Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
184-016
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 28 Township: 11N Range: 9E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 7380 ft MD Lease No.: ADL 0025657 Operator Rep: Suspend: NA P&A: X Conductor: 16" O.D. Shoe@ 109 Feet Csg Cut@ NA Feet Surface: 9-5/8" O.D. Shoe@ 3150 Feet Csg Cut@ NA Feet Intermediate: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production: 7" O.D. Shoe@ 7358 Feet Csg Cut@ NA Feet Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing: 3-1/2" O.D. Tail@ 6982 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Balanced 6650 ft 1960 ft 6.9 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2335 2260 2260 2260 IA 2340 2275 2235 2215 OA 270 270 270 270 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location to witness the slickline tag and the combo mechanical integrity test of the tubing and inner annulus (CMIT TxIA) after the intermediate cement plug was pumped via coil tubing on 7/8/25. A 2.25-inch drive down bailer string was used. They found the top of cement (TOC) inside the well's 3.5-inch tubing @ 1960 ft MD with mulitple licks down to gather a cement sample. Once out of the hole cement was observed in the bailer. A passing CMIT TxIA was then completed to a target of 2000psi. Test was ran to 45 minutes to prove inner annulus stabilization. July 14, 2025 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2F-05 ConocoPhillips Alaska Inc. PTD 1840160; Sundry 324-533 none Test Data: CMIT TxIA P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0714_Plug_Verification_KRU_2F-05_am 9 9 9 9 9 9 999 9 9 9 9 99 9 9 9999 9999 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.16 11:11:54 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 28 Township: 11N Range: 9E Meridian: Umiat Drilling Rig: Rig Elevation: Total Depth: 7380 ft MD Lease No.: ADL0025657 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 109 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3150 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 7358 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6982 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Retainer 7226 ft 6762 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2710 2650 2635 IA 1230 1230 1230 OA 280 280 280 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Halliburton wireline had 130 pounds of toolstring with a 2 1/2 inch drive down bailer with a mule shoe with a flapper valve. The bailer tagged cement at 6762 ft MD including the correction of 24 ft for wireline. The sample was of good cured cement and some softer cement mixed in. Barrels in and out for the MITT were 0.2 bbls. July 5, 2025 Guy Cook Well Bore Plug & Abandonment KRU 2F-05 ConocoPhillips Alaska Inc. PTD 1840160; Sundry 324-533 None Test Data: P Casing Removal: rev. 3-24-2022 2025-0705_Plug_Verification_KRU_2F-05_gc 9 9 9 9 9 9 999 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.11 14:16:40 -08'00' 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. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2F-05 (PTD 184-016) Sundry Extension Request Date:Wednesday, October 22, 2025 12:08:38 PM Attachments:KRU 2F-05 10-403 PA SUSP EXT 2025. signed.pdf From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, October 22, 2025 8:33 AM To: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: Re: KRU 2F-05 (PTD 184-016) Sundry Extension Request Thanks Jaime. Your request is approved to extend to 2/28/26. Jack From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Wednesday, October 8, 2025 3:59 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: KRU 2F-05 (PTD 184-016) Sundry Extension Request Well Name: 2F-05 Facility: CPF2 PTD: 184-016 Well Type: Prod AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Jack, Please see attached request to extend the current 10-403’s expiration date to February 28, 2026. Thanks! Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 5 October, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find the attached request to extend the existing 10-403 (324-533) for ConocoPhillips Alaska, Inc. well KRU 2F-05 (PTD 184-016). We are requesting to extend the expiration date of the procedure to February 28, 2026, to complete the Plug and Abandon procedure. Also please note on the original 10-403 application in Box 10, the current pool was listed incorrectly as KRU Oil Pool – Suspended. It is KRU Oil Pool - Active. If you need additional information, please contact us at 265-1053. Sincerely, Jaime Bronga Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Jaime Bronga DN: OU=Conoco Phillips Alaska, CN=Jaime Bronga, E=jaime.bronga@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.10.08 15:56:31-08'00' Foxit PDF Editor Version: 13.1.6 Jaime Bronga ORIGINATED TRANSMITTAL DATE: 8/26/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5605 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5605 2F-05 50029210730000 Perf Record 14-Aug-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 184-016 T40801 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.26 12:41:17 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-07-07_24020_KRU_2F-05_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24020 KRU 2F-05 50-029-21073-00 Coil Flag 07-Jul-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 184-016 T40677 7/18/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.18 11:11:26 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7380' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-1053 Senior Well Integrity Engineer KRU 2F-05 6283' 6991' 5956' None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: jaime.bronga@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6953' MD and 5924' TVD 1806' MD and 1791' TVD Jaime Bronga STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025657 184-016 P.O. Box 100360, Anchorage, AK 99510 50-029-21073-00 Kuparuk River Field Kuparuk River Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool- Abandoned TVD Burst 6982' MD MD 109' 2853' 109' 3150' 6265'7358' 16" 9-5/8" 80' 3121' 6896-6914', 6988-6999', 7000- 7011', 7026-7040', 7102-7108' 7329' 5877-5892', 5953-5963', 5963-5973', 5985-5997', 6049- 6053' 7" Perforation Depth TVD (ft): 11/1/2024 3-1/2" Packer: Baker FB-1 Packer SSSV: Camco TRDP-1AENC Perforation Depth MD (ft): J-55/ L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 6969' Jaime Bronga Digitally signed by Jaime Bronga Date: 2024.09.17 10:39:44 -08'00' 324-533 By Grace Christianson at 2:45 pm, Sep 17, 2024 X 10/23/2024 DSR-9/27/24 XX 10-407 SFD 10/23/2024 AOGCC witness after wellhead cutoff and before top job. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 10:56:58 -08'00'10/25/24 RBDMS JSB 102924 2F-05 P&A August 25, 2024 Expected Start Date: November 1, 2024 Jaime Bronga (907-229-8282) Objective: Gain approval for the full abandonment of Well KRU 2F-05. Well History: KRU 2F-05 was initially drilled and completed in 1984. It was completed in the A, B and C sands. The well was worked over with new tubing in 1990 and equipped with 7” production casing and 3-1/2” tubing. During production, KRU 2F-05 was a known rock, sand producer. A sand screen was set in the tail pipe in 1993. Part of the screen was pulled in 1996. In 1996, the well was shut in and has remained shut in. The well was replaced by a new drill KRU 2F-05X to the same reservoir target. In 2017, the well exhibited signs of IA integrity issues. In 2018, pressure tests and a leak detection log established that the tubing has integrity but there is a production casing leak from 6670’ to 6770’ rkb which includes the production packer. The current condition of the well is shut in and secured. The tubing was left secured with a WRP set below the production packer. The gas lift valves have been dummied oC and the IA was circulated out to seawater with diesel freeze protect. The well has no future utility, Conoco Phillips Alaska would like to proceed with permanent plug and abandonment. Well Status: The well has a retrievable plug set and tested to 2500 psi at 6790’ rkb. The well was circulated to seawater with a diesel freeze protect in the tubing and IA. The gas lift valves are dummied oC. The OA has a cemented shoe; an MIT-OA to 1800 psi passed on 7/3/2024. The top perforated interval is 6896’ rkb, with the top injection mandrel at 6813’rkb (83’ above). The injection valves in the production interval are open. Reservoir injectivity is expected to be ~1 bpm at 1000 psi. The production packer is located at 6768’ rkb. MIT-IA failed in 2018, the production casing leak was identiHed with a liquid leak rate of 7.2 gpm at 2200 psi. The packer may not have integrity between the IA and the reservoir due to the production casing leak in the vicinity. The most recent tag is 6870’ rkb. Reservoir Information: - Reservoir pressure 9/28/1996: 4107 psi at 6200’ TVDSS/6900’ RKB. - Freshwater Zones: None - Hydrocarbon Bearing Zones: o Kuparuk: ~6896 to 7210’ rkb o West Sak: ~2620 to 3290’ rkb o Ugnu: ~1790 to 2370’ rkb Tubing Information: Program: Slickline – Plug Plug, ConHrm injectivity. 1. Pull plug. 2. ConHrm injectivity into reservoir. Coiled Tubing – Reservoir Plug and Lower Lateral Cement Plug. 1. Set cement retainer at ~6790’ rkb. 2. Establish injectivity through the retainer into the perforations. 3. Cement the perforations with 11 bbls of cement pumped through the cement retainer. String Top Bottom Size ID bbl/ft volume ft/bbl 3.5" Tubing 0 6982' 3.5", 9.3# 2.992" 0.0087 61.0 115.0 7" Inner Annulus 0 7358' 7", 26# 6.276"x3.5 0.0264 194.3 37.9 9-5/8" Outer Annulus 0 3150' 9-5/8", 36#8.921"x7" 0.0297 93.6 33.7 1/4" Control Line 0 1806' 1/4" 0.152" 0.0000224 0.0405 44642.9 a. If cement locks up before 11 bbls of cement is pumped through the retainer, build squeeze pressure to 2000 psi and unstring to lay in cement in tubing. 4. Perform clean out and leave TOC at ~6750’rkb. Slickline and Pumping: Test and Tag Reservoir Plug 1. Give AOGCC witness 24 hrs notice. 2. Drift and tag TOC. TOC is expected to be left at ~6750’ rkb. 3. MIT-T to 2500 psi with diesel. (also State-witnessed) Coiled Tubing – Intermediate Plug 1. Set cement retainer at ~6650’ rkb. 2. Circulate 128 bbls of cement into the IA to bring TOC to ~1850 ft RKB. 3. Lay in 42 bbls of cement into the tubing to bring TOC to ~1850 ft RBK. DHD: 1. Provide AOGCC 24 hrs notice for witness. 2. CMIT-TxIA to 2000 psi. Eline/Relay: 1. Provide AOGCC 24 hr notice for witness. 2. Tag TOC. Expected at ~1850 ft RKB. 3. Perforate at ~1750’ rkb to establish communication from the Tubing to IA and OA. 4. Cut tubing with jet cutter at ~1800’ rkb. DHD- Cement Control Line: 1. Attempt to cement control line if have injectivity. If not, proceed with surface plug. Pumping/Cementing – Surface Plug 1. Pump 77 bbls of cement down the tubing and up the OA: a. Check that clean cement is observed at surface from the OA. b. Pump an additional 10 bbls of cement. 2. Pump 55 bbls of cement down tubing taking returns up the IA: a. Check that clean cement is observed at surface from the IA. b. Pump an additional 10 bbls of cement. DHD: 1. Wait on cement 48 hours. 2. Cut oC the wellhead and all casing strings 4 ft below original ground level. 3. Inspect the cement job in the T/I/O. a. Perform a cement top job if needed to ensure cement is at surface on all strings. See contingent steps below. b. Take photos to document. 4. Notify the AOGCC of cement inspection (24 hrs notice required) prior to proceeding to welding. 5. Call AOGCC to witness cap welded label (24 hour notice required). 6. Weld a ¼” thick cover plate (16” OD) over all the casing strings with the following bead welded label. a. Conoco Phillips b. 2F-05 c. PTD#: 184-016 d. API#: 50-029-21073-00-00 7. Remove the cellar and backHll with gravel as needed to ground level. 8. Obtain site clearance approval from AOGCC. 9. Provide photo documentation to the engineer for preparation of the 10-407. Contingency Cement Top Job Procudure: 1. Using a 1” pipe into annulus down as far as required pump cement until returns are seen at surface. 