) and PCBs (U.S. Army COE, 2003). 24 The wellhead is equipped with two bull plugs, a flange and a 2 3/-inch nipple. There are no fresh water aquifers in the area, but due to potential contaminants downhole and existing contaminants on the surface, the well does pose a risk to human health and the environment in its cun•ent condition. Umiat #6 Umiat #6 was spudded August 1950 to test the southern limits of the Umiat anticline. The hole was drilled to a depth of 825 feet. The well was cased to 35 feet and a 42-foot cement plug was placed on the bottom of the well in order to stop water influx from sands at the base of the permafrost. The well encountered very poor shows in the Killik Tongue (Chandler Formation) and a productive sand in the upper Grandstand Formation. Oil recovered in open-hole pumping tests was produced at rates averaging 53 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 55-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 theimistor 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 f, ,~ most well drilled on the _ '° '~°": Umiat anticline. The a objective was to further delineate the southern extent of the producing Figure 13: Umiat #7 summer and winter photos. field. The well encountered residual hydrocarbons in the Chandler and Grandstand formations. Oil recovered in bailing tests was so minute that it was measured in gallons. The small amount of crude recovered in each test is indicative of residual oil staining. The sands encountered in Grandstand are downdip of the productive reservoir and are water bearing. Minor gas shows were encountered at 260 feet (Robinson and Bergquist, 1956). The well is located within the Northeast planning boundary (see Map 2) on lease AA- 081726. There is some potential for future development to occur in the area within the 25 next 20 years but since the well is located below the oil/water contact it has less potential to be adversely affected or affect future development. The wellhead assembly consists of 7-inch casing (with collar) clamped inside 11 3/-inch casing at a total height of 30 inches (Figure 13). Surrounding the open hole is wet tundra with no indication of remaining debris or other surficial issues. The hole poses no tlueat to humans or the environment. The well location is currently situated on Alaska Dept. of Transportation land that was transferred in 1966, but the well remains the property of the BLM. Additional 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 primacy 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 Figure 14: Photo of J.W. Dalton taken October 26, 2004. Soil cracking is occurring around the wellhead and the north and east side of the cellar is exposed. 26 Figure 15: J.W. Dalton wellhead with pilings. Photo was taken August 2000. to the edge of the Arctic Ocean. As a result, casing is now exposed to a depth of 15 feet on the present day beach (Figure 16). The top of the diesel is approximately 60 feet below the present beach level. The reserve pit has been breached on the northwest coiner from the advancing shoreline (Figure 17). The pit is known to contain chromium, cobalt, zinc, and barium. However, chromium, cobalt and zinc were detected in background levels, due to the east-west water movement into and out of the pit. Barium is a constituent of the drilling muds and is consolidated with other sediments (U.S. Bureau of Land Management, U.S. Geological Survey, 1992). The well is located within the Northeast planning area (see Map 2), on a tract cun•ently closed to leasing. .. - ~. ~ . '", This well is in danger of " <-- _ - becoming engulfed by the ocean. -;~ ~,~ ~ -~.~~s_ ~: - The diesel fuel in the well and .~~,t: ° '~~~'`~'""~;-~-~~- - reserve pit contaminants raises '~ concerns. The concerns can be ;~ .~ ?~,;.:; - _ ~ _ - eliminated by pumping out the ~. ~- ~` - = diesel, or displacing the diesel _~,~ ,;~' ~ F, ~-~` -',~z ~~~. with water and adding a bridge ,.;.. ~ ' plug and cement to close off the = ~~ _ < hole. The casing would be cut off rr ~ 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 cunent condition, the well does not pose a threat to humans or the environment, but if the casing were to break in its exposed condition, the diesel fuel would, over time, leak into the ocean. The release of heavy metals from the reserve pit may pose an immediate risk to human health and the environment. The pit was sampled October 26, 2004, and results are pending. 27 Figure 16: J.VV. Dalton with exposed conductor (left), and rat hole (right). The mouse hole (not pictured) is completely exposed. Figure 18: Simpson Peninsula showing well locations. Simpson Core Test #26 Simpson Core Test #26 was drilled in the middle of one of the larger, active oil seeps in NPR-A (Figure 19). The Navy described this location as Seep 3. The hole reached a total depth of 1,171 feet and was cased to 350 feet. The well encountered one very poor gas show and one productive oil sand in the Ninuluk/Seabee undifferentiated formation. In production tests, the well flowed at rates averaging 110 barrels of oil per day (Robinson and Brewer, 1964). Other formations encountered include the Gubik, Seabee, and Grandstand Formations. Gas bubbles have been observed around the base of the casing since the 2000 field season. Bob Burruss of the USGS, sampled and analyzed gas from Simpson Core #27 which is part of the same .oil field, located less than half mile to the east. His findings showed the gas to be biogenic methane indicating that microbial alteration (breakdowns) of the hydrocarbons has generated the gas. Additionally, oil sampled in the well was extremely biodegraded. Simpson Figure 19: The wellhead is located in the center of Core #26 has a wellhead flanged to the the photo. The green color liquid defines the area of active seepage. The orange color is oil-eating casing, a 2-inch line pipe, and four bacteria. wing valves and will likely flow oil if 28 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 cased to 101 feet. The objective of drilling was to collect a core to view the material at the bottom of the seep. The well does not meet standard oil and gas exploration well definitions. The casing is not cemented in place and the well is probably not capable of holding substantial pressure. The well encountered a few sands with shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. In 65 hours of testing, this zone flowed oil to the surface at rates averaging 125 barrels and 2,000- 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 harm was mitigated by the fact oil was seeping into a natural oil seep. In June 2001, BLM spent $35,000 to remove the old wellhead and install a new master valve and needle valve. Oil and gas samples were taken by the USGS prior to the replacement. There are no fresh water aquifers in the well so there are no risks to sub-surface resources but there are risks to surface resources if the well is .left unplugged. Oil will flow to surface if the wellhead or casing corrodes or if the well is left open. There are no solid wastes or hazardous materials (besides the natural oil) that would present a concern or pose a risk to the health and safety of the land and people. Simpson Core Test #30A Simpson Core Test #30A is an oil well drilled in 1951 to a depth of 693 feet and cased to 152 feet. The well encountered some very poor gas shows and one productive sand in the Ninuluk/Seabee undifferentiated formation. The well was bailed and averaged oil rates of 6 barrels per day during bailing tests (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The wellhead consists of casing swedge, a nipple, and a brass gate valve and will flow oil to surface if the valve is opened. There are no sub-surface fresh water aquifers at risk. However, if the well is left unplugged it could pose a risk to surface resources. In its current state, oil could flow to surface if the well is damaged, corroded, or the valves are opened. Additionally, concerns have been raised regarding the bubbling around the base of the casing. When the valve is opened, the bubbling subsides. This indicates a small leak around the base of the casing or through a hole in the casing. The gas was sampled by the USGS and has been identified as reservoir-produced biogenic gas. While the well does pose a risk, it is mitigated by the fact that the well is drilled in an active, natural oil seep. 30 Simpson Core Test #30 Simpson Core Tests #30 and #30A were drilled about 100 feet apart in the same oil seep. The seep is part of the same regime that contains Cores #26 and #27. These wells were drilled to gain an understanding of the producing field limits and to help determine underlying structure. Simpson Core #30 is an oil well drilled in 1951 to a depth of 1,500 feet. No plugs were set and the well was cased to 102 ft. The hole encountered the same formations as Cores #26 and #27; Gubik, Seabee, undifferentiated Ninuluk/Seabee, and the Grandstand with a few poor gas shows and ---~--- .~ - _ one productive sand in the Ninuluk/Seabee -`~-°~!`' =_-- undifferentiated formation. Poor oil shows were also noted in the deeper Grandstand Formation. During production tests of the shallow oil sand the well was bailed at rates averaging 5 barrels of oil per day (Robinson and Brewer, 1964). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since any development will likely target deeper, more productive formations. The well was left with sheared, open casing above ground. Even though the well produced oil 50 years ago, it is static today. This suggests the hole has collapsed below the shallow casing. There are no fresh water aquifers in the well, however, since the well was drilled to a reservoir with sufficient energy to flow oil to surface, the well should probably be considered a risk if left unplugged. This well would probably be plugged by placing a 100 foot surface plug downhole to eliminate risks to surface resources. The potential risk is alleviated by the fact that the well is drilled in an active, natural oil seep. There is no drill pad as the Navy drilled within the seep and camped on the tundra. Some light trash is present in the seep between the Core #30 and Core #30A, which may prove difficult to clean (Figure 22). The well lies three tenths of a mile from both Core #26 and #27 (Figure 18). Simpson Core Test #27 Simpson Core Test #27 is an oil well that was spudded February 1951 and completed one month later. Total depth of the well is 1,500 feet, with casing down to 102 feet. Oil was encountered at a depth of 380 feet and was bailed at a rate of 3 barrels per day. The core test encountered the same formations as Simpson Core Test #26, with a few very poor gas shows and one productive oil bearing sand in the Ninuluk/Seabee undifferentiated formation. Oil-based muds were used from the drilling depth of 325 to 661 feet. At that point the oil was displaced and the drilling crew resumed using water based muds. 3i 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 5/8-inch casing, a flange and a brass gate valve. The casing was set in a small inactive oil seep. It will flow oil to surface if opened. There is no surface debris present at Core #27 (Figure 23). The well poses little threat to human health and the immediate environment around it in its current condition. Simpson Core Test #29 Simpson Core Test #29 is a dry hole drilled in 1950 to a depth of 700 feet and cased to 152 feet. The purpose of the well was to determine the limits of the producing field encountered at Core #26. A very poor oil show was identified in the Seabee Formation. The productive sand present in the other Simpson Cores does not exist in this well. The test hole also penetrated the Gubik and Grandstand Formations. No oil was recovered from this well (Robinson and Brewer, 1964). The well is grouped higher on the priority list due to its close approximation to Simpson Cores #26, #27, #30 and #30A (Figure 18). The well is located within the Northwest planning boundary (see Map 2). The tract was recently leased and received a high bid of $7.51 per acre during the NW NPR-A lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development if left unplugged since any development will likely target deeper, more productive formations. The well was left with 8 1/z-inch casing, open to the atmosphere at a height of 6 inches. Thermistor cables protrude from the casing. It is located in a four-by-four foot wooden 32 Figure 23: There is no surface debris present at Simpson Core #27. cellar filled with water. A drilling pad was never established. There is some light trash around the wellhead including drill pipe, and various sized wooden scraps. A small barrel pump and other small debris can be seen in the casing and within the cellar (Figure 24). This well poses no threat to the human population or the environment. Umiat #1 .~, _ ~,.~ ,. , ~, 1 F,: - ~~~~ ~. - ,~:; r Figure 24: Simpson Core #29 ~;>~ f .. ~- ... ~, .. Umiat #1 was spud in 1945, and completed in 1946. Total depth reached was 6,005 feet and the well was cased to 685 feet. The well encountered residual hydrocarbons and a few poor gas shows in the Seabee, Ninuluk, Chandler, Grandstand, and Topagoruk Formations. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are located five miles to the east. Oil recovered in bailing tests was so minute that it was measured in pints and officially recorded as a trace. Lab tests determined the oil to be of a different type of crude oil than that found in the productive Umiat wells (Robinson and Bergquist, 1956). The small amount of crude recovered in each test is indicative of residual oil staining. No fresh water aquifers exist in the Umiat area, so this well poses no tlu-eat to sub-surface water resources. There is no pressure on the wellhead and it is fitted with a blind plate, a 2-inch nipple and a brass gate valve (Figure 25). The well is located on an unleased 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 tlu•eat 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 form of steel framing and scrap metal are near the wellhead. The solid wastes pose no threat but are unsightly. Umiat #11 Umiat #11 was spud June 1952 and completed two months later. The well reached a total depth of 3,303 feet with 486 feet cased. One cement plug was placed at 440 feet. The objective was to test production possibilities of the Grandstand Formation on a fault that parallels the Umiat anticline. The well encountered residual hydrocarbons in the Seabee, Ninuluk, and Grandstand Formations but no oil or gas was recovered during production tests. The sands of the Grandstand were outside the productive area encountered by other Umiat wells, which are over one mile to the south. The well is located within the Northeast planning boundary (see Map 2). The tract is located on lease AA-084141 but there is little possibility of the well interfering with future development due to its location outside the Umiat structure. The well was drilled in the alluvial plain of Bearpaw Creek, 0.6 miles from Umiat #8. A drilling pad was never created as operations consisted of mounting the drill rig on a sled and then placing it on top of large timbers that were secured to pilings (Robinson and Bergquist, 1956). A pile of unvegetated drilling muds is present 30 feet west of the wellhead in between the wellhead and the creek. The wellhead consists of a 10 3/-inch open-ended casing with a collar sticking up inside a 30-inch conductor that is filled with water. Minor wood debris can be found around the wellhead. The well poses no risk if left unplugged. Wolf Creek Area Three test wells were drilled in the Wolf Creek area. The wells were drilled in the early 1950s with the intent of testing the northwest-trending Wolf Creek anticline structure. Wolf Creek # 1 and #3 (Figure 26) are located at the crest of a hill with about 250 feet of relief from the valley. Wolf Creek #2 is located about one and one- third miles north within the Wolf Creek valley. Wolf Creek #2 and #3 are open holes but Wolf Creek #1 is equipped with a wellhead. .. 3 ." e. ~ ~, .lG+,.~ 3 '~ ~4 ~ s~ ~ ~ 7 f :- ~ik~ ~v ~~ T" i 3~ C\; e~~~~ ~ ~ ~ ~ ~~~, Figure 26: Wolf Creek #1 after adding a new ball valve to the wellhead. August 2004. ~,~ .._ ~. ~4 .:• Wolf Creek #1 Wolf Creek #1 is a gas well drilled in 1951 to 1,500 feet and cased to 48 feet. The well encountered very poor gas shows in the Killik Tongue and productive sands in the Grandstand Formation. The well produced at rates up to 881 MCFPD in open hole tests 34 of the Grandstand. The well is equipped with a blind plate, a 2-inch nipple and a brass gate valve (Figure 26). There is a small gas leak in the threaded wellhead flange and, if the valve is opened, the well will flow about 10 MCFPD but the pressure is so low it does not register on a gauge. In its 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 1952 to a depth of 3,760 feet and cased to 625 feet. It is deeper than the other two Wolf Creek wells because its primacy purpose was to test the Grandstand Formation (the producing formation around Uiniat, 35 miles to the west). The Grandstand Formation produced from four different sands. In 35 !' figure 27: Wolf Creek #2 had casing cut off at ground level. open hole flow tests of the well produced at rates up to 445 MCFPD. The gas appeared. to be sufficient to supply a small camp, but not of commercial proportions (Collins and Bergquist, 1959). Two plugs were set in the well above the Grandstand Formation. The top of the shallowest plug is inside the casing at 554 feet. In addition to the Grandstand, the hole penetrated the Ninuluk, Chandler, and Topagoruk Formations. Upon abandonment, the hole was filled with oil-based. drilling muds and left open to the enviromnent. A total of 103 bat7•els of crude were used. The well is located on an unleased tract within the Northwest planning area (see Map 2). No offers were received in the June 2004 lease sale for the tract and near-term development is unlikely. The well poses no tlueat to surface or sub-surface resources and has no potential to adversely affect future development. The drill pad is shared with Wolf Creek #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 barrels of oil per day tlu•ough agravel-packed completion. It also produced a small amount of methane gas. The hole encountered the Gubik, Shrader Bluff, Tuluvak, and Seabee Formations. Cun•ent condition of the wellhead is that it has no pressure at surface and consists of two wing valves and a master valve. The well is located within the Northeast planning area (see Map 2) on lease AA-081857 where, in 2004, ConocoPhillips Alaska Inc. drilled an exploratory well within seven miles. The target of the exploration is in the Upper Jurassic at depth of approximately 8,000 feet and it is not likely that this unplugged well will adversely affect development in the area. The recent Alpine Satellites EIS approves oil and gas development in this area. ConocoPhillips has proposed roads and a drilling pad less than eight miles from this well and will likely be 36 Figure 28: Fish Creek #1 with concrete cellar. producing by 2008. Given the low level of risk, the plugging of this well should be postponed until infi•ast~ucture is established. Surficially, there are still soiree solid wastes present. The drilling pad and cellar construction consists of concrete reinforced with steel matting. The concrete, matting, and pilings are still in place today, albeit heaved by permafrost (Figure 28). Several 55- gallon trash drums filled with debris are located off the concrete pad. Other light debris is also present within 500 feet of the pad. The oil seep is located about 1.5 miles to the southwest of the well site and is inactive. The USGS 305-I reports the dimension of the seep as being 6' x 20' (Florence and Brewer, 1964), however, BLM personnel located the seep in 2001 and noted its dimension to be 3' x 6'. Simpson Core Test #28 Simpson Core Test #28 was drilled in September 1950 to a total depth of 2,505 feet and cased to 110 feet. Despite the depth, the hole did not encounter any hydrocarbon shows. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. A drill pad does not exist, however a large area of disturbance is visible. The wellhead consists of open casing inside a wooden cellar. There is considerable solid waste near the well. These include: numerous metal pilings, drill pipe, large wood fragments (spool, plywood, timbers), and some partially crushed drums. The solid wastes are unsightly, but pose no threat to humans or the environment. Simpson Core Test #13 Simpson Core Test #13 was drilled in the summer of 1949. It was a relatively shallow test and did not generate any significant oil or gas shows. The well encountered residual hydrocarbons in the Seabee and Grandstand Formations at depths of 1,079 - 1,084 and 1,138 - 1,148 feet (Robinson and Brewer, 1964). No oil or gas was recovered during production tests. The well is over three miles north of the Simpson Core wells that penetrated productive Grandstand sands. Total depth of the well reached 1,438 feet. The top 26 feet are cased and the hole was filled with water-based drilling mud. Fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. 37 A drilling pad does not exist. Seven-inch casing was cut off at ground level and is very difficult to locate. The well is open to the atmosphere. There is no solid waste, nor is there anything hazardous regarding this location. It should not be considered a risk to surface or sub-surface resources. Simpson Core Test #15 Simpson Core Test #15 was drilled in August 1949 near an active oil seep. The well was drilled to a total depth of 900 feet and cased to 18 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations (Robinson and Brewer, 1964). No oil or gas was recovered during well tests. Additionally, fresh water aquifers were not encountered. The well is located within the Northwest planning area (see Map Z) 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 uea is clean with no solid waste. This well poses no risks to the environment or human activities. Simpson Core Test #14 Simpson Core Test #14 was drilled in 1949 to a depth of 290 feet. The records do not clearly state how much casing was run but the well was left with casing above ground open to the atmosphere. Its present day location lies within 1000 feet to the west of an active oil seep. The well was not drilled deep enough to encounter the hydrocarbon stained sands evident in the Simpson Core #14A well. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years. This shallow well did not penetrate any hydrocarbon bearing zones and poses no risk to surface or sub- surface resources, nor does it have the potential to adversely impact future development. 38 Simpson Core Test #14A Simpson Core #14A was drilled in 1949 to a depth of 1,270 feet and casing was set to a depth of 32 feet. The well encountered only residual hydrocarbons in the Ninuluk/Seabee and Grandstand Formations. No oil or gas was recovered during tests (Robinson and Brewer, 1964) and fresh. water aquifers are not present. Present day location of the well is approximately 1000 feet to the west of an active oil seep. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper, more productive formations. Surficially, it is best to consider both Core # 14 and # 14A together. A r ~, v ~~~„ ~ ~~--~ -~--- ~ ;h, ~ ~ =: - _ drilling pad does not exist, the ` `~ ~:~ ~~-. ~ ,~~ ` ~ '~` : ~ ;~ ~ wellheads are non-threatening, and • .~~~ ~'1. n ~~.~ ~ there are no solid wastes. There is ~~~ ~ ~~`~~ , , °.~ some discrepancy between the USGS • , ` ~ -~~ ~~ .t~ :~,~ 305-L report and the BLM field `~ ~ ' " ~' ~ *`~ ~~' ~- ~ - ~ findings in terms of the wellheads. f >~~ '~'~ ~ ~ '~, ~ ~~~ ~~~ ~~° . According to the report, Core # 14A r - ~ ~ ~ ~j w , was uncased and the casing for Core ~ ~ ~' ~ . t ..- .: M , ~y ~.~, -~ •" ~~.~~~ r:~~°t~~-~' ~~ . ~ , <. fi 14 was cut off at r ound level In g _ . ~.. w:r ~~~ ~~ b~ ~ . 2002 BLM discovered both holes ~ ` , ~;: ~~ ~,~.~~_ ~:~ side-by-side with open casing Figure 30: Simpson Core Tests #14 and #14A. extending upwards 24 inches from the ground surface (Figure 30). The site was last visited in August 2002. This well does not pose any concern and should not be considered a risk to surface or sub-surface resources. East Simpson #2 East Simpson #2 was drilled in 1977 to 7,505 feet and cased to 6,427 feet. Five cement plugs were set, with the top of the shallowest plug set at 1,997 feet. The primary objective of the well was to test the Ivishak Sandstone where it onlaps the Pre-Devonian age basement rock (Husky Oil NPR Operations for U.S. Geological Survey, 1982). Small scale faulting was found between the wells in the area, possibly accounting for the thin section representing the Sadlerochit Formation. The well encountered very poor oil shows at 6,000 feet in the Torok Formation and Endicott age sandstones were cored with poor porosity and dead oil shows. The well is officially listed as a dry hole. Upon completion of the production tests, the well was plugged back to 1,997 feet and filled with approximately 280 bagels of diesel to facilitate permafrost temperature measurements. However with East Simpson #1 less than five miles away, the USGS has no plans to use this well for temperature monitoring. The well is located within the Northwest planning area (see Map 2) on a recently leased tract that received a high bid of $21.51 per acre during the lease sale of 2004. Exploration and development is a distinct possibility within the next 20 years but it is unlikely this 39 well will have an adverse impact on development. If this exploration and development establishes infrastructure nearby, it would greatly facilitate plugging this well and significantly reduce costs. The wellhead consists of a casing head, side gate valve, a master gate valve, and a needle valve. The drilling pad is of the thin pad variety and is slowly being reclaimed by natural processes. Exposed pilings stick up a height of two feet from the surface, but no other objects needing removal are present (Figure 31). The cellar is a wooden 12' x 12' with standing water. With the existing plugs and the static condition of the well, there is no risk to surface or sub-surface resources. Kaolak #1 Kaolak #1 lies in the northwest portion of NPR-A and is considered one of the more remote well sites within the reserve. Kaolak #1 was drilled in 1951 to a depth of 6,952 feet and casing was set to 1,000 feet. Drilling served two purposes, to determine the presence of any reservoir characteristics, and to determine if oil or gas shows were present in this remote ~ , portion of the reserve. The site was chosen based on a seismograph survey in 1950 - that identified an anticline at this location. The intent was to drill to a depth of 8,000 feet, but a windstorm destroyed the derrick. After the storm, the hole was abandoned due to unsatisfactory oil and gas shows. Findings indicated some very poor oil and gas shows in the Chandler Formation and very poor Figure 32: Kaolak #1 with cabin on the drill pad. shows in the Topagoiuk Formation. Gas shows were attributed to association with the coal beds (Collins and Bergquist, 1958). Upon abandomnent, no plugs were set and the hole was filled with heavy muds. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. Exploration and development in the area is a possibility within 40 ,~ Figure 31: East Simpson #2 is partially submerged during the spring thaw. Photo taken June 2003. 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 envirorunent. The well is left with a casing head and is open to atmosphere. The wellsite is 45 miles southwest Wainwright, which is the nearest community. There are no hazardous materials or anything that would pose a risk to the general health and safety of the land. The cabin may be a concern, but dealing with the situation is outside the scope of this report. Meade #1 Meade #1 is a gas well drilled to a depth of 5,305 feet in 1950. The well was cased to 2,785 feet and two cement plugs were set, with the top of the shallowest plug tagged at 2,783 feet inside the casing. The well encountered some gas shows in one productive sand within the Grandstand Formation. The gas tested at rates up to 1.1 MMCFPD during openhole flow tests of the sand at 2,949 - 2,969 feet. The well is estimated to have gas reserves of 10 BCF. Gas pockets are relatively common in this portion of NPR-A due in large part to the underlying coal. At one point while conducting tests, some problems were encountered while attempting to pull a testing tool out of the hole; aball-peen hammer was inadvertently dropped downhole, causing the tubing to stick. The tubing could not be freed and as a result, it twisted off leaving tubing in the hole. When the lost tubing could not be pulled out, heavy muds were pumped downhole and the well was abandoned (Collins and Bergquist, 1958). The well is located within the Northwest planning area (see Map 2). The well is adjacent to a recently leased tract that received a high bid of $10.26 per acre during the 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years and has the potential to target the Grandstand Formation. If left unplugged the well has no potential to adversely affect future development. There is no pad present at Meade #1. Several pilings and light trash are present, but overall is pretty clean. The wellhead is at ground level and consists of an open flange `~ ~ A ``~ -~~t-~~` + bolted to the top of the casing (Figure 33). This s,~: ~ ~ ~~=: ~ ~ ~ _ '~° ~' differs from the Navy reports that indicate the ~;~ -~ ~'- ;~ ~ wellhead was abandoned in place. There is no 1 ` 'r ~' _, record as to why it was removed. A BLM field ~ " ~ i~ ~ ;. ~ ~ crew bailed the hole and discovered a swedge ,~ and 2-inch needle valve junked downhole. This ~ ~~ - ' ~ - '~~ ~ site is ve remote 30 miles south of At asuk +~ "• °~ , _ , ~ and since the gas zones are currently isolated ~ below the cement plugs there is a limited risk of ,: '~'.;~;- ~ ~' ~., c adverse impacts to surface or sub-surface _ _ .~ resources. 41 Figure 33: Meade #1 wellhead. Titaluk #1 Titaluk #1 was drilled in 195.1 to a depth of 4,020 feet and is a dry hole. The well was drilled on the end of an anticline to test the oil and gas potential of foiznations 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 2004 lease sale. Near-term development is unlikely. Surficially, there are no concerns with this well. The well is open, 10 3/- inch casing above ground to a height of 3 feet. It is open to the atmosphere. The area of disturbance is completely revegetated Figure 34: Titaluk #1 wellhead with wooden cellar. with no Solid waste concerns. The wooden cellar is in a state of disrepair and filled with water (Figure 34). The site is clean with very little debris. There are no hazardous conditions associated with the surface. The nearest settlement is Umiat, 60 miles to the east. The well poses no risks 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 2004 lease sale. Exploration and development is a distinct possibility within the next 20 years but it 42 is unlikely this well will have an adverse impact on development since industry will likely target deeper, productive formations. An oil seep located at the base of Skull Cliff (land/ocean contact) was observed and documented in the 1940s, which influenced the Navy's decision to drill. BLM and USGS crews searched for the seep when they were in the area but nothing was found at the cliff/beach contact. However, another seep was reported in 1996 by a group from the Academy of Natural Sciences in a small gully about a mile to the east near the old radio tower site. This seep was never confirmed by BLM. Oumalik #1 Oumalik #1 was drilled in 1950 and is a dry hole. The well was drilled to a total depth of 11,872 feet and cased to 2,762 feet. It is the deepest well drilled by the early U.S. Navy program. The well location was positioned on the apex of the 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 '/z-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 stressed vegetation was noted around several of the low-cut pipes. Despite the diesel, the well does not pose a risk to any existing communities or habitation. It is in a remote location approximately 55 miles southeast of Atgasuk. Overall, the well poses no risk to people or the environment. East Oumalik #1 East Oumalik # 1 was drilled on a ridge that overlooks an unnamed tributary of the Oumalik River. Topographic relief is approximately 100 feet. The drill site is highly remote as the nearest village (Atgasuk) is 65 miles away. The well was drilled in 1951 and reached a total depth of 6,035 feet and is cased to 1,100 feet. It is a dry hole. Veit' poor oil and gas shows were reported in the Grandstand Formation and very poor gas shows were reported in Topagoruk Formation. The well is located within the Northwest planning area (see Map 2) on an unleased tract that received no bids during the lease sale of 2004. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future. development. The well was left with open casing below ground level and has theimistor cables protruding from inside the casing. The casing is marked by a 7-foot, 3/-inch pipe. The open pipe lies within awater-filled cellar. The standing water has produced numerous algae and other aquatic vegetation obscuring the wellbore. Surficial hazards consist of several 10-foot timbers and a few 4-foot pipes (probably rig anchors) sticking up out of the ground. The site is mostly overgrown with shrubs and appears to be relatively clean. The airstrip, incoming, and outgoing trail scars are obvious and can be used to navigate to the wellsite. There are no risks associated with the well in its current condition and was given this ranking due to its close proximity to Oumalik # 1. Topagoruk #1 Topagoruk #1 was drilled in 1951 to a depth of 7,154 feet and is a dry hole. The intent was to test a small, buried anticline and the various formations associated with it. The well was cased to 6,073 feet, plugged back to 6,175 feet and then drilled to a new total depth of 10,503 feet. Prior to re-drilling to total depth, approximately 250 barrels of crude oil from Cape Simpson were added downhole to help offset lost circulation and caving. Additionally, 20 ban•els of diesel were added downhole during the drilling phase. No plugs exist in this well. The well is left with open casing to the surface and thermistor cables protruding from the casing (Figure 36). The well encountered the following stratigraphic units while drilling; Gubik, Grandstand, Topagoruk, and Oumalik Formations, Middle and Upper Jurassic rocks, Shublik Formation (Triassic age), Permian rocks, and Lower-Middle Devonian rocks. Hydrocarbon shows were limited to a few very poor gas shows in the Oumalik Formation. No oil or gas was recovered during 44 multiple production tests (Collins and Bergquist, 1958). The well penetrated no fresh water aquifers and does not represent a tlu-eat to surface or sub- surface resources. The well is located within the Northwest planning area (see Map 2). It is adjacent to a recently leased tract, receiving a high bid of $50.00 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the area is a distinct possibility within the next 20 years but since this well did not penetrate productive oil and gas zones it will not have an adverse impact. ~::i',m ` Aw .k."vl'G'4.; ~':osF.~'X -;:. ~~ ~ ~ ~ * ~, ~~~ There is not a visible pad, but rather an area of ~ ,~,-~ E = ~'~~~: t ..> ~~~. disturbance. Disturbance stretches !4 mile in an Figure 36: Topagoruk #1 casing on its east-west du•ection and /8 of a mile in a north- side. When the casing was pulled out of south direction. Solid wastes exist in the form of the ground, thermistor cables were piping remaining from a refrigeration system that discovered. circulated diesel to keep the permafrost frozen. A potential hazard exists because diesel still occupies the ground circulation lines. These lines stretch approximately 750 feet to the east, 250 feet to the north, and 100 feet to the south from the wellhead. Other debris on site include some large, partially-burned timbers, awater-filled wooden box (Figure 37) that resembles a cellar ('/4 mile east of the wellhead), and drilling muds. Atgasuk is the closest village approximately 30 miles to the southwest. The well is remote with the exception of a subsistence camp approximately one mile southwest of the wellhead along the Topagoruk River. Topagoruk's wellhead consists of an open hole cut off at the ground surface «~ith several thermistor cables. A thin piece of weathered metal fits around the cut-off casing to resemble a marker. The weathered metal has been smashed at the base and now lies bent in half on its side. Overall this site poses little hazard to the environment or human population. East Topagoruk #1 East Topagoruk # 1 was drilled on top of a small ridge in the Chipp River delta in 1951. It reached a total depth of 3,589 feet and is cased to 1,100 feet. The purpose of the well was to test an anticline with closure as well as test the fluid content of the permeable Cretaceous sandstone (Collins and Bergquist, 1958). A very poor gas show in the Topagoruk Formation is the only reported hydrocarbons encountered in the well and no oil or gas was recovered during multiple production tests. One cement plug was set in the 45 Figure 37: Drilling muds and a wooden box that resembles a cellar are located about'/ mile east of the wellhead. well at 1,049 feet. The well is located within the Northwest planning area (see Map 2) on a recently leased tract. The tract receiving a high bid of $84.99 per acre during the NW NPR-A lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years but it is unlikely this well will have an adverse impact on development since the well did not penetrate productive zones and future development will likely target deeper formations. A drill pad does not exist. There are a few rig anchors near the wellhead, but no other surficial debris. The cun•ent state of the wellhead is open-ended 10 3/-inch casing. Casing height is three feet above the ground surface. It is housed in a small 9' x 9' water-filled cellar. The area is remote and poses no health and safety risks to humans or the environment. Knifeblade Wells There were three shallow test wells drilled in the Knifeblade Ridge area. Knifeblade #1 was drilled on the ridge at the head of a small stream, with wells 2 and 2A drilled about a mile downstream. The wells are in a highly remote location with Umiat being the nearest settlement, 65 miles to the east. Knifeblade #1 Knifeblade #1 is a dry hole drilled in 1951. The well was drilled to a depth of 1,805 feet and cased to 1,211 feet. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959}. The well encountered very poor gas shows in the Killik Tongue of the Chandler Formation and very poor oil and gas shows in the Grandstand Formation. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. , l - 2~ - - } ~ ~ Y.5 ~ ~` w t ~ ~ , 4 _ i 2. .: 4 f ~, ,, 2t' = r ~ , ` ,, tt ~ ~ ~~ 3. ~ ~~ ~ ~ '~ ~ f S h ~ ryY Y1 J~ y , t `y Z fv~ ~ 4:. ~. ~ Surficially, there are no concerns J z ~ x~ ~ - ~~, ,, a~ ~;~ ~ t ~ - ~ ~ ~~~'" ~ ~ "~k ~ ~`' x ~; ~ f associated with this well. A drill pad ~ ~~ ~~- ,,t~~~ ~ ~'~~~,~~'x does not exist and the wellhead ~~ nix ~, ` ?~, ~ ~ ~ 75~ ~r 4~ ~ ~ fi:i ~ _ ~ consists of open-ended casing ~Y~~f ~`~~ , ~ ,~ (Figure 38). The wellhead is 8 /8- ,-, a u~,~ y ~,•.~ ,~~,:'" inch pinup inside 11 by 12 '/ -inch Figure 38: Knifeblade #1 is located in a marshy area at collar. The plumb-bob hit solid at 12 the headwaters of a small creek. feet. Total height for the well is about three feet. If this well is left in its current condition, it poses no risk to adversely impacting the surface or sub-surface resources. 46 Knifeblade #2 Knifeblade #2 is another dry hole dulled 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. Sm•ficial issues are negligible. A drill pad does not exist and the wellhead consists of open-ended casing. There are approximately eight empty drums near Knifeblade #2 and #2A. The wells are highly remote and should not be considered a threat to the environment or human activity. Knifeblade #2A Knifeblade #2A, also drilled in 1951, reached a total depth of 1,805 feet and was cased to 38 feet. The well lies 28 feet to the north of Knifeblade #2A. The purpose of the well was to test the oil and gas properties of the Grandstand and Tuktu Formations (Robinson and Bergquist, 1959). Only very poor oil and gas shows were reported in the Grandstand Formation. The well was left with casing open to the atmosphere and poses no threat to surface or sub-surface resources in its current condition. The well is located on an unleased tract, in Southern NPR-A (see Map 2) where a lease sale is scheduled for 2008. It is unlikely that exploration and development will occur in the vicinity of this well in the near future. If left unplugged, the well has no potential to adversely affect future development. Simpson #1 Simpson #1 test well was drilled with a rotary rig in 1948 by the U.S. Navy. The well was drilled to a total depth of 7,002 feet and cased to 5,954 feet. The purpose of the well was to test the various formations of the Lower Cretaceous and Upper Jurassic rocks. The well encountered several very poor oil and gas shows and one productive gas sand in the Lower Jurassic at a depth of 6,183 - 6,193 feet. The well produced gas at rates up to 3.0 MMCFPD during open hole flow tests of this Lower Jurassic sand. The gas zones are currently isolated from other formations and the surface by two cement plugs set above the productive sand. The top of the shallowest plug is at 5,520 feet (Robinson and Yuster, 1959). The well is located within the Northwest planning area (see Map 2) adjacent to recently leased tract that received a high bid of $7.51 per acre during the lease sale of 2004. Exploration and development in the vicinity of this well is a distinct possibility within the next 20 years and this exploration has the potential to target the Lower Jurassic. Since the well is partially plugged, however, it poses little risk to surface or sub-surface resources and will not likely adversely affect any future development. 47 The pad is highly visible and was constructed in the same fashion as Fish Creek #1 in which concrete was used as a working pad. Concrete was poured over a landing mat which was placed on pilings. As a result of ground movement from perniafrost freeze/thaw cycles, the concrete has buckled in numerous places creating apartially- collapsed surface. This feature provides excellent shelter to small animals and rodents. Additionally, there is a small pile of drilling muds near the wellhead. The well was left equipped with a casing flange, spool w/ side bull plug, and another flange and nipple and is shut-in with no pressure at surface. The components past the flange have since been removed. Overall, the current condition of the site is non-threatening to the sparse human population and the surrounding environment. North Simpson #1 North Simpson #1 was drilled in 190 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. Surficially, the area is wet with the wellhead partially submerged intermittently throughout the surmner (Figure 39). The drill site lies only a few miles from the Arctic Ocean. The work area is visible with metal pilings around the wellhead. It is unknown if additional solid wastes exist under water. The well was left Figure 39: North Simpson #1 is partially submerged in the With a bull plug installed on summer. top of a swedge. The well is not near human activity, and does not pose a threat to surface or sub-surface resources. South Simpsoq #1 South Simpson #1 was drilled in 1977. The purpose of the hole was to test the Sadlerochit Formation where it laps onto the south flank of the Barrow Arch. The well was drilled to 8,795 feet and cased to 7,206 feet. Reports show that poor gas shows were identified in the Nanushuk Group, Kingak Shale and Shublik Formation. Gas flowed at a rate of 75 MCFPD between 6,522 - 6,568 feet within the Kingak Shale (Gyrc, 1988). The gas contained more than 70% nitrogen. The origin of the high nitrogen content is unknown, but appears to be a localized phenomenon (Bunuss, 2003). Sandstone tongues 48 (Simpson sand) within the Kingak Shale in the Simpson and Barrow localities are known to display good gas reservoir quality (Houseknecht 2001). Poor oil shows were discovered in the Nanushuk Group and Shublik and Torok Formations. Drill stem tests did not recover any oil. ~. ~ a R t; :~L d .~x ~ .. Figure 40: South Simpson #1 had its cellar backfilled with silt, consequently bur in the casino head 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 with silt which resulted in y g 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 :_ ..: ~ ,, ,-~., ~.:.,. o ~~ well for staging areas and _ ~:. ~ '" ~ .. ~ a camp. It would be _ •: 1 r ~K.~'s f wk> y <' ,~,. ~'~ ~ ~ a'~"3 fairly simple to remove ~ ~~- .