2. Once the cement reaches compressive strength cut the pipe Oush with the casing cuts and continue with welding on marker plate. AOGCC witness after cutoff and before top job. Well Schematic – Current: Well Schematic: As Proposed (fit -�s IN-a/Ivo Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Saturday, October 01, 2016 5:45 PM 114` (��` To: Cook, Guy D (DOA) �� Cc: Regg, James B (DOA); NSK Fieldwide Operations Supt Subject: Emailing - 2F-05 Deficiency rpt complete 10-01-16.pdf Attachments: 2F-05 Deficiency rpt complete 10-01-16.pdf Guy- enclosed is an updated Deficiency Report for 2F-05. Included is a photo of the installed sign on the wellhouse. Darrell Humphrey/ Matt Raiche Production Engineering Specialist Conocophillips Alaska Inc. n1139( conocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 SGp► • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: teU F-6 - Date: 9/A0/4, PTD: f�D Operator: doo[o/A4/�,__s Type Inspection; 511,5 Operator Rep: /30 r 7. r i� eet 5 - Inspector: 6w7 /tO J�J, Position: pia. LS Op.Phone: 4 6-9-75-3S- Correct by(date); 9/ & Op.Email: Jf 1131 , un�oOl7 s(jr'ps . /-"o041Follow Up Req'd: I Detailed Description of Deficiencies Date Corrected 44c.,// SON; Pe-A,- 'fa AO ,9Ac 2.5, 0-4p 23=-05 u w Q Sc.qc.t V W_.1 Anic ttA41/-10.t b 9.3 U • 1 to SWAN gyrrsrA-C69 1-N N1gC["Z 35i►y5 NAa pier ung..g F_ os Wet.c.f3aua Sr.c.,1J N57".14.-E/). e-Triee • Signatures: ,51/5 rj5p`�� rP�' dp s/Y� Operator Rep y tJ AOGCC Inspector "After signing,a co olthis form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. include the'Date Corrected"and attach supporting documentation for each corrective action Implemented to address the deficiencies. if a follow- up inspection was performed by AQGCC,Include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by date must requested and accompanied by justification(Attention:Inspection Supervisor), Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and Is subject to enforcement action under 20 AAC 25,535 Revised 12/2015 ,•t.It.,:i,+!;"2,.C,".....'rik:'1f'.,.*,*.*„*--t'W1i.':•:2;'-„•J-•-.--,::-5-.*,.4!.Ar.4.l''1+"'70s,:'*:1.-,'I•'.',.14:,4!,',.,„2,',;;:!%1/,.'--..-.*.---,;-:::'0.-'.m'4,,11,'.1„4.-1„),4.t,:,,,.,!,,,,4:*,!-”t#,..:,2F‘,.,, ' .-il.-.:.1...t..„.-'r,*;i:- :,:,.„4.",1.i:ii',,41•:;1.3,',(4 ,.: ++'''r,.:;',,',„*..,,F1' ',•'2''''-,'•2'•,'.,.,,;+=,'„,-;=•v0:,a•,—,7, ',a..3.114f'.„:j.'.- i-I;rV::." .f'.t,.-: 1 :"T;' "*,t- "'0.*7*.,,*.*:;.,',.,'.',2*,.'„,..,,e-V, t`.` ,`::, �` „:,;s ',;:%:' It'ini< ,, y.i"w '♦ »"""�€ ,' "+ -,-',2,..A.-,t'i «, tilt, ,.'4:.i'',.,.':,s..I:'7,•:.9„i4.'.4*,'.i.,;.k-'-+,'.'4:..'a" .... .. 4 ,... .t ii: .. . : ; . ... 1p...,,,,, . ..,..4..,,t,r, 4i.:;,_:_..1„..,.. r ,a. , ,,,,,‘ar , '34.-...., .. ;; a r- •r..0.4a..,.. .„-a:: ..,,, , i- -,= „...=, ,, „ ,,,, -, -„ „.,;,,— .r= - . it a= -t;a:,/:, �” _?:, ",i. . �. `:a": ;_t<r Iiiir,''' ..t,. i.. j, 'dam '."' f. err ` ''''3141`, "*. it..,-., i **..„- .” '4, "*;* ; '• --f` rx `i= r'!✓ 7.=�ss*.', C..t = .. • +='fi «. x�^'ki'h .. y ....A.;•;•..`..-2-14:1' 1 CO . .*OcoPhillips -:.,.4-_,-,,,,- .. . .. ., e. ;; r `4444; 'a (- ", . W y. FWeli Name: K2F-05 - . r :7'. • '_ '` 2.s„..:;'' ' ,,, API Number: : OA*, f .M 7 . " y . ,.? , .. _, pro. I84-016 ':.'-,1,..,!,...,-!,,.-,.....4,,_;„; _- µ:1. ,: : : <' , rte'. :;, • - ., .�,`, .a '' r, : - Sur. Location: NL 590' --.:;:i-,:t� . .r:: :: .<�f .. HI,':;'::r'''' MI 4597' ! ■ J� if;,'.1,,.. x. s � r E� , Sec. 28, T1•tH,• r• ry w _:_":'':µ :» :, il,, 4474 33',',' t *..', -+,,, . Ilik f ' ..' . .,..... ,,, ,,:i:.., ;,_ ,,,,:_,,,itook.,. 1,.. . f,, '-.: . ,....,-.4 -...' I , • ., . ,,, Pf 1 1", ,...:*!‘444;14i.;;.„..:,,„-,..,:.0,,,..;,,,,,,,,,,, ::„.2;=.:1:.:4,54*,,:,,.. ,'2 ,4' 111 tt: Y. .. .. "9MiF".„ .':: «.<.. :'�Le'' .r r i•. t.M t3,,aa•,�•�' x57.» :y[,. .'£' •, t, k +-'• •- ', '''.,-, ,,,,,,, ,, ,.,,., 4 _ f, • •(• ' t„?..-v , ( v•f,•-•• '1', t • %••••44` • ' ' '• .:7:';1 'k-.;'.::',.., . -..• '..11 *:' ' • ' ., ': � '• :; s „ •165;, _ 4 4:AI' arc:,.t , .44.., „ •. $1104#r--=.1, -* A '‘ f, .„ . .. . ' ., . i'.. ..a.,i''.'&-.*,'', - fl • ....„:3',.% �` '�t�. .� �+M• a 'aa� `�-•.at:.M.�; „„;',:14....,., :7' •�; • i Vis.; _ fl�~ 6:. .s e , +• .*.r"._ 4 £„ayw <x's.�;;"1,..', s' _ .:.;:.,,,,,,„i.,_;.,.:::::;.,:: r.<",`v •-„Rr'£ + ' •10''• ,,'w>;..'�} '�' c: y, • %.••, _..,'.1 22.C;12,*_. i>' µ„•ng'.: "t'Y'€*,,,.*,.'�"�„. :;1 -,: s .*Iir +'3 i« ,- zy^.? ^'"y4 y. .:A ':;;''-''n< .,,',. .s,' ;°'Y` ' ..1.* ".4s� e< �y •-3 ,7 �: y 4._. 7, .3 ' ' ' • _ i~ • ,-F` r.-: ..,.,,,r,<_•: .....r3 ”«'”; s:. =x i, �,• ' moi.^r- .. *".,x Prt Regg, James B (DOA) t g4 ,« From: Cook, Guy D (DOA) Sent: Tuesday, September 20, 2016 6:36 PM 2e t , 'Z�(Ic To: NSK Prod Engr Specialist G t Cc: Regg,James B (DOA) Subject: 2F-05 Deficiency Report Attachments: 2F-05 Deficiency Report.pdf;IMG_0538.JPG Please see the attached Deficiency Report. When the deficiency is corrected, please send a picture of the well sign attached to the well to us. I have attached one picture of the well in question for your reference. If you have any questions please contact Jim Regg. Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Cook at 907-659-2714 or guy.cook@alaska.gov. 1 eit qV" State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: g gll F 6 5 Date: PTD: /;(e) - Operator: d/40(45/AG 111.7( Type Inspection: Operator Rep: Inspector: abk /30 12A,- e.14 5e4.-- Position: '? , prve_t- £ ier-e- 3pd /1 - Op. Phone: -75-3,5— Correct by(date): Op. Email: t , Follow Up Req'd: Lep . re-1 Detailed Description of Deficiencies Date Corrected P i y5k futi kie-1 1 5 I"- re_(-L.,— 11- 9OAA 5, a 4 5 Operator Rep V5 re-a. eiA sre , Signatures: / AOGCC Inspector *After signing,a co6(of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow- up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 • • Deficiency Report—KRU 2F-05 (PTD 1840160) Photos by AOGCC Inspector G. Cook 9/20/2016 Deficiency: Missing well sign { ra___ Eami-, , ,,- r _ _ AI! IMIIMMIMIIII FF ,,„.y. e4 .,,,, sad .-, i "'"r q :.,fir. , ,sr 4he' ,y-rv,, ,ra, . rte' .fs. - - •is s r u y.aS ;VC'.: tiA--.;%*; .' 1 4,�{ s , r ji't2 ✓i+.ks..,�C Wit;: ; - .+,x. ' .may G -4,..,---"Y .;R rw * . •,. I i•'..: a at,.r+«i .,;,,. .;i. _ a E;•'- '.' '-. <h.t ;11 • , . • ' `" -T' , w A o. .� a ' , w '- -4- * 'c. 2016-0920_Deficiency KRU_2F-05photo_gc.docx Page 1 of 1 Im : ~'~ ect.Well History File Cov_ ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file,. L Well .History File Identifier Organizing I~one! 1:3 Two-Sided [] Rescan Needed ' RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] ,Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~ OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [] Other BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation BY: BEVERLY BREN VINCENT BHERYL ~LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FLEE: "] '/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~.YES I$1 NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES __ NO . F~ESCANNEDBY: BEVERLY BREN VINCENT SHEEYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (None) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend_ Operation Shutdown Alter casing _ Repair well_ Plugging _~_ Change approved program _ Pull tubing _ Variance _ Re-enter suspended well Time extension Stimulate _ Perforate _ Other _Z_Plugback for Redrill 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1482' FNL, 1318' FEL, Sec 28, T11N, RgE, UM At effective depth 1281' FNL, 1275' FEL, Sec. 28, T11N, RgE, UM At total depth 1227' FNL, 1264' FEL, Sec. 28, T11N, RgE, UM 12. Present well condition summary Total Depth: measured (approx) true vertical 7380' feet Plugs (measured) 6283' feet 6. Datum elevation (DF or KB) RKB 127'. Pad 98' GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-05 9. Permit number 84-16 10. APl number 50-029-21073. 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 7276' feet Junk (measured) 61 95' feet None 13. Casing Length Structural 8 0' Conductor Surface 31 21' Intermediate Production 73 2 9' Liner Perforation depth: measured 6896'-6914', Size Cemented 1 6' 175 Sx ASI Measured depth True vertical depth 109' 109' 9-5/8' 850 sx ASIII 650 sx Class G 7' 280 sx Class G 250 sx ASI 3150' 2852' 7358' 6265' 7000'-7011', 7026'-7040', 7102'-7108' MD RECEIVED true vertical 5877'-5892', 5963'-5973', Tubing (size, grade, and measured depth) 3-1/2', 9.3#, J-55, @ 6981' MD Packers and SSSV (type and measured depth) Baker 80/40 @ 6788'r BAKER HB @ 6768'r FB-1 PERM @ 6953'~ CAMCO TRDP-1AENC SSSV @ 1806' Attachments Description summary of proposal ~ Detailed operation program BOP sketch 5985'-5997', 6049'-6053' TVD MAY 30 1995 Alaska 0il & Gas Cons, Commission Anchora.~ 14. Estimated date for commencing operation 115. Status of well classification as: 6/6/95 I Oil X Gas __ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereb,y~ce~tha~the foregoing is true and correct to the best of my knowledge. Si~lned ~,1"~ ./"~./-'-~ Title Kuparuk Development Supervisor . FOR COMMISSION USE ONLY Suspended Conditions of approval: Noti.fy Commission so representative may witness Plug integrity~ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require ,.,~',~mai Signed By Approved b~/ the order of the Commission David W. Johnston 10- ~ e~ap-oved Copy Returned IApproval No~,~_ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KRU 2F-05 SUNDRY OBJECTIVE to P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) NOTE - CURRENT WELL STATUS: There is collapsed casing across the A Sand perfs. The wellbore below the bottom packer has been plugged off with sand and clay. The A Sand will not flow and recent attempts to inject into the A Sand were unsuccessful. The C Sand is capable of being injected into. PRE-RIG WORK: 1. Dummy off all GLMs, leave deepest GLM open. Pull dummy valves from all C Sand mandrels. 2. Set BPV in tubing. Install VR plug in annulus valve if necessary. WQRKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-fine to tree. Pull BPV and VR plug. 2. Load pits w/kill weight brine (expected kill wt = 10.4 ppg). Circulate well to kill weight brine. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/tubing, inspect for corrosion, and change out seal rings. Stand back tubing and LD all jewelry. . PU DP and RIH with cement retainer. Set retainer at 6205'. Pump cement squeeze below retainer into C Sand perfs filling 7" casing to top of bottom packer. Unsting from retainer and spot 3 bbl cement plug on top of retainer. Circulate well to milling fluid. POOH standing back DP. 6. RIH w/section mill. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in the 7" casing from 6005' - 6055'. POOH w/mill. . RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. WSI 3/25/95 Sas G0na. 00mmissi0n gnch0ra,~? 2F-05 Proposed Plugback APl #: 50-029-21073 RKB = 127' G L = 98' 9-5/8" 36#, J-55 set @ 3150' MD Cement Kick-off plug 5805' - 6155' MD: 17.0 ppg 7" Casing section milled 6005' - 6055' MD 18.0 ppg Mud from 6155' - 6205' MD: 17.0 ppg 7" Baker 'K-I' Cement Retainer @ +/- 6205' MD with cement squeezed below retainer down to bottom packer. 3-1/2" x 7" Baker 'HB' Retrievable production packer w/PBR bbl @ 6755' MD. Abandoned C Sand Perfs Abandoned A Sand Perfs 7", 26#, K-55 Top pedoration @6896' MD Bottom perforation @ 6914' MD RECEIVED MAY 30 1995 3-1/2" x 7" Baker 'FB-I' Permanent packer @ 6953' MD. A~aska 0ii & Gas Cons, C0mliliSSJ01~ Anch0ra.je A Sand Perfs isolated by collapsed casing @ 7030' MD and plugged off w/sand and clay. A Sand will not flow and attempts to inject into A Sand were unsuccessful. Top perforation @6988' MD Bottom pedoration @ 7108' MD PBTD =7276' MD TD = 7380' MD WSl 5/25/95 STATE OF ALASKA ALASKA OIL AND G/~ CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator Operation Shutdown Plugging __ Perforate _ Pull tubing X __ Other __ 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Alter casing __ Repair well 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 683' FSL, 1590' FEL, SE 28, T11N, RgE, UM At top of productive interval 1482' FNL, 1318 FEL, SEC 28, T11N, R9E, UM At effective depth 1281' FNL, 1275 FEL, SEC 28, T11N, RgE, UM At total depth 1227' FNL, 1264' FEL, SEC 28, T11N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical 7380' 6283' feet feet Plugs (measured) RKB 127'. GL 98' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-5 9. Permit number/approval number 84-1 6 10. APl number 50-029-21073 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 2 7 6' true vertical 61 95' feet feet Junk (measured) Casing Length Structural 8 0' Conductor Surface 31 21' Intermediate Production 73 2 9' Liner Perforation depth: measured 6896'-6914', true vertical 5877'-5892', Size Cemented 1 6" 175 sx CS I 9-5/8" 850 sx AS III 650 sx Class G 7" 280 sx Class G 250 sx ASl Measured depth 109' md True vertical depth 109' tvd 3150' md 2852' 7358' md 6265' 7000'-7011', 7026'-7040', 7102'-7108' md 5963'-5973, 5985'-5997, 6049'-6053' tvd Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 , @ 6981' MD Packers and SSSV (type and measured depth) BAKER 80/40 @ 6788', BAKER HB @ 6768', FB-1 PERM @ 6953', CAMCO TRDP-1AENC SSSV @ 1806' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil ~ Gas Suspended Service 17. I h__ereby cert~e foregoing is true and correct to the best of my knowledge. Signed ~ ~/~ /'~ '~'' ~ Title Area Drillin~ Engineer --orm 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS WELL: 2F-05 PAGE: 1 BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD LEASE: ADL 25657 ALK 2583 API: 50-029-21073 PERMIT 84-16 APPROVAL: AFE: AK5415 WI: 55.252072 ACCEPT: 11/26/90 RELEASE: 12/15/90 SPUD: OPERATION: WORKOVER RIG: NORDIC 1 11/27/90 ( 1) TD: 0 PB: 7276 SUPV:GB 11/28/90 (2) TD: 0 PB: 7276 SUPV:GB 11/29/90 (3) TD: 0 PB: 7276 SUPV:GB 11/30/90 (4) TD: 0 PB: 7276 SUPV:DB POH WITH 3-1/2" TUBING MW:ll.0 NaCl/Br MOVE RIG TO 2F PAD, TRANSFER SEAWATER TO TANKS, THAW ICE PLUG OUT OF FLOW LINE KILL WELL, SET BPV, ND XMAS TREE, NU BOPE, TEST BOPE TO 3500 PSI, SLIP AND CUT DRILLING LINE, BOLDS, PULL TBG HNGR, PULL TUBING, STRAP AND DRIFT TBG WHILE POH DAILY:S44,210 CUM:$44,210 ETD:S44,210 EFC:$1,000,000 PREP TO LOAD PIPE SHED W/ DP MW:ll.0 NaCl/Br MIX AND PUMP DRY JOB, CONT POH W/ TBG AND CHANGE COUPLINGS TO AB-MOD, LAY DOWN SSSV, PU HOWCO STORM PACKER ON TBG AND RIH TO 60', TEST TO 500 PSI, ND BOP, ND FMC GEN II 3000 PSI TUBING HEAD, NU FMC GEN II 5000 PSI RETROFIT TUBING HEAD, NU BOP, PULL HOWCO STORM PACKER, CONT POH W/ TUBING, RECOVER BAKER PBR SEAL ASSY, REMOVE 8RD COUPLINGS FROM RIG FLOOR DAILY:S36,843 CUM:$81,053 ETD:S81,053 EFC:$1,000,000 PUMP SLUG, PREP TO POH W/PKR MW:ll.2 NaCl/Br SERVICE RIG, CROWN, BLOCKS, CHECK CROWN-O-MATIC, MU FTA #1 W/BAKER PKR RETR TOOL, RIH, PU & SERVICE KELLY, BREAK CIRC, TAG & LATCH ONTO PBR @ 6775', ROTATE & RELEASE PKR, WAIT FOR PKR TO FREE, ATTEMPT TO CIRC, CAN'T CIRC, PU BREAK OFF KELLY BLOW DOWN, MU CIRC HEAD AND REV CIRC, CAN'T CIRC, DROP BAR BALL TO OPEN PUMP OUT SUB, PRESS ON DP & OPEN PUMP OUT SUB @ 1500 PSI, CBU THRU CHOKE, RETURNS CUT TO 10.7 PPG, MONITOR WELL, FLOWING SLOWLY ON DP & ANN, WELL APPEARS TO BE GIVING WATER, SHUT IN WELL & WEIGHT UP PITS TO 11.2 PPG, SIDP=50 PSI, SICP=O PSI, CIRC 170 BBL 11.2 PPG, SHUT IN & WEIGHT UP FLUID FROM HOLE TO 11.2 PPG, CIRC 11.2 AROUNG, MONITOR WELL, STABLE, POH LD 1 SNGL-WET, NOT SWABBING, MIX & PUMP 25 BBL DRY JOB DAILY:S45,970 CUM:$127,023 ETD:S127,023 EFC:$1,000,000 WEIGHT UP TO 12.7 PPG MW:12.7 NaC1/Br FINISH MIXING & PUMP DRY JOB, SERVICE RIG, POH 18 STDS, WELL FLOWING, SHUT IN WELL, SIDP=1000PSI, WEIGHT UP TO 11.2 PPG, ATTEMPT TO BULLHEAD INTO WELL, NO INJECTION, CIRC 11.2 AROUND HOLDING 400PSI ON CHOKE, WEIGHT UP RETURNS TO 11.5 SIDP=SICP=400PSI, BLEED OFF PRESS & OBSERVE WELL, SLOW FLOW, RIH 20 STDS, 15 BBL GAIN, SHUT IN'WELL, WEIGHT UP PITS TO 11.5, CIRC AROUND HOLDING CHOKE @ 500 PSI, RETURNS GAS & WATER CUT, SHUT IN & MONITOR, 30 MIN BUILD TO 315 PSI, WEIGHT UP THIKSAL TO 12.7 PPG, CIRC 140 BBLS 12.7 HOLDING 300 PSI ON CHOKE, SHUT DOWN TO WEIGHT UP RETURNS, 12 BBL GAIN, SIDP=0, SICP=100PSI @ 03:00, WEIGHT UP PITS TO 12.7PPG SIDP=0, SICP=125 PSI @ 06:00, FIELDWIDE WATERFLOOD FROM STP RESUMED 36 HRS AGO, MANY WELLS SHUT IN DUE TO PIPELINE SLOWDOWN DAILY:S69,299 CUM:$196,322 ETD:S196,322 EFC:$1,000,000 WELL: 2F-05 OPERATION: WORKOVER RIG: NORDIC 12/01/90 (5) TD: 0 PB: 7276 SUPV:DB 12/02/90 (6) TD: 0 PB: 7276 SUPV:DB 12/03/90 (7) TD: 0 PB: 7276 SUPV:DB 12/04/90 (8) TD: 0 PB: 7276 SUPV:DB 12/05/90 (9) TD: 0 PB: 7276 SUPV:DB CIRC 12.9 PPG MW:12.9 NaCl/Br WEIGHT UP PITS TO 12.7 PPG, SIDP=0, SICP=120PSI,FINISH CIRC 12.7 PPG, NO GAIN OR LOSS, NO FLOW, WELL DEAD, MIX & PUMP 20 BBL DRY JOB & WEIGHT UP PITS TO 12.7 PPG, POOH SLOW, MONITOR WELL, LD PUMP OUT SUB, LD PBR, FHL PKR & TAILPIPE TAIL CLEAR NOT PLUGGED, MU 6-1/8" BIT & BITSUB ON BUMPER SUB & JARS, RESET WEAR BUSHING, RIH TAG FILL @ 6894', 15 BBL ON TRIP IN, VERY SLOW FLOW, WEIGHT UP PITS TO 12.9 PPG, SIDP=50PSI, SICP=75PSI, CIRC 135 BBLS INTO WELL HOLDING 100PSI ON CHOKE, WEIGHT UP RETURNS TO 12.9 PPG & MONITOR WELL, SIDP=0,SICP=50 CONT CIRC. DAILY:S103,349 CUM:$299,671 ETD:S299,671 EFC:$1,000,000 MILL ON FILL @ 7050 MW:12.9 NaCl/Br FINISH CIRC 12.9 PPG 3 BPM 1100 PSI, WEIGHT UP RETURNS TO 12.9 PPG, WELL WELL STABLE, KELLY UP, TAG FILL @ 6894', CLEAN OUT & DRILL UP JUNK TO 7020', DRILLED 15 MIN & LOST RETURNS, CAN'T SEE FLUID LEVEL IN STACK, CLOSED ANNULAR & LINED UP ON CHOKE & FILLED HOLE, GOT RETURNS BACK, HOLE TOOK 28 BBL LOSS, HAVE FULL RETURNS, CONT DRILLING ON JUNK @ 7020 NO PROGRESS, CBU @ 3.5 BPM 1500 PSI, BLOW DOWN & STAND BACK KELLY, SLIP & CUT DRLG LINE, POH W/BIT#l, MU TRISTATE 6" MILL+2 JB+BS+BUMPER+OIL JAR, RIH, BREAK CIRC, MILL UP JUNK @ 7020' & CONTINUE CLEANING OUT TO 7050, VERY LITTLE PROGRESS, PREPARE TO TRIP OUT WITH MILL. DAILY:S47,112 CUM:$346,783 ETD:S346,783 EFC:$1,000,000 MILLING @ 7052' MW:12.9 NaCl/Br RIG SERVICE, FUNCTION BOP, CHECK CROWN-O-MATIC, BLOW DOWN & STAND BACK KELLY, POH LD MILL, RECOVER CUP OF METAL & ROCKS, WEIGHT UP 80 BBLS TO 12.9 PPG, MU 6" MILL+REV CIRC JET BSKT TAG TIGHT @ 7018', MILL TO 7024', TORQUE & STALLS ON LAST 2', TRY SEVERAL TIMES, SAME RESULTS, BLOW DOWN & STAND BACK KELLY, POH LD, NO RECOVERY, MOST FINGERS GONE FROM CATCHER, RECOVER 2/3 CUP OF METAL PEICES, SAND & GRAVEL FROM BOOT BSKT, MU 6" BLADED JUNK MILL & JUNK BASKET, TAG UP @ 7027', MU & SERVICE KELLY, SERVICE ROTARTY TABLE, MILL & REAM FROM 7027' TO 7052', NO PROGRESS BELOW 7052' IN LAST 1.5 HRS, PREP TO CBU & POH DAILY:S28,147 CUM:$374,930 ETD:S374,930 EFC:$1,000,000 RIH W/ 5.5" OD MILL MW:12.9 NaCl/Br SERVICE RIG, CIRC ONCE AROUND, SLIP AND CUT DRILLING LINE, POH W/ BHA #4, RECOVER CUP OF METAL PIECES, SAND, AND SEVERAL FINGERS FROM JUNK BASKET, MU 5-3/4" OD LIB, RIH, TOOK 5K# THRU TIGHT SPOT AT 7027', TAG BOTTOM AT 7051', SET DOWN 15K#, POH W/ BHA #5, LIB HAD FEW MARKS ON FACE, 1 SMALL PIECE METAL STUCK IN FACE, SIDES OF BLOCK SCRAPED AND GOUGED LOOKS LIKE PINCHED IN CASING TEST BOPE, MU 5-1/2" MILL, RIH DAILY:S41,424 CUM:$416,354 ETD:S416,354 EFC:$1,000,000 RIH W/ 5-1/2" MILL MW:13.0 NaCl/Br SERVICE RIG, TEST BOPE, FINISH RIH W/ 5.5" MILL AND BHA #6, SET DOWN TIGHT SPOT WITH 4K# AT 7020' AND GO THRU, TAG BTM AT 7051', MILL ON JUNK/FILL TO 7102', PUMP DRY JOB, POH W/ BHA #6 TO CHECK MILL, MILL IN GOOD SHAPE, LD 12 JTS 3-1/2" DP, LOAD 12 - 4-3/4" DC IN SHED, STRAP DCS, MU NEW 5-1/2" MILL, RIH ON BHA #7 ON 3-1/2" DP DAILY:S31,638 CUM:$447,992 ETD:S447,992 EFC:$1,000,00 PAGE: 2 WELL: 2F-05 OPERATION: WORKOVER RIG: NORDIC 12/06/90 (10) TD: 0 PB: 7276 SUPV:DB RIH W/6" TAPERED MILL MW:13.0 NaCl/Br SERVICE RIG, FUNCTION BOPE, CHECK CROWN-O-MATIC, CONT RIH W/BHA#7, MU KELLY TOOK 5K# THRU TIGHT SPOT @ 7027', TAG BOTTOM @ 7095', WASH & REAM TO 7102', PACKED OFF & PUMPED AWAY 22 BBLS INITIALLY, MILL OUT FILL TO 7226', TORQUED UP ON JUNK @ 7130' & 7216', SLOW PROGRESS FROM 7216' TO 7226', 10' IN 3 HRS, CBU, PUMP SLUG, BLOW DOWN & STAND BACK KELLY, POH W/BHA#7, MILL IN GUAGE, TIPS WORN DOWN 1/4" TO 1/2", CENTER WORN DOWN, PEICES OF METAL IN BOOT BASKET, 3 OF 6 JETS PLUGGED, MU BHS W/6" TAPERED MILL+2 BOOT BSKETS+BS+BUMPER+JAR, RIH DAILY:S30,498 CUM:$478,490 ETD:S478,490 EFC:$1,000,000 PAGE: 3 12/07/90 (11) TD: 0 ?B: 7276 SUPV:DB PREP TO RU HLS MW:12.9 NaCl/Br RIH W/ 4-3/4" DC AND 1 STD 3-1/2" DP, SERVICE RIG AND TEST BOPE, CUT 50' OF DRILLING LINE, FINISH RIH WITH 6" TAPERED MILL AND BHA #8, KELLY UP AND REAM W/ 6" MILL FROM 6776'-7020' (NO TIGHT SPOTS), REAM THRU 7020' W/ 10K# ON FIRST PASS, REAM THRU 3 TIMES UNTIL SMOOTH, CONT REAMING OFF STICKY BUILDUP TO 7226, CIRC HOLE CLEAN, MIX AND PUMP DRY JOB, BLOW DOWN AND STAND BACK KELLY, RU DP SPINNERS, POH W/ BHA #8, LD DCS AND 6" TAPERED MILLAND JUNK BASKETS, MILL IN GAUGE AND GOOD CONDITO , DAILY:S84,519 CUM:$563,009 ETD:S563,009 EFC:$1,000,000 12/08/90 (12) TD: 0 PB: 7276 SUPV:DB STRAP 6-1/8" STRING MILL MW:12.9 THXL ND FLOW NIPPLE, RU HLS E-LINE UNIT, PREPARE TO RUN BOREHOLE TELEVIEWER LOG, HYDRAULICS FROZE FOR SPOOLING ARM, MU TOOL, TOOL WON'T TALK TO SURFACE GEAR, TO COLD, RUN IN HOLE TO WARM UP, HEATING UP LOGGING UNIT, RIH TO BHT LOG, TAGGED UP AT 7029', LOG UP TO 6750' FOR FIRST PASS, DROP BACK DOWN AND TAG UP AT SAME SPOT, LOG UP TO 6700', TOOL STOPPED SPINNING IN TWO SPOTS, LOG SHOWS 'C' SAND PERFS AND UPPER 'A' SAND PERFS, LOG SHOWS OLD PACKER SET AREA, RESULTS FROM ANY CASING DAMAGE QUESTIONALBLE, POH, TOOLS CLEAN WHEN OUT OF HOLE, RD HLS E-LINE, NU FLOW NIPPLE, STRAP AND CALIPER 6-1/8" STRING MILL DAILY:S54,387 CUM:$646,229 ETD:S646,229 EFC:$1,000,00 12/09/90 (13) TD: 0 PB: 7276 SUPV:DB REAMING AT 7180' W/ MILL MW:12.9 THXL STRAP AND CALIPER 6-1/8" MILL, SERVICE RIG, MU BHA #9: 5-1/2" MILL+XO+2 BOOT BASKETS+BS+6-1/8" STRING MILL+BUMPER SUB+OIL JARS ON 4-3/4" DC, RIH, REAM DOWN FROM 6887' TO 7226', SAW TIGHT SPOTS AT 6887' & 7029' & 7103' & 7153', REAMED THRU TIGHT SPOTS, GOT CUP OF METAL OFF DITCH MAGNETS, CIRC ONCE AROUND, SANDY JUNK OVER SHAKERS, PUMP DRY JOB, BLOW DOWN AND STAND BACK KELLY, POH W/ BHA #9, RIH W/ BHA #10, PU AND SERVICE KELLY, REAM FROM 6800' TO 7026', TOOK A LITTLE WEIGHT AT TOP OF 'C" PERFS, WORKED SCRAPER TO 7026', COULD NOT ROTATE THRU BUT WORKS THRU FREELY, CONT REAMING TO BTM AT 7180' DAILY:S54,387 CUM:$646,229 ETD:S646,229 EFC:$1,000,000 WELL: 2F-05 OPERATION: WORKOVER RIG: NORDIC PAGE: 4 12/10/90 (14) TD: 0 PB: 7276 SUPV:DB 12/11/90 (15) TD: 0 PB: 7276 SUPV:DB 12/12/90 (16) TD: 0 PB: 7276 SUPV:DB 12/13/90 (17) TD: 0 PB: 7276 SUPV:DB 12/14/90 (18) TD: 0 PB: 7276 SUPV:GB MU 5-1/2" MILL MW:12.9 THXL CONT REAMING FROM 7180' TO 7226', SERVICE RIG, CIRC ONCE AROUND, PUMP SLUG, BLOW DOWN & STAND BACK KELLY, POH W/BHA #10., LD SCRAPPER & MILL, 2-1/2 CUPS METAL & SHALE IN JUNK BSKTS, 1 CHUNK METAL LOOKS LIKE CSG, ONE OF 3 LOWER BLADE BLOCKS ON SCRAPER DAMAGE FROM SIDE FORCE, RU HLS, RIH W/CAST TOOL, LOG F/7200'-6700', LOG QC LOWER THAN YESTERDAY, NOT AS WELL CENTRALIZED, POH CHANGE RIGID CENT TO FLEXIBLE CENT, RIH LOG F/7220'-6880', LOG QUALITY BETTER BUT RESULTS STILL NOT DEFINITE, POH, REVIEW & DISCUSS LOG WITH OPS ENGR, LOG HAS SOME DEFINITION ABOVE BAD SPOT @ 7026' BUT LITTLE OR NO DEFINITION BELOW BAD SPOT @ 7026' RD HLS, RU FLOW NIPPLE, MU 5-1/2" MILL+2 BOOT BSKT+BS+6-1~8" STRING MILL DAILY:S32,966 CUM:$679,195 ETD:S679,195 EFC:$1,000,000 POH W/ 6" GAUGE RING MW:12.8 THXL SERVICE RIG, RIH W/ BHA #11, RD SPINNER, MU KELLY AND BREAK CIRC,- REAM FROM 6900'-7226', CIRC BTMS UP, RU TO LDDP, PUMP DRY JOB, PU ON DP, STUCK 18' OFF BTM, STUCK ABOVE JARS, WORK STUCK PIPE, SLIP AND CUT DRILLING LINE, RESUME WORKING STUCK PIPE, PIPE PULLED FREE AT 280K#, POH AND LD DP, ND FLOW NIPPLE, RD SPINNERS AND LD LINE, RU HLS E-LINE, MU LUBRICATOR, RIH W/ 6" GAUGE RING AND JUNK BASKET TO 6995' WLM (OK), POH W/ GAUGE RING AND JUNK BASKET DAILY:S33,742 CUM:$712,937 ETD:S712,937 EFC:$1,000,000 RIH W/ 6-1/8" BIT AND MILL MW:12.8 THXL FINISH POH W/ 6" GR/JB, HAD RUN TO 7012' WLM, MU BAKER FB-1 PACKER AND TAIL ASSY, RIH ON WIRELINE, TAG UP AT 6890', UNABLE TO GO DEEPER, PACKER STARTING TO GET STICKY, POH, MU 6.094" GR/JB, RIH, WORK BETWEEN 6800'-6996' WLM, PULLED TIGHT A COUPLE OF TIMES AT 6892' CCL DEPTH, RAN FREELY LAST 6 TO 8 PASSES, POH, MU PACKER AND TAIL ASSY, RIH, TAGS UP AGAIN AT 6890' WLM, TRIED TO WORK DOWN BUT NO GO, POH, RD HLS E-LINE UNIT, LOAD DP IN PIPE SHED, MU 6-1/8" BIT ASSY, RIH DAILY:S42,937 CUM:$755,874 ETD:S755,874 EFC:$1,000,000 TIH W/ FB-1 PAKCER ON DP MW:12.8 THXL FINISH TIH & PU KELLY, WASH 6830'-6910', BAD CSG AT 6910', UNABLE TO WASH DEEPER, WORK BIT THRU TIGHT SPOT W/ ST AND ROTATION, PU TO 6900', TIGHT SPOT STILL PRESENT, WORK BIT AND STRING MILL THRU TIHGT SPOT 3 TIMES, STILL TIGHT, POH, BREAK OFF BIT, MU TAPERED 6-1/8" MILL AND STING MILL AND RIH TO TO 6910', MILL THRU TIGHT SPOT AT 6910', ROTATE/MILL THRU TIGHT SPOT 25 TIMES, WASH FROM 6910' TO 6997' W/ MILLS, PUMP DRY JOB, SET BACK/BLOW DOWN KELLY, POH AND LAY DOWN BHA, PU BAKER FB-1 PERM PACKER W/ TAIL ASSY ON DP AND RIH W/ SAME DAILY:S56,840 CUM:$812,714 ETD:S812,714 EFC:$1,000,000 LAYING DOWN DP MW:12.8 THXL FINISH TIH W/ BAKER FB-1 PERM PKR ON DP, RU HLS E-LINE AND RIH W/ GAMMA RAY AND NEUTRON AND CCL TO 6900', CCL MALFUNCTIONED, POH, CHANGE OUT CCL TOOL, RIH W/ SAME TO 7002', CORRELATE DEPTH TO DIL LOG, POH W/ E-LINE TOOLS, POSITION PACKER AT 6948', RIH W E-LINE TOOLS TO CHECK, POH W/ E-LINE, DROP PKR SETTING BALL, RD HLS E-LINE, PRES DP TO 3000 PSI .TO SET PKR, PKR NOT SET, SIRGE RELEASE PRESS AND RE-PRES DP AND SET PKR AT 6948' WLM, PRES TO 3000 PSI AND PU TO SHEAR OFF SETTING TOOL FOR PKR, SETTING TOOL PARTIALLY PLUGGED, POH, LAY DOWN DP USING MUD BUCKET, KEEPING CELLAR PUMPED OUT AND UNLOADING DP FROM PIPE SHED DAILY:S31,668 CUM:$844,382 ETD:S844,382 EFC:$1,000,000 ~11' 2F-05 OPERATION: WORKOVER RIG: NORDIC Page 5 12/15/90 (19) TD: 0 PB: 7276 SUPV:GB ND BOPE MW:12.8 THXL FINISH LD DP, KD KELLY & SWIVEL, RU TO RUN TBG, RUN 3-1/2" COMP STRING, CBU EVERY !500', PU SSSV & TEST, BREAK CIRC @ FB-1 PKR @ 6948'ELM, STAB INTO PERM PKR, SPACE OUT MU TBG HGR, TEST C-LINE, RESTAB INTO PKR & LAND TBG, DROP BALL, PRESS UP & SET PKR, SHEAR PBR, TEST SSSV F/15 MIN, TEST TBG W/2500 PSI F/15 MN SHEAR BAKER SOS W/3700 PSI, LD LNDG JT, SET BPV, ND BOPE & CLEAN MUD PITS. DAILY:S168,105 CUM:$1,012,487 ETD:S1,012,487 EFC:$1,000,00 12/16/90 (20) TD: 0 PB: 7276 SUPV:GB RIG RELEASE MW: 0.0 Diesel FINISH ND BOPE, NU TREE, CLEAN PITS, TEST PO & FLANGE TO 5000 PSI, PULL BPV, SET TP, TEST TREE TO 250/5000 PSI, OPEN SSSV, RU TO DISP WELL TO DIESEL @ 1BPM @ 2500 PSI THRU GLM, SECURE WELL RIG RELEASE 18:00 12/15/90 DAILY:S232,466 CUM:$1,244,953 ETD:S1,244,953 EFC:$1,000,000 ARCO AI~,~. Inc. Date: February 22, 1991 Transmittal#: 8019 RETURNTO: ARCO Alaska, Inc. ATTN: Marla Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted-here with are the following items. . signed copy~ of this transmittal. ,/2F-0S ,/ 2F-0S V/ 2F-05 :. Receipt 'Circumferential Acoustic _ Scanning Tool Pass #3 With 6O SPF Circumferential Acoustic Scanning Tool Circumferential Acoustic Scanning Tool 120"/Hundred Please acknowledge receipt and return one Acknowledge: 12-9-90 6880-7221 12-7-91 12-9-91 Date' · . 