~ ..,~ = r w - ~ ~ ~ ~ ~" - , k the wellhead but the well ~ ~'- rj ~ -~ has no potential to ~- , ~'~ ;; ` ~' adversely affect surface "~;` ~ ~ ~°~. or sub-surface resources. ~ ~ ;3 k`• ~} "'t r; ~ ~ `" the well Additionally t rt,_ ~~ .:, ~ ` ~ _ , poses no tlu-eat to ~-~=~ ;: ~ ` adversely affect future ~y ~.~ = ~ ! ' '~ development. ; ? ~ ~': ; ~ ~t` y ~ y~ ~v -~ ^~~~`~ ~.E- 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 cun•ently used are properly plugged above the hydrocarbon bearing zones and into the well casing. The wells are filled with diesel fuel down to the shallowest plug at depths ranging from 1,500 - 3,000 feet. For a list of wells see Appendix B. The program began in 1958 and will continue for the foreseeable future. After this project ends, the wells will have the diesel extracted and the well will be properly plugged to surface. Diesel is a non-con-osive agent, and even if the casing should conode there would be no impact to the surface resources and minimal impact on the sub-surface resources as there are no known fresh water aquifers in NPR-A. The following wells are monitor wells with surficial issues. It is difficult to establish a rank since the wells are sufficiently plugged. The cleanup priority is difficult to deterniine 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 vas drilled on a small peninsula on the southeast side of Teshekpuk Lake. The southern shore of the peninsula is protected from the prevailing northerly winds, however the north shore doesn't have the luxury of a barrier and is subject to erosion. Unfortunately, solid wastes from the camp and drilling operation were buried on the northern portion of the pad, possibly in the old reserve pit. The northern shore has been battered by numerous storms which have eroded the shoreline and exposed the solid wastes. The wastes are unsightly and potentially hazardous. While the nearest village of Nuiqsut is 52 miles to the southeast, Teshekpuk Lake is rich in subsistence resources and numerous sununer cabins dot the lake's shoreline. It is possible that at the time of surficial restoration, the downhole could be pumped free of diesel and plugged to the surface. Awuna #1 Awuna #1 was spudded February 1980 and completed April 1981. It is the only well drilled in the southwest portion of NPR-A and is 90 miles south-southwest of Atqasuk. Awuna is the most remote well in the entire petroleum reserve. The well was drilled to a total depth of 11,200 feet. Drilling was conducted over two consecutive winters. Ice roads and an ice airstrip were constructed for logistical support. The project cost approximately $6 million (Husky Oil NPR Operations-Awuna, pg 5). .Due to the orientation of the pad, the prevailing winds force wave action into the drilling pad, undermining the sands and silts which make up the pad. Below the sands and silts, Styrofoam was used to insulate the underlying permafrost. Wave action has eroded tens of feet into the drilling pad, exposing the Styrofoam, which consequently breaks loose and blows away. Wooden pilings exposed from erosion show how much attrition has taken place. Styrofoam can be seen all around the pad with pieces blown up to 5 miles away. Downhole, the well is in good shape with sufficient plugs. Diesel fuel fills the top 4,000 feet. The well is an USGS monitor well. Wellhead components are in working condition with no problems. annual basis Tunalik # 1 The immediate concern with this site is the blowing Styrofoam, but as the years progress erosion could become a major issue (Figure 42). The loose Styrofoam should be cleaned up and erosion progress should be monitored on an . It is also worth mentioning that the same type of scenario is unfolding at (another USGS well). Wave action from the reserve pit is beginning to 51 Figure 42: Awuna wellhead with exposed wooden pilings and Styrofoam. undermine Styrofoam from the drilling pad. Tunalik #1 differs from Awuna #1 in that prevailing wind direction does not force erosion in the direction of the wellhead. Uncased Core Tests There are thirty-nine uncased core test holes. These holes were typically left filled with drilling mud and abandoned without being plugged. Drilling depths ranged between 500 and 1,500 feet depending on the purpose of the test. By nature, core tests were drilled to test soils, permafrost, or lithologic units. They were not drilled for oil or gas exploration purposes and did not encounter hydrocarbons. Many of the cores are stored in the Alaska Geologic Materials Center (Figure 43). The BLM has examined the cores and they are extremely friable. It is likely that these uncased core holes have naturally collapsed and harmlessly blended into the environment. There is no surface indication of their location and BLM has been unsuccessful in locating them during several visits to their reported location. They do not pose any potential risks. Barrow Gas Wells The Barrow Gas Field Act of 1984 (P.L. 98-366, 98 Stat. 468, July 17, 1984) allowed the U.S. Navy to transfer several wells to the North Slope Borough. The Navy drilled six shallow wells between 1953 and 1974 to test the. natural gas potential. Between 1974 and 1982, 10 additional wells were drilled to help supplement the local gas supply. The wells were developed for use by the local government agencies and Barrow residents. The act conveyed the sub-surface estate, held by the federal government and any other interest therein, to the Arctic Slope Regional Corporation (ASRC). The BLM acknowledges the surface and sub-surface lands as conveyed and the Office of the Regional Solicitor has confirmed that the Transfer Act included the wells and well locations, and any liabilities associated with these wells are the responsibility of ASRC. 52 Figure 43: Core samples from Simpson Core Test #25, an uncased core test, are stored in the Alaska Geologic Materials Center. Plugged Wells Square Lake #1 Square Lake #1 is a Navy well that was drilled to a depth of 3,984 feet. Its primary intent was to test the Cretaceous rocks in east-west trending anticline structure (305H pg 424). No significant shows of oil were found. Gas shows were encountered in various sandstone beds between 1,600 and 1,900 feet, but otherwise the hole was dry. Upon completion, four plugs were reported to be set with the upper plug at 728 feet, well above the gas shows. Two other plugs were reported to be set in the gas zone, spanning depths of 1,640 - 1,840 and 1865 - 1934 feet. In addition to the six plugs, water and mud fill the remaining distance to the surface (Collins and Berquist, 1959). Upon successive visits to the site, BLM field crews dropped aplumb-bob down the hole and hit a solid obstruction between 8 and 10 feet. Don Meares, Northern Field Office, visited the site in August 2003 with an underwater camera and determined the solid surface to be cement. The Square Lake area is clean of debris with a few deadmen pilings (anchors) near the wellhead that could pose a ground hazard. The wellhead is open casing cut off at ground level. Umiat #2 and #5 The Umiat #2 and #5 wells were plugged and abandoned in 2002 by the COE (Figure 44). The wells were drilled on a common four-acre pad in 1947 and 1951. The purpose of the wells was to test for producing lithologies and determine petroleum quantities. Umiat #2 penetrated the Gubik Formation, Nanushuk Group (Chandler and Grandstand Formations), 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 ban•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. M from Umiat #5 were removed. Costs were approximately $25 million dollars due in part, to soil Approximately 30,000 tons of petroleum-contaminated soil was excavated. remediation. The soil was 53 transported on an ice road to the Umiat camp where it was thermally treated in a rotary kiln to remove petroleum residues. Small quantities of PCB contaminants were unexpectedly encountered after the excavation was completed. The source of the PCBs has been linked back to the #5 well and the fluids used downhole. The ever-shifting Colville River continues to erode the north bank and is approximately 50 feet from the old wellbores. With the removal of hazardous soils, this site should not be considered a threat to humans or the environment. Umiat #3 Umiat #3, also known as Umiat Core Test #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 S ~ Y ~. Formation within the Nanushuk n~ ~' 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. Um1at 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 fiznction 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 environment. No valves or gauges are present. The well was plugged by the BLM on May 9, 2004. The well poses no risk to humans or the environment. Umfat #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 Forniation produced approximately 60-100 barrels per day of oil and more than 6 million cubic feet per day of gas. The well was shut in with a gas pressure of 275 pounds per square inch. The gas was analyzed by the Bureau of Mines and determined to be 97.3 per cent methane. Brine was mixed (35 lbs of salt per barrel of water) and used in the drilling fluid to prevent freeze up. Brine solution of approximately the same ratio of salt per barrel of water was used to kill the well and set the plug while cementing casing. A total of 21,695 pounds of salt were used in the well (Robinson and Bergquist, 1956). The well was plugged May 2, 2004. Prior to plugging, the well was nicknamed the "Whistling Well" due to the gas of which was escaping through fittings and valves in the wellhead. The wellhead is easily the most complex of the 11 Umiat test wells. It consists of five valves and multiple gauges. It has several homemade components and reaches a total height of ten feet. After reporting the seeping gas in 1996, two new valves and gauges were installed in 1997. The new gauges have been checked regularly since 1998 and have consistently read 250 psi. Despite replacing the two valves and gauges, gas continued to leak from the wellhead. The largest of the leaks occurred just above the top flange where a 4-inch nipple and collar are welded together. Other leaking occurred at the fittings of some of the gauges. The wellhead is sited on a gravel pad. A series of piping extends from the wellhead to a small stock tank about 100 feet to the south. The tank probably was used as a holding tank for the oil while testing the production potential of the hole. The same style of stock tank is present in various old photographs found in the Umiat area and 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 Unuat anticline and is located about a half mile northwest of Umiat #8. Total depth of the well is about 1,573 feet. When the well was bailed, it produced 222 barrels of oil in a 24-hour time span. The most productive layers occurred at 980 feet and 1,095 feet, penetrating both the Ninuluk and Grandstand Formation (Robinson and Bergquist, 1956). Also encountered were the Seabee and Chandler Formations. The hole was somewhat problematic as it caved considerably during drilling. Operations consisted of a drill rig set on a foundation of 12" x 12" timbers with a thin layer of gravel in between. Twenty-five pounds of salt mixed downhole to help lubricate the drill bit above the 650-foot marker (from the surface). More Aquagel-brine mud was used down to about 1,000 feet to keep the hole from caving. The wellhead contains two valves; a master and a gate, both are closed. The total height of Umiat #10 is approximately 10 feet. The 8 5/8-inch casing is flared and open at the top. This well was plugged May 6, 2004 (Figure 47). with Aquagel and water (per barrel) were used The surface near Umiat #10 is in good shape. There is no existing pad and no solid wastes. With the recent plugging of the well, it is not a risk to human health and safety or the environment. 56 Figure 47: Plugging operations at Umiat #10. May 2004. APPENDIX B 20 Wells Currently Monitored by the United States Geological Survey: NAME Ati garu Awuna* Drew Point East Simpson #1 East Teshekpuk West Fish Creek # 1 Ikpikpuk Kugura Koluktak* Kuyanak Lisburne North Inigok North Kalikpik Peard Bay Seabee* South Meade South Harrison Bay Tunalik* Tulageak West Dease HOLE DEPTH(meters) 648 884 640 600 727 735 615 582 227 856 532 625 660 591 393 549 399 556 756 823 *Are also part of the CALM network (Circumpolar Active-Layer Monitoring). 57 m remote areas of the leased acreage. These staging areas have the potential to aid BLM's future remediation work associated with the legacy wells. Map 3 shows the relationship of usable airstrips to legacy wells. BI.M efforts 1976-1982 The USGS initiated cleanup of the early Navy wells in 1976 and contracted Husky Oil NPR Operations, Inc, to manage the project. The NPR-A was divided into four quadrants; Arctic Coastal Plain, Northwest; Southwest and Southeast. The cleanup effort focused on the solid and hazardous materials that were abandoned in place by the Navy and was carried out during two phases. After the spring thaw, crews would travel b}~ helicopter to new sites to break down and transport the wastes to an accumulation site. If a suitable site was located, non-combustible solid wastes were buried. While the ground was still frozen in the spring, aCat-Train crew retrieved wastes from storage sites established the previous summer. When hazardous materials (explosives and full drums of barite) were found they were transported to the storage site and hauled out the next spring. There is no evidence of anything hazardous remaining on site. In 1978, an extensive cleanup occurred at East Oumalik, East Topagoruk, Knifeblade, Ikpikpuk (explosives), Skull Cliff, Square Lake, Titaluk, Topagoruk, and Wolf Creek. A -- _ total of $1.87 million dollars was spent and 7.2 million pounds of solid wastes were handled. stockpiled or burned. During 1979, cleanup occurred at Fish_ Creek, Grandstand, Gubik, Oumali_k, and ----_.._ several other areas in which a well was planned but not drilled. Approximately $1.85 million dollars were spent and 24.1 million pounds were handled, stockpiled or burned. Field work for 1980 consisted of cleaning up what had been stockpiled and over-wintered from 1979. There is no recorded summary of cost or amount of wastes handled past 1979. In 1981, Husky discharged itself as contract operator and put out an invitation for bids. While waiting for bids, Husky continued its scheduled spring cleanup work at East Oumalik (Figure. 5), Wolf .Creek, Fish Creek, Kogru .River, Meade,_Oumalik, Square -- _ -- Lake, and_T`italuk. The USGS did not fund additional work at Skull Cliff. The contract received no bids and Husky did not return. The USGS drilling program ceased in 1982. is void of surticial debris. The cellar is visible in the mid- right portion of the photo. KNIFEBLADE TEST WELL 1 CRETACEOUS Chandler Formation, Killik tongue: 61-8201 Grandstand Formation: 8201-18051 KNIFEBLADE TEST WELL 2 CRETACEOUS Chandler Formation, Killik tongue: 51-1051 Grandstand Formation: 1051-3731 KNIFEBLADE TEST WELL 2A CRETACEOUS Chandler Formation, Killik tongue: 151-901 Grandstand Formation: 901-18051 . . Form. 9-5.3 (April 1952) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY CONSERVATION DIVISION *Sec. ___ ~\ ; , , : I I , , ' . _____,0_____,._____,-_____ , , ' , , ' , , ' I I ; ------:-----:----_.:--- -- : I J , , , ------:----_.,,----:._---- : : : : 1 : T. __.________________ R. ____________ INDIVIDUAL WELL RECORD __u____________________ Mer. fi..I~I.~Mr"' If. P. R .'4 Land office ______________ Date_u._~UE~_ 5, 195!\t_____ Ref. No. _____________ State Alaska ------ Serial No. ..- Cuuub.)' _ Lessee ______ Field KnÏ:teblade øea Operator tJ. s.. Na.~_________ District West øeast Regi.on Well N o. _~;f ebla.de_~!~_.~!~_t~__.________ * Subdivision ______________________________._______ * Location _.B~1ðÌ_lg.§2g~~11~__~:QP1i'~~~!...1._!!I!1..~__~__~!__~_~!'_~p~_~__'ª1_____________________ Drilling approved_ ____, 19_____ Well elevation __~__________ feet D ·11' d 0et. 13 52 n lUg commence ____....:_____, 19___ Total depth __ 1805 ___ feet Drilling ceased ke. a2 ___,19 52__ Initial production none Completed for production________, 19_____ Gravity A. P. I. __ ed Abandon-·4~1{'~-~--- Dee. ft,19_S2 Initial R. P.__ Geòlogie Formations Productive Horizons Surface Lowest tested N G'IM .Depths C01Item8 -------~ ----------- ----------------------- WELL STATUS ------------------------......---...- -------------------------- -- - YEAR JAN. FEB. MAR. APR. MAY JUNE JULY AUG. 8JiJPT. OCT. Nov. DBa. 1952 Drg. Irg. Drg. Abd. ----------- ----------- ----------- -----....----. ---------- ----------- ---------- ----------- ----------- ----------- --....---_...._- -----...----- --------- ---------------- ----------- ----------- ----------- ----------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- --------- -------------...-- ----------- --...._------- -----..---- ----------- ---------- ----------- ----------- ----------- ----------- ----------- ----------- .....----- ----------..--...-... ----------... ----------- ._--------... ----------- ----------- ----------- ----------- ----------- ----------- ----------- -...-------- ----- ...--....--------. ----------- .-----------. ----------- ----------- --- -------- ----------- ----------- ----------- ----.;.------ ----------- ----------- --- * Vnaurveyed REMARKs ______________________~___________ ...-...--------------------------------...----...----------------.;.--.;.--.;.-.;._....;..._-_.._~ ---------------------...--------------------------------..-----------------...----...---------..--------------------------------------- ------------------------- ------..----------------------------------------------------...----...--------------...------- ------------ëÑõi-¡g~Cãi-~~~.!~~!~~~~~!~~~r~~i!f~~]~!~~~~~~~~~~~==~~~~=---------------------------------~ -_.-_.._-_......._-------_...~~----------------------_..--------..-----..------------------- ;¡v~ U. s. COYIRHMENT PRinTING onrlCE 16-38067-4. TEST As, TIT.A.LUK .AND KNIFEBLADE AREAS,&KA /YJ 0 fA.)'¿¡ r r 397 was not defëiÏnii1ea oj Mr. 13fêwer as thermal equi- librium had not been reestablishëd when the last read- ings were obtained. The minimum temperature in the well could not be obtained because" of the loss of the upper cables. , (" KmFEBLADE TEST WELL~, 2A ) Kn1feblade 1: Location: Lat 69°09'04" N., long 154·53'21" W. Elevation: Ground, 993 feet; derrick lIoór, 999 feet Spudded: October 13, 195L Completed: December 22, 1951; dry and abandoned. Total depth: 1,805 feet. Knifeblade 2: Location: Lat 69°08'19" N., long. 154°44'12" W. Elevation: Ground, 871 feet; derrick lIoor, 876 feet. Spudded: .July 26, 1951. Completed : August 5, 1951; junked and abandoned. Total depth: 373 feet. Knifeblade 2A: . " "" Location: Lat 69°08'19" N., long 154·44'12" W. Elevation: Ground, 869 feet; derrick 1Ioor, 874 feet. Spudded: August 6, 195L Completed: October 7, 1951; dry- and abandOJÍed. 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, & 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, Alaska. (See fig. 28.) This structural feature is a little over 20 miles south of the Titaluk test well; the Titaluk rig could be seen from Knifeblade ridge on clear days. The name "Knife- blade" was given to the sharp-crested ridge by a pilot dying 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. 27B and 28~) The test well on the south side of the main thrust fault (see Structure) was thought to offer the best possibilities for finding oil; so it was drilled first. The number previously assigned to this test was "2," and this number was retained to prevent confusion in the records, although it was actually the first hole drilled. Knife- bladè test well 2 was drilled to a depth of 373 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 succeeding Knifeblade tests are as follows: KmG flJtlf Ue of fM 01&arwn.r fOf"lllGUotI (depf. fa feet) 1l'nt~..þ1AdA test well 1__________ 8-820 Knifeblade test well 2.._________ 5-105 Knifeblade test wen 2A..__________ 15-90 486318 18 I GrøIId.tflM4 /OfmGfltm (depf. ,,, fe8f) 820-1, BOG T. D~ 105- 373 T. D. 90-1, BOG T. D. oph-- t~ /<171 The rig was skidded 28 feet due north and Knife- blade test well 2A was drilled to a depth of 1,805 feet. Good shows were absent in the sandstones of the Grand- stand formation, although an asphaltic residue was noted. The hole produced some brackish water. (See page 414:.) Knifeblade test well 1 is 4,865 feet N. 23°13' E. of 2A in a bowllike depression that opens to the south near the top of Knifeblade Ridge. This test well was on a different 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 negligible. 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 thiclmesses with TitaIuk 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- ever, it is very un likely 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 Knifeblade area were determined by reconnaissance altimeter traverses by C. L. Whit- tington and have been tied to the Umiat datum. (See page 381.) The well elevations 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. STRUCTURB The following brief discussion of a structure in the Knifeblade anticline is based on the work of C. L. Whittington (written communication, 1956). The anticline is about 14 miles long and 4 miles wide, although it can be traced for many more miles as a low fold. A major thrust fault, thrust from the south, is north of and approximately parallel to the axis at the east end of the anticline. (See fig. 32.) Beds of the Chandler and Grandstand formations are pushed over strata of the Chandler formation. On the surface this fault is marked by an abrupt change in strike be- 11/~ F/- ..,," . . 398 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 f11" --f- __ ..... 10' - ___ " ---............. (J ¿'''' ... ........... ....., . KNIFEBLADE TEST WELL I 0 ¥2 1 " .......... ?- . "'< I Scale I~ miles I "''''''''''' ~ -1--\"/ ( I "'''''' KNIFEBLADETESTWELLS -1 D_, '.... -___2AND2A .Y--- ------------------- \ 155· 154"60' I I ----------------------- 40' I %A¡)--26'1.'~ t: ~ ~ ~. ... ,S! :> !;; :!: ~ ~ EXPLANATION -+-- Axis of anticline D u Fault U, upthrown side; D, downthrown side APPROX'MAT. MEAN D&CL.'NATION, t... t- Thrust fault r, upper plate ( ---------- Outline of anticline .ç. Dry hole _f11" 10' , ~ 155" 154"50' Geologic structure by C. L. Whittington, 1955 I 40' FIGURm 32.--outline of part of the Kntfeblade anticline, showing the closure on an Imaginary horizon in the Chandler formation and the relation of the test wells to important faults. The west end of the anticline, not shown on this map, is complexly faulted. 