6700-7029 5700-9200 Drilling State of Alaska TO: THRU: MEMO R~~oq~ Lonnie C. Smi~i ~ C ommis s loner o~s c o~ ~,~ ~, ~v,, ~ ~ot~e, $ ~°~ ?laska DATE: FILE NO: December 20, 1990 JT.RH.1220.7 TELEPHONE NO: SUBJE~T: szo/sor~, i~r~n Kuparuk rv .'?~f z~e~i-dJ FROM: Harold R. Hawkins Petroleum Inspector ~onday Dec. 12, 1990: I went to AAI KRU CPF 2F-5 where Nordic rig no. i was doing a workoVer. The Nordic rig checked out o.k. except the biowdown lines running from the choke manifold to tanks outside of rig still has not changed connections from knock on union to unibolts yet. Don Breedon said it would be 2 to 3 weeks yet before new blowdown lines could be built. They are building 2 blowdown lines with unibolts and 18.5 lbs dOuble extra heavy pipes. The last bop test performed was on 12/3/90. In summary: In 2 to 3 weeks, the blowdown system should be up to our regulations. 02-00LA (Rev. 6/89) 20/11/MEMO1.PM3 · '~'-"~ STATE OFAI.ASKA 0 i!~ I G I~/~ ~. ALA,.,,A OIL AND GAS CONSERVATION COMMIS,51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1482' FNL, 1318' FEL, Sec. 28, T11N, R9E, UM At effective depth 1281' FNL, 1275' FEL, Sec.28, T11N, R9E, UM At total depth 1227' FNL, 1264' FEL, Sec. 28, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB 127 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-05 9. Permit number 84-16 10. APl number so-029-1 7300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7 3 8 0' feet true vertical 6 2 8 3' feet measured 7 2 7 6' feet true vertical 61 9 5' feet Length Size 109' 16" 31 50' 9 5/8" 7385' 7" measured 6896'-6914', true vertical 5877'-5892', 7000'7011', 5963'-5973', Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3#/ft., EUE, 6823' Packers and SSSV (type and measured depth) Packer: Baker FHL 6792', SSSV: Baker FVL 1839' Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 175 Sx CS II 1 09' 109' 850 Sx AS III & 31 50' 2852' 650 Sx Class G 280 Sx Class G 7 3 8 5' 6 2 6 5' 250 Sx AS I 7026'-7040', 5985'-5997', 13. Attachments Description summary of proposal _ Hydraulically fracture stimulate the A & C Sand w/21,400# Detailed operation program X.~ BOP sketch _ of 16/20 & 12/18 Carbo-Lite & 2750 bbls ~lelled water. 14. Estimated date for commencing operation September 1. 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service that the foregoing is true and correct to the best of my knowledge. ~), ~'tJ~---~ Title Senior Operations Engineer FOR ~MISSION USE ONLY Date Conditions of approval: Plug integrity m Mechanical Integrity Test Notify Commission so representative may witness BOP Test Location clearance m Subsequent form Approved Copy Retumea Approved b), order of the Commission Form 10-403 Rev 09/12/90 require 10- Commissioner SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY LONNIE C. SMITH Kuparuk Well 2F-05 'A' & 'C' Sand Re-Fracture Treatment Schedule nf Events 1. Prefrac Slickline Work. a) Tag fill and locate end of tubing. If fill is above bottom perf, please contact Operations Engineering. b ) Set SV in Camco 'D' nipple. c) Pull GLV's at 1919', 3961', 5557', and 6741' and run DVs. NOTE: OV at 6741' is L. Wade valve. d) Pressure test tubing to 4500 psi to ensure DVs are set. Pull SV. 2. Refracture Stimulation. 1 a) Install Tree Saver and pressure test equipment. b) Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Ute for fines due to excessive handling. Obtain a sample of the Carbo-Ute and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. c) Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 4200 psig FraCture Gradient = 0.82 psi/fl (5965' TVD) Tubing Friction = 285 psi/1000 ft (6823' MD) @25 BPM * If treating pressure during the Job exceeds 5500 psi, reduce rate to a minimum of 15 BPM. If pressure exceeds 6500 psi, shut down job and confer with Engineering. Follow attached flowback schedule procedures, entering welltests into KDGS at regular intervals. STAGE 1 2 3 4 5 6 7 8 9 10 KUPARUK WELL 2F-05 'A' & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 8121190 FLUID D;sc~PTION CLEAN VOWME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT BBLS Bi:WI PPG DESCRIPTION LBS DIR3Y VOLUME STG/CUM GW PRE-PAD 175.0 2 5 0 .............................................. - SHUT DOWN FOR GW PAD 1900.0 2 5 0 GW wi2 PPG 114.9 2 5 2 GW wi4 'PPG 123.3 2 5 4 GW wi6 PPG 130.5 2 5 6 GW w/7 PPG 133.7 2 5 7 GW w/8 PPG 136.8 2 5 8 GW wi10 PPG 86.8 2'5 10 GW w112 PPG 58.9 2 5 12 SLICK D!.ESEL FLUSH.. 60.0 +SV ,,, 2 5 , . .0 ,, TOTAL GELLED WATER = 2744.1 BBLS TOTAL MUSOL = 0.0 BBLS TOTAL DIESEL = 115.7 BBLS TOTAL SLICK DIESEL = 60.0 BBLS +SV Stage I is Gelled Water. ISIP 0 1751 175 16/20 M CARBO-LITE 0 19001 2075 16/20 M CARBO-LITE 9649 1251 2200 16/20 M CARBO-LITE 20709 145'1 2345 16/20 M CARBO-LITE 32884 1651 2510 16/20 M CARBO-LITE 39320 1751 2685 16/20 M CARBO-LITE 45957 1851 2870 16/20 M CARBO-LITE 36440 1251 2995 12/18 M CARBO-LITE 29669 901 3085 . - 0 60/3145 16120 M CARBO-LITE = 184959 LBS 12/18 M CARBO-LITE = 29669 LBS TOTALPROPPANT- 214628 LBS Stage 2 is Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a no more than a 6 hour break. Stages 3 through 9 are Gelled Water with 6 hour breaker and WITHOUT silica flour. Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should Include a volume adjustment for Surface equipment between the wellhead and densitometer. Stages 3 through 10 are scheduled to pump at 25' BPM. However, decrease if treating pressure dictates. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained to at least 100 F on the surface. HIT PERFS BBLS 62 237 2137 2262 2407 2572 2747 2932 3057 3147 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATI COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1482' FNL, 1318' FEL, Sec. 28, T11N, R9E, UM At effective depth 1281' FNL, 1275' FEL, Sec. 28, T11N, R9E, UM At total depth 1227' FNL, 1264' FEL, Sec. 28, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 73 80' feet true vertical 6283' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-05 ProductiQn 9.84-16Permit nuTr/a~r_.~ov,~,.~uj~ber 10. APl number 5o-029-1 7300 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 72 76' feet Junk (measured) true vertical 61 95' feet 13. Casing Length Size Cemented Structural Conductor 1 0 9' 1 6" 175 Sx C.S. II Surface 3150' 9-5/8" 850 Sx A.S. III & Intermediate 650 Sx Class "G" Production 738 5' 7" 280 Sx Class "G" Liner 250 Sx A.S. I Perforation depth: measured 6896'-6914', 7000'-7011', 7026'-7040', true vertical 5877'-5892', 5963'-5973', 5985'-5997', Tubing (size, grade, and measured depth) Measured depth 109' 3150' 7385' True vertical depth 109' 2852' 6265' 7102'-7108' MD 6049'-6053' TVD 3 1/2", J-55 9.3 #/ft.,EUE, 6823' MD Packers and SSSV (type and measured depth) ~'~ ,~'-~ Packer: Baker FHL 6792'~ SSSV: Baker FVL 1839'. Stimulation or ~ment squ~ze summa~ · ~.. Pumped a scale inhibitor squeeze treatment to prevent scale de~sition in tb.e well." Inte~als treated (measured) 6896'-6914', 7000'-7011', 7026'-7040', 7102'-7108' MD .... Treatment description including volumes used and final pressure Pumped 100 bbls diesel, 2 drums S-8660, 5 drums S-289 and 230 bbls seawater. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .X 625 849 317 1250psi 118psi 829 1074 183 1250psi 138psi 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FormSigned 10-4~04 R~ 06/1/'~ ~~-.~,~~ Title Sr. Operations Engineer5/88 Date ~''~ ~ ~ ~ SUBMIT IN DUPLICATE ARCO Alaska, In~~ ' W'ELL REMARKS Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT 1 FIELD ' DIS~C.~ATE IDA~,S IOPERATION AT REP~)RT TIME IDATE ,~-/ / 7'DO /~o ,,D oo0 Ooqz I--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather TemP.Report °F !chi" Fact°r I visibi"ty0F[ miles ] Wind Vel. 1. Type of Request: STATE OF ALASKA ALASKA OIL ANDGAS CONSERVATION COMMISSION 0 ~{ APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator Operation Shutdown__ Stimulate Plugging Perforate __ Pull tubing Alter casing Repair well Pull tubing Other X 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARCO AlaSka, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 6. Datum elevation (DF or KB) RKB 127' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-05 9. Permit number/approval number 10. APl number 5o-02~)-17;~00 11. Field/Pool Kuparuk River Oil Pool 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1482' FNL, 1318' FEL, Sec. 28, T11N, R9E, UM At effective depth 1281' FNL, 1275' FEL, Sec. 28, T11N, R9E, UM At total depth 1227' FNL, 1264' FEL~ Sec. 28, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 7380' true vertical 6283' feet Plugs (measured) feet Effective depth: measured 7276' feet Junk (measured) true vertical 6195' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 0 9' 1 6" 175 Sx C.S. II 1 0 9' 1 0 9' Surface 3150' 9-5/8" 850 Sx A.S. III & 3150' 2852' Intermediate 650 Sx Class "G" Production 73 8 5' 7" 280 Sx Class "G" 7 3 8 5' 6 2 6 5' Liner 250 Sx A.S. I Perforation depth: measured 6896'-6914', 7000'-7011', 5877'-5892', 5963'-5973', true vertical Tubing (size, grade, and measured depth) 7026'-7040', 5985'-5997', 3 1/2", J-55 9.3 #/ft., EUE, 6823' MD 7102'-7108' MD 6049'-6053' TVD Packer: Baker FHL 6792', SSSV: Baker FVL 1839'. _. · Description summary of proposal _ Detailed operation program Packers and SSSV (type and measured depth) 13. Attachments 15. Status of well classification as: Oil ~ Gas__ Service that the foregoing is true and correct to the best of my knowledge. FOR C.,O~I~ISSION USE ONLY Suspended _ Date Squeeze scale inhibitor into the C Sand 14. Estimated date for commencing operation June 1, 1989 16. If proposal was verbally approved Name of approver L. ~ ~; ~ ~ Date approved Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance__ Mechanical Integrity Test__ Subsequent form require IApproval No~- .~::~ -- Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE Approved by the order of the Commission Form ~0-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Messrs. Lyden and Wade May 12, 1989 Page $ Kuparuk Well 2F-05 Scale Inhibitor Squeeze Treatment Procedure 1. Obtain a fluid sample* just prior to pumping the treatment. 2. Mix 5 drums S-289 (275 gallons) with 2940 gallons (70 bbls) seawater. 3. MIRU pump equipment. . , Spear ahead of inhibitor pill with 40 bbls of diesel containing 2 drums of SS-8660 (Chemlinks Mutual Solvent). Follow spear with premixed inhibitor pill pumping at 1 to 2 BPM rate, to ensure against fracing the formation. Overdisplace pill with 160 bbls of seawater to push pill out into formation pumping at 1 to 2 BPM rate. Follow seawater overflush with 60 bbls of diesel to displace tubing. 6. RDMO pump equipment. . Shut in well for 24 to 36 hours to allow chemicals to soak. Bring well back on production at 500 BFPD for the first 24 hours. Open well fully and turn on gas lift after the first day. Leave gas lift scale inhibitor off (if applicable) to allow inhibitor residuals to be measured. 8. Sampling* for residuals should be done as follows: a) Twice a day for the first three days. b) Once a day for the next four days. c) Once a week thereafter. All samples should be sent to the Kuparuk Corrosion group. *Note that due to the increasing intricacies involved in the lab analysis, new Nalgene bottles should always be used for sample collecting. No workover fluids are required. No BOPs are required. The estimated bottomhole pressure is 3300 ps£ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, R9E, UM At top of productive interval 1482' FNL, 1318' FEL, Sec. 28, T11N, R9E, UM At effective depth 1281' FNL, 1275' FEL, Sec. 28, T11N, R9E, UM At total depth 1227' FNL, 1264' FEL, Sec. 28, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7 3 8 0' feet Plugs (measured) 6283' feet 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-05 Production 9. Permit number/approval number 84-16 ,/ ~'-' ~¢ 10. APl number so-029-1 7300 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 2 7 6' feet Junk (measured) true vertical 61 95' feet Casing Length Size Cemented Measured depth Structural Conductor 1 09' 1 6" 175 Sx C.S. II 1 09' Surface 3150' 9-5/8" 850 Sx A.S. III & 3150' Intermediate 650 Sx Class "G" Production 73 8 5' 7" 280 Sx Class "G" 7 3 8 5' Liner 250 Sx A.S. I Perforation depth: measured true vertical 6896'-6914' 7000'-7011' , , 5877'-5892', 5963'-5973', Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 #/ft., EUE, 6823' MD 7O26'-7O4O', 5985'-5997', True vertical depth 109' 2852' 6265' 7102'-7108' MD 6049'-6053' TVD Packers and SSSV (type and measured depth) Packer: Baker FHL 6792', SSSV: Baker FVL 1839'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 338 1 94 0 1 1 75 557 164 235 1 150 112 128 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~;°md 10-40~ev 06,1;,00 ~,.(,,u, ~ Title SUBMIT IN DUPLI(~ATE *ARCO Alaska, Inc' Subsidiary of Atlantic Richfield Coml3any WELL SERVICE REPORT "")NTRAOTORL/~. / ./__/: ' - [OPERA:rJ.ON A EPO T TIM~' REMARKS IDAYS / DATE ~ s f cox/-/.~ 70_57.°`' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' I Chill Fact°r I VisibilityiWind Vel'Report °FI OF milee REMARKS CONTINUED: · DESCRIPTION DAILY ACCUM. TOTAL .... CAMCO oT,s " SCHLUMBERGER DRESSER-ATLAS .., DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B, J. HUGHES , Roustabouts Diesel Methanol ..... SUpervision pre'Job Safety Meeting AFE ,, · .. 15 7~..? TOTAL FIELD ESTIMATE,., ~~~. ~- STATE OF ALASKA ALAS}_ OIL AND GAS CONSERVATION COMM, ,,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order l~ Perforate [] Other [] 2. Name of Operator ARCO Alaska. Iqc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 683' FSL, 1590' FEL, Sec. 28, T11N, RgE, UM 5. Datum elevation (DF or KB) 127 RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-05 feet At top of productive interval 1482' FNL, 1318' FEL, Sec. 28, At effective depth 1281' FNL, 1275' FEL, Sec. 28, At total depth 1227' FNL, 1264' FEL~ Sec. 28, 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 109' Surface 3150' Intermediate Production 7385' Liner Perforation depth: measured TllN, R9E T11N, R9E T11N, R9E 7380' feet 6283' feet 7276' feet 6195' feet Size 16" 9-5/8" 7" 7000'-70~[1' , UM , UM , UM 8. Permit Number 9. APl number 50-- 029217300 10. 'P°°~Kuparuk River Oil Pool Plugs (measured) Junk (measured) Cemented Measured depth' 175 Sx C.S. II 109' 109' 850 Sx A.S. III 3150' 2852' 650 Sx Class "G" 280 Sx Class "G" 7.~65' 6265' 250 Sx A.S. I , 7026'-7040' 7102'-7108' MD true vertical 5963'-5973' 5985'-5997' 6049'-6053' TVD Tubing (size, grade and measured depth) 3 1/2", J-55 9.3 #/ft., EUE, 6823' MD Packers and SSSV (type and measured depth) Packer: Baker FHL 6792'. SSSV: Baker FVL 1839', 12.Attachments Description summary of proposal [] E~etailed operations program [] BOP sketch [] Perforate C Sand from 6896' MD to 6914'-MD at 8 SPF. 13. Estimated date for commencing operation 12/24/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to t~ best of my knowledge Signed.,. .~ J~'~,~ ,~,~¢~,.4,~ Title Commission Use Only Conditions of approval Approved by Date Notify commission so representative may witness [] Plug integrity [] BOP '[est [] Location clearance Approved COpy Returned .~/~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner J Approval No. ~_ ~ ~.~------ by order of the commission Date /- ~,/- 9¢ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, In, Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal f.! 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one sigqed copy of this transmittal. xX-OlB_2 '"~1C-4 '"~lH-4 "~lH-4- "'-~ 1H-3 ----O2F_5 "--.52C_9 ~'-O2F_6 -'-o3C-13 ~',33A-13 ~'"~- 1L-2 '"'~lL-5 '-'"lL-7. ~"-~-IL-1 "---31L-16 "-OlE_4 '"~lF-16 -'"~IF-10 '"--~lF-9 ----o 1F-4 '"-J1Q-9 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis)- KOE Buildup Analysis- KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis Kuparuk Well Pressure Report 6-10-87 6-13-87 6-14-87 6-17-87 6-18-87 6-14-87 6-11-87 6-10-87 6-17-87 6-12-87 6-9-87 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 100591H 7-15/19-87 6-10-87 Static 7-28-87 Static 'C' Sand 'C' Sand Both Sands Both Sands Both Sands Both Sands 'C' Sand Both Sands Both Sands 'C' Sand Both Sands 11-3-87 Static 'A' Sand Receipt Acknowledged: DISTRIBUTION: 0il & ~as cons. C0mmissl0r~ ~ch0rage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany f- ARCO Alaska, lnG._~ Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ~CO ALAS~, I~. AT~: Records Clerk ATO-1115B P.0..~100360 /~z~orage, AK 99510 ' /~nsmitted herewith are the following it,s. rand return one signed copy of this transmittal. Please acknowledge receipt OTIS PBU SURVEYS' 2W-8/' 1 / 08 / 85 lB-7" 12/14/84 2F-12.' 1/06/85 2F-5 ~ 1/02/85 2W-§ ./7. 1/07/85 .~w-6 ~---1/07/85. 12w-7 -"1/07/85 (l lA-i'~ 12/31/84 lA-1 12/23/84 G-5 ...... 12/25/84 2F-3~' -12/31/84 2V-8A ~ 12/16/84 2B-10 ~ 12/17/84 1Y-9-~ 12/20/84 -~1 C-~3~ 12/10/84 2F-2 ~ 12/29./84 2F-15 .... 1/05/85 2F-14- 1/04/85 2F-9 ~ 1/02/85 2~-8~ 1/01/85 API 02 9-21228 '029-2D616 02 9-21097 029-21073 -- 029-21220' -- O2 9-O590O 029-20908 02 9-21178- 029-21084 O2 9-23 O63 029-21048 029-23 090 029-21077 CAMCO PBU SURVEYS 1E-12 ~' 12/14, 16/84 /cat Receipt Acknowledged: Date:~kn 0il ~ ~r~..~ {:n~.. nn.,a~iS~iC,"] Anchorac~ DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Ratkmell Well Files ARCO Alaska. Inc. i~ ,, subsidiary ol AtlanllcRichfieldCompany ARco Alaska, In,r-``` Post Office ,:,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 27, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2F-5 Dear Mr. Chatterton: Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Si ncerely, d. Gruber Associate Engineer JG:tw GRU7/L20 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .~-- ALASK~ ~IL AND GAS CONSERVATION ¢. ~IMISSlON IPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21073 4. Location of well at surface 9. Unit or Lease Name 683' FSL, 1590' FEL, Sec.28, TllN, RgE, UN- Kuparuk River Unit At Top Producing Interval j L©C/,,TJOix~S 10. Well Number 1482' FNL, 1318' FEL, Sec.28, T11N, R9E, UM i VEP, IFiED 2F-5 At Total Depth i SurJ: ~'- 11. Field and Pool 1227' FNL, 1264' FEL, Sec.28, T11N, R9E, UMI~ .~----~ ] Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial ~ Kuparuk Ri ver Oi 1 Pool 127' RKB ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/08/84 02/14/84 04/06/84 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I21-Thickness°fPermafr°st 7380'MD,6283'TVD 7276'MD,6195'TVD YES MX NO [] 1839 feet MD 1400' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 175 sx CS II 9'5/8" 36.0# J-55 Surf 3150' 12-1/4" 850 sx AS Ill & 650 sx Class G 7" 26.0# J-55 Surf 7358' 8-1/2" 280 sx Class G & 250 s;~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7102' - 7108' 3-1/2" 6823' 6792' 7026' - 7040' 7000' - 7011 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None. RECEIVED ,qY o 1 1984 Alaska Oil & Gss Cons. Commission Anchorago Form 10-407 GRU7/WC07 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate :"'_ .. ".i-;:i.~ GEOEOGi-(~M,~'RKERS :::' :' .:~ ' · , --;" ~::'~ .' t"":~"-.- ".:' '. -' ' ~ORMATioN'TE~Ts' : .' ..' '.'.' , : · . NAME I nclu de interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper 5and 6897' 5877' Base Upper Sand 6910' 5888' Top Lower Sand 6988' 5953' N/A · Base Lower Sand 7133' 6074" .. 31. LIST OF ATTACHMENTS Drilling History, _Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing !s. true and correct to the best of my knowledge Signed Title Area Drilling En~r. Date ./-/~.?/ - . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas-Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 2F-5 Drilling Ristor¥ NU 20" hydril and diverter- Spudded well @ 0530 hfs on 2/08/84. Drld 12-~' hole to 3165. Ran 72 its 9-5/8" 36# J-55 HFERW BTC csg. w/shoe @ 3150. Cmtd 9-5/8" csg w/850 sxs AS III and 650 sxs class "G". Bumped plug w/1500 psi - ok. ND 20" hydril and diVerter- Performed top job with 89 sxs AS I. Instld 9-5/8" packOff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi-ok- Drld FC and cmt. Tstd csg to 1500 psi - ok. Drld FS and 10' new Drld Sh" hole to 7345'. Ran logs form- Tstd form to 12.5 PPg ' E/4W - ok. 8~" hole to 7380 TD as DIL/SFL/SP/GR/CAL/FDC/CNL f/7335" to 3149'. Cont drlg of 2/14/84. Ran 169 ~ts 7" 26# J-55 ~FERW BTC csg- w/ shoe @ 7358. No cmt details available, lid BOPE- Displ fluid from top of well. Instld 7" packoff and tstd to 3000 psi - ok. performed Arctic pack w/250 sxs ASI, & 55 bblS'ArctiC pack. Secured well and released rig @ 1000 hfs on 2/16/84. D5103 ih RECEIVED MAY o ! 1984 Alaska Oil & G~s Cons, Commission A. n,,horage 2F-5 COMPLETION SUMMARY RU Gearhart/Eastman. Ran GR/CBL/CCL; good bond. Ran JB/gauge ring to TD. Ran Gyro. RD Gearhart/Eastman. Secured well. Accepted rig @ 1830 hrs, 4/5/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Perforated the following intervals' 7102' - 7108' 7036' - 7040' 7026' - 7O36' 7010' - 7011' 7000' - 7010' Ran~2~" completion assy w/tail @ 6823', pkr @ 6792', & SSSV @ 1839' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel ~ 220 bbls crude oil. Dropped ball & set pkr. Tstd 3½" x 7" annulus to 2500 psi - ok. Opened SSSV. Set BPV. Secured well & released rig @ 2030 hrs, 4/6/84. RECEIVED 0 1984 Alaska Oil & Ga= Cons. Commission Anchorage ARCO AL..A'.!::I::iA., I I',IC ,, (":OMF'I_ITAT I O1',1 F:'A(3E NO.. · " ~ " -"'~ ....... ~ !:~ ,"'. .... . · '"- ~'~ #' I<IJF:'ARLII< FI i:[I_D., ixI(]RTH SI_.Cfl:::'IE., AI..R'."-';I<A 11 ,", 4.0: C)'.:.'~ 1/:,-~PF .... 84 I'"IEA:BI.II::~I::::I.:t [~RIF'I" DF;IIF'I" COI_IF;~'.:;E: VFi:R'T'IC:AI_ VERTICAl_ '.::;IJBF';E:.AR E C: T A I',1 G I_1 L A · .. '-' -f'" ' .. . '-' I-'- ]Oli.':F::"l"H AI',IGI_L::DIRFC]"IFd',I L..ENG]'H DIEF::'TH .::,[:..TIFfl',I 'I'VD C 0 0 IR D I N A 'T' I..'E ::-; DI.'",TAN...I::: !:)IREC]'ION SlEVI::'F;~IT'~' F.-:E:ET [) ........... D'I ....................... D ..... L"k ............. F:'.EE:'[ .......... 17_'EE~L ..... .EE E,T ........... E:JEET_ F E ETI __ ~,'_L ........... I';L ..... p.:l_ ........ .D.(:E/._i.!;'~.!i:LF:")' ()., ()' 0 0 c) ('). O. O0 f). 0 C) - .1. 27. C) O O. 0 ¢) O, 00 O. 00 0 ¢) O, (')() ........ 'LO0 ............ 0-.1 '-~-,S'-2.~-A.:..'. ................. ~,~ ..... -1.O_(U ' ~ o0~ oo -._ ~-~ZL__.__:'~_~. (O!!__.O '-" ......... O~=__ ~, C~':.? ~ ~Z'., '.::; '2¢~ --4"::' _L4.("~ ,,. :"",¢~ ':;::()0,, 0 .1. 8 'S .1 9 .1. 1 W 1. 00, 2(:)(:), 00 -.C). 76 7:::, O0 O, 74. S O, 27 W C)..7':? S 2C) 12 W () ,, 0 .1. 30(') 0 19 S 1"" =;P"; S 19 44. W () 0'2 .... :, 14 100 :300.¢)0 -1 2:0 :1.7:3 O0 1 27 S 0,,4.6 14 1 ":' i~ ,.. ,.. ii . I "' ' ..... ~-' "2l "~ ....... ,"'~'- · '-, '-, "- ,.")" ,-' ,'.',, '-,,-, .... , 1.00C),, C) :36 S' !5:3C) W 1C)(:l~I':i:::'9'}~!?~":"'~,i.~ _:_-5~_4:1 ~':~'.-78_ !5, :25 S. 2. :30 Lq .... 7,:, :--; .,.-'..:: I 14 C),, 1..,., ...... .......................... '--., -'::-..:"-:.,:. ........ ............................. ,..,: ............ ,. '.,.,..,: .... 1. ':-::'(") C)(') 2 I',1 '7 '""'"" C) . '~ ':~ ':' ~ ' o,= .... 4 S 2!:5 4.':? ("). ....... ......... :'":' ' · 1. ~!. ! ..... ~' ~= '1(~'.~ ' ._,. ,;,; .=, ' , ,:,,.,, 14 .. w ...-::..::: · (-) :",.T,"; c"/ .,:'/") .': '-,, ,~,'-, o ,-,: .':;: 1:30C),, :3 19 11 12 :5 E'!: ].. '~ ,7:,., 14 4,04 '.:; 42 ::-:::3 Ikl 3, ':.::'F' .1. Fi(")(") 1 () .1. 