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, offsets 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 sufficient to permit a definite interpretation. No geophysical work was done in the area. Knifeblade test wells 2 and 2A were located on the southeast block, on the hanging wall of the major thrust. There is no evidence in either of the two holes to suggest that they penetrated this thrust fault. Be- cause they are so close together, correlation between 2 and 2A is excellent. The top of the Grandstand forma- tion is at 766 feet above sea level in test well 2 and at 779 feet above sea level in test well 2A, a difference of 13 feet, indicating that the beds dip 25° on that zone, assuming 1 hole is directly down dip from the other. A dip measured on the surface nearby is 19°8. as the fault is approached. Dip .measured on the cores in Knifeblade test well 2A decreases from about 40° in the upper 2 cores (171 and 365 ft) to 20~ or less in Ùë deepest cores. The 1,805 feet of beds drilled in test well 2A represents an actual thickness ~f approxi- mately 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 well site it is 18°NE. Dips measured on cores range from 5° to 15°, much less than in Knifeblade 2A. There is no evidence of faulting in Knifeblade test weIll. The top of the Grandstand formation in Knifeblade test well 1 is at 179 feet above sea level, or 600 feet lower than in Knifeblade test well 2A on the overthrust sheet. Correlation between the two holes is good both litho- logically and paleontologic ally after taking into con- sideration differences in thickness due to dip. The test well;;; 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 history. TES.LLS, TlTALUK AND KNIFEBLADE ARE~KA Core Depth (feet) DESCRIPTION OP CORES AND CUTTINGS The following descriptions of cores and cuttings of the Knifeblade tests were made by the author on the material shipped to Fairbanks from the Reserve at the time of drilling. AIl samples were described dry, and the colors can be referred to the National Research Council's Rock Color Chart (Goddard and others, M 1948). See plate 26 for a graphic representation of the I4Y lithology of the Knifeblade tests. {!'^-kJ. ~---,7 105-130 130-140 ( . XNXFEBLADE TEST WELL 1 ~ The quality of the well cuttings was good, but there may be loose sand contamination in the lower 250 feet. ".le L:d. l . -3__ . t· ......0 ogu; ......cnp ¡on [Where no core Is listed, descr:lptlon Is based on cutting samples) '~kfl- Core Depth (feet) ~ ~ ~ t .~ ~- 2. '- '.I (... ~~ ~ ~ ~.~ ..;t ~ 40-45 45-55 55-60 60-65 65-70 70-90 90-95 95-105 140-155 Remarks 155-160 0-6 6-40 Height of derrick floor above ground level. Sandstone, light-gray very fine to coarse- grained, very slightly calcareous; yel- lowish iron stain near the surface; grains subangular to subrounded; 15 percent is white and clear quartz; remainder is dark-gray and brownish chert, dark rock fragments and car- bonaceous particles, ironstone particles and other rare minerals; some black carbonaceous plant impressions. As much as 5 percent moderate yellowish brown and light-olive-gray clay iron- stone. Clay shale, medium- to medium-dark- gray; trace of medium-dark-olive-gray ironstone. Coal, black, shiny to dull; blocky fracture; trace of medium-light-gray clay shale and clay ironstone. Sandstone, light-grayj mostly white and clear quartz, some carbonaceous par- ticles, dark chert and rock particles; outstanding in abundance of interstitial J<)ricitc which makes up 25 percent of total volume of rock and gives rock chips a silky sheen; trace to 5 percent moderate yellowish-brown clay iron- stone. Clay shale, light- to medium-light-gray, micaceous; trace of sandstone. Coal, black, shiny to dull, thin-bedded, brittle; 5 percent medium-light-gray clay shale. Clay shale, medium-light-gray, sericitic, silty; 10 percent coal and trace of clay ironstone at 70-75 ft. No sample. Clay shale, medium-tight-gray; also 15 percent very fine-grained nonealcareous sericitic sandstone and siltstone; trace of dark-gray carbonaceous shale. ~ 160-165 165-170 17{}-185 185-190 1 190-194 399 Lithologic description-Continued Remarks Clay shale, medium-tight-gray; trace to 10 percent dark-gray shale at 105-110 ft and 115-120 ft; trace of sandstone at 105-110 ft aI!d 125-130 ft; trace of ironstone at 120-125 ft. Clay shale, medium-tight-gray, micaceous, and sandstone, tight-gray, sericitic; trace of light-brownish-gray clay iron- stone. CIayshale, medium-tomedium~tight-gray; 5 percent dark carbonaceous shale and black coal at 140-145 ft; 10 percent medium-tight-gray siltstone and sand- stone; as much as 5 percent brownish- gray clay ironstone. Sandstone, light-gray, medium-grained; grains subangular to subrounded; 80 percent white and clear quartz; also carbonaceous particles, dark chert and rock fragments; 5 percent grayish-brown ironstone, 10 percent medium-grey clay shale. Coal and carbonaceous shale, black, dull to sl-iny; 20 percent sandstone as above; 10 percent clay ironstone. Clay shale, medium- to medium-light-gray, 60 percent; 30 p~rcent coal and car- bonaceous clay shale, 10 percent clay ironstone, trace of pyrite. Clay shale, medium-light- to mooium- dark-gray, sericiticj 30 percent siltstone and some véry fine-grained sandstone at 17{}-175 ft, 15 percent black sbiny coal at 180-185 ft. Siltstone, and very fine-grained sandstone, 60 percent; 30 perceDt medium-light- gray clay shale; 10 percent coal and carbonaceous shale. Recovered 4 ft: Microfossils absent. 1 ft, sandstone, medium-light-gray, fine-grained, bard; grains subangular to rarely subroundf!d.; 80 percent white and clear quartz: fairly large amount of carbonaceous particles; some dark chert, rock fragments and mica; much sericitic mica in the matrix gives silky sheen to fractured surfaces; very rare carbonaceous partings; noncalottreous: dip possibly ? 10°-15°(1). No·shows. 2 ft, clay shale, medium- to medium- light-gray, noncalcareous, medium- hard; fair cleavage; dip undetermined. 1 ft, clay shale, medium-dark-gray, moderately soft; fair cleavage; car- bonaceous particles and fragments in partings. Several laminae as much as one-half inch thick of black shiny brittle platy coal. Dip undetermined. - e . 400 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-1S3 Lithologic åescription-Continued Core Depth (feet) 194-205 206-210 210-265 265-267 2 267-271 ® 271-290 290-295 295-306 305-311 3 311-315 ® Lithologic description-Continued Remarks Clay shale, medium-light- and medium- dark-gray; 6-10 percent siltstone and sandstone, 88 much 88 10 percent black shale and ~al. Sandstone and siltstone, light-gray fine- grained to silty; 70 percent white and clear quartz; ironstone and carbona- ceous particles common; also dark chert and rock fragments, sericite is abun- dant in matrix and gives sheen to chips noncalcareous; 5 percent dark-gray carbonaceous shale; trace of çoal. Clay shale, medium- to dark-gray; trace of siltstone at 215-225 ft, carbonaceous partings at 220-225 ft, 10-20 percent black shiny coal at 230-240 ft, trace of coal at 255-260 ft. S~ne, light-gray, medium-grained, 70 percent; grains subangu]ar; 65 per- cent white and clear quartz; 30 percent medium-gray clay shale; abundant black ~oal particles; some brownish and some gray chert; no sericite; slightly calcareous cement. Recovered 4 ft: Microfossils absent. 1 ft, sandstone, light-gray, very fine- to fine-grained; represented in core box by chips up to three-quarter inch in diameter and a few larger pieces; 75 percent white and clear quartz; abundant black coal particles and some dark-gray c:tiëii" and rock frag- ments, rare white mica; argillaceous cement; dark carbonaceous partings; very slightly calcareous; at 267 ft the effective porosity is 4.42 percent and the sample is impermeable; no shows. 3 ft, clay shale, medium- to medium- light-gray, very silty; grades to non- calcareous bard siltstone, poor cleav- age; dip 13°. Clay shale, medium-light- to dark-gray, 50-80 percent; 88 much as 40 percent light-gray medium-grained salt and pepper sandstone, with 40 percent dark minerals; non calcareous, also 40 percent black coal at 283-287 ft; trace of brownish-gray clay ironstone. Sandstone, light-gray, fine-grained, seri- citic; also medium-dark-gray clay shale rarely medium light gray. Clay shale, medium-light-gray, silty, Beri- citic; 5 percent medium-dark-gray clay shale. Siltstone and sandstone, as in core below; 30 percent medium- to medium-light- gray clay shale. Recovered 4 ft: Microfossils absent. Sandstone, ligbt-gray, massive, fine- to rare medium-grained, bard; sub- Core Depth (feet) 315-360 360-365 4 365-368 (j 368-380 380-405 405-415 415-420 420-450 450-455 Remarks angular grains 75 percent white and clear quartz; also rock fragments, dark chert, carbonaceous· particles, white mica, and tan earthy particles; micaeeouS-argillaceous-noncalcareous cement; dip 8°; no shows. At a depth of 314 ft the effective porosity 5.29 percent; and the sample is impermeable. Clay shale, medium- to medium-light- gray; trace to 15 percent sandstone at 316-320 ft, 340-345 ft, and 355-360 ft; 5 percent black shiny co~ at 33D-335 ft; trace of ironstone throughout. Sandstone, light-gray,. medium-grained; subangular grains; 85 percent white and clear quartz; 15 percent medium-dark- gray clay shale; also dark chert, car- bonaceous particles, rock fragments and some white mica; slightly calcareous. Recovered 6 in.: Microfossils absent. Sandstone, medium-light-gray, fine- grained, bard; angu]ar to subangular; 85 percent white and clear quartz; also rock fragments, coal particles, dArk chert, some white mica; argil- laceous cement; noncalcareous; dip undetermined; no shows. Sandstone, as in core above, noncalcare- ous; carbonaceous impressions at 375- 380 ft. Clay sbale, medium-to medium-dark-gray; 10 percent very fine-grained sandstone and siltstone at 380-385 ft; trace of siltstone at 385-390 ft; 20 percent light-gray fine- to medium-grained salt and pepper sericitic sandstone at 395- 405 ft; trace of clay ironstone at 395-400 ft. Clay shale, medium- to medium-light- gray; trace of siltstone. Sandstone and siltstone, medium- to medium-light-gray, very fine- to fine- grained; 75 percent quartz; some iron- stone particles. Clay shale, medium-light- to medium- dark-gray; trace to 10 percent sandstone and siltstone at 420-435 ft; 5 percent brownish-gray clay ironstone at 420-430 ft; and trace of black shiny coal and carbonaceous shale at 420-4!r'1i; 15 percent siltstone at 445-450 ft. Sandstone, light-gray, fine-grained; grains subanguJar to subrounded; 70 percent white and clear quartz; remainder is dark chert, rock, clay ironstone and carbonaceous particles; abundant in- terstitial mica; noncalcareous; trace of siltstone; 10 percent clay shale. Core Depth (feet) 455-475 475-480 ---- 4~5oo 500-505 5~535 535-540 540-567 5 567-570 ® 570-575 575-605 .WELLS, TlTALUX AND KNIFEBLADE ARE' ALASKA Lithologic ducription-Continued Bemarb Com Depth (feet) Clay shale, medium~ to medium-light- gray¡ 5-40 percent silty sandstone as in the above 455-465 ft; trace of black shiny coal at 465-470 ft, 20 percent light-g;åÿ siltstone at 470-475 ft. Coal, black, shiny, 30 percent; 30 percent carbonaceous dark-gray shale; 30 per- cent medium-gray clay shale: 10 percent siltstone. Clay shale, medium- to medium-light- gray; trace of medium-dark-gray clay shale; trace to 10 percent sandstone and siltstone; trace of yellowish-brown clay ironstone at 480-485 and 490- 500 ft. Clay shale, medium- to medium-light- gray; 75 percent; and 25 percent sand- stone made up of 70 percent quartz, quite sericitic, very slightly calcareous; trace of ironstone. Clay shale, medium- to medium-light- gray¡ 10 to 15 percent siltstone at 505- 515 ft, and trace of siltstone at 520-525 and 530-535 ft, trace of coal and car- bonaceous shale at 510-520 ft, trace of grayish-brown ironstone at 505-510 and 515-620 ft, 5-10 percent olive-gray, and yenowish-brown ironstone at 525- 535 It. Siltstone, medium-light-gray; and medi- um~ to medium-light-gray clay shale ¡ 5 percent ironstone. Clay shale, medium- to medium-dark- gray, some dark-gray¡ 10 percent very fine-grained light-gray sandstone; trace of ironstone at 540-545 ft. Recovered 2 ft: Microfossils absent. Claystone, medium-dark- to dark-gray, dense, hard to very hard; grades downward through siltstone into 6 in. of medium-gray very fine-grained silty sandstone; dark carbonaceous plant impressions in sandstone; non- calcareous. Dip possibly 100. Clay sh&lè, medium- to medium-dark-' gray; 20 percent medium-light-gray. very fine- to medium-grained sand-. stone¡ much carbonaceous material¡ sericitic¡ very slightly cal,..A.reo~¡ trace of brownish-gray clay Ironstone. - , _ Clay shale, medium- to medium-dark- gray; carbonaceous partings at 59()'-595 ft; traoe of medium-dark-gray siltstone at 5~85 ft¡ 5-20 percent medium-' to medium-light-gray siltstone; very fine~ to, fine-grained very slightly cal- . careous sandstone; trace of dark-ýëi- lowish-brown clay ironstone at 590-595 ft; 10 percent black shiny coal at 600- 605~ .-- 605-610 6HHi40 640-645 ---- 645-660 660-665 665-700 700-710 710-745 745-750 75()'-768 6 768-773 ® 773-780 401 LitTwlogic de,cription--Continued Bemarb Coal, black, dull to shiny¡ blocky fracture; and dark-gray carbonaceous shale; 15 percent medium-gray clay shale; 5 percent dark-yellowish-brown clay iron- stone. Clay . shale, medium~ to medium-dark- gray, rarely dark-gray¡ trace to 5 per- cent coal at 610-620 ft¡ trace to 5 percent yenowish-brown and brown clay ironstone at 615-620 and 630-640 ft¡ 5-10 percent finè-grained medium~ light-gray sandstone at 625-630 and 635-640 ft. Sandstone, medium-light-gray, fine- grained¡ 70 percent white and clear quartz ¡ remainder is carbonaceous particles, dark chert, and ironstone particles: coal-1 partings, slightly ~ ~ous; 10 percent medium-dark- to k-gray clay shale¡ olive-gray iron- stone quite common. Clay shale, medium- to medium-dark- gray ¡ trace of ironstone at 645-650 ft. Clay shale, medium-dark- to dark-gray; 20 percent black shiny =- Clay shale, medium~ to medium-dark~ gray¡ trace of siltstone at 665-670 ft; trace of dark-gray carbonaceous shale; black dull and shiny coal at 670-680 ft. Clay shale, medium- to medium-dark- gray¡ 10-20 percent medium- to medi- um-light-gray sandstone and siltstone; much carbonaceous material; mod- erately calcareoUS¡ trace to 5 percent olive-gray ironstone. Clay shale, medium- to medium-dark- gray, rarely dark-gray; 10 percent medium- to medium-light-gray very fine-grained slightly to moderately cal- careous sandstone and siltstone ¡ 5 per- cent black dull coal and carbonaceous shale at 735-745 ft';- trace of brownish- gray clay ironstone at 710-715 and '730-735 ft. Clay shale, medium-dark-gray¡ many plant fragments; also 30 percent black shiny coaL Clay shå1ë,'" medium-light- to medium~ dark-gray; trace of coal and carbona- ceous partings; trace 01 ironstone at 750-760 ft, trace of siltstone at 765- 768~ Recovered 5 ft: Microfossils absent. Clay shale, medium-dark-gray, Don- calcareous, hard; fair oleavage; very rare slightly silty streaks; dip not determined. Clay shale, medium-gray with trace of ctark-graYi 10 percent; black shiny !2!!- 402 ConI -ti i ~ u__ ~~ -- ~ J .---- . . EXPLORATION OF NAVAL PETROLEUM RESERVE NO.-4, NORTHERN ALASKA, 1944-53 Depth (feet) . 780-785 - 7~795 79&-815 815-820 820-826 7 826-830 ð> 830-845 8 84&-846 Œ> 846-850 Lithologic description--'Continued Remarks Coal, black, shiny, 40 percent; and medium~ray clay shale; trace of iron- stone. Sandstone, medium-light-gray, fine-' grained; made up of 6&-70 percent white and clear quartz; fairly large amounts of carbonaceous or ~all material, clark chert, much sencite;· very slightly calcareous; 10 percent clay shale; trace of konstone. Clay shale, medium-ligbt- to medium- dark-gray; 5 percent dark-gray earbo- ' naçeous shale at 800-805 ft. No sample. Sandstope, light-gray, fine-grained, 8Ò per cent; composed of 75 percent white and -_ clear quartz; also carbonaceous frag- ments, dark chert, rock fragments; no sericite; very slightly calcareous; 20 percent medium-dark-gray clay shale. The top of the Grandstand formation is pìë:cëa at 820 ft. Recovered 4 ft: Microfossils' absent. Sandstone, light-gray, salt and pepper, very fine- to very coarse-grained" hard; subangular to lounded grains; up to 50 percent dark material- coal particles, rock fragments and d:rlc-gray chert; remainder is mostly white and clear quartz and light- earthy particles. Several streaks of conglomerate up to 2 in. thick. contain subrounded to rounded gran- : oles and pebbles of clark-gray green- ish-gray and black chert, milky· quartz, coal, medium- and medium- light-gray clay shale, yellowish-gray _ ironstone and light-gray sandstone; noncalcareous; at a depth of 828 ft the effective porosity is 10.58 per-_ cent, and the sample is impermeable;: dip 9° (1). - Sandstone, as in core above, medium- to coarse-grained; 5 percent very pale- orange clay ironstone and trace of dark-gray clay shale at 830-835 ft. Recovered 1 ft: Microfossils absent. 6 in., sand, fine- to medium-grained, loose; and very small chips of light- gray sandstone, highly rust-stained from metal chips from the bit; grains angular to subangular; 90 percent white and clear quartz; remainder is dark chert and'= particles. 6 in., sandstone, light-gray, very hard; possibly slliceous cement; composi- tion as above, but with larger pro- portion of dark materials; noncal- careous; dip undetermined; no shows. Sandstone, as above. Core 11 Depth (feet) 850-878 9 878-882 @ 882-910 10 910-915 Q9 915-930 930-935 93&-940 940-945 94&-950 950-955 955-960 ® Lithologic de8cription--Continued Remarks Clay shale, medium-light- to medium- dark-gray; &-25 percent medium- grained sandstone at 850-860 ft; trace of fine-grained sandstone containing much carbonaceous material at 86&- 875 ft; 35 percent medium-light,..gray fine-grained moderatelyoaIcareous sand. stone at 87&-880 ft; trace of olive- gray ironstone at 87&-880 ft. Recovered 3 ft 6 in.: MicrofosSils absent. 1 ft 6 in., sandstone, medium-light- gray, very fine-grained to sllty, medium-b.a.rd; subangular to sub- rounded; largely white and clear quartz; some dark chert, rock frag- ments; dark micaceous-carbonaceous partings; very slightly - calcareous; dip undetermined; no shows; be- comes slltier toward base. Grades into unit below. 2 ft, clay shale, medium-clark-gray,non- calcareous medium-hard, poor cleav- age; dip undetermined. Clay shale, medium-dark-gray; sllty at 900-910 ft; slightly to moderately calcareous at 89&-910 ft. Re~vered 3ft: Microfossils absent. Clay shale and claystone, medium- gray, slightly silty, non calcareous, medium-hard; poor to fair cleavage; some micaceous-carbonaceous part- ings; a few black plant impressions in partings; dip 5°-10°(1). Clay shale, medium-light- to dark-gray; trace ironstone at 920-930 ft; trace black shiny ~ at 92&-930 ft; 5 percent medium-light-gray very fine-grained sandstone. Sandstone, medium-light-gray, sllty to tine-grained; composed of 75 percent white and, clear quartz; also carbona- ceous particles, dark chert, some sericite, slightly calcareous; 20 percent black dull to shiny coal and carbonaceous shale; trace of ~um-gray clay shale; trace of grayish-brown ironstone. Sandy slltstone, medium-light,..gray; and 40 percent medium-gray clay shale; trace of coal. - Clay shale, medium- to medium-light- gray. No sample. Siltstone, and very fine grained sandstone, medium-tight-gray, 40 percent; and medium- to medium-dark-gray clay shale; trace of dark-yellow-brown clay ironstone. Recovered 3 ft 9 in.: Microfossils absent. Siltstone and sandstone, medium-light- gray, hard,~ight ;}airly good cleavage ; Core Depth (teet) 960-965 965-1,000 1, 000-1J 010 1,010-1,020 1, 020-1, 030 1,030-1,040 1,040-1,085 1,085-1,100 IJ 100-1, 145 1J 145-1J 149 TES&LLSJ TlTALUK .AND KNIFEBLADE JALASKA Lithologic description-Continued Remarks dark carbonaceous 2<>alt partings; sandstone is very fiñe grained; sub- angular grains consist primarily of opaque grayish-white quartz; also rock fragments and carbonaceous particles; much sericitic material in the matrix gives sheen to the hand· specimen; nOD calcareous; dip 8° (?). Siltstone and clay shale, medium- to medium-dark-gray; trace of coal and ironstone. - Clay shale, medium- to medium-dark- graYJ rarely medium-light- and dark- gray; trace of coal at 970-975 and 990- 995 ftJ trace omnstone at 990-995 ftJ . - 10 percent black dull and shiny coal at. 995-1,000 ft. _ - . Clay shale and coalJ 60 percent. Shale is dark gray ana carbonaceous; also medium- and medium-dark-gray _ clay shale; 5 percent slightly calcareous sandy siltstone; trace of pyrite. Coal, blackJ shiny, 10-20 percent; blocky ""{¡:acture; 20 percent dark-gray clay shale; 70 percent medium-dark-gray clay shaleJ trace of pyrite, ironstone, and siltstone; p.!:!.ec~d fragments and ostracod impression at 1,015-1,020 ft. Clay shaleJ medium- to medium-dark- gray; 20 percent dark-gray clay shale. Coal, blackJ dull to shinYJ 30-SO percent; . medium- to dark-gray clay shale; 10 percent medium-dark-gray sandy silt- stone; one piece of siltstone with bi- tumen stain. Clay shale, medium-dark- to dark-gray; trace of siltstone and sandy siltstone· at 1JO~IJ050 ftJ trace of medium-dark- olive-gray calcareoulJ siltstone with bi- tumen at (065-lJ075 and IJ080-lJ085 ft; 5-10 percent coal at 1,075-1,085 ft; trace of pyrite a£"IJ075-1,OSO ft. Coal, blackJ shinYJ 20-30 percent, and -cIåy shaleJ medium-dark to dark-gray; . trace brownish-gray ironstone. Clay shaleJ medium-dark- to dark-gray; trace to 10 percent of S2!!at IJI00-1,125 ft; 5 percent coal at 1,1~lJI45 ft; trace of sandy -;m;tone at 1,135-1,140 . ft; trace of pyrite at IJ120-IJ125 and IJl~IJ145 ft; shell fr8. l!;ments at IJl00-l,105, 1,110-1,120, and 1J130- 1,135 ft; lnoceramtul prisms at IJno- 1J12O ft. Sandstone, light- to medium-light-gray, salt and pepperJ medium-grained, looseJ soft; grains subangular with a few sub- rounded; 60, percent white and clear quartz; many ~Mf - particles, dark chert. .rock fragmentsJ some white mica, Core Depth (feet) 12 1, 149-1, 152 ~ 1, 152-1, 155 1, 155-lJ 160 13 1, 160-1, 165 ® 1, 165-1, 195 1, 195-1, 200 1,200-1,220 1,220-1,245 1,245-1,250 ---- 1,250-1,255 1,255-1,265 14 1,265-1,270 ~ 403 Lithologic deøcription-Continued Bemazoks noncalcareous; 10 percent medium- dark-gray clay shale. Recovered 1 ft: Microfossils common. Core consists almost entirely of mud containing a few chips of medium- gray clay shale. Sandstone 88 in interval IJ145-lJ149 ft; few coarse sand grains. Sandstone 88 in interval above core 12J medium- to coarse-grained. Recovered 3 ft 4 in.: Microfossils absent. Sandstone, medium-light-gray, thin- bedded(?), medium-grained; moder- ately hard; grains subangu1ar; 75 percent white and clear quartz; many dark rock fragments and chert, some mica and a few other minerals. Non- calcareous; no shows; dip probably 5° or less; at 1,162 ft the effective poros- ity n.5 percent and the air permea- bility < 1 millidarcy. Sandstone, medium-light-gray, salt and pepper, loose, medium- to rarely coarse- grained; fine to medium grained at base of interval; 70 percent white and clear quartz; remainder largely dark chert, some coaly particles and rock fragments. Nonc&Icareous; 5-20 percent medium- to medium-dark-gray clay shale. Clay shale, medium- to medium-dark- graYJ 60 percent; also some loose sand 88 above. SiltstoneJ medium-dark-gray; slightly sandy at 1,200-lJ210 ft; argillaceous (40 percent near base of interval) at IJ210-1, 220 ft; trace of coal at 1,200- 1,205 ft. -..._- Clay shaleJ medium-dark-gray; trace to 15 percent siltstone with bitumen stain. Siltstone, medium-light-gray, sandy, non- calcareous, SO percent; bitumen stain; and medium-dark-gray clay shale. Clay shale, medium-dark-gray, 60, per- cent; also 15 percent medium-light- gray sandstone and medium-gray silt- stone; chunk of stubby lnocerGm~ prisms; bitumen stain. SañãšlõÏie, medium-light-gray, very fine- to coarse-grainedJ 75 percent; also me- dium- to medium-dark gray clay shale; very rare bitumen in cracks. CoDStit- uents as in core below. Recovered 3 ft: Microfossils absent. Sandstone, medium-light-gray, salt and pepper, medium-grainedJ hard, mas- sive; rare coarse grains; 75 percent white and clear quartz; much dark chert and some rock fragments; cal- careous cement; very rare browñIšL. plant 1mpressions; dip undetermined; 404 . . EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 Lithologic dBBcription-Continued : "Lithologic dèecription-Continued Core Depth (teet) 1,270-1,295 15 1,295-1,298 (3) 1,298-1,325 1,325-1,335 1, 335-1,355 1,355-1,365 1,365-1,375 16 1,375-1,379 f1) Remarks no shows. At 1,269 ft the effective; porosity 13.06 percent and the air permeability < 1 millidarcy. Carbon-' ate content at the same depth 19.64 p;.eent by weight. Sandstone, as aboye, mostly unconsoli- dated; medium- to coarse-grained at, 1,265-1,280 ft, fiDe- to medium-grained' at 1,280-1,295 ft, slightly calcareous slightly harder, interval of rock at 1,280- 1,285 ft; sericite in matrix; rare bitumen on broken surfaces at 1,285-1,295 ft. Recovered 1 ft: Microfossils absent. Sandstone, medium-light-gray,' fine- grained, hard; subangular tÖ rare subrounded; 80 percent white and clear quartz; remainder is dark chert, coal particles,' rock fragmen~ and' mica. Noncaleareous to very cal- careous: no shows; at 1,297 ft the effective porosity 8.16 percent and: the sample is impermeable. Sandstone, as above, fine-grained; slightly calcareous at 1,295-1, 300ft, moderately calcareous at 1,310-1,315 ft, slightly, calcareous at 1,315-1,325 ft; very fine grained and composed of 90 pèrcent white and clear quartz at 1,320-1,325 ft. Siltstone, and very fine-grained sandstone, slightly calcareous; some clay shal~ near . base of interval. Clay shale, medium- to medium-dark- gray; 20 percent siltstone at 1,335- 1,340 ft. Ditrupa fragments through- out. - Sandstone, light.