4 N 1 '"" ............. :, .: .... 2 , ....... ::., ::,::_'-, E :00, 57 :s .:_,4 .'.:.,7 E 6O N E 4 ............ : 6oo ............. ~ :~ 3 :, ._ N :. 2a_..l~_£ ........ :.~".)~ ....... ~,.., ".~ ...... 3::u_.'~ .... _.1..:.~:::::.,_2.1 ..... .~8,/;,...LB .............. 1..(:.J,l_...~ :::'-?, ':' ::__!!_!_:,__J...:~ ... ._E .............. :!:.., :_:'.i!5. 170c).. ,, :/:-'.: 4.7 N 1 .1. 19. E 100, 1691 , '-?:::... 67 ,44 15/:,4 , ¢/:..-{. _ 66 ,19. N17 ,9::'~. .. E 6F.: , ".'-i':'._ ,_, Nlf:: ..... ].(') [ii: 4 ,, 9':.'-'... ,-, r= / f:,-, ":, :l :::::C)(") 2:::] 1 Iq 6 4.1 E 1 ¢)0 17,:,...,, .7:8 1 ¢):3,00 1 :,.: ,:,, 1C') 1 41 N 23 ,, .:i':' .... ., E 104 11 N 1;3 4 I-- 4 ':'":' ...... . # # ._ .,.i . a ,_1,,.I .......... l..':2..OO ........... 28 .5 ~:: /7 :':: .F 1(')¢). 1'"~,:,7 ''"",_, , 5A .. 14E,. Q'.-? 174:_--:: ,56 ..... 14.4 2:B bi .... . '"~'.o,,'-' 6::':; E 14.7, t)." 5 N _1 ]. 1 5 E 5 ,. (..),.:,' ' :2:00 C). :3:2 17 N !5 '.7:'. 1 E 10 C), .1. '? 61. ,-..4o", 2.i.D_O .............. 3.4_..2.Q_J~2 .... A_-t~z._~ 100, 2:045, Sq. . :2'20 (') :3 ._, ._ 7 N 4 4. 4 E 1 C)0 212'7, 2 '22: C) ('). :37:2: 4. N . 5 1 E 100. 2.':2:C)7,40 . "24. c)¢) ............ ~.~L ....... 1._..._BI =, ,-v- ':lC ........ 1()~) .."-"-"-. <- :, :::7 196. :35 1:3:34.98 '-'.~ . '2 ::.: 918. ~._ 1 I 54 194.:21 N :34.12 E 197. 18 N 9 58 E 4..2':) 248.94 N :3:3.7..5 E 251.94 N E: 51 E 2.1:3 3:08. :36 2000.2'..7,' · ~1 (" i-i ' ._,c,/._,,.c: 71 ..' .),:, 0 ,4 0 430.69 '2158 ,, :37 · 7:0 6. :34 N 4:3,28 E '-'/' "=" '78 · :, :...,. N 48 :.38 E 427.71 N 53, 88 E :309. :"48 N :3 2 L-- 1.64 :369.16 N 7 32 E 1.6]. 4:31.09 N 7 I I [-_-2 :L. 4'7 :25(")(). 40 15 N 5 '26 E ..... 26(/_2.0 ........ ~4.~~_/',1 5 '2.::5 E .... 2700. 4C) :2::3 N 4 59 E 280C), 41 7 hi 4 4/:, E · ":,,:z (') c) 4 :t ":'/- · ':' ': ....... ......:. .................. : ,_.,,.L_N ...... 100. Si::--: 62.87 ! 00. 2.4. :3'.:~, 08 100. 2515. 11 1 O0, ':--"590.76 1 ¢)¢), .-,,z. ~- .... .... ~..:,6.Z, c/(') 494.48 2 '.? :=: .=i . 87 ?] 9 ".~"-' :2.7:12 08 .... ~ ,~,.._1 # . 491.24 N 5'..'-.~. 77. E · / =. ::':'F~ 17. 555 7(:) N :,._, 4,94. :3/_-, .N 6 56 E =.~'--~ F,'-? N 6. ,.1.6. E ::,~:4.17 -__ 11 689, 5:3 246,:3.76 755, =.~ '-'5'"':' '_-:,,C) 62(') .:,o ...... :, N 7].. 78 E 6,=,....,. 54 N 77.._,':'.~._ E 751..7:(-) N 82.7.5 E /:,:,24-.52 hi 6..7:.,(:, E: 6,89.8'7" N 6 2.::6, E 755.84. N 6 17 E ]. 2-,',1. C). ':.::0 O. :3¢) (") .~'::' (). :3:-:: A R C 0 A i... A S I< A., I I',.IC ,, I<UF:'(..~F~I._II.':i I:-"' I I:::.: l__ I') :. I',IF)RI"H SLF. E'E~ AI_.A$1<]A C 0 M F'IJ T A T Z 0 N T I ME" I)A'FE :1. I: 40: 0':? 16- A F'R-:34- .: "rRUF I¥1EA'.:;UI::;[ED DF:4IF:'T' [RIFT F"IIIR'.$;F VERFI_.AL VERTICAl.. '.F;I_IBSEA R E C: .T A N G I~1 L A R C: L r'i S IJ R [-_- [/"iF:;I E'":i '1 - *' r. - \ -.m ..... ~ .... . Dt!i:.F::"I'H AIxlGI_.E ]01Rf-'[C:T 101',1 L.E:IxlG'I"H Il.. EF TIq sEF:T ]' ON TV[I C 0 0 R D I N A T E :--; D .'[.=, FAI Ibc D I rd"' .."i' I r)N SIEVIER i' T'/ [:: '::' ': ....... ~ ¥ "1 1 I:::' E:' E:" :' E' F T f) D G / 0 () F:"T' E,,,[ ] ............ J:.l ................... ] ..... _E .................. L____F - - F E E'F F..' E [ii: T F' E E T F E E.'i T M .1. ........ =.,:., N 4 17 I::' 1. 0(). 27.,10 , ,:,""=._, c,,-.. 1 ., 77 z./.:, 13 , ,= ..., ,_, 1 '7 · ..., = N ................ ;!I.QO ............... :tl_;~SL_B.L_&' _i.~L.L. :1. 00. 2:Ei: 15.75 888. 04 2:688 ,, 75 :38:3. 40 N :32()(). 4-1 '7 Ixl :3 38 E ].0(). 2890,84 954.07 :27./:,:3, ::::4 94?. ?:3 N ::::::3()0,, 40 54. N 2 2::: E .1.00, :2966,2'::/ 1019,6:"3' :2 ,".:: :3 ':? . :2 '.:~ 1014,7R N ............... :;i:!.:1:.!;.:!!;;!,,. ............... :l:0...;.::i:_!.....l:.l :3 7 E 1 O0 "::'n4'-, 15 1 r '-' ':)'Z...' 8:':: E '-"-'- ...... :::,,=, ::,. 2:'7 FI 6 0 F_:: 0 ,, 0,::., 97.._,":":',.., I'Z '-? F, 4 .. _ 26.Iq ._,':'= ..,='1. E 0 . ._,="?, 101.41 E 1019. :'-':4- N 5 42 E 0. :2 :i]', I. (')5..., 11 E I. 0:::4.. ,94 N ._,'=' :_::4. E () ,, 52 ::i:: 5 0 () ,, 39 ':39 N - 2. 46 E:' ............ ;'::J.?.:.('!!"J ................ i:::j:_..SQ,N ....... Z...;'J!/"~_.[:::. .1. O0 :311 c, .-.,,.?,.-~ ,:.,. 72 1.14'.'?. 11. ~...- 1 . '72: 1144. .07 hi 100. :31 '..'-'6. 16 121 "2. :34 :3069. 16 :1. 207, :.27 N 108.43 E 114.9.:20 N 5 25 E 1:1.1.4.0 E 1:21:2.40 N 5 16 I:.': 1.14 04 E 1274 =; '= ..... · ..., N '-' E .. 116:37 I:-: '-'"" 5. -' ._ . . 1 .:, ..... :::, .1. N 5 (") E 1..1. :3.7 2 E 1:3':? 6 ,, 25 N Zl 5:3 E (.') 7c, (') '= · · ,, .J C:, 4000,, :36 49 N :2 1:3 E ................ :ti. lO.(! ................ 3/~....2[~:._N ................ 1_:2 E 4:200,, :36 2:::: !',1 1 55 E 4:30(),, :36 15 N 1 4() E .............. 4 <~1-00 """=' ~ '" ............ :~.~ ....... Z..........F...I ........ 1 ......... ~1_ E 45 ()0 ,, :'_.'.:5 4. 2 I',1 1 16 E 100, 17.51,96 N 4. 15 E: (). :26 ............ :I:.a,.<:!i::,~ ........ :D._.....32.._N ........... 1 ........ 22:_[:. ........ ___I..D~ .... .'_3'~)'FL"7...,_l '.~ ...... ~.~...(.."_).., 0_~___ '~3~.:_7_.(.."_)_,_.!.7L__::L?,J')~_. ~/__2_J_x!. ..... ! :i:? .!.., 3! ~ 1L::: 1 0. 1 3 Iq . 4 1 0 E' F), 1 47 () 0, ,.,':' ~._ 1 'P. Ixl 1 :::._ 0 E 100 · 407 ::: .68 1867.9. 2 ._':: 9. 5._ 1 ,68 1 ,_,c, /.., ._,--:, . :'41 N 122,77 E 186 :::: ......... ¢) 2 N 4. 5 [::.: (') . :2 ::: 1:34 4.7 E 1" .... ,,= z..,::, .-.Y z._, N 4 0 E 1 :E:6..5:.3 E 1 ':?:-2:3,2 :.:: N ::: :5'7 E 1 :.':.:'T¢. (')2 E 2040 ?4 hi 2 ... 4 E.' 14,1,70 E '20'P 8.4 :':'.: N :':: ,5 :-2 E: 144.7 F)_ E z.'-' 1 ._5._5. 'p 6 N ::3 ..., =' 1 IF_ 14 7. '.-:> 6 E 221:3 ,, 3"? N :E: 50 E 1. !51,....._,5':' E 227 (') ..... 4. 8 N 2 =',d''' Er (:), 26 0 ,, 12::'i:.: 0 ~ 1 .L (:), 5:'4. (), 22 (), 17 O. 4.-/]. 50(:)0. :35 1.3 Iq 2:31 E 100, 4':32:3.78 2040.74 4196.76 20:38. tO N ............ 5.1C!.!] ............... :~..~ ............ a__bJ___2~4-~ E __100. 440:5,54 2098, 26 427:..-.::. 54 209:3.69 N 5200,, :35 7 Iq :3 10 E 100. 4487.:37 2155,72 4:360.37 2151. lO N 5:-- (')C) :2:4 =i':' N :3 1 '-? E 1 O0 4. F;/-,9 24 :2121 '-' 14 4.442 24 '-"-' ' '" -,'., (.),:, 44 N .... , . I - - . t ..~l i · . ........ .5~l~00 .............. :':~..._:::_?_. N ..... ::_L'__~_E: .......... __1Q('JZ,~_..Y:,51_,":'zt._,~ ~.,~':"-,'m. ~.'-,'-, 4.. ,_~_~ ... :34 ........ 21:.'/-,~. 42 N '.:::.1500 ,. :34. 2'? hi 4 16 [ii: 100 · 4 732:. 68 2:326.9 7 4606.60 2322. C) 3 N ::i&~] .......... ~ 54. hi 4~.E ...... 2.0.D. .....~t~, 38 238:3, 1,:~; 4689, :38. 2:378, 0:3 N 5700 ................. :34- . (') N ~; 14 E 100 4.:::99:3':' 24.:39 03 4772 '::'? --',z~ I..:,.:,'-"-', 74 N 5.:::' (") ("):3:3 0 1'4 ~ 2 9 E ] 00 Zl 9:3 2. 4 ':' Pi Pi 54 2494.4.8 ~=~. 2488 94~ N -- - a _ _ , ~ __- i_1%, ,_ i -- m 164.54 E 24:3'?. '.:29 N 7:52 E 169. :-30 IE :2494. '73 N :2:54 E 1 '7.=.5,7 :'3 E 7550. 16 N :3 57 [.:.: 0. '.::."P ()..=,9 O. 4-/:, 0, 7.1. I~'IIE:(~SI...II:Rli::'[) EIRIFT DRIFT C:CII...IR'.E;I.;: VERTICAl.. VER'FIC:AL. SI..IB'.::;EA R E [: 'l" A N G I_1 L. A R C I.. 0 S I.J R E [~r'iGL. E:G Dli']:I:::'"I"H (..~NGI...E i.'J I REC:T l ON I_IENO'T'H £ I:F' T H '- ....... I .... "' ' .... ~' I .... .. .:,E L.. [ Z 0 N 'r'v D F: 0 F~ R D Z N A T E :F.; D Z .:, 1 F~ N ... E: D ]: IR E C T Z -~ N '.i3 E: V E: R ].' "1' Y ................ E..EE]:: D .......... M ................. ]Et ......... I~L ................ E'.[:iE 7[' ............. ET~ .... __EEE]- ...... E;~Z'[' [E _,F~ E;.::E EE E.._i'JL_ ............. ~;L_,,..I':! ................ ~:!,L.7,'j, ~,.:J:.j;!!; ! ,1:!!.i :'!' ........................ ~ o ;- .:, , ..., ,,,. N 2:2:7 ...... , E:' 2"?~(')'..".45 N 4:3() E · z ........ ":= "" ..... '"~ ..... '= .... ' = '-":~ ' ' ='=" =' '"~";'= "-' ""'-'"" '" " '::"P~',Z !~ 4 :':::::: I:: (") /",":~ /-,70('* :3~ '"" . ...... , ........ , ..~, N ";'?iO.05 E ::~0~7 66 N 4 45 E ~ ~2 ..... ,, .:: 7 N ~ 1 Z 4. E: 1 ()0 57 ~ .:: ~ ,,~0 Z 7 /-,6 ...=~?-'/.,. ,:, :, =~=' :3007 . ~":' . ...... ., ....... . ............... :,062.26 N '261 :27 E :307:3 :'::9 N 4 ,58(')c). :3:3 4.:E: N 11 49 E 100. ~'7':M,._,.~,~'~ .... .:,.~0'~..:, .... ..:,o'"' .~/-,~'7; 3:3 '"' '- . . . .... ...._, IE 0,, 72 '700c:), 3:3 24 N 11 29 [E ............. Z..10.D ............... :3.3_.l?/_~.bi._l..~_..J2 E: '72(')(), :3:2:20 I\1 1:2 :3 E '7 2.'::; ..... (") ,, :7:: 1 =;.., ._,':' hi 1 I .~;_/..,.. E F:' R f:),_1 Ii"": C T E [.:1 "f' 0 F:'B"f' D A PE'TROLANE COMPANY F:' R 0,..I E" r":"f' E D 1' 0 'T D F I NAL_ C:LOSI..IRE - D I REC:T I r.')l,,I: N 5 DEGS :31 MINS :'::6 F:EF:S E [) I S'I" A N C: E: :':: :3 :E: ./:, . 24' FEET ._ ." .... Z (34./i' c, I:::'AI] 21::'., WELt I',10: =i '.:"; 16 MA-GYRO .JOB NO A¢~:':::::4 ..... ' "" I':::I...II:::'AI-]I...II'::: F I EL.D, NORTH :::;L. OI::'E, ALA'-?.';I<A ......... ~..l...Bh'l.fi:'"_'.l.~!iYRO ....... C~-727./:'. Id]i;!., ~::::11~~B, F: E. FFERk. URN/~M, [, A]E RUN 2:]::-MAR-84 SIGMA :':i:C)O NO. 6:27, F'Rr]BIE NO: 05::3 ::: I ~ ~1.:,~ I.'_::' :-:; I G H T :. I',1'i;) :2:7 W ............................. . Eastman A PETROLANE COMPANY 0.,::,.., 0 =;":' '"''''- '~';~ 31 ~, 3. ':~':~ ..... '"' ~ '~' · .,,:, ..-,':: "l-r)F::' L...OWE~I~ SAND '"'"""-' . .............. . ~:, ::~,:, ,::,. 0 c~ .'=','"~:: .. ~:,,::'- . '~. '~. 1 ""' :' ._ ,:,.~..:, N z :::,.~ ...... E 31 '7 ~, '=''-' N ~, IE . .................. ::,(.. E N 16, E B(-~,SIE LONER '.E;~ND 7~33 C~O ~,074 27 ~(')f4:::.7 ~:;';>4.7 :'.7 : "A PETRQLANE CQMPANY Suggested form to be inserted in each "Active" well folder to d~.eck for timely ccmpliance with our' regulations. Operator; 'We/1 N~ne and Number Reports and Materials to be received by: ~ U~'~ Date Required Date Received Remarks Ccmpletion Report Yes ~--~ /.=-~q ~ K Well History Yes '. _Samples Mud Log Core Chips Core Descr±pt2.on Registered ..Drill Stem Test Reports · · ProdUctiOn Test Reports y~,_~ ,/~,,0~_~/,~ ~, ~/: _ Logs Run. Yes -- ARCO Alaska, InC Post Office ..,.)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-5 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Associate Engineer GRU7/LO8'tw Enclosure If RECEIVED APR 2 Alaska Oil & Gas Cons. Comm~sslon Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany .... STATE OF ALASKA ~-~ ALASK~ ~IL AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-16 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21073 4. Location of Well Surface: OTHER [] 683' FSL, 1590' FEL, Sec.28, TllN, RgE, UM 6. Lease Designation and Serial No. ADL 25657 ALK 2583 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB, 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Gearhart/Eastman, Ran GR/CBL/CCL; good bond, Ran JB/gauge ring to TD. Ran Gyro. RD Gearhart/Eastman, Secured well, Accepted rig ~ 1830 hrs, 4-5-84. ND tree. NU BOPE & tstd - ok. Perforated the following intervals: 7102'-7108' 7036'-7040' 7026'-7036' 7010'-7011' 7000'-7010' Ran 3½" completion assy. w/tail @ 6823', pkr ~ 6792', & SSSV ~ 1839'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel & 220 bbls etude oil. Dropped ball & set pkr. Tstd 3½" x 7" annulus to 250( psi - ok. Opened SSSV. Set BPV. Secured well & released rig ~ 2030 hfs, 4-6-84. RECEIVED APR2 41984 Alaska Oil & Gas Cons. Commission AnChor~.ge 14. I hereby ce/r, tq~")that the foregoing is true a~l~d correct to the best of my knowledge. /"f / /~, ~z/~ Area Dri 11 ing Engineer Signed i' /J-~¢"~ Title The space b~w f~¢ssion use Condition~f APpr~f any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU6/SN50 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc~-'' Post Office =ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-5 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU6/L61 'tw Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ', ALASKA OIL AND GAS CONSERVATION CtJMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 683' FSL, 1590' FEL, Sec.28, T11N, R9E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 127' RKB 6. Lease DesignationandSerialNo. ADL 2565TALK 2583 OTHER I~X 7. Permit No. 84-16 8. APl Number 50-- 029-21073 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-5 11.-Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well ~ 0530 hfs, 02/08/84. Drilled 12-1/4" hole to 3165'. Ran, cemented & tested 9-5/8" casing w/shoe ~ 3150'. Continued with well as originally planned. 