-gray, fine- to medium- grained, 50 percent; 85 percent white and clear quartz; remainder is mostly dark chert and some rock fragments, slightly calcareous; also 30 percent medium-dark-gray clay shale; Ditru~. Sandstone, as above; mostly loose sand, noncalcareous. Trace of clay shale; Ditrupa at 1,365-1,370 ft. Recovered 3 ft: Microfossils absent. Sandstone, medium- to medium.,light- gray, very fine- to medium-grained, hard subangular grains; 75 percent white and clear quartz; remainder is rock fragments, dark-gray chert, mica, . pyrite, and other minerals rare; rare partings of coal. Very few pieces of core have "bitumen or a ,tarry- residue on broken surfaces, also a very small amount of medium- gray, noncalcareous to slightly cal- careous claystone. Dip undeter- iñiiìë'a; possibly low; no cut or resi- due from 1,377 ft. At 1,377 ft Core Depth (feet) 1,379-1,390 17 1,390-1,395 ø (~ \{ I ~ q i). 1,395-1,435 1,435-1,445 1,445-1,465 1,465-1,485 18 1,485-1,490 (8) 1,490-1,495 Remarks effective porosity 4.58 percent and air permeability 2.72 millidaroys. Sandstone, as in Core above, me!lium- grained; very slightly calcareous at 1,385-1,390 ft. Recovered 3 ft: Microfossils absent. Sandstone, medium- to medium-light- , gray, medium- to coarse-grained salt and pepper, hard; subanguIar grains; 70 percent white and clear quartz; rem&inder is mostly dark-gray and black rock fragments and chert; noncalcareous; argillaceous cement and much interstitial bitumen; dip 12° (1). Trace of an odor, brownish- yellow cut and blackish-yellow-brown residue from i,394 ft. At 1,394 ft effective porosity 6.08 percent, and air permeability 2.66 millidarcys. Sandstone, as in core above, fine-to medium-grained; mostly loose sand; slightly calcareous at 1,415-1,420 ft, moderatelycalcareo~ at 1,395-1,400 and 1,430-1,435. ft, much rust stain from bit at 1,425-1,435 ft, chunk of lnoceram'UB prisms at 1,430-1,435 ft, 5-25 percent medium-dark-gray clay shale at 1,405-1,420 ft. . Sandstone, medium-light-gray, fine- to medium-grained, salt and pepper; grains subangular to subroundeð; 60 percent white and clear quartz; much dark chert and some rock fragments; slightly to moderately calcareous ce- g¡¡j;. Rare lnoceram'UB ·prisms. Sandstone, medium-light-gray, line- to medium-grained; 75 percent white and clear quartz; sericitic in part; very slightly calcareous at 1,450-1,465 ft, very calcareous (!ement at 1,451)-,1,465 ft. - Sandstone, light- to medium-light-gray, very fine- to fine-grained, silty, 50 per- cent; very calcareous cement at 1,465- 1,470 ft; chunk of l!lf'C61'am'UB prisms; also as much as 50 percent medium- dark-gray. shale; trace of coal and pyrite at 1,475-1,480 ft. - Recovered 2 ft 6 in. Microfossils absent. Sandstone, medium-light-gray, thin- bedded, very fine grained to silty, hard; subangular to subrounded grains; 90 percent white and clear quartz; also dark chert and rock fragments; noncalcareous; dip unde.- termined; no shows. At 1,486 ft effective porosity 11.1 percent, and air permeability < 1 millidarcy. Sandstone, as in core above, silty, nODcal- careous. Core Depth (Ceet) 1,495-1,505 1,505-1,510 1, 510-1, 515 1, 515-1, 550 -.-- 1, 550-1, 580 1,580-1,590 1,590-1,600 1,600-1,660 1, 660-1, 685 1,685-1,710 19 1,710-1, 712 @ 1, 712-1, 715 1,715-1,730 'l'ELLLS, 'l'ITALUX .AND XNIFEBLADE A ALA.SK4 Lil.kologic description-Continued Bemarb Siltstone, medium-light-gray; and very fine light-gray sandstone; very cal- careous cement; also 30 percent medium- gn..y ClaY shale. Sandstone, medium-light-gray, fine- grained; grains subanguJar to sub- rounded; 90 percent white and clear quartz; remainder is dark chert and rock fragments, some sericite, car- bonaceous patches; moderately cal- carØ()Us cement. - Siltstone, and very fine sandstone; mod- erately to very Cþlcareous cement. Clay shale, medium-dark-gray; trace of medium-gray noncalcareous siltstone and very fine-gra.ined sandstone at 1,515-1,520 and 1,530-1,540 ft; 25 per- cent very fine sandstone and siltstone; DüruPtJ at 1,535-1,540 ft. Sandstone, light- to medium-light-gray, very fine-grained; grains subangular to subrounded; 90 percent white andJclear quartz; trace of dark-yellowish-brown clay ironstone at 1,555-1,560 ft. trace of bitumen throughout. Siltstone, medium-light-gray; trace of clay shale. Sandstone, light-gray, fine- to medium- grained, salt and pepper, soft and friable; 65 percent white and clear quartz; subangular to rarely angular. Sandstone, light-gray, mostly loose sand, fine-grained, rarely medium-grained; 75-85 percent white and clear quartz, some siltstone and clay shale; trace of carbonaceous shale at 1,615-1,620 ft. trace of bitumen in siltstone at 1,625- 1,630 ft, ~ltJ at 1,605-1,620 ft. lnoœramUB pnsms at 1,625-1,630 ft. Clay shale, medium-d&rk-gray; 30-40 percent medium-gray sandy siltstone at 1,660-1,675 ft; 30-50 percent sand- stone at 1,675-1,685 ft. Sandstone, light- to medium-light-gray, very fine-grained; grains subangular; 90 percent white and clear quartz; dark chert and a minor amount other minerals; slightly calcareous; trace medium-d&rk- clay shale. - Recovered 8 in.: Microfossils very rare. Siltstone, mediuin-gray, very slightly calcareous, very bard; dip undeter- mined. Siltstone, medium- to medium-light-gray, sandy, noncalcareous; trace medium- dark-gray clay shale. Clay ehale, medium- to medium-dark- gray, silty. . . Core Depth (feet) 1, 730-1, 735 I, 735-1, 750 1,750-1,755 1,755-1,760 1,760-1,765 1,765-1,770 1,770-1,785 1,785-1,795 20 1,795-1,800 1,800-1,801 1,801-1,805 21 ® Cole Depth (Ceø&) o-s 5-15 ---- 15-2/i 25-65 '" 4Õ5 Lithologic description-Continued ReÌD8l'b Siltstoñe, medium- to medium-light-gray; 20 percent medium-dark-gray clay shale; rare bitumen coating. Clay shale, medium- to medium-dark- gray, very silty. Siltstone, and very fine sandstone, me- dium-light-gray, slightly !:ßlcareous: 30 percent medium-dark-gray clay sbale. Clay shale, medium-dark-gray, 75 percent; 30 percent medium-dark-gray slightly calcareous siltstone. Siltstone, medium-light-gray, slightly cal- careous, slightly micaceous, 80 perce";ii; ã1šõëJåy shale; Ditrupa. Sandstone, light-gray, very fine-grained to silty; grains subangular with some sub- rounded; 90 percent white and clear quartz; also carbonaceous and mica- ceous particles, dark chert and rock fragments; 10 percent medium-dark- gray clay shale. Slightly calcareous. Siltstone, and very fine saÍulstone, slightly csJ.ca.reous j trace of clay shale. Clay shale, medium-gray, silty, traoe of co~; Ditrupa at 1,780-1,790 ft. No recovery. No sample. Recovered 1 ft 2 in.: Microfossils common. Clay shale, medium-dark-gray, fiÌ1ely micaceous; . noncalcareous, moder- ately bard; fair cleavage; dip unde- termined. , ---.. i ~WBLL.. 7 ~ from this test was good. : , . 412 . . EXPLORATION 011' NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 Can Depth (1-) 1,822-1,881 24 1,881-1, 8M 1,864-1,890 1,890-1,125 1, '12&-1, 130 . 1,130-1,165 1,15~1,185 1,166-1,110 I, 110-1, 115 1,11~1,18O 1,180-1,186 1,186-1,190 25 1,190-1,802 1, 802-1, 805 LitAologtc tløcrip 'ÌOft-Continued Bemarb mostly dark chert, some carbonaceous particles aDd mica, other miDeralø rare; rare ar¡iJJaoeous partinp; nOD- calcareous; dip 8°-19°; lIOIDe croeø- bedding; nO shOWll. Looee aaDd. 85 percent fiDe-¡rained, rarely very ~e- or medium-grained; white and clear quartz. Recovered 1 ft 9 in.: MicrofOSBils absent. Sandstone, light-gray, fine-grained, hard; 90 percent white aDd clear quartl; remainder is dark chert. coal, and rock particles; argillaceou8 cement; one black carbomed-coaly plant fragment 2J' in. long aDd One quarter inch wide; noncalcareous; dip SO-I2"; no shows. At 1.661 ft effeo- tive porosity 6.13 percent, and sample Is impermeable to air. Loose saDd, very fiDe- to fiDe-grained; 86 percent white aDd clear quartz; One clay chip at 1,680-1,685 ft. Sandstone chips. light-gray. very fine- grained; trace to 8 percent sDtstone and trace of clay øbale; much very fiDe loose BaDd. Sntstone. medium-light-gray. BaDdy; much loose saDd. Sandstone, light-gray. tine-grained; mostly loose saDd; trace to 20 percent clay abaIe at 1,130-1,140 ft. Clay øhale, medium-4ark-gray, silty. Loose saDd, light.-Oliv.gray, very fine- grained to ailty; grains 8ubangular; mostly white aDd clear quartz. 8i1tatone. medium-light.-gray, BaDdy, DOD- calcareous. Loose saDd. very fiDe-¡rained; BODle silt- stone. Bntatone, medium-light.-gray; loose sand; some clay abaIe. Clay øhaIe. medium-gray, silty; rare medium-dark-gray chipø. No sample. Recovered 2 ft 9 in.: MicrofOSBils very rare. Claystone. cloøe1y interbedded, with siltstone. with all gradatioDB of each, medium- to medium-4ark-gray. non- calcareous, hard; irregular fracture; dip 21°. COB.B ANALYSBS 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 imperm~ble 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. Cor. ow,.... Kftij.b1.øtl. '"' tÐelll Can. = 2____________________________ 261 3____________________________ 314 1____________________________ 828 13___________________________ 1, 162 141__________________________ 1,269 15_____________;_____________ 1,291 16___________________________ 1,311 11___________________________ 1.394 18__~________________________ 1.486 Bffeetln t:c: ~ 1Id8niJI) 4.42 0 6. 29 0 10. 58 0 11.50 ~t 13. 06 8.16 0 4. 58 2.12 6.08 2.88 lL 10 <1 I Oar~ am&em !t.M perGIDI by-SPt. No analyses were made of Knifeblade test well 2. The following table gives the porosity and perme- ability determinations made on Knifeblade test well2A. Cor. ow,.... Kftij.blød. '"' tÐell .A 0cJn = B1IeetIn ~ 1__________________ 3__________________ 5__________________ 1__________________ 9_____~____________ 11_________________ 14_________________ 18_________________ 19_________________ 20_________________ 24_________________ 1 112P 465P 158P 192P .807P 893P 1. 066P 1, 508N 1, 621N 1, 557N 1. 661N 16. 00 10.01 10.25 14. 20 20.90 8. 93 9.45 11.45 9.14 11.56 6.13 ~~ 41. O. Sample too smaIl to drill plug. 1.3. 325. o. o. o. o. <1. O. I P Ja pnIIello the beddIDc. N Ja IIOnIIAl to the beddlD¡. IlBAVY-MI1OI:R&L ANALT8JS Robert H. Morris examined (see p. 392) 5 heavy- mineral samples from Knifeblade test well 1 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 Knife- blade test wells although many of the sandstone and silt.. . . /J1 owllrr ----- 378 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 ,... IOC' leo" 168' 152" 1"- /f~ EXPLANATION C 8 . C 1 .. N -- It ¡. + A.......... ... + 70". 0.,- 70" 118"" lOC· ~ . . . .., '4!0 1M ...1&... 152" I _ UlllIOW_1I&I. . __UII__1I&I. _ · _ UlllIO__1I&I. . 4 SOUfll UlllIOW _ 11&1. 4 · AWAII _ 11&1. . · IIOIITII..._ _ 11&1. . 7 .,.PSOIITDTWILL' . taPAlIOIIUII TDT 11&1. . I lEAST TOPAIIOIIUII TDT WILL I '1 'ISH CIIIØ TDT WILL t .. II-.AII TDT WILL . .. .IADKTDTWILL . II au.aull TDT WILL . .4 lEAST auMaull TDT WILL . II SOUAIIE UllCE TDT WELL"' II nTALUII TDT WUL I 17 !IOU' CIIŒII TDT WILL . II WOLf CIIIØ TDT WELL _ .1 !IOU' CIlUII TDT WILL . . IlIIllCTDTWlU..t 2. IU..II TDT WILL . as ICII"UUDK TDT WELL . U ICIlIfUUDK TDT WUI.S _ AIIOM .4 lIIAllmAIID TDT WILL . as UMIATTDTWEUS.';'II ~L~l-¡ f~.~ FIQUU 28..~lDdU map of DOrtberD AlUka 1h0wiDg locaUoD of test wells aDd 00 fteldø. The . United States. Bureau of Mines at Bartlesvi)le, Okla., analyzed a gas sample from Titaluk tešt well 1. . The"assistance· of the Personnels of the above organi- .zatioDS is gratefully acknowledged. _ -.. - ~STRATIGRAPHY r ¡ïta.Î~1 1 )penetrated the Ninuluk, Chand- ler, G~J~ - and Topagoruk formatjp._. ft of ~ ta.ceous age (fig. 29). The much shallowtfr:' , tes¡...~l!J.. penetrated only the Chandler an - -~fðrtñations. Lithologically, however, the section drilled in the Knifeblade test wells is similar to the same formations in Titaluk test well 1. ~ en D. 1&1 III ~ ... æ 0 ~ 1&.1 a: en en C) FORMATION a:: 1&1 A. A. :::J NINULUK KILLIK TONGUE ~ en .::J ::J . OF THE % CHANDLER N.ANDISAUA. OROtJP o l01I o ..: I- IaJ 0: U en :::J a:: z 1&1 ..: ~ 0 Z ..J GRANDSTAND BOOD OJr .OBBTAOE0t18 AGE lIDI'U1.VK I'OaJUTlO. The Ninuluk formation of Late Cretaceous age is· the youngest formation drilled on both the Titaluk or the Knifeblade anticlines. In Titaluk test weIll, it is made up of about 65 percent of clay shale, 30 percent of sandstone and siltstone (primarily in 2 thick sandstone beds), and 3 percent of coal and carbonaceous material. The other 2 percent is bentonite and clay ironstone. The clay shale is medium light to medium gray but is darker gray where it contains an abundance of carbonaceous material. It is moderate]y hard to hard and has a sub- TOPAGORUK FIC:uu 29.-Roelrl of er.taeeoul age penetrated by Tltaluk test well 1; TEST ex-s, TlTALUK AND KNlFEBLADE .ARE~KA u.., ..onchoidal fracture or breaks irregularly along bedding thick sandstone where there is a diminution of micro- planes but is finely laminated where interbedded with fossils which may be indicative of nonmarine beds. coal, carbonaceous shale, or bentonite. The Killik tongue is composed of 85 percent of clay- The sandstone is light gray, hard, and massive where stone and clay shale, 10 percent of sandstone and silt- cored near the base of the formation; it is very fine to stone, and about 5 percent of coal, very carbonaceoœ 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 chert1), and rare mica. The siltstone is similar to cleavage and subchoncoidal fracture, that is, primarily the sandstone-medium light gray and hard. a claystone. Some of the carbonaceous beds are finely The sandstones and siltstones are slightly to mod- ' laminated. erat.ely calcareous. The cementing material is partly The sandstone is light to medium light gray, hard, argillaceous, partly calcareous, and probably partly and the beds are rarely more than 20 feet thick The sideritic. The effective porosity in the sandstone beds grains are subrounded to subangular and range in size near the base of the formation is 11.7-12 percent, and from very fine to medium. They are made up of 75-80 the beds are impermeable. percent white and clear quartz, and varying amounts Coal beds as much as 5 feet thick are present at the of dark chert, rock fragments, and carbonaceous and top and at about 250 feet below the top of the Ninuluk ironstone particles. The matrix in Titaluk test well 1 formation. The coal is soft, shaly, dull to shiny, is' slightly to moderately calcareous, whereas in the and black In a few places it grades into dark-gray Knifeblade test wells' it is particularly argillaceous. carbonaceous clay shale that contains black plant . fhe siltstone is similar to the sandstone but is mostly fragments. slightly darker. The sandstone, siltstone, and clay- Bentonite is interbedded with the coal but is rare stone are gradational in places. Rare small-scale cross- elsewhere in the' Ninuluk: formation. The bentonite is bedding is present. light gray to white and contains some brown biotite The effective porosity of the sandstone and siltstone plates~ Yello,vish-brown clay ironstone concretions in both areas is low, ranging from 0.96 to 5.29 percent are . present in the Ninuluk,' although they are not in the few samples tested. All plugs were impermeable. nearly as common as in the underlying'Killik tongue Except fora very small amount of gas found while of the Chandler formation. drilling at 640 feet in Knifeblade test well 1, no oil The shallowest sample in Titaluk: test well 1 examined or gas shows were found in the Killik tongue of the by the Fairbanks laboratory was from a depth of 40 Chandler formation. feet. . This was from the Ninul~ formation and is Coal, carbonaceous material, and plant fragments essentIally the top of the formatIon. (See p. 383.) are scattered throughout the formation. The coal is '!he total thickness of the fo~ation in the :ritaluk area. black, shiny to dull, brittle, and thin bedded. Very rare IS about 550 feet. The Nmuluk formatIon was not small inclusions of clear ~nish-yellow amber are found in the Knifeblade test wells, as older formations present. Dark-gray carbonaceous shale is present above only are exposed along the axis of the Knifeblade and below the coal and elsewhere in the section. Black. anticline; the Ninuluk: formation is present off the plant impressions are found in both the claýstone and north Hank of the anticline, according to C.L. Whitting- sandstone being abundant at some depths. These ton (o~communication, 1956.) imprèssio:uï are fragmentary, and the plants cannot be DespIte the presence of coal and carbonaceous beds, identified. . the Ninuluk formation is primarily. mar~e as in~cated Very characteristic of the Killik tongue are clay iron- by the repeated occurrence of marme nucrofosslIs. . A stone (sideritic mudstone) concretions and laminae, few pelec~pods w:ere also ~ound. The f~w nonmarlUe . particularly in the Knifeblade test wells. The clay beds ~Iated WIth the Nmuluk formatIon are ?ngers ironstone is hard, has conchoidal fracture, and ranges of the NIakogon tongue of the, Chandler formation. from gray to yellowish bl'9WD. Brown dense dolomite au.u TOnu. 01' TO CIIA1IDr.D l'OaJIA.TIOll (or siderite') laminåe as much as 2 inches thick are found near some of the thicker cOal beds in Titaluk test well 1. Tiny vertical veins of' yellowish-gray dolomite crystals a~ r80!e. . In the Knifeblade ~ wells and the subsurfacë in other places in the Reserve, there is a great deal, of 'authigenic sericite in the Killik tongue. This mica. The Killik tongue of the Chandler formation, 1,260 feet thick, underlies the Ninuluk: formation in Titaluk: test weIll; at the type section it is mostly nonmarine (Detterman, 1956, p. 237). In the subsurface there is no good break between the two formations. The con- tact in the Titaluk test well is placed at the base of a . . 380 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, NORTHERN ALASKA, 1944-53 gives a silky sheen to fractured surfaces. The sericite is most common in the lower part of the Chandler for- mation although some is also found in the upper Grand- stand formation. 8UJfDBTARD FOUUTIOR Thè Chandler formation grades into the marine Grandstand formation; the top of the Grandstand for- mation is placed at the first common occurrence of the Verneuili:noidea boreolú marine fauna. This is also the approximate top of a very sandy section, the thickest sandstone bed of which occurs about 350 feet below the faunal top. The Grandstand formation in TitaIuk test well 1 is 1,650 feet thick. About 1,710 feet of this formation was drilled in Knifeblade test well 2A, but this is at least 10 percent in excess of the true thickness because of the steep dips. A comparison of thicknesses in the two wells suggests that the bottom of Knifeblade test well2A is near the base of the formation. The Grandstand contains about 700 feet of sand- stone and siltstone in beds as much as 180 feet thick; the rest is clay shale and claystone. The sandstone is light gray (rarely medium light gray), hard, and massive. The grain size ranges from very fine to medium in the TitaIuk test well and from very fine to very coarse in the ·Knifeblade test wells; grain size de- ereases with depth. A few thin beds of conglomerate were recorded at the top of the formation in Knifeblaœ test well 1. The conglomerate contains subrounded and rounded granules and pebbles of dark-gray, green- ish-gray, and black: chert, milky quartz, coal, medium- and medium-light-gray clay shale, yellowish-gray clay ironstone, and light-gray sandstone. .As is usual in the sandstones of the Nanushuk group, the predominant mineral making up the sand is white and clear quartz, ranging in quantity from 60 to 90 percent of the total. The other grains are mostly dark 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 subanguIar, and a few are subround; but the very coarse grains are round. Where tested, the eftective porosity of the Grand- stand formation ranged from 4.58 to 20.9 percent in the Knifeblad.