14. I hereby certif~y~that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 i ng Engineer The. spac ssion use Condition/eof Appr v~r, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 GRU6/SN22 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, ~' Post Offl,.,~ ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-5 2B-5 WSP #3 2F-6 2B-6 Hemi Spring St #1 2F-7 2B-7 2B-8 2B-9 Thank you. Sincerely, JBK/SH1: ih RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany - ' ?,,. STATE OF ALASKA ALASI, OILANDGAS CONSERVATION .)MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-16 3. Address 8. APl N~rl:jVr 21073 P. 0. Box 100360, Anchorage, AK 99510 5o- 9. Unit or Lease Name 683' FSL,1590' FEL, Sec.28, TllN, R9E, UM KPK River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 98' 127' RKB , 6. Lease Designation and Serial No. ADL 25657 ALK2583 10. Well No. 2F-5 11. Field and Pool KPK River Field KPK River Oil Pool For the Month of. February ,19__84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0530 hrs, 02/08/84. Drld 12¼" hole to 3165'. Ran, cmtd & tstd 9-5~8" csg. Performed top job. Drld 8½" hole to 7345. Ran logs. Cont drlg 8½" hole to 7380 TD. Ran, cmtd and tstd 7" csg. Displ fluid from top of well. Performed Arctic pack. Secured well and released rig @ 1000 hrs on 02/16/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3150. "G". 7" 26# J-55 HFERW BTC csg w/shoe @7358'. Cmtd w/850 sxs AS III and 650 sxs class (No cmt details available). 4. Coring resume and brief description 15. Logs run and depth where run I)TL/SFT,/SP/GR/CAL/FDC/CNL f/7335' to 3149'. 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--RepOt ~s~or~--~is required for each calendar month, regardless of the status~-~f ope?ations, and must U'e//file~ in duplicate with the Alaska Oil and Gas/Conse~fon Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 HILL/MR117 Submit in duplicate 2F-5 Drilling History NU 20" hydril and diverter. Spudded well @ 0530 hrs on 2/08/84. Drld 12-~" hole to 3165. Ran 72 jts 9-5/8" 36# J-55 HFERW BTC csg. w/shoe @ 3150. Cmtd 9-5/8" csg w/850 sxs AS III and 650 sxs class "G". Bumped plug w/1500 psi - ok. ND 20" hydril and diverter. Performed top job with 89 sxs AS I. Instld 9-5/8" packoff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi-ok. Drld FC and cmt. Tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 7345'. Ran logs DIL/SFL/SP/GR/CAL/FDC/CNL f/7335' to 3149'. Cont drlg 8½" hole to 7380 TD as of 2/14/84. Ran 169 jts 7" 26# J-55 HFERW BTC csg. w/ shoe @ 7358. No cmt details available. ND BOPE. Displ fluid from top of well. Instld 7" packoff and tstd to 3000 psi - ok. Performed Arctic pack w/250 sxs ASI, & 55 bbls Arctic pack. Secured well and released rig @ 1000 hrs on 2/16/84. DH103 ih KUPARUK ENGINEERING Date: Well Name Transmittal Log Date _ 4.._~_~ . , ; Run # DISTRIBUTION NSK Operations Dr il 1 ing Geolbgy ~--~~-~-~ ~ Bluel~ne Bluel ine Film Blueline & Sepia~ Lreturnthe attached copy as re_ceip~ o~. dat.a~,.~_' iA Return to: ARCO ALASKA, .INC. ATTN: D. Fay ALLISON ATO-1115B P.O. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING Date: _ ~,~9~, Well Name: Transmittal Log Date Run # DISTRIBUTION NSK Operation Blueline Dr i%1 ing Bluel ine Geology Bi / S e/Film R&D Blueline D&M Blueline F.G. Baker Blueline D.B. Schaf er Blueline Sign & return the attached ~:, ':.4 copy as receipt o;f data,,>:×7 ~~e turn to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING TRANSMITTAL TO' FROM' D. Fay Allison DATE' WELL NAME: see below Transmitted herewith are the following' - ,~ PHOTOCOPY PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T TAPE' - Well Description Date ~ , PT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. DATE' ATTN: D. FAY ALLISON - ATO/]ll5-B P. O. BOX 100360 ANCHORAGE, AK. 99510 OAS E_ _~ -//- p q/ B. O. P. E. TEST REPORT MAKE TYPE · . .. ',B~ - 'l' ? [PE RAHS--~'[ZE~/~,~ .se} ,5-" .L 1ND RAMS - ~,g ~/e.. $'~ ~ CHOKE t,b~.NI FOLD }ICR VALV£ CHECK VALVE UPPER KELLY COCK LOWER KELLY COCK SAFELY VALVE INSIDE B.O.P. LOCATION ~P.S.~F ~e// SIZE 13 5/8" WOP, K]NG P .S. ! .G. 5000 13 5/8" 5O00 ] 3 5/8" 1I 500D 5000 TEST P.S.I.G. TEST O.K. _ Ok o~.. ACCUMULATOR' ROSS HILL · _ FULL CHARGE PRESSURE' PRESSURE AFTE~ CLOSURE' P.S.I.G, P. S. '[ .G. I TEST TII~IE:' liRS. TEST RESULTS: FULL. CHARGE PRESSURE ATTAINED P.S.I.G: ' =(-e KIN, . ~/~ SEC, NITROGEN P.S.I.G'~3oo~ ',~ CONTROLS- MASTER ARCO Alaska, Inc.x-''~ Post Office box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 8, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-5 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to change the 9-5/8" casing depth in order to cover the West Sak Sands. Since this well has already spudded, your earliest approval will be appreciated (verbal approval for this change has been received from M. Minder). If you have any questions, please call me at 263 -4970. Sincerely, A~'~~~neer JBK/GRU5L165: tw Enclosures E£E VED FEB --- 81984. Comml~,o,! ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _.IL AND GAS CONSERVATION C~ AMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I~x COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 683' FSL, 1590' FEL, 5ec.28, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 12. 127' RKB I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 7. Permit No. 84-16 8. APl Number 50-- 029-21073 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-5 (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation [] Change Plans ~ Repairs Made Repair Well Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed OPerations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Due to an error in the geologic picks for the K-12 marker on 2F-Pad, ARCO Alaska, Inc., proposes to change the 9-5/8" casing depth in order to cover the West Sak Sand. The 9-5/8" will now be set at 3081'MD (2856'TVD). Estimated Start: February 8, 1984 S,a!~seq~aent Work Reportecl Verbal approval received from M. Minder, AOGCC, 02/08/84. 14. I hereby cerJ;~y that the foregoing is true and correct to the best of my knowledge. // Signed ...... Title The space/ow~or~/C/o~/mission use Conditicrfls of ApproVal, if any: Date Approved by. COMMISSIONER .Approved Copy Returnmd By Order of the Commission Form 10-403 GRU5/SN90 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc., Post Office E~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 27, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-5 Dear Mr. Chatterton· Enclosed is a Sundry Notice for the subject well. complete this well with our workover rig. We expect to start this work on March 20, 1984. questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG'tw GRU5/L145 Encl osures We propose to If you have any JAN 2 ? ]984 Alaska Oil & Gas Cons, A~,~h~,~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~,lL AND GAS CONSERVATION C~. ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. 'ARCO Alaska, Inc. 84-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21073 OTHER I~'~ 4. Location of Well Surface: 683' FSL, 1590' FEL, Sec.28, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. . (Su~mit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Fgrm 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 1~3. Describe PropoSed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested . weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The! subsurface safety valve will be installed and tested upon conclusion of the job. EStimated Start: March 20, 1984 Subsequent Work Reported on Form N°./d" .¢t~Dated ~J_/.~l~/4~ 14. I hereby c.¢r-t-i~y that the foregoing is true and correct to the best of my knowledge. Signed /.,,~-~,~/ ~ · ~_,~--~ Title Date Condition's of Approval, if any: Approved by. Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU5/SN81 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PHASE I AS BUILT CONDUCTORS I- 8 95.0 09 160 010 150 011 140 O~ 130 28 27 BASIS OF ,PAD ELEV. IS T.B.M. 83-25-49. O.G. ELEV. s INTERPOLATED FROM DWG. SR. 8 F- 12- :30:30 REV. I RENUMBER ALL WELLS PER N~K a DRILLING 12/2/83. ( 180° ROTATION OF '. NUMBERING) REV. 2 CHANGE ALL ELEVATIONS LOCATED IN PROTRACTED SECTION TOWNSHIP II N.~RANGE 9 E.~UMIAT 28 MER. ,BASIS OF LOCATION I$ MONUMENTS C.EF.-2 N.E. & 2'C MIDDLE PER LHD ASSOCIATES. · DELL-, SITE A5 BUILT 2, F CONDUCTORS LOCATIONS WELL I WELL 2 WELL3 Y= 5,949 ~ 341. ~9 FSL Y= 5,949,4C0.93 ,X" 517, $82.$4 518' FSL Y=5~949,460.06 X" 517,372.18 577' FSL WELL 4 Y' 5,949,51 9.07 X= {I 7,:362.08 636 FS L WELL 5 Y=5,~49,566.$9 X= 517m658.11 683' FS L WELL 6 'Y= ~949, 507.09 X, 517,648.17 624' FSL WELL 7 WELL 8' Y=5,949,448.14 X= .~17,658. $ I 565 FSL ¥ · 5,949,389.0 2 X · 517~668.35 506' FS L Lat. 70e 1'$'21. 9780" L~dlg, 1.49e 51' 33.357~' 1837' FEL Let. 70° 16'22.5595'° L. oa~. 149e51'33.896'' 1847' FEL Lot. 70° 16'23. 141:3" Lonq. !49451~34. 161 ' 1856' FEL Lot. ?0el6'25.7219'' L0ma. ~49e51 '34.451" 1866 FEI.~ Lot.7Oel6' 24. 18 I1" LOn~. 1,490 51'26. 410" 159.0' FEL' Let. 70e 16'?.~. 5977" Le aq. !,49e51 '26. 12 I" 1580' FEL Let. 7~16'2~.0176" Lee~ 1,490~1'25.851'' 1570 FEL' Let.?Oe 1~'22.455 7"' LO~. 149e5 I 156 I' FEL DAVID FILUCCl 527 3O I HEREBY CERTIFY THAT I AM PROPERLY . REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND ~ THAT THIS PLAT REPRESENTS A SURVEY MADE .UNDER MY DIRECT SUPERVISION AM:) THAT ALL. DETAJI. S ARE CORRECT AS OF NOV.' 5 ~ 1983. e 32 THIS - 33 31 ~ , SURVEY J'~ _1 '=1 Mi,. ! ~. -8SSOI], ARCO Alaska, Inc. Kuperuk I~oJect North Slol~ Drilll~ DRILL SITE 2,F CONDUCTOR AS'BUILT LOCATIONS date' 11.9,83 drew. by: J. 8, . ,cale' 1"·400' dwg. riO. :9.05.206JJd4 January 26, 1984 ~k'. Jeffe~ B. Kewtn Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska' 99510 Re: Kuparuk River Unit 2F-5 A~CO Alaska, Inc. Permit No. 84-16 Sur. Loc. 683'FSL, 1590'FEL, Sec.28, TllN, RgE, b~4. Btmho!e Loc. tlI3'FNL, 1303'FEL, Sec. 28, TllN, R9E, Dear Mr. Kewin-: Enclosed is the approved application for permit to drill the above referenced well. If ¢orIr~ i~ conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter su_~veys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habigat Coordinator's Office, Department of Fish and Game. -2- January 26, 1984 Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to co~enclng operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to-witness te~ttng of the equipment before the ~urface casing shoe is drilled. Where a diverter system is required,. please also notify this office 24 hours prior to commencin~ equipment installation so that the Commission may witness testing before drilling below ~he shoe of the conductor pipe. In the event of suspension or abandor~ent, please give this o~~ adequate advance notification so that we may have a Very truly yours, C. V. ChaCCert:on Cha ~rraan of -d Alaska 0~1a,~ Ga~ Con,ervation Co~ission lc Enclosure DePartment of Fish & Game,' liabitat Saction w/o encl. Department of EnvirOnmemtal Conservation w/o encl. STATE OF ALASKA '-'". ALASKA L..-AND GAS CONSERVATION CO...,/IlSSION ERMIT TO DRILL 2O AAC 25.005 1 a. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 683' FSL, 1590' FEL, Sec.28, T11N, RgE, UN At top of proposed producing interval 1405' FNL, 1327' FEL, Sec. 28, TllN, RgE, UN At total depth 1113.' FNL, 1303' FEL, Sec. 28, TllN, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2F-5 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 127' PAD 98' J ADL 25657 ALK 2583 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 15. Distance to nearest drilling or completed 2F-3 well 105' ~ 1550'TVD feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1113' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7426' MD, 6253' TVD feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 39 o (see 20AAC25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1200 feet. 18. Approximate spud date 02/05/84 2786 psig@ 80°F Surface 3126 . psig@ 6097 ft. TD (TVD) SIZE Hole 4" 2-1/4" )-1/2" Casing Weight 16" 65.5# 9-5/8" 36.0# 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling Length / / 'cl SETTING DEPTH MD TOP TVD 80' 29' I 29' I 29' 29' I I I 28' I 28' MD BOTTOM TVD 109'1 109' I 2966'I 2766' I 7426'16253' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 860 sx AS III & 660 sx Class G 490 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7426' MD (6253' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 2966' MD(2766' TVD). A 13-5/8", 5000 psi, RSRRA BOrE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2786 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals Will be perforated within ?~Fu~~d~mation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) ~'i~i~.~ ~ ~ ~,~; 23. I hereby c/ertl~ that the foregoing is true and correct to the best of my knowledge ~1 ./'[~ ['~'-~-~ ''~ 2'? i!J() ,- ~7 ~- // SIGNED TITLE Area Dri ~ +' '~' "-' 'l" t,0D~E.~ / CONDITIONS OF APPROVAL Samples required []YES Permit number APPROVED BY Form 10-401 Mud log required [~YES [~LO Approval date /) ./..~ 01/26,/84 -/ Directional Survey required I APl number ¢.Y_E s []NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 26, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-5 installed and tested upon completion of the job. 2F-5 will be 105' away from 2F-3's proposed directional plot at 1550'TVD. At the actual crossing, there will be better than 250' of vertical distance between the two wells with 2F-5 crossing under 2F-3. With our normal drilling practice of leading the well to the left, these distances will increase and shouldn't pose any problem. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6157'MD, approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-518" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. ---: ...... ~ ..................... ~ ..... ~, ~ , ~ ,' , , ,:, . ~ .......... , ~ , , : : i . ,,,1 ' ~ ' ~. , ~ . : .~ .... , ~ - : ~ASE ~R~'ROST ......... ''~ : __: ~ : , ~ _ ~ ~_~.u~_.T~~~'~=~]r~ ~-~,~ ~, ~,r[, ~ : . ; . . ~ _ . ~ ~ ;~']--~:':I: ::N :'~: :~ ~ ' ' -~4- ~ ~ : ~ : . . ..... ....... ~' ~'~'~. ~,~ - : ~ : · ~' ~ : : ~ ~ ~ ~ i ..... , ~ : ~' ~ ' ~ ~ ' ' I ~ ~ ;'' "' ~I ~]~&~, ~ ~~ ' ' : ': ~ ~ : .... : : ' ~'; . ", ~ . - ~ ........ ~ - ~ I . ............ ~ . , ~ i, ............ ~ ...................... ~.:. .... ~ .... , ~ ,, . i,, , i .- ,.~ Surface Oiverter I. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. ¢. 20" 2000 psi drilling, spool w/lO" side out I ets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to resem~e pit. Valves to open automat'ically upon closure of annular preventer. 6. 20" 2000 psi annular'preventer. ' 7. 20" bell nipple. · Maintenance & Operation 1. Upon in'itial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines 'every 12 hours. 3. Close annular preventer in the event-that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor r ANNULAR PREVENTER BLIND RAMS PIPE RAMS 7. L' -PIPE RAMS ) 5 CSG HD i . DIAGRAM ~I 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. Il" - 3000 psi casing head 3. 11" - 3000 psi x X3-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool ~. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8' - 5000 psi pipe rmms 8. 13-5/8' - 5000 psi blind rams -g. 13-5/8' - 5000 psi annular ACCUI41JLATOR CAPACITY TEST 1. C~ECX AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUL[C FLUID. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI I)OgNSTRE~ OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIHE AND PRESSURE REK~,INING AFTER. ALL UNITS ARE CLOSED WITH CMARGING PU~P OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIHE AND 1200 PSI REHA[NING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND I~IFOLD WITH ARCTIC DIESEL. ~. .CHECK THAT ALL HOLD DlTdN SCREWS ARE FULLY R~- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AI~' SEAT IN W~_LLHF..AD. RUN IN LOCK DOWN SCREWS HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES ANO BYPASS VALVES ON HANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 $. INCREASE PRESSURE TCR~o_.i]RjT~~. AND HOLE FOR I0 MINUTES. BLEED TO ZE $. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO ("J~AND HOLD FOR 10 #INUTES. 8. CLOSE VALVES DIRECTLY UPSTRF. JU~ OF C~OKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PS! UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTE~ TO ZERO g. OPEN TOP SET OF PIPE RA31S AND CLOSE BOTT04 SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 #I~S BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RNMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 #INUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCY~S AND INSIDE BOP' TO 3000 PSI WITH KOOMEY PUMP. ' TIONALL' OPERATE BOPE DAILY. ' :: ;': i"!:! ;" ·. ... i II ANNULAR PREV~NT~.R · . 11 II __ . · BLIND RAMS". " ) Io PIPE RAM~ PIPE ~ 7 D IAGRAH ~2 13-5/8" 5000 PSI RSRRA BOP STACK 13. 14. 1. 16" - 2000 psi Tankco starttng head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7-1/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 11" - 3000 pst x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 ps1 drilling spool- 7. 13-518" - 8. 13-$/8" - 9. 13-$/8" - I0. 13-$/8" - 11. 13-$/8" - 5000 psi pipe rams 5000 psi drtI1tng spool w/choke and k~11 lines 5000 pst pipe ram 5000 psi blind rams 5000 psi annular AC~LATOR CAPACITY TEST 1. OIECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH IiYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 30~0 PSI WITH 1500 PSI OONNSTREAM OF THE REGULATOR. 3. OBSERV/ TIME THEN CLOSE ALL UNITS SIHULTANEOUSLY AND RECORD THE TINE AgO PRESSURE REGAINING AFTER ALL UNITS .ARE CLOSED WITH 04ARGING PU~P OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LONER L114IT · I$ 45 SECONDS O. OSING Tilde ANO i200 PSI RigdAItllNG PRESSURE. 13-$/8" 60P STACK TEST I. FILL 80P STAC~ AND Ka. qlFOLD WI'ill ARCTI.C OIESEL. OIEOi TI, IAT' ALL ~OLO OOWtl SCREWS ARE FULLY RETRACT- ED. PREOE'TEI~INE DEPTH THAT TEST PLUG WILL SEAT AND SEAT I11 gELLtlEAD. RUN IN LOCX DONg SCREgS Itl 3. CLOSE ANNULAR PREVENTER AND ., O4OKES AND BYPASS VALVES ON HANIFOLD. 4. TEST AU. COHPONENTS TO 260 PSI ANO HOU) FOR 10 HIHIJTES. S. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 HINUTES. BLEED TO ZERO PSI. 6, OPEtl ANNULAR PREVENTER Alto CLOSE TOP SET OF PIPE P,~. 7. INCREASE PRESSURE TO 3000 PSI ANO HOLD' FOR I0 t'IINUTES. 8, CLOSE VALVES OIRECTLY UPSTREAN OF O'iOKES. BLEED OOWNSTR~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAItlING UNTESTED ~L4NIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTRE/~ OF VALVE AND ZERO PSI O0~NSTREN4. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE ~ AND CLOSE 801'I'OM SET OF PIPE 10. ltlCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 HINUTES BLEED TO ZERO PSI. 11. OPEN 80'J'TOId SET OF PIPE RAIDS. 8ACK OFF JOINT AND PULL OUT OF HOLE. CLOSE 6LINO RAFTS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. I2. OPEN BLINO RAMS ANO RECOVER TEST PLUG. HAKE SURE MANIFOLD ~ LINES ARE FULL OF ARCTIC DIESEl. AND ALL VALVES ARE SET IN DRILLING POSITIOH. TEST STANOPIPE VALVES TO 3000 PSI. TEST KELLY COCX.~ ANO INSIOE 80P TO 3000 PSI I~ITI. I KOOMEY PUHP. RECORD TEST ItlFOP, MATION ON 6LO~/OUT PREYENTER TEST FORM SIGN AND SENU TO DRILLING SUPERVISOR. PERFORM CONPl. E"TE 8OPE TEST ONCE /1 WEEK AHD F'UNC- TIONALLY OPERATE BOPE DAILY. ARCO Alaska, Inc. ~ ~' Post Office B,._ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 16, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: KuParuk 2F-5 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2F-5, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o ~A proximity plat o A diagram and description of the surface hole diverter system o Diagrams and description of the BOP equipment Since we estimate spudding this well on February 5, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. . rely, Enginler JBK/JG5Lll9:tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (1) Fee (2) Loc 8) .~.~(8) (3) Admin .~-- ('gZthru 11) .(12 thru 20) (5) BOPE~ /-~J'.,, ~'~ (21 thru 24) (6) Add:~~. _~:/.'~° ~"'y 1' 2, 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15' 16. 17. 18.. T9. 20. 21, . 22. 23. 24. 25. YES No '" REMARKS Is the permit fee attached ...................... ,~ .................. i '"1 .......... Is well to be located in a defined pool ........... i~, ~'~ Is well located proper distance from property i ........... Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deViated and is well .bore plat included ............... Is operator the only affected party . ~ ............................... Can permit be approved before ten-day wait .......................... Does opera'[or have bond in force ~ Is a conservation order needed ...................................... · Is administrative approval needed ................................... IS conductor string provided ................................... Is enough cement used to circulate on ~ond;~tor and su;face ~ . Will c~ment tie in surface and i. ntermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will alI casing give adeqUate safety in collapse, tension and burst.'. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed.. .......................... divert~r system required ' 4~ Is a ...................................... .. Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to 3~ psig .. _~, Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: t~ 0 ~-~0 Geology: Engykepwring: HWK 'LC~ BEW ~'-~' ..IAL _ rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. :/??/ ~IIIIIIIII1~111111111~ O~TG~N :0000 ~AXIMU~.LEN~T~ : 1024 ~TLE..TYP~ ,, PReViOUS F~LE CN ~ ~RCO ALASKA T~C KUPA~U~ cou~ CT~Y~ USa ** CO~EWTS ** UNIT TYPM CA~E SIZE CODE 000 000 016 000 000 0O4 000 000 000 000 002 000 000 004 000 000 002 000 000 OOB 000 000 006 ~r)O 0o0 004 O65 WKLL = CISI}{G : g.6~:57 (a 31,50~ - BTT STZ~ = 8,5" TO 7345' TYPE FLUID = X-C POLY~,,,FP DENSITY = 10..~ l.,B/~ P~ = 4.3 ~ 68 Dr VISCOSITY = 37.0 S R~F = 4,4~ ~ 68 OW PH = 9.0 ~C = 3.3 ~ 68 DF ~LUID I~OSS = ~.6 C3 v~ AT BHT = 9.107 ~ 146X DF ********************************************************************************* , , , · , · , · · , ~ , , * , , , , · , , , , , , , , , , , 4 1 66 8 a 73 ~0 q 4 65. .1I~ 0 ! 66 0 DATU~ ~PECII:'TC~,,TIC,'Is~ B.b ,:CK$ LVP 010.!~0~. V~TI~.TC'ATTt'~!',~ 1L?$TT~;~ P~GE 4 S ~ R V I C ~ U N FT 0 n 0 0 0 OH~~ 7 0 0 0 n OH~ 7 ~9 46 0 0 "V 7 ~ 0 0 0 nA~T 7 3~ ~ 0 0 Pt) 42 68 2 0 0 ~tC3 4~ 44 0 0 0 cp~ 42 ~4 q~ n 0 CPS 42 34 q3 0 0 T~ ~2 2~ 3 0 0 a2 4~ 1 0 n 42 0 o 0 0 CAPI 42 31 32 n n S!Z~ PROCESS ~EPP 6P 6~ 6~ 6~ 6~ 6~ 6~ DaTA DEOT RHO'B OEPT NR~T D~PT D~T ~HOB DEPT ~0~ -15..0313 3.0234 7300 nooo -o:OOOO ,.~020 .16~0 ~00].0000 -15,9687 ~477 7~00,.0000 34.,:~563 2.~82R 72°0!nO°° 6~O0,nO00 ~.OBO1 6800,0000 -~4,.0000 ~;07,~375 NPHI 2~00, 000 ~C~[., 3 .~94g 1,09.937~ NPH! 105.1875 4.1095 OR 6.8008 2326.0000 rC~L 10.9687 ]:000o rCUl., ~70 40..0000 IL~ $~,.06~5 302~.,0000 1.7~-0o00 9.8504 TLD 34,9.121 DRHO 667,5000 107.9375 2,33'59 TLD 49,0234 OR~O 447,5000 CALl 105.~875 3~ 6289 4,797 685 0000 96 4,375 DRHu C~l,! ',.~ .3o65 DR~O 73.1. 875 3.539l TIED,, 50,5371 O~rl ]7~.0000 CALI 2,7266 .0547 8.3439 ~.316:4 0,1t87 8Z9766 5.9453 0.0444 8,8437 .0166 8.6641 3.,:.2734 0.0317 9. L'I'"~ I'I ! ! I iil ii:-] ~ [:-] ii NRAT 3.0551 Ioo oooo RHOR ?.4434 NRaT ~PT 6~00~0n0 SP. -0..~595 NR~T '999.~500 DEPT 6~00,.0000 ~9~T -~99.9500 ~P.., mH~B -999,.~500 NRAT -999.2500 DEPT 6:00.0000 SP, ~HOB -99 ~500 , ~sno -ggg OEP? 6100.0000 Sp. 6000.~000 ."42.4'375 N~? -990.~500 $900.0000 .-~l,.?i~7 ~HOB .999.2500 DEDT $~00.0000 SP,, 5?.O3 5 B~DT 5?00.0000 4.55~6 OR ~.55n8 !08],.OOnO ~CN!, 203.6250 -99~.2500 ., ..2500 FC~L -999.~500 CR 105.~750 NPHI . ~,, 8047 ~:L~ 1.29.6250 -099.2500 ~09.4375 ' 9:9.950'0 '909.~500 , .63~7 11].06~ -999.2500 23,5000 247'5000 3.0469 ILO -999,.~500 DRHO 546.5000 21~.7500 ~.4551 TLD -999.'~500 DRHO -999.~500 ~03.6250 2.9863 -999.~500 -099.~500 ~4,?~00 3.9453 -999,~500 DRHO -999.~500 ~.~676 -9:99.~500 CALI -999 500 D~O ~00 i20.6250 999:.~00 DRHO -999,~500 CALI 4.5977 TLD '999.~500 .~g9:~: ~.50:o 109.4175 ! LD DRHO CALI ].0977 -99~.~500 DRHO -99 .:250:o CAL! 1 ~297 TLD 99~:~500 PR. HO 3.02~5 0.0347 9.4219 2.2910 -999..2500 ~. 1953 2.9316 -999.~500 3.83~9 -099,~500 ~.2207 9.4609 3.1680 999,~:500 10.3359 4 -ogg "tO: =99:~.69~6 9~2500 .9609 3. O3? ! -990, ~00 -999.2500 . t, VP 01n. HO~ VFmlFlCA~'Tn~,~ I,TSwI~¢; P&C.E 6 ~HOB -099'750© ~'CWL 9EPT 5600.0000 ~P. -44.2500 ~RAT -999.9500 DEPT 5500.0000 ~, -56.~1~? ~HOB -999.~500 DEPT 5400,nOnO SP. m48.7813 ~R ~RAT -99o.~500 DEPT 5!O~:OOnO SFTL, ,~. 5.. ?500 RHOB -999.~500 ~P, -46..7500 DEP? 5100,0000 ~FLU ~HOB ~.~500 NCNL D~.,: T 5000'.0000 SP,. ~49,46~ ~mT 4~:00,0000 ~OB -090- 500 NRAT -999.9500 D~DA DEPT 4700.0000 ~HOB -999.,75n0 D~DT 4600.0000 -099.2500 FCNL 15~ 50~0 ~P~I -990,~500 ~.~164 TL~ -990.2500 ~CN! .... 114.56~5 ].7695 q9..06~5 NPH7 999.9500 ·, ~CNt, ~.56o5 2999.2500 FC~'i., ~.73~3 999.;2500 WCNL -OO9,2500 - 96' 5oo ~.6660 115,~6~5 106~6~7~ ].06~4 NPHI WCNL I:'CNL -999.2500 CAT..I -q99.2500 1.9141 -999.~500 -999,~500 3.16~0 TLD · ,Q90,.9..500 DRHO 999.~S00 CAL! 2.~073 It, D. -999.2500 DRHO -999.~500 ¢ILI -099.~500 3,5293 -999.~500 CALl -09.:9.~500 -999,2500 OReO -q99.,~500 -999.~500 .99~,7402 TLD -25on DRHO -a99,.2500 '~,. ~g45 ILD -.999,2500 DRHO 999,~500 CAtI ~.72~.7 :999,2500 -oqq. 250o O0 DRHO 500 3.0332 -999.2500 ,2500 . 3. 406 999.{5n0 -999,2500 ~. 35'/4 -999 2500 .999 3.4863 -999..~500 -990.~500 -.999.2500 q 99. :~ 5 0 0 ,, 2,, 3730 