ø test weIls and from 0.56 to 12.45 percent in the Titaluk test well. The highest air permeabili- ties were 325 millidarcys and 17 miIlidarcys, respec- tively, although most samples tested "impermeable." 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 samp1e in the Titaluk test well had an exceptionally high reading that measured 30.4 per- cent by weight. Ordinarily the matrix of the sand- stone of the' G-randstand formation is argillaceous. A few feet of limestone (or possibly siderite or dolo- mite )-medium-dark-gray with a brownish cast, har?, argillaceous, with white vein calcite-was found m TitaIuk test weIll, but none was found in the Knif&- blade test wells. Most of the oil-producing zones in the Umiat field are in the Grandstand formation (Collins, 1957). In the Knifeblade test weIls this formation contains nu- merous deposits of black bitumen or asphaltic residue suggesting that at one time the fault blocks that were drilled (see p. 413) did contain oil. The light frac- tions have long since escaped. The two deep Knife- blade holes yielded brackish water on bailing tests. In TitaIuk: test weIll, 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 sandston&-siltstone bulk. Some swirly bedding and some sma1l-sca1e crossbedding were noted in the siltstone near the top of the formation in TitaIuk . test weIll. The clay shale and claystone are medium to dark gray and hard. The clay shale has fair to good cleav- age, and the claystone has almost no cleavage but has irregular to conchoidal fracture. These clayey beds are mostly noncalcareous but are very silty in places and grade to siltstone. The clay shale has some micaceous- carbonaceous partings. Sericite is present but is not common in the formation. There is considerably less coal and carbonaceous ma- terial in the Grandstand formation, particularly at Titaluk, than in the Chandler formation above. A few coal beds are near the top of the Grandstand in the Knifeblade test weIls, but these beds interfinger with marine microfossil-bearing shales. The coal may rep- resent nonmarine stringers of the Chandler formation. No thick coal beds were cored; the cutting chips are black and shiny to dull. Rare carbonaceous shale beds and a few plant fragments in the shale partings were noted. Clay ironstone is less common in the Grandstand formation than in the Chandler formation. Marine microfossils (see p. 417) are present through- out the formation, as well as I fWC61'a:mUll sp. (mostly prisms in the cuttings), Ditrupa sp., and crinoid frag- ments. The Knifeblade area was probably closer than the Titaluk to the source of the material that makes up the Grandstand formation as the sandstone is coarser grained, even conglomeratic, and there are more coaly beds. , / TEST WEeT1TALUK AND KNIFEBLADE AREAS, + 381 1_ TOPA.GORUK FOlUU.T.ION which underlies the Nanushuk group. Only a few (Only 520 feet of the Topagoruk formation was pene- minor shows o~ oil and gas were found.. (~pa~ 394.) tr&ted by Titaluk test weIll. The Knifeblade tests were The formatIon contacts as deterIIllned m this test t~ shallow to reach it. In Titaluk test weIll, the divi- are as follows: Slon between the Grandstand and Topagoruk forma- Ninuluk_________________ 40-590 feet. tions is a well-defined lithologic change. The base of Chandler________________ 590-1,850 feet. the Grandstand (also the base of the Nanushuk group) Grandstand______________ 1,8~3.500 feet. is placed at the bottom of the thick sandstone group. Topagoruk_______________ 3,500-4,020 feet, total depth. The Topagoruk formation is about 70 percent of clay Field investigations by W. P. Brosgé, C. L. Whitting- shale and 30 percent of siltstone and a little sandstone. ton, and A. L. Kover, U. S. Geological Survey, show The clay shale is medium to medium dark gray and that the Seabee formation of the Colville group of late hard. The cleavage ranges from very good to very poor, Cretaceous age is present on the surface at the rig and some of the rocks can be classified as claystone. site;. Samples representing the top 22 feet of rock were Some of the claystone is calcareous. not received by the Fairbanks laboratory, but W. P. The siltstone is light to medium. light gray, slightly Brosgé 1 believes that this interval of rock, based on to moderately calcareous, hard, has fair to good cleav- the well geologist's description, represents the Seabee age parallel to the bedding and some carbonaceous and formation. The uppermost sample from 40-50 feet micaceous partings. There are a few thin beds of very received in the laboratory contained a few microfossils fine- to fine-grained quartz sandstone. Effective poras- which are distinctive of the Ninuluk formation. ity in the coarsest siltstone beds cored was between 4 The elevation of Titaluk test well 1 has been adjusted and 6 percent, and the plugs tested were impermeable. by W. P. Brosgé to the Umiat datuIn.1 All elevations A very pale cut of oil was obtained from one core near and locations in the Umiat-Maybe Creek area are sub- the top of the formation. ject to correction, pending the results of new topo- The siltstone and the clay shale are interbedded, some graphic surveys. places in thin laminae. An inch-thick intraformational conglomerate made up of subangular clay shale frag- ments in siltstone was found 170 feet below the top of the formation. A small amount of swirly bedding and small-scale crossbedding is also present. The Topagoruk: formation contains the same micro- fossils and megafossils as the Grandstand formation. (' TlTALUK TEST WELL 1 ;) Location: Lat 69°25'21" N., long 1M·34'M" W. A.ppro%lmate elevation: Grout!, 822 feet; ke1I7 bushfng. 840 feet. Spudded: A.prll 22, 1951. Completed :11Jl18, 1951, dr7 and abandoned. Total depth--.zo feet. Titaluk test well 1 is on the· Titaluk anticline about 62 miles west of Umiat. The test is on' the top of a ridge 7 miles northeast of the junction of Maybe Creek and the Titaluk River and about 650 feet above the streams. The area has rolling hills and intrenched streams near the north edge of the .Arctic Foothills province. Fifteen miles north of the test site the land flattens to the monotonous lake-covered Arctic coastal plain. The purpose of the hole was to test the oil and gas possibilities of the formations of the Nanushuk group to the extent· of completely penetrating the lowest sand-. stone or reaching the capacity of the rig. (approxi~ mately 4,000 feet). The hole was drilled to 4,020 feet, at which depth it penetrated the Topagoruk formation 4888151---18---2 I STB.11CT11BB The Titaluk anticline is a long and narrow structure extending from a point southeast of the Meade River at lat 69°35' N., long 157°05' W. about 80 miles east to a point near the headwaters of Maybe Creek at lat 69020' N. and long 153°30' W. Near its midpoint the TitaIuk anticline is crossed by the river from which it derives its name. Titaluk test well 1 was drilled on a local closure near the east end of the anticline. The minimum closure on top of the Seabee forme.tion 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. Contôurs on figure 3() are projected over the- top of the anticline where the Seabee formation is eroded. Sur- face geological control is lacking on the northwest side but it has been supplemented by seismic lines (United . Geophysical Co., party 144, 1950) which indicate clo- sure at depth (phantom seismic horizon A in shallow rocks of CretaceouS age). . The test well is just south of, and 70 feet below, the apex of the anticline. The strata drilled in the test &r8 flat lying to a depth of about 2,000 feet, indicating that : the test was drilled near the apex to this depth at least. . 1 William Bl'OIIIf. personal eommmdeatloD. . Datum 1IIII!d 011 the Umiat Speda1 Jrlap. a topocrapb1e _eet pabo Uahed bJ' the U. B. Geolock&l SU1'ftJ' In 1948. ~~~~§§§§§§§~~§§§~§§§§§œ§~§§§~~~~§œ§~ ~ GEOCO, INC. '1 SERVING THE,-MINERALAND CHEMICAL INDUSTRIES ~ t:-: 1'515_1 WARD ROA-D~O;,4;;WHEAT RIDCiEõ~COLaRADO 80033 -- ......;.- TELEPHONE' (303)>422-81 12 __ œœ§§§§œ§~~§§§§§§§§§~œ§~§~œ§§§§§§§§~§§§§~ Client: Date Client I Log' Invoice , '9-"-78 1013 \ 103 Report of Analysis Analysis Requested: . U 5 Co S - A ,..¡c.....oe.A <õ e::- ,. R~\1~~ '5 AMple.s Lab Sample /I Client Sample /I r S·(JJP" ~;> ~~ ~~ '-- ù30,&" ';1 ~~ ~ . f'c pptr\ ,4..1.1 :1J ~q V ~$~ ~"3 - "03 -21(0 - ET - , 2.00 - S w V X 2- -,2.,O-SW /?114 v v- a/' 3 -, 230 -SlAJ ~O3.~ v V' V /4 S~ )( <..f -\ï31 -Rß 1'60 v V V vr 'J .x .s- -\ì 3. -C, ~.,~ / /...,,- fø - \ ì 3 , - c..c.. J{'1 V Y X 7 -\73,-DO 1.1. v y vfß' ~ ~ -'13,-F 4,(" v.... ./....- . '\JF'ss 9 -1731-1-1 ~q v ..4; 10 -1-7;31-M .~'1 v .~ ~ 1\ -20'b-B ~f v- IZ- - 20' <0 - c.. Ih,~ V· Þ' Y 13 -20Ib-I 110' ..... V'" -e- t~ -Zo3Z-A 4-1- y ", .S -2032-0 4~ y' ~ tJF~? w Samples will be disposed of after by ~~. 60 days unless o~herwise directed. l) , ·~~~~~~~~~~~~tf~~~~~~~~~~~~~~~~~~~~~~~~ ." 'GEOCO, INC. - -- .. Date C¡~II·_ Client: _. Report o£ Analysis: (con'to) Lab Sample I .Client Sample I t?3 Os. f~~tW" ~.r;¡ ~ ~J 'I'" ft,ro PPM ,..,.,A 'J13 -/1 D3 -.;Jlfo - / b &-. r: - 2032- }/ .~ V V 17 - 2.0 s-o -B of V- v -lfS - 2.0S1) - F Jl v 19 -z07o-A 5 V Iv 2,0 - 2.0 70 - c.. J Iv 21 - 2 o8</-A /9 V' t/ 2.2- - 208<1- B I~ v 23 - 2D3Y- D - _ER> / /.:L ý 2'1 - 208'1-£ /9 v ,/ . ~CL. . Z-S- - 20~V-M IA v 2b - 2.oW- ¡J ¿,¡.r ,/ V )( 27 -208'-1- 0 5 V- i/' 79 - 2../ 03 - A ~ f/" z1 - 2./03-.8 ~-f~ V- i/' ;;0 - 2 103 - c.. .~ v ~I - 2/o3-D 45 y v X "3Z -2/03 -F S ,/ I/' 33 - 2./2Z- A .2.R V" 1/ 34- - 2/2 7. -r~ .c¡. t/ 35 - 21.'32 - B ~ 1/ I/' ~, - 21 3 &./ - c... 109 V ,/' f( 37 ~ 2./ c¡. If - A ~ /- v .,r -2/'1'1-0 .1'" v yo vf: 5'f e ~í - 2/ V'/-I-- ,4~ v V Iv- ,,¡: .J'r I/o -2/Y¥-G .q ~QJ, Samples will be disposed o£ a£ter 60 days unless otherwise directed. ~ø§§§§@§§§§§ølffiœ§§§§§§§§~æ~§§§§§œ@@§§§§ o GEOCO, INCo Þ Client: Lab Sample 1/ 3- 1103 -2Ifo- <..11 LIz ¿¡3 ~~ liS' JI' tl7 'If '19 5lJ It I Sl 5";L . 53 5Ý s-s- ~~ 57 s-fr .:s¡ /:,0 ~I b.:l- ¿,,3 6¥ ~S" Report of Analysis (con't.) ..,-------:-'::", '.. ~ ,. . -=- - =; Date 9::''7/-,.. . , Client Sample 1/ u3Q f~~~I~~ .þI.~ PPM ~'1. ~ £~j)¡' F'."'" I1r'A(y. 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I " . --- - ".">"'';'; -"" :- 9-11- . - .~ " -Client: Date Report of Analysis :( con' t. ) rs~ ~? ~ .., Láb Sample I Client Sample I u3o, - I!AJ, - ~J) - .f;.,. p¡o~ / .f\o'.4 ~/3-/¡() ~ ~16- -66 ¡:-r - 35" b c¡ - 1= .~ v V þ~J fD7 -35" 9-1{ I "g M - 292..- A 4'1 v .þ\ I/' Ass X be:; - 29 2.--ß 1 V' ïD - 2.. ~ 2.-c:.. £/ \)( t/' ït -2..92.- Top -3 V'" 11 Ä:F5 . 12.. -5"90-/\ ;L V 7~ - s-<=fO - B c:L V 7'1 -sYO-c 7 V\ t/ It 7S" ~~ --I'i q 0 - 1\ ~I v ~ ;'IAAA..J.ø~ . 7Í::> - \ '\ ~Q - \3 Iø v'" .x 1/ ~ I -t"\~O-c. V . $":1 -1 77 .2 v ,. ¡g -- \\\~o - D 01 ~ V ï7 -~'\90-£ I v gO - \ì C¡O - A ,~.'" v '" V -~x 81 -,,90 -B .:J..~ V )( 8z.. -\ì ~o-c.. ..' v V '¿:f~ ~3 -\,90 -ù '1 v ,.>( V" 8'1 -\ì90 - E ,:J v V' gS- -\,cro-F ~? v f)( V 8"'- -\190 -G ¿I V"" 87 - Zobs-A Lf v .f/' 8"8" - 20 b 5" - B j v IX' v - 8'1 - 2C6S-c.. 1 v &>Ç V 70 - 20 6S-- 0 I v~~~.~ Samples will be disposed of after 60 days unless otherwise directed. 'I§§'§§§§§§§ §§§rA§[£j@j§§§§§§§§§.@][§[9[§@i@j[£j@i[§§§§ ¡ GEOCO, INC. .., ~lient: -~ IE -J)ate-':¡'-7rÞ -= I' . --- ~~ .'. Report of Analysis (can't.) Lab Sampl e , Client Sample I ñ;r('~ ~. ? Ù.3~ 7 -" J~ - . ÞÞM .- .,,- IOI.~-II03 -2C~- q \ M- 20(05"- E ~I v v q2 - 20bS--1= . /5 v v q:~ -20bS-G l v· ~ ., qq I ,I - zofoS-1I 1/ '15' - 2 3foS-A "'I 11 9' - 23 ~s-.8 / V ~ 97 - Z36S - '- "" 1/ ~ 9K - 23 "s-D / v 99 - Z3bS--£ at ~ e lOt) - ~q~9-A I ~ 10/ -;),9 <19 - A-I J./. .v *' 10;;1- -;). 9'19-8 :¿ v .J ..¡ð3 7.;l9~'j-C. ~ v /ð9 -.;J9Y9-LJ ,,~ V'" IOS' -.;1. 9S/7-E ¿I V'" IO~ -~«7~?-F :J v- 107 -c;;1 9v?- G ~I v lot - 299"7-1/ I v It) 'J -29$1<7-Z ~I v ~. /10 -2?~7'-A ..c..' . v ~ Q 2Z.~·-A III Jf V '----"" /1.:1- -2'2S- 8 I 113 - 1/25 - A :; V e IIÝ - 'IZ.S--ß / V 'V' liS - c¡ zs- - c... J Samples will be disposed or after .! 60 days unless otherwise directed. 'i~~~§§§§§§§~~§§~§§§~§~~§~~~~~§§§§§~§~ · GEOCO. INC. t Client: ,_-,~ 11 'c:~-1 i-Date q-tt-78Ì1 Report of Analysis (con't.) . -- Lab Sample I Client Sample # Ùi9¡· /). r¡#J '0 /'" rj, pp"" o '3-110'3 -~, '0- \\ b ÞC -bd.S- - B S V \\ì -ß2S"'-R 4 v \\s -8~- 0 t \\9 - ß';;lS - c.. .1 I ZÖ -tOz.c:;-A 1"1- 1'2.1 - 'OZ5"'- A f v ,z,z.. - lOZS"-C. 1- \ 2.3 -tOZs-- F g , 2.. \ -10 2.5'-(; 1..2.. - 17_~ -toz,S'--L 4- '4 -\02S-J 1 ý l.;lì -I ~~S""-ß .~ ", - I~ß .- i ~-z.¿ - c.. j.. v l.;ttt -'~Gl.S-A .l. ~ ,3D -\~J5-Q . .~ V ./-' \3\ - 'b~S- A, B.c. ..~ v(~ ÞjIoV' \ 3:J.. - \bqS--g 9 )1' ,53 -\,¡S-,- A ,2 13l/ -\~SI-8 ., V" ).3S" -20fal -B 4· ,/ J 3£:, - 2,,70 - t\ 4- "... ,37 -G.~<13-A 1- v-_ 138 -;2700 - c.. :J v e '3~ - 2<1 1"-- ß rl. v I ILlo -2Cf~S"-~ :¿ ~o~j Samples will be disposed of after 60 days unless otherwise directed. ~~§fu§~§§~§§§~§§§~~~~§§~~~ID§§§§~~~§~~§ . GEOCO. INC. t Client: Lab Sample" ~3- \\03 -z I <0- I~ I I 'I 'Z. , 'f3 14Y I'IS" t '\b \'11 \ \I g ''Ie¡ I . 5"0 \5\ 152- . '53 15'1 155"" 1St:. 157 I~ \59 1,,0 Ibl \~;t I {'3 I{,'I \bY It ~ (<-, -('-..-.,-,....', ....0. . - , i Date 9- ìJf7i Report of Analysis (can't.) Client Sample I Þ'c.- 2q¿¡S-- 11 -2950-8 -?9¡,O-A I -29~O-E -.;;2Cþ70 -D -~98o-A -2980-£ -30oo-A - '3010- c.. - 30 'GO - fl - 3 (j 30 - A- - 3 0 ~O-c.. -: "30 Yo - A -3050-8 - 30'+0 -C,. -3'Coz.-A -~\ìl-B -3'3Sb-~/- e - ~ '?>S"lc - B - $ ...~ 3 S lø - ~ I -'33b~-B - 331<o-C,. - 337" - D - 3Sìlø -A . - ~5"7b-(3 Samples will be disposed of atter 60 days unless otherwise directed. ù3°"5 PPM ~ I <I ~ I ) .~ ¿I ~ :¿ 4./ .1 <:1 ~I . "'I .LI ' I / ~I "''- "'I .£1 ~I ¿I .L../ ~ fj ~Y' X~ v" 1/ V-' v v' .Þ- V' 1/ v v '" ".. v' t..oo""" I- V .,- V" £-. " .., V'" "".. - I.." V b~~ÞN' .~ ~~~~a~~~~~~~~~~~~~~~~§~§§~~§~§§§~§§§~~ , .. 'GEOCO, INC. - I Client: L ._.=..IL.:.·.·, Date Report of Analysis ,( con' t. ) .... Lab Sample I Client Sample I Ù3 Ots-. '15~ ,- 'I." PPK - .3-(\0'3-/\b- \ fob F=' c- 377 Co - A ¿".I ",.,.- ''''1 - 3' 97 "-8 ,I J..- tbß - ClltJo-8 h' V- Ih9 - (¡ 3 C/O -8 . ~I v 110 - t.¡ 5'/'1- c.. J '" , 71 - f../6 9 K-ß ,t .V' 172 -~90o -A "I "oJ. 17~ - 5'"078- A L/ ...... . 17'f -S"~8D-8 :J.. ¡,.-. t 'is- - S'l8D -C,. :J.. V- I'" '7" -S~8D-D .:; 1/ '1' -SY90-C- "I v . '7ß . . -,s-V90 - D "I v .,.,. 119 --SS"()O-11 .c.1 v'· \~ - 5500 - C- . .c./ V t,;! \~\ -sSlo-A LI 1/ t- \ t2.. -s-szo- 8 .¿I V" \ß3 -Ss-;JO - c. "'t v ~ 1 ~'f -~S-..30 - B "I V "'" \ß~ -S530-8 "'I _ V" 19b -SSPo -c.. -c.t ..... (~ì -S-s-S-O -4 -<-I &,,000"_ '8~ -ss-s-o -1) I V ¡,...- t IRî - 5s "5"- ß LI V'" V' 'îo - S-s- ,s- - e- el Samples will be disposed of after 60 days unless otherwise directed. L" .:.",:-. - .. 9-11~~ ~~~~§§§§§§§§~§~§§~§§§~§§§~~§§§§§~§~§§~ .' · GEOCO, INC. t Client: -~ IIf' " k.. ~ ~ - -~ate 'l-1I-7K ; Report of Analysis (con' t. ) T) "r¡:~~9, .. Lab Sample-~ CJ.ient Sample I lJ3~ - 't~ pp~ :,...0- ,'3-\&03 -"2.\b- \~ \ ¡:-c- SS"7 S- - A <.., V "" - ,qz - O.s-7 ~- c.. <.1 V v lq3 - SS-8'~ - D :J... . v- I - \q '-I - S-s-9'i - 8' ~, y- \qS - S-800-c'' <I V- \9£' - foooo-ß <I v ,Ql - (0000 - Co <I V ...... ,q\ - 60oo-D <I v v \~~ - - blJ 10-8 <.J v- ¡,....oo I c::o?oo -foOZO-8 < I v ",.. 2.01 - G,020-C. <I v ZO~ - ~o':?O-/. . <I to.- za3 -' - h6c.¡O-A <./ V" ~r.¡ - bD\.}o -/3 - S <:.J """ aoS- - iA">\j () - c.. .~ V'" J.- ~b -60C1()-D ,;¿ ØlD7 -6DC¡O-~- S I V 1- õ208" -'23S--ß <: I J- ~oc¡ -"t/Z(J - 8 ~I v .t- ;1./0 -67ÝO-A c..J ¿,... I c:2./ I -l:, 9/S--A , ..... ~/2- - f:, 9/5- <?- 3 V ¡.... - 6113 -6 c¡ / s-- D .:t l;f e c>llt,/ -6~/S--E . ~ V- I..- :<'1 S- - 7ð10-A d- "..., ~ Samples will be disposed of after b~AA'~ 60 days unless otherwise directed. ~;;,.... .1IB. '¡ANSENS~ 265-5206 .: DENNIS MAEZ~ 234-3181 . Page 10.6 mffi§~~§§§§§§§§§§§§§§§§§§§§§§~§§§§§§§§§§§§ . . GEOCO. INC. 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"j:t:' _~ ) () Á ----<'1v~..._Qt_'_'"J(_6 <:J. 1/ ßy - ~~~JJ~ J " ~~~'-4'~ ~- ~.¡,...- '% (G~~'~') -,-~--_._-, (/ ,~ ~~(;"-~-G::4- ~JJI o.rJ /:~'1-" - u 1<,- , ~ 5/.> 5's SJ S<::{j',¡jy s':J-h~,--J ~ 55 S5 Ss >5 55 5'",·, - :::J X' X K ,>«' X )( X X X' K x- X X K X' X X X X 'i X ì< x 'X X x 1 !f" ~ /Î ,',\ '-' /"'X ........ J 0 .- ",5""0 ~y /V~Ô p:Jò -./ ,.., CJ j-,X T¡\ "... IU" / i..-' /1 ,}O- 30 v-o ~~ .!J'- -Ió - J,) 9 s ~/'1 //) 7!Y- - ß / ,,~ ?_t) - C- ¡ 3 ?~, - Æ /3 9S-ß / i '7"- L1 ".: '~_b - f;' l/'J ~'- ß J~!j-, /3/6-C / l' /J.5- -Ii II)!D -It 1 !(P--L CORE .8 AND TEST WELLoS, OUMALIK ÅRE~KA ~ Simpson Seeps: 34 core tests; a shallow oilfield was defined by of gas was fOtind in these older rocks. Oilfields the series of core tests. discovered at Umiat and Simpson seeps and gas Square Lake: 1 test well; a prospect northwest of Umiat defined at Barrow and Gubik. Some shows of oil or gas i by seismic and photogeologic techniques. 'Ì'italuk River area: 1 test well; located on an anticline mapped also noted in other holes. primarily by field and photogeologic methods. The United States Geological Survey participated Topagoruk River area: 2 test wells; in the central part of the in the program as a cooperating agency. Drill cores coastal plain; a deep test penetrated rocks ranging in age and cuttings from the tests were shipped from the from Devonian to Pleistocene. Umiat: 11 test wells; many produced oil. reserve to the Suryey laboratory in Fairbanks where Wolf Creek area: 3 test wells; relatively shallow tests; shows of they were processed, described, and analyzed. De- gas. tailed subsurface information based on laboratory The test holes range in depth from 47 to 11,872 studies and analyses by the authors has been compiled feet, and the drilling penetrated rocks of Paleozoic, by groups of related wells j in addition, logistic, engineer- Mesozoic, and Quaternary age. Most of the footage ing, and drilling operational data have been abstracted was drilled of Cretaceous rocks, and all the oil-bearing from the files and reports made to the Navy by beds found are in this age. Figure 3 shows diagram- Arctic Contractors, United Geophysical Co., Inc., the matîcally the relationships of the Cretaceous rocks. Schlum.bèrger Well Surveying Corp., the U. S. Bureau Paleozoic, Triassic, and Jurassic sedimentary rocks of Mines, and the National Bureau of Standards. These were penetrated in the drilling of a few holes in . the data as well as a geological interpretation of the sub- northern part of the Reserve, but only a small amount surface information constitute this paper. a: ... ... ... => ell => 0 ... I- ... "" "" II: ..... .. ~c.. 0·" U .. ::> --?-- ARCTIC COASTAL PLAIN PROVINCE ;,..';..... ..,.....,.-_..--~....' Sentinel Hill member SCHRAOER Barrow Trail member BLUFF ----------- FORMATION RoO.... Creek member Ayiyak member SEABEE FORMATION ------ NINULUK FORMA TIOH GRANDSTAND FORMATION GRANDSTAND FORMATION TOPAGORUK FORMATION -----------_..:_-? a: ... 3: o ..J FORTRESS MOUNTAIN TOROK ?---------=----- ------------------------? OUMAU K FORMATION FORMATION FORMA nON OKPIK~UAK FORMA nON ?--------------- UNITS OF JURASSIC AGE --? LOWER Relationship of th... CRETACEOUS (? AND rocks to those to the UPPER south is unknown JURASSIC<?>ROCKS, UNDIFFERENTIATED Not known Predominantly marine Predominantly nonmarIne - FInUXII 3.-Nomenclature of the Cretaceons rocks of northern Alaska. ¿f, ~. .... . Kt2 -L '- ¡;¿"-"/Ì . ¡C.,.ç _. /'-' ¡; ,~~ ~ J rL¿J( v-,,\ AI') C? . V-;J þ' / A.Á./i~ ~?/,,:;.--z¡ ,// 'J 0... > ~¡ -'. //:j' _. ".¡ A; /G: '...- --'."Y t,¡.- -., -z.,"c/"~ ....~~ ¡; â) ~ ''-e': Ii ,,; / --'-'~\ ¿/~ .-d . /1 vUc /\AJ-"-"-~' r\'¿/1..~1 ~ / /' "p. .,> Á;I., /' ~ ,.¿ ".L :::Le- ~~~ /;¿¿/~/. AJ{j"' ~'~")"''2>/U . -- "- / eWL~~t-(~/' -é~i{~~~. VfV~ j l b. ('>"'\ -- /'"7 ) l " '. .J . 378 . EXPLORATION OF NAVAL PETROLEU1:1 RESERVE NO.4, NORTHERN ALASKA, 1944-53 168' 154' 160' 156" 152' 1Mj' I f,'~. EXPLANATION C 0 C E . C T 04 Gal wen It ,. ... Abendon.d well + 70· _ 0,)' hole B ROO 164' so . , \ 29°101I11..1[. U10 '~O , sour.. sAR ROW TEST WE'lL I 2 SOUTH BARROW TEST WELL 2 3 SOUTH BAR ROW rEST WELL :3 4 SOUTH BARROW TEST WELL" 5 AVAK TEST WELL 1 6 NORTH SIMPSON TEST WELL 1 7 SIMPSON TEST WELL t 8 TOPAGORUK rEST WELL' 9 EAST TOPAGORUK TEST wEll I 'D FISH CREEt( TEST WElL-. t 1 KAOLAK TEST WELL I 12 MEADE TEST WELL 1 - 13 OUMALlK TEST WELL I ~~ 14 EAST OUMAUK rEST WELL' 15 SQUARE LAKE TEST WELL" 18 TlTAlUK TEST wELL 1 -~ 17 WOLF CREEK TEST WEll 1 18 WOLF CREEK· TEST WELL 2 70' .~., . '. ";~~TlO~.....·····r. e .. . ........ 11 1 ¡oI p Il 0 ~68' 152- 19 WOLF CREEK TEST WELL :3 20 GUBIK TEST WELL. t 21 GUBIK TEST WELL 2 22 KHlrE8lADE rEST WELL 1 Z3 KHIFEBl...OE TEST WELLS 2 AND 2A 2,( GRANOSTANO íEST WELL 1 25 UMIAT TEST WELLS 1-11 FIGURE 28.-Index map of northern Alaska showing location of test wells and o.il fields. The United States Bureau of Mines at BartlesviJIe, Okla., analyzed a gàs sample from Titaluk test weIll. ' The assistance of the personnels of the above organi- . zations is gratefully acknowledged; STRATIGRAPHY Titaluk test well 1 penetrated the Ninuluk, Chand- . leI', Grandstand, and Topagoruk formations of Cre- . taceous age (fig. 29). The much shal10wer Knifeblade test wells penetrated only the Chandler and Grand- stone formations. Lithologically, however, the section drmed in the Knifebladè test weIls is similar to the same formations in Titaluk test weIl 1. ~ \f) 0... III III ~ I- ~ 0 \f) >- III a: \f) \f) C) IX: lLJ a. a. ;:) ~ II) ;:) :::I ::c 0 II) W :::I U .:( IX: Z W .:( I- 3: 0 z W ...J IX: U ROCKS OF CRETACEOUS AGE NA.NUSHUK GROUP NINULUX FORMATION The Ninuluk formation of Late Cretaceous age is the youngest formation drmed on both the Titaluk or the Knifeblade anticlines. In Titaluk test weIll, it is made up of about 65 percent of clay shale, 30 percent of sandstone and siltstone (primarily in 2 thick sandstone beds), and 3 percent of coal and carbonaceous material. The other 2 percent is bentonite and clay ironstone. The clay shale is medium light to medium gray but is darker· gray where it contains an abundance of carbonaceous. material It is moderat~ly hard to hard and has a sub- FORMATION NINULUK KILLIK TONGUE OF THE CHANDLER GRANDSTAND TOPAGORUK FIGURE 29.-Rocks of Cretaceous age penetrated by Titaluk test well 1. -a"-~~Vt ~·.,,~v~'- ."-"'U A_'.UhnL_"-U'!o' A.tt..ALAti.K..... ,j/:¿ c0l1c}¡oidl11 fracture or break~eguIarly 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. coaT, carbonaceous shale, or bentonite. The Killik tongue is composed of 85 percent of clay- The sandstone is light gray, hard, and massive where stone and clay shale, 10 percent of sandstone and silt- cored near the base of the formation; it is very fine to stone, and about 5 percent of coal, very carbonaceous medium grained, and 80 percent of the grains are white clay shale, and clay ironstone. The claystone and clay and clear quartz, and the remainder are coal particles, shale are medium light to medium dark gray. The dark chert, white chalky material (weathered feldspar darker colors are more common. This rock has poor or chert?), and rare mica. The siltstone is similar to clen, 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 subrounded to subangular and range in size near the base of the formation is 11.7-12 percent and from very fine to medium. They are made up of 75-80 '.. . the beds are impermeable. percent white and clear quartz, and varymg amounts Coal beds as much as 5 feet thick are present at the of dark chert, rock fragments, and carbonaceous and top and at about 250 feet below the top of the Ninuluk ironstone particles. The matrix in Titaluk test well 1 formation. The coal is soft, shaly, dull to shiny, is slightly to moderately calcare{>us, whereas in the and black. In a few places it grades into dark-gray Knifeblade test wens it is particularly argillaceous. carbonaceous clay shale that contains black plant fhe siltstone is similar to the sandstone but is mostly fragments. slightly darker. The sandstone, siltstone, and clay- Bentonite is interbedded with the coal but is rare stone are gradational in places. Rare small-scale cross- o elsewhere in the Ninuluk formation. The bentonite is bedding is present. light gray to white and contains Some brown biotite The effecÚve porosity of the sandstone and siltstone plates. Yellowish-brown clay ironstone concretions in both areas is low, ranging from 0.96 to 5.29 percent are present in the Ninuluk, although they are not in the few samples tested. All plugs were impermeable. nearly as common as in the underlying Killik tongue Except for a verý 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 Titaluktest weIll examined òr gas shows were found in the Killik tongue of the by the Fairbanks laboratory was from a depth of 40 Chandler formation. feet. ... .This was from the Ninulu~ formation and is Coal, carbonaceous material, and plant fragments essentIally the top of the formatIOn. (See p. 383.) are scattered throuO"hout the formation. The coal is !he total thickness of the fO~'mation in the !italuk area black, shiny to dull, brittle, and thin bedded. Very rare IS about 550 feet. The Nmuluk formatlOn was not small inclusions of clear areenish-yellow amber are found in the Knifeblade test wells, as older formations present. Dark-CTnty carbon:c~ous shale is present above only are exposed along the axis of the Knifeblade and below the c~alandelsewhere in the section. Black anticline; the Ninuluk formation· is present off the plant impressions are found in both the claystone and north flank of the anticline, according to C.L. vVnitting- sandstone, being abundant at some depths. These ton (on~l communication, 1956.) impressions are fragmentary, and the plants cannot be Despite the presence of coal and carbonaceous beds, identified. . the Ninuluk formation is primarily. marÌ1:e as in~icated Very characteristic of the Killik tongue are clay iron- by the repeated occurrence of marIne nucrofossrls. . A stone (sideritic muclstone) concretions and laminae, few pelecJ:'pods ",,:ere also ~ound. The f~w nonmal'1ne particularly in the Knifeblade test wells. The clay beds asso.cIated with the Nmuluk formatlOll are ~ngers 0 ironstone is hard, has conchoidal fracture, and ranges of the NIakogon tongue of the Chandler formatlOll. from gray to yellowish brown. Brown dense dolomite KILLIK TONGUE OF THE CHANDLER FORMATION (or siderite?) 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· yellowish-gray dolomite crystals ar~ rare. In the Knifeblade test wells and the subsurface in other places in the Reserve, there is a great deal of authigenic sericite in the Killik tongue. This mica The Killik tongue of the Chandler formation, 1,260 feet thick, underlies the Ninnluk 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 I . . 380 EXPLORATION OF NAVAL PETROLEUM RESERVE NO.4, KOHTHERN ALASKA, 1944-53 gi¡",'s a ::oi]k)' slleen to fractured surfaces. The seÓcite is most common in the lower part of the Chandler for- ma60n although some is also found in the upper Grand- stand formation. GRANDSTAND FOR:r.rATION The Chandler formation grades into the marine Grandstand formation; the top of the Grandstand for- mation is pInced at tIle first common occurrence of the Yel'neniUnoides bOTealìs marine fauna. This is also the approximate top of a very sandy section, the thickest sandstone bed of which occurs about 350 feet below the faunal top. The Grandstand formation in Titaluk test well 1 is 1,650 feet thick. About 1,710 feet of this formation was drilJed 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 well 2A is near the base of the formation. The Grandstand contains about 700 feet of sand~ stone and siltstone in beds as much as 180 feet thick; the rest is cIay 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 t.est well 1. The conglomerate contains s~brounded 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 cIay 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 subangular, 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 wells and from 0.56 to 12.45 percent in the Titaluk test well. The highest air permeabili- ties were 325 miUidarcys and 17 millidarcys, respec- t.ively, alt.hough most samples tested "impermeable." 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 tBst weIll is higber than that in the Knifeblade te.st wells, and 1 sampJe in the Titaluk test well had fin exceptionally high reading that measured 30.4 per- cent by weight. Ordinarily the matrix of the sand- stone of the Grandstand formation is argilJaceous. A few feet of limestone (or possibly siderite or dolo- mite)-medium-dark-gray with a brownish cast, hard, argillaceous, with white vein caIcit.er-was found in Titaluk test well 1, but none was found in the Knife- blade test wells. :Most of the oil-producing zones in the Umiat field are in the Grandstand formation (CoIlins, 1957). In the Knifeblade 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 have long since escaped. The two deep Knife- blade holes yielded brackish water on bailing tests. In Titaluk test weIll, a lit.tle gas and a few oil shows were hoted. Siltst.one 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 lessthan 10 percent of the sandstone-siltstone bulk. Some swirly bedding and some small-scale crossbedding were noted· in the siltstone near the top of the formation in Titaluk test well L The clay shaJe and claystone are medium to dark gray and hard. The clay shale has fair to good cleav- age, and the claystone has almost no cleavage but has irregular to conchoidal fracture. These cJayey beds are mostly noncalcareous but are very silty in places and - grade to siltstone. The cIay shale hassome micaceous-- carbonaceous partings. Sericite is "present but is not cominon 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 wells, büt tllese beds interfinger with marine microfossil-bearing shales. The coal may rep.. resent nonmarine stringers of the Chandler formation. No thick coal beds were cored; the cutting chips are black and shiny to dull. Rare carbonaceous shale beds and a few plant fragments in the sllale partings were noted. Clay ironstone is less common in the Grandstand formation than in the Chandler formation. i\Iarine microfossils (see p. 417) are present through- out the formation, ~s well as Inoceramus sp. (mostly prisms in the cuttings), DitTupa sp., and crinoid frag- ments. The Knifeblade area was probably closer than the Titaluk to the source of the material that makes up the Grandstand formation as the sandstone is coarser grained, even conglomeratic, and there are more coaly beds. " TOPAGORUK FOR..O~ Only 520 feet of the Topagoruk formation was pene- trated by Titaluk test weUl. The Knifeblade tests were too shallow to reach it. In Titaluk test weU1, 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. :·TITALUK TEST WELL 1 Location: Lat 69°25'21" N., long 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 Umiat. The test is on the top of a ridge 7 miles northeast of the junction of Maybe Creek and the Titaluk River and about 650 feet above the streams. The area has rolling hills and intrenched streams near the north edge of the Arctic Foothills province. Fifteen miles north of the test site the land flattens to the monotonous lake-covered Arctic coastal plain. The purpose of the hole was to test the oil and gas possibilities of the formations of the Nanushuk group to the extent of completely penetrating the lowest sand- stone or reaching the capacity of the rig . (approxi~ mately 4,000 feet). The hole was drilled to 4,020 feet, at which depth it penetrated the Topagoruk formation 466356-59--2 which underlies"~anushuk 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. ChandleL_ __ __ __ __n n _ _ 590-1,850 feet. Grandstand.. n n__ nn _ _ 1,850-3,500 feet. Topagoruku_nnnn____ 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 weU1 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 thé results of new topo- graphic surveys. STRUCTURE The Titaluk anticline is a long and narrow structure extending from a point southeast of the Meade River at lat 69°35' N., long 157°05' W. about 80 miles east to a point near the headwaters of Maybe Creek at lat 69°20' N. and long 153°30' W. Near its midpoint the Titaluk anticline is crossed by the river from which it derives its name. Titaluk test weIll was drilled on a local closure near the east end of the anticline. The minimum closure on top of the Seabee formation as shown by structure con- touring by 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 eroded. Sur- face geological control is lacking on the northwest side but it has been supplemented by seismic lines (United Geophysical Co., party 144, 1950) which indicate clo- sure at depth (phantom seismic horizon A in shallow rocks of Cretaceous age) . The test well is just south of, and 70 feet below, the apex of the anticline. The strata drilled in the test are flat lying to a depth of about 2,000 feet, indicating that the test was drilled near the apex to this depth at least. I 1 William Brosgé, personal communication. · Datum used on the Umiat Sp;!c[al Map, a topographic sheet pub- lished by the U. S. Geological Survey in 1948. I . . KNIFEf?1ADß TF:ST wELL NO. 1 )-6 " COP Y N 0 .._u_........·..... Knifeblade Test ~ell No 0 1 was the third hole drilled on the Knifeblade str'uc':;: (see the vn'itten su~~ary of Knifeblade Test 'Well NOa 2A)o Knifeblade NOG 1 was spudded in on October 13, 19~1 and completed dry and abandoned on December 22, 1951, . Tt was located 48651 t>J 23013! E of Knifeblade No", 2A, Quadrangle J-14, on the north flank of the anticline north of a major E·-1i thrust fault w"J.d east of a N-S normal fault e Elevation of the derrick floor '.'Vas 891 " The rig floor was 61 above ground level.. 11-3/1,11 surface casing was set at 58 ¡ and 8-5/8!t casing waS set at 12111" The upper 1145' of the hole, in the Cretaceous N~~ushuk, is primarily a cl¿y shale containing & large amount of coal and clay ironstone plus a few thin streaks of sand. Sericite is '''rery common in the matrix of. the upper sandso The top of th,,, thick Tuktu ~ember sands was reached at 1145'. These sands are quite coarse at the top, become finer gra.ined wit.h depth aJld are "salt and peppert? in part. Several very calcareous streaks are present but ve~Ÿ little coal or clay ironstone is to be found. Dips through the hole average 100. Vern~uilinoìdes F occurs throughout the sect.ion; however in the upper 860' of hf\ it isë;'T"relatively,infrequent occurrence and lacks abundant faunal assodates., Belcy; 860' there are numerous species of fora.'I1Iinifera as "I'i:'Bl1 as common Verneuilinoides F, ~evidenta11!:1.!!l_, Jnoceramus and ot.her molluscs are found w"ith the Verneuilinoides ir-> microfauna. Correlation between Knifeblade Nosa land 2A is good" Knifeblade No.. 1 sptlddi.'"c' 735' stratii!l""aphically higher than Knifeblade No", 2.40." 'I'he top of the sand at 114:> ¡ Knifeblade No.. 1 equals the top of the sand at 4551 in Knifeb1ade NOQ 2A" Paleont.o-", logically the top of the Verneuilinoides F fauna at 860 1 in Knifeb1ade No 0 1 eq12a.l:3 1251 in Knifeblade No" 2A:-~-'-"---" ~ The oil and gas ShO'NS in this test, are rather poor" Minor amounts of bitumen were notsd in the sands and silt.s below 10001 ~ The following shows were noted i.n the ditch qy the well geologist or driller: Depth C" ,:Jf1OW ~ 640 1265-70 1273=74 1300 1300=05 1370=15 1390=95 lLoo~05 1480-90 1,05-10 1550=55 1695-1700 1705",·10 17S5-60 -, -.,,.- I') 61':' r. r Ch....=~ ./ Slight amount of gas encou!1tered while Reddish brown cut A little gas while drilling Odor of oil Reddish brovm cut Pale cut C~od reddish brown cut Straw cut Good straw cut Good straw cut Good straw cut Good straw cut Good straw cut Good straw cut Good st:,ra"!fl cut, Good st.ra.rV C1J.t, Slight, t,low of d.r:tlJ=1, (J\ ~' . . fv·~l ot.'Tlnl:1 C11tS Tlêr3 fù£lde o~f co.:res~ Core - Der>th cut - Residue - -" ,: 16 17 l377 1394 Hone Hone Drcmn1sh ;reJJ.ow B1ack1sh y-eUovl-brown In ~dit1on a .fair blow of gas (ex:bausteð in one hour) was encotmf;ered af'ter drilling out csnent plug and float shoe after setting casing at 121l'. !_ of the sands appear to be m. It is interesting to note that Kniteblade rre. 1 first encouniered salt water while dr1lling at 002' (Dine tect a.bove sea level) and that KDfteblade IIo. 2 f:1rst encountered it at 753' (eight teat above sea levol). TIds suggests there fI8Y be a COJII:'lOD water lEfO"eJ. between the two tests, or, it might l'têp.L'et:lêUt the base of the pEØ."!1B.frost. Upon completion of KnUeblade 1'10. 1 the hole _8 I!Bldng -.ter at the rata of 1.0 gal. per hour,. average salinity above SOOO ppn sodium oblor:J.deo Porosity, permeability and carbonate content analyses made in the Fairbanlca 1aborat01"7 are as tollows I Core Depth Et'£ect:Lve Porosity Air ?ermeabiJ.ity - 2 287N 4.42% impermeable :3 3l4N 5.29 impermæble 7 S2SN 1O.SS impermeable J3 1l62N 11.5 less than 1 DId. 14 1269N 13.06 less t'an 1 Md. 1S 1297N 8.16 impørrnea.b1e 16 1377£'1 4.59 2.72 m. 17 1394i'f 6.08 2.66 md. 18 l486N 11.10 less tban 1 Ind. Oore D~th Carbonate Content-% by. weight - . ~ . 14 1269 19.64% 'rhe quality of the well cuttings was good, but with the possibility of loose sand contamination in the lower 250 .teet. AlJ. cores and outtings were described dry. No electrio log was run. Paleontological determinations were made by H. R. Bergquist. 0-40 40-4; 45-5' 55-60 "cr·, 1'... -.,:;\.;---0' Core and rIell Outtinß Descriptioµ S;:.ndstOD.e, light grq with yeJ.lowisb iron stain near the surface, 'wary fine to coarse grained, grains subangular to subrounded, 15% white and clear quartz, l.ìI.1lanoe is dark gm.y and brownish chert, dark oolored rook frag- ments and carbonaceous ¡:articles, ironstone particles a.nd other rare minerals, some black carbonaceous plant impressions, up to 5% moderate yellowish brown and light olive gray clay ironstone, sandstone ver:r slightly calcareous. C1a.y shale,:t medium gray to rnediœ dark gray, trace medium darIc olive gray ironstone. Coal, shiny to dull blacI(" bloclcy fracture, trace mediUIJ1 light gray clay shale and clay ironstone. Sandstone, light fJJ:tly, mostly "t'1hite a.nd clear quart., some carbonaceous particles, dark chert and rock partioles, outstanding in a.bundanoe of interstitial serioite, makes up 25% of" total volume of rock and gives ohips a silky shee;t trace to 5% moderate yellowish bro't'm clay il'OTIErtonèi CJ~y shale~ light gray to medium light gray, micaceous~ trace s~nd8tçn3 ') 70-90 90=9 5 95-10; 105-130 130-140 140-155 155-160 160-165 165-170 170-13; 185-190 Core - 1. . . (~tJal." sh~I..n:ý" ·t(; d.ull ·bJ..a.cl~" ~Gh.ill~~1Jedded, 1xr~i.~ttJ..ø;j slJ2¡.le» ßl)8kY--- C lEJo;¡' Clay sl'k'Ü.e, medium 1i[- 10 gray, seric:ttic, silty, 10% coal and trace clay ironstone 70-75 t .. :rIa sample Clay shale, medium light gray, also 15% very fine non-calcareous sandstone and si1.tstone, sericitic, tra.ce dark gra.y carbonaceous s11.:'11e.. Clay shale, mediUT.<l light gray, trace to 10% dark gray sr1élle 105-110' and 115-1201, trace sandstone IOS-llO' and 125-130u, tr;,ce :L":"onstone 120-125' Clay shale, medium light g¡:ay to medium gray, 5% dark carbonaceous shale and bl.9.ck coal 140-145' 10% medium light gray siltstone and ændstone up to 5% brownish gray clay ironstone. Clay shale, medium. li[;ht gray to medium gray, 5% dark carbonaceol1s shale and black coal )40-)45' 10% medium light gray siltstone and sandstone" up to 5% brownish gray clay ironstone. Sandstone, light gray, medium grained, grains subangular to subrounded, SO% white and clear quartz" also carbonaceous part:lcles, dark chert and rock fragments, 5% grayish broml clay ironstollC3, 10% mediul11 gray clay shale. Cœl anc1 carbonaceous shale, dull black to rarely shiny black" 20% sand- stone as above, 10% clay ironstone. Clay sl1a.le 60%, medium light gray to medium. gray" cool and carbonace:;·us clay shale 30%, 10% olay ironstone, trwce pyrite.. Clay shale,madium light gray to mediuil1 dar~ gray, sericitic, 30% siltstone a.nd some vt5rY fine sandstone 170-175, 15% shiny black coal lSo-ISS' Siltstone a.nd very fine sandstone 60%, clay sr.a.le medium light gray 30%, 10% ooal and carbonaceous shale" . Depth 190-194 ! RGOov~ 41 on l' 0" Sands-tone, medium light gray, b9,rd, fine grained, grains suœngular to rarely sub- rounded, 30% white and clear quartz, fairly large amount of carbonaceous particles, some dark chert; rock fragments and mica, much sericitic mica in the matr:ix gives silky sheen to fractured Síl'l:"f'acesJ} vary rare oarbon- aceous parti:."lgs; non-calcareous; dip possibly 10-150 (11) no shows. :2 t ot! Clay shale" medium light gray to medium gray medium hard, fa.ir cleavage; non-ca1careous; dip undet·armined I! on Clay shale, mediuill dark gray, modsra t e1.y soft fissile, fair cleavage, carbonaceous par'ùioles and fragments in partinßs. Se7eral laminae up to ! inch thick of shiny black coal, brittle, platy; dip undetermined ~1icrofoss~~ absent., 195-205 Chy shale, medium light gray ar..ð m.edium dark gray, 5-10% s:IJ.tl:r'Gone and sand- stone, up to 10% black shale and coal.. 285-210 Sandstone and siltstone" light gray, fine GI'ained to silJ"GY:I 70% white and clær quartz" carbonaceous and ironstone particles common, also dark Cher-'ii and rock fragments, sericite is abundant in matrix and eives [taheenn to ohips, non-calcareous, 5% dark gray carbonaceous shale, trace coal :1 . . ;'j:i_LU~ ":l2<i:i12rú T~C' Ij.3-1~:~~ ;"';'9',.. t>~~CE-- s5.1tatcl}S· ~!j _"'..'";._. ';':=OJ.1nJ;~::: O'L1S . ~ ~~J.·-;:C~~~,~?· '~"J- ~--l~ ::;':,r'----~}L""-_¡<)' '1>,_ ,', ..,M.~,._'~.'_~~.>"':'_~:',. .,,_.,_~,':'.,-:.'-'-""~','_-'-'~O .,., :" ~r~arti:ngs ~.:2(L<?25¡J 10""",20;i] ~-,_~~";' ";'.i;!._ ~_~~_-_.~_~;..; >,...,,__'.·_,_.:~,:,""-r'~ " ;?6S-~267 'Sandst~ne 70%, light gray, medium grained:! grains subangu,lar;¡ 65% vIhit.e and clear quartz, abundant black coal particles:; some brownish and some gray chert, not sericitic, slightly calcareous cemente Clay shale 30%, medium gray Core Dep~h Recove~.[ 2 267=271~ ù90n l¡on DescriJ?tio~ Sandstone, light gray, represented in core box by chips up to 3/4 inch in diameter and a few larger pieces, v9!"Yfi.YJ.e to fine grained, 75% white and clear quartz, abundant black coal particles and vome dark gray chert and rock fragments, rare white mica, argil= laceous cement, dark carbonaceous partings; very slightly calcareous; b~ Sh01v,so D;pth EfJ:~y.~ _~c?!,~§i tr t1~ Permeabili tl_ 207N 4..42þ impermeable 3 'olt Clay shale, medium light gray to medium ~ay, very silty grades to silt shaleð hard poor cleavage; non=calcareous; dip 13 Microfossils absent 272=290 Clay shale50=80%~ medium light gray to dark gray, up to 40% light gray, medium grained sandstone, 1<salt and pepper", with 40% dark minerals, non= calcareous, also 40% black coal 283~287', trace brovmish gray clay ironstone a 290-·295 Sandstone, light gray, fine grained, sericitic, also medium dark gray clay shale, rarely medium light gray. 29~-305 Clay shale, medium light gray, silty, sericiticj 5% medium dark gray clay shale 305~310 Siltstone and sandstone as in core below, 30% medium light gray to medium gray clay shaleo Core Depth ~.£overy }JtSs(:rj.p~~0!l :3 311-315' 4øo" Sandstone, light gray, hard, massive, fine to rare medium grained, subangular 75% white and elear quartz, also roel. fragments} dark chert, carbonaceous part,icles, white mica and earthy tan particles, micaceous=argillaceous cement non-calcareous; dip 8°; no shows De~ ,Effecti'v€ Po_r~s:i.tI Air Permeab:ni!z 31 N 5~29% impermeable Microfossils absent 31~~360 Clay shale, medium light gray to medium gray, trace to 15% sandstone 315=320' 340-34S' and 355-360·, 5% shiny black coal 330=335Ø, trace ironstone through= out 36,0=365 Sandstone, light gray, medium grained, sub-angular, 85% white and clear quartz also dark chert ca'ebonaceous particles f) rock fragments and some whit.e miCét,i) slightly calcareous. Also clay shale, medium dark gray 15%0 h Depth 365-368' Recover.x Description Core 0'6" / Sandstone, medium light gray 1 hard, fL."!e grained, angular to subangu1ar, 85% white 4 368~=J!30 380=Ì;o5 I.to s'=lJ 5' Ll~=-,Lt20 h20=450 1!50~h~5 t rl,-J 1 :-.:~TO! I.J.? ')=4 {:::; I .",,", LA", tJ. ( ~-4..A..) hBo-50o 500-~05 501)=535 535'=5'40 5~o~56? Core - ".J ') ) 70,~57S 57i),=60'5 605~~610 . . .~ ~"~,:~:(-,y <? J:~i'Gt l,; J' ~;V'~' ,i : t -:c~ ~:: ŒD. e :6\. ] ; dtl:J arf"illaceous cement; In;.dete:~:r¡j..ni(~dj :no ShOliVS ~ Microfossils abS8nt~ Sandstone, as in core above, nOl1=calcareous, ceœbonaceoli8 impressions 375-380' " Clay shale, medium gray to medium dark gra:y, 10% very fine sandstone and siltstone 380=3551, trace silt shale 385~3901 and 20% light g~ay, fine to medium grained t1salt and pepper!i, serici tic sandstone 395c.i.¡051, t,race clay ironstone 395-400~ Clay shale, medium light gray to medium gray, trace silt shale Sandstone and siltstone.. medium light gray to ruedhun gray~ ve!'";¡ fine to fine grained, 75% quartz, some ironstone particles Clay shale, medium light gray to mediu.I!l dark gray, trace to 10% sandstone ~~d siltstone 420-135' 5% bro?mish gray clay ironstone 420-430' and trace of shiny black coal and carbonaceou.s shale h20-h35', 15% silt shale 445-450' Sandstone, light gray, fine grained, grains sTIban~~lar to subrounded, 70% white and clear quartz, balance is dark chert, rock fragment.s, carbonaceous and ironstone particles, abundant interstitial mica.$ nm'h~alcareous, trace silt shale, 10% clay $hale~ Clay shale, medium light gray to medium gray, 5~L¡O}S silty' sandstone as aiDove 455'-65 i trace shirry black coal 465-470 1, 20% light gl'ay~ s i1 t she,le 4.70-475 q Coal 30%, shiny bla.,ck, carbonaceous dark gray sha1<3 30%, medium gray clay shale 30% and 10% silt shale Clay shale, mediu.m light gray to medium. gray and traee of medium. dark gray trace to 10% sfu"'J.dstone and silt sha.le, trace of ye1.1mv-1sh brown clay iron- stone 48o~h85~ a.nd 490=5001ø Clay shale 75%, mediu.111 light gray to medium gray.? also sa;,1dstone 25%, 70% quartz, quite sericitic~ verJ slight calcareous, trace ironstone Clay shale, medium light gray to m.edium gray, 10 to 15% silt shale 505-,515 and trace silt shale 520-525 and 530-535', trace coal and carbonaceous shale 510=520', trace grayish brown ironstone 505-5101 and 515-520', 5-10% olive gr~ and yellowish brown ironstone 525=53510 Silt sha.le, medium light, gray a.nd clay shale, medium light gray 'to medium gray, S% ironstone Clay shale, medium gr&y to medi11J1l dark gray, occasj.onal dark gray, 10% very fine grained, lig~t gray sandstone and trace ironsto~e 54û=5li5~o £,epth 567.~570 1 ?eC:0vt?.El. Description . .~... 2¡On Claystone) medium dark gray to dark gray, hard to very hard.. dense, gradi33 dOTì'inWard thru siltstone into sL'C inches of' mediU!)1 gray ~;er::/ fine graL~ed silty sa~jstonü, dark carbonaceous p18~t impressions in sandstone; non-calcareous dip possibly 10°. Microfossils absent~ Clay shale, mediu¡n gray to medium dark gray, sandstone 20~¿;, medium lighii gray, very fine to medium grained, much carbonaceous material, sericitio, ve~J slightly calcareous, trace brownish gray clay ironstone~ Clay shale" medium gray to medium dark gray with carbonaceous partings 590-595 ~ j trace medjum dark gray silt shale 580=,851, Sç·20% silt shale a.nd medium light gray to medium g;ray, very fine to fi.ne grained, very slightly calcareous sandst.one,. trace dark yellowish brown clay ironst.one 59û=S95Y, 10% shiny black coal 600=6050 Coal, dull to shiny black, blocl<y fracture and dark gray' carbonaceous shale. l~% medium gray clay shale, 5% dark yello<r.Lsh bro~m clay ironstons0 r" 6hO,~6ll'? .(1,1:" C,£r, U4J'.:cc:.UVv 660=665 66S"~ 700 700,,710 '(lO"745 745~7'50 750~ 770 CorB 6 773~~ 780 780,->785 785,~795 795·-815 815=820 820..,825 Core 7 . . _"' ,,; ;li~~::~(!.::LÜ.); ;'\7' $' " ~2-~-t:,:n' :} t;':C~?:.CE; to 630=ÓÌ:J,O ¡" )=107; fin~~ 635=6ho j . Sandstone, nlcd.il1lli light. gl~a:.r;; f'ine grairled, 70% vJhite ,anà clear quar~t~~~~ balance ls carbonaceous particles.') dark chert. and ironstone particles, coaly partings, slightly calcareolis, 10% clay shale med:J.11m dark gra~r t.o dark g'i:ay, olive gray ironstone quite commonG Clay shale medium gray to medium dark gray, trace i:ronston8 645=650!e Clay shale, medium dark gray to dark gray, 20% sh:Lny hlack coal Clay shale, mediUTIl gray to medium dark gray, t.race ,silt shale 665=670 trace dark gray carbonaceous sl1ale, dull and shin;y"" ble.ek coal 670-680~ 0 Clay shale, medium gray to medium dark gray, lO<~20~r; sandstone and siltst,oneç medium light gray to medium gray ~ muc11 carbonacecms !11.ai:;erial, lUoderatel:y calcareous, trac (~ to 5~b olive gray ironstone. Clay shale, medium gray to medium dark gra:h rarely dark gray} sandstone and siltstone, ~ædium light gray to mediwTI:. slight~f calcareous 5~t dull black coal and carbonaceous shale 735-745 , trace brown- ish gray ironstone 710-715' and 730-73510 Clay 3ha1e, medium,dark gray, many plant fragments, also 30% shiny black coal. Clay shale, medium light gra:.r to medium dark gray, tra3e coal and carbonaceous partings:ll trace ironstone 750=7601:11 trace silt shale 765-77t~ '. J_ ';:~ c;· Y1 S --r..:) c :.. (::;' ,. :;;;sr 625"·-0'0>630 ;( rûeÒiltril 15..grtt {š1:B;:I' sa~ld8ton.e 8J1G. 10% very- fine to moderately Dept~ 768- 7'73 ¡ g.§'çpve:ry: P.Ê~çriJ:)~ 5iO" Clay shale, meCi~um dark gray:. hard, fair cleavage, very rare sligLrtly silty streaks; nOTI=calcareous, dip not determined. lliticrofossils absent Clay shale j medium gray 11111.-1:.1'1 trace of dark gray, 107.; s':l].ny black coal Coal 40%, shiny black and medium gray clay shale, trace irons~i;one Sandstone, medium light gray, fine grained, 65=70% 1:,vhit,e and \~lear quartz)) fairly large amount of carbonac30us or coaly material, dark chert, much sericite~ ver"J slightly calcareous, 10% clay shale;> t,ra.ee ironstone. Clay shale, medium light gray to medium dark gray, 5% dark gray carbon~' aceous shale 800~805¡: trace coal 805=810Q No sample Sandstone 80%, light gray; fine grained, 75% white a~1d clear quartz~ also carbonaceous fragments) dark chertj> rock fragment~~;¡ not sericitic¡J very slightly calcareous, 20% :medium dark gr.'ay c1a;r shale Depth - Re.coy~El. DeSC1"'iEtion ~-_-: .. -<.....---- 826=830" hiol? Sandstone, light. graY$ hard, !~salt and p\8pper!~, very fine to 'rfel:Y coarse grained, suban¡;n.Ilar to rounded, up to 50% dark material--coal particles, rock fragments and dark gray chert, balance is mostly whi t,e 8.nà clear quartz an.d light colored earthy particles. Several st.reaks of conglomera~e up to two inches thick COD- taining subrounded to rounded granules and pebbles of dm"k gra~r.\l greenish gray a..'1d black chert, milì{y quart~, coal~ medium light. gi,"'ay and medium gray' clay 3ha1e, ;rellowish gra:,r ironstone and light gray sandstone; non= calcareous, dip possibly 9° (?) 6 8 ":\'Cc DbS fJ()l~e 8 3Lt6-850 850=880 C()re 9 882,=910 Core 10 91~,-9.30 . . E~b3;9rr:', Sand.st.OT.le as in. COJ~e ,ab(r~~~= rnedi'uHl tc~ coarse gr;;a.j.l16(j;) 'Uj;:' to')'% ~rery r.)a.l(~ ;:>ran2e .clay ì:r~ont3.1ton_B and tr<lce da:t~k gray cla.:l sb.al,e 83·~}·:~E335v ~ Derrt.lk' -~ 8h5-846 Recover::,l _........~~-..-....... Description ...".,.......-'"""''"'',:....~-''''~.~ 1'0" 4 0 6!f IOÐSE! sEnd and \fer-:f small cl1i:os of sandst.orle J.ight, gray but. higl'1l;,)7 rust=st,ained from met.al c11ips fpom the 1)it" f.i.l1e to m',9dilli~1 g¡Aairlecl9 "'1"'~'; rj~ ~"'0'1",1 Q"X' +0 S~ '1}..~¡~.C'111·1 ""~. 90%' "",1->; 'c',,,,, :::;·.r..;~; b- ti.J...__O .a.¿.1~~.....I...'I..io '.I .... 1..o'·t..J<::t.-~e' ."'-":;.I".L,~ I !1j",~_ G '-">0 _,_ clear quartz; balance is dark chert and coal pa:rticles, 0; 611 Sandstone;, light gra:l}J ve.fY hard) possibly silìceol1 S CSll1ent ~'It COD1};:Josition ,9.S above.$ bu:t with larger proportion of dark colored mater-, > -, ... '1- d t . d J.~1.S 3' no~:::>ca..L{;aJ.,;e?~13 ,;~ :~lp ~111 ·:e ermlne ; flO snows ~ 1'J1lcrofoss~J..3 \9.0S8TTt Sandstone as above, Clay shale, medium light gray to medium dark gray, 5=25% mealum grained d· 81:'0 860!' <>. ., , . . . . , b san S"Gone 7 - ':} t.race L lrl9 grallled. sanaS1ione c()}:')_t.a::u~nng muctl ca.r' on·» , ., Q6'"'''7r'g ....-'C/ d· 1"", ~. , d d t 1 aceous mat.erUi..L- 0 ')=(3 ?', .5~!" me llln1 19n" gray, I IT!.i.';) gralnet , ma "era e_y calcareous sandstone 875,-880 ¡ $ "Grace oli v"e gray ironstone 875~,,380 9 . P?1?th 878-.882 lieco2T~ry Descri~~~ 3'61t 1"6!t Sandstone, medium light gray, m.ediu.m hard;, very fine grained to siltY!I subangular to subrounded, largely~vh:tt,e aJ."1.d clear quartz, some dal"k chert" ('(jck fragments" dark micaceous~carbonaceous partings; vs:rj'" slightly calcareous, dip undeterw~ned; no shows, becomes siltier to'm;ard base and grades into.; 2!O!f Clay shale, medium dark [!)."ay, mediu.m hard.:; poor clea"ìlage; non=calcar'30us,; dip undeterm- inedo Microfossils abserrGo Clay shale, medÌ1.lID. dæ"'k grfAY~ silty 90o.-~910', slig.htly!:'o moderately calcareous" 895~-,910 ¡ .0 £K?pt!"! 910=915' ReCOVS1"V' ~ n . t' ;;:pSCT'J.p ~ûTi. 3'0:1 Clay shale and -claystone., mediüm gray" poor to fair cleavage} mediltm hard, some lITÍcaceous- carbonaceous partingsJ slightly silty, a few black plant Lüpressions in partings; non= calcareous; dip 5-10° (?)J Microfossils ab~errto Clay shale) medium light gray t.o dark gray:;t.l'fl'ße J.l"onstone 920=930', trace shir~ black coal 925=930', 5% very fine} medium light gray sandstoneo 7 935-940 9ho=945 945-950 950·,·,955 Core 11 960=96, 96t;-lOOO lOOO~lOlO 1010~l020 1020=1030 1030~l040 1040=1085 1085=1100 1100-1115 1145~ll49 Core 12 . . . -~' nldtll.uru i2;""W) ~¡ .;-~ ,; -,'~ :..:, _.' -"-,:_0>J.",,> \l(ÜitG:; dJ.·~G. qllart,z, also c8..r~bollctceOllS ~1G~:rt i~~les:; d,8,I':}: cÌ1(-;[t, sorne ;.:'3rici tIe:; £:1:1 gh~:':::f'~ calcareous!J 20~g coal anò. eflrbon.ace01..,lS a11ale, dull to sr.t.in~.r bla-ck:. trace medilli~ gray clay shale, trace grayish bro~TI ironstonG~ Sandy siltstone, medil.L'!l light gray and i¡o% medium gray clay' shale, trace coal 0 Clay shale, medium light. gray to medium gray 0 No samples Siltstone and ver'<J fine sandstone 40%, medium lj.ght. gra,y aûd clay shale~ medium gray to medÌ'l1J1l dark gray, trace dark yellow bro'WD clay ironstone 0 De~t!! 9,5=960 ~~c_ov:e!l Desc!,i~~J2E. Siltstone and sandstone, medium light gray, hard, tight, fairly good cleavage, dark carb- onaceous coaly partings, sa.'1dstone is veI"J fine grained, subangular~ grains consist primarily of opaque grayish wÜite quartz also rock fragments and carbonaceous particles, much sericitic mate~ial in the matrix-gives sheen to the hand specimen; non~calcareous; dip 80 (1). Microfossils absent. 3'9" Silt shale and clay shale" medium light gray to medÍlun dark gray, t:rac~ coal and ironstone . Clay shale, medium gray to medium dark gray, rarely :medium light gray and dark gray, trace coa.l 970-97,1 and 990=995', 10% dull and shiny black coal 995-1000', trace ironstone 990=995~o Clay shale and coal 60%, shale is dark gray- and carbonaceous also medium gray and medium dark gray clay shale, 57;; slightly calcareous sandy silt. shale, trace Prrite Coal 10-20%, shiny black, b10crf fracture, 20% dark gra.y clay shale, 70% medium dark gray, trace pyrite, ironstone and silt, shale, pelecypod framments and ostracod impression 1015-20J~ Clay shale, medium gray to medium dark gray, 20% dark gray clay shale Coal 30=80% dull to shiny black, clay shale, ruedium gray to dark gray, 10% medium dark gray sa."ldy siltstone, one piece of siltstone with bitumen stain 0 Clay shale, medium dark gray to dark graY:I trace of siltstone and sandy siltstone lo4o=1050'~ trace of calcareous siltstonep medi~~ dark olive gray with bitumen 1065-1075 ~ and 1080=10853, 5-10% coal 1075-1085 q J trace p,yrite l075-1080Qo Coal 20=30%¡; shirw black and clay shale, medium dark gray to dark gray, trace brownish gray ironstone Clay shale, medium dark gray to dark gray, trace to 10% coal 1100~1125' 5% coal I1ho-ll4,;, trace S&.lîdy silt shale 1135=llL~o':> 'trace pyrite 1120- 1125' and 1140-1145, shell fragmeIT~s 1100-110S, 1110-l120~ and 1130-1135', Inoc&ramu~ prisms 1110-1120J, a few shell fragments l130=1135~0 Sandstòne; light gray to medium light gray~ soft, loose, medium gra.ined, grains subangular to occasionally subrounded, ftsalt and pepper It , 60% white and clear quartz, many coaly particles., dal"k che~t't, rock fragments, some white mica, non-calcareous, 10% medium dark gray clay-shale e Depth RecoV"!3l'"l. 1149-1152' 1 a On De$crj.~:!.~m Core consists almost entirely of mud con= taining a few ch~ps of medium gray clay shale.. Microfossils rare, two species common" 8 . . 11:;5=1160 Sandstone <:is in :L'1terval above Core 12, mediu:m. to coarse grained. Core 1':¡ -.." 116~-119, 1195-1200 1200-1220 1220-1245 12115-1250 1250-1255 1255-1265 Core 14 Depth Recove~ Description 1160-1l65 , 3'4" Sandstone, medium light gray, moderately hard, thin bedded (?), medium grained, grains subangular, 75% white and clear quartz, many d~rk colored rock fragments and chert, some mica and occasional other minerals; non-calcareous; no shows; dip probably 5° or less; no shoW's. ~E~~ Effective Porosity Air Permeability . If..5% Less-than 1 ma... Microfossils absent. Sandstone, medium light gray, loose, medium to rare coarse grained, fine to medium grained at base of inJ"erval, Itsalt and pepperl1, 70% white and clear quartz, balance largely dark chert, some coaly particles and rock frag·- ments, non-calcareous, 5-20% medium gray to medium dark gray clay shale. Clay shale 60%, medium gray to medium dark gray, also some loose sand as above. Silt shale, medium dark gray, slightly sandy 1200-1210', argillaceous (40% near base of interval), 1210-1220', trace coal 1200-1205'. Clay shale, med:1mn dark gray, trace to 15% silt shale with bitumen stain Silt shale 80%, medium light gray, sandy, non~calca:reous and clay shale, medium dark gray, bitumen stain in silt. . Clay shale 60%, medium dark gray, also sandstone 15%, medium light gray and si.ltstone, medium gray, chunk of stubb.r Inocera!J'!Us prisms, bitumen stain Sandstone 75% medium light gray, very fine to coarse grained, constituents as in core below, also clay shale, medium grð'-J to medium dark gray, very rare bitumen in cracks. Depth Recovery 1265-1270' 3'0" Description Sandstone, medium light gray, hard, mas.si va, rtsalt and pepper", medium grained with rare coarse grains, 75% white and clear quartz, much dark chert and some rock fragments, calcareous cement, very rare brownish plant impressions; dip undetermined; no shows. Effective Air Carbonate Content De~th Poro~ity Permeab~lity __. % by Weight 12 9N 13.06% less than 1 md. 19.6l¡;~ Microfossils absent. 1270-1295 Sandstone as above, mostly unconsolidated, medium to coarse grained 1265~ 1280', fine to medium grained 1280-1295, interval 1280-1285' is slightly harder, slightly calcareous also vlith sericite in matrix, rare bitumen on broken surfaces 1285-12950 Core W- Dep~h 129 -1298' Recovery 1'10" Description Sandstone, medium light gray, hard, subanøular to rare subrounded, fine grained, 80% white and clear quartz, balance is dark chert, coa.l particles, rock fragments and mica; non-cal- careous to very calcareous; no $hows Depth ~fective Porosity Air Permeability l291N a 016% impermeable Microfossils absent, Inoceramus prisms in the microfossil cut . 9 . . 1325=13.35 IdS a~ DOV-E, r·:~2'lS C¿L_LC~L:";:~:' 0118 <_ calcareous 1310~~1315 ~!' sliglrtl~T calca:C~BOílS 1315---1325' ~ V'3X'i:J~ f1.!lÐ gl·\s1.inecl and 90% white and clear q~artz 1320=132S~~ Silt shale and ve!:"lJ fine sandstone, slightly calcareous, some clay shale near base of interval~ Clay shale, medium gray to medium da.rk gray, 20% silt shale 1.335-1340' Laevidentaliwn fragments throughout interval. Sandstone 50%;- light gray fine to medium grained, 85% white and clear quartz, balance is mostly dark colored chert and some rock fragments, slightly calcareous, also 30% medium dark gray clay shale, Laevidemalium. Sandstone as above, mostly loose sand, non~calcareous, trace of cla~~ shale, Laevidenta1ium 1365=1370~ 1335~·1355 135'5=~1365 1365~1375 Core ~pth Re~ov~!:.l Descrip~i0l!. 16 1375~1379 3'Ofl Sandstone, medium light gray to medium gray, hard, very fine to medium grained, suba.ngular 75% white and clear quartz, balance is rock fragments, dark gra;r chertj) mica, pyrite and other rare minerals, rare partings of coalQ Very rare pieces of core have bitumen or a tarry residue on broken surfaces, also a very small amount of medium gray claystone; non-calcareous to slightly calcareous; dip undetermined, possibly low;no cut or residue from 1377° D~th Effective Porosity Air Permeability 1377N 4,,58% - 2·.72 mdo - Mtcrofossils a.bsento 1319=1390 Sandstone as in core above, medium grained, very slightly calcareous 1385- 1390) 0 Core 17 Depth Recover;r 1390-1395' 3'0" pes~ription Sandstone, medium light gray to medium gray, hard, medium to coarse grajned, subangu1ar, Itsalli and pepper", 70% w.tdte and clear quartz, balance is mostly dark gray and black rock fragments and chert, argillaceous cement plus quite a bit of interstitial bitumen; dip 12°?; non-calcareous; trace of an odor, brownish yellow cut and blackish yellow-broil'm residue front 1394 e Dep~h Effective ~orosìty. Air Permeabi~ity 139 N 6008% 2066md. Microfossils absent 1395-1435 Sandstone a.s in core above, fine to medium grained, mostly loose sand, slightly calcareous 1415-1h20, moderately calcareous l395-1hooä and 1430-1435' much rust stain from bit 1425-1435', chunk of Inocer~s prisms 1430-1435' 5'-25% medium. dark gray clay shale 11.r.o5=1420 ¡ .. . 1L35-1445 Sandstone, medium lig.l1t gray, fine to medium. grained, Usalt and pepper!!, grains subangu1ar to subrounded, 60% white and clear qvartz, much dark colored chert and some rock fragments, slightly to moderately calcareous cement, rare Inoceramus prismso 10 . . 14h:;,·1l.¡(;6 Sa.1'}dstone, medium light gray, fine to medium grained, T;;"~ v¡hite and c1eaI' quartz, sericitic: in part, ve?:":! slightly ca.lcareous 1LSO-1455 :J very calcareous cement 1455-1465'& 1465",1485 Sandstone 50~', light gray to medium light gray, very fine to fine grained, silty, very calcareous cement 1465-1470', chunk Jn~~e£amu~ prisms, also up to 50% medium dark gray clay shale, trace coal and pyrite 1475-1480~ Core 18 1490~lh95 149'5c-150, 1,0,=1510 1510~151S 1515=1550 1550~"1580 1'580$,1590 l590~1600 1600=1660 1660=1685 1685=1710 Core 19 Depth Recove~ 1485-1490' 2'6" Description Sandstone, ~editlln light gray, hard, thin bed= asci (?), very fine grained to silty, sub- angular to subrounded grains, 90% white and clear quartz, also dark chert and rock frag- ments; non=calcareous; dip undetermined; no - .. shows.. ~~ih ~,ctive Porosity ~ir Permea~~lity N 11..10% less than 1 md. Microfossils absent~ Sandstone as in core above, sjlty, non-calcareous Siltstone, medium light gray and very fine sandstone, light ?ray, very calcareous cement, also 30% medium gray clay sha1eo Sandstone, medium light gray, fine grained, grains subal1gular t.o subrounded, 90% vihite and clear quartz, balance is dark chert and rock fragments, some sericite, carbonaceous patches, moderately calcareous cement. Siltstone and very fine sandstone, moderately to very calcareous cement Clay shale, medium dark gray, trace medium gray, non-calcareous siltstone and very fine sandstone 1515-1520' and 1530-15.40', 25% very fine sandstone and siltstone, Laevidenta1ium 1,35-1540'. Sandstone, light i;ray to medium light gray, very fine grained, grains subangu1ar to subrounded, 90% white and clear quartz} trace dark yellowish brown clay ironstone 1555-1560', trace of bitumen throughouto Siltstone, medium light gray, trace clay shaleo Sandstone, light gray, fine to medium grained, "sal-!i and peppel"l!, soft and friable, 65% white and clear quartz, subangular to :rarely angular Sandstone, light gray, mostly loose sand, fine grained, r.arely medium 75-85% white and clear quartz, some siltstone a.nd clay shale, tra.ce carbonaceous shale 1615-1620', trace of bitumen in siltstone 1625-1620' Laevidentalium 1605=16209, Inoceramus prisms 1625-1630' Clay shale, medium dark gr8,y, 30-40% medium gray sandy silt shale 1660- 1675', 30=,0% sandstone 167,~1685'e Sandstone, light gray to medium light gray, very fine grained, grains subangular, 90% white and clear quartz, dark chert and minor amount of other minerals, slightly calcareous, trace medium dark gray clay shale. Depth l710~1712 ~ec.?"'T.~:r.y 0'8» Description - ---- ,..,. . . ~ --........ Silt shale, medium gray, very hard; very slightly calcareous; dip undetermined. Micro.fossils very raree 1712-1715 Siltstone, medium light gray to medium gray, sandy, l1on=calcareous, trace medium dark gray clay shale. 1711)-1730 Cla'.f shale, medium gray to medium dark gray, siltyc 11 17 1735,"T150 17jO~ol ?i)5 17<5-·1760 l~·'-· 17"r:' f öu~<_ b:; 176'.;-1770 1]70~o.1785 178r::-1795 ~ 20 21 . . Siltstone, !!ledium, light gra;;r t.o med:Lum gray., 201; meòiu!:; d.arK gray cla.y shale, rare bitumen coating> Clay shale, medium gra~y to medium dark gray, vet""f silty Siltstone and very fine sandstone, medium light gray, slightly calcareous 30% medium dark gray clay shale. Clay shale 7~% medium dark gray, 30% medium dark gray, slightly oa1= careOllS silt,~shale" Siltstone 80%, medium light [ray, sliF;htly calcareous, slightly micaceous, also clay shale, baeviden~~lium Sandstone, light gray, very fine grained to silty, gratns subangular to occasionally subrounded, 90% white and cleæ' quartz, also carbonaceous and micaceous particles, dark colored chert and rock fragments, slightly calcaroous, 10% medium dark gray clay shale~ Siltstone, and very fine sandstone, slightly ca1careous7 trace clay shaleo Clay shale, medium gray, silty, trace coal, Laevidentalium 1780-1790j " ~-r--""~ DeEth ~ecovery, 1795=1800 ! 0' Olt ~j.ptí~n No recove!'"lJ 1801=1805' 1'21f Clay shale, medium dark gray, moderately hard fair cleavage~ finely micaceous; non=cal= careous; dip undetermined Microfossils common but species rareo JJI&~d..-t?~ Florence Rob1naono Geologist April 240 1952 12 !~~'!--:..;, -,....-.:...~~ . . "Old" , I.a\-")' Hells (1944-~3) Well Name Avak -, IOb-Od'?- South Barrow-l /ðO -083 South Barrow-2 / ()O -oB"f Sôuth . Barrow-3 10D ~O~ i South Barrow-4 1 0 0 j- ()é}." F±sh Creek-lIDO -)CÒ i GJrandstand-l 100 -< P""-3 , I Gubik-l 10C>-;):;) I ¡ I Gubik-2 100 -:J:J ~ ' Kaolak-l 100 -G)-;;)~ Knifeblade-l It10 - IB / YJ1ifeblade-2 I bD - .I;;.i;J Knifeblade-2A ì:s "OW (K¡Pe.Jalt1de 6- Heaàe-l OU11lalik-l loo-il<¡ Eas-t Ou.'nalik-l IOD -116- Si.mpson-l / /:>()-/f¿,3 Nðll"fh S,'",p$þq-I /bD,-OI1! Squ-are Lake-l J 00 -¡J{, Tita.luk-l 10(;)- dJb Topagoruk-l JOO -Iq~ Ea~t Topagoruk-l I o:J ~ 6- Umiat-l /DC -QeD, Umiat-2 loo-QID Umiat-3 (oo-é}.(/ Umiat-4 100 -f¡/:J Umiat-S 100 -g./3 Umiat-6 /OD -;).ll..fj Umia:t-7 'l?ó-c9/~1 I Umiat-8 /oP-;).I(P \ Umiat-9 Jó b -Q/1- J Umiat-10 IDD...f)I(f Umiat-ll 100 ...f)/~ Wolf Creek-l I tp-11"1 ). Wolf Creek-2 JUO-Út75 ! wolf Creek-3 I (i) -ì I~ .. J , , . " , t , t I . ¡ ...'..' --." ---_.' .,.-- _.-. ....-' --'--- ~.- ...._-~" -',.--- -~---_....~-'.._-_.... ,- . "Intermediate" Wells at Barrow.C19SS-l974) . South Barrow-S lóO-ö;;).15 South Barrow-6 iOO-ö;;)Oo¡ " South Barrow-7 ¡6o'-O'3D South Barrow-8 / lJó!-031 South Barrow-9 IDD-ä3;;¿ South Barrow-10 1d.:>-0'33 South Barro...·-ll If$> -63« ~ I t I South Barrow-12 /óO"'b~ ~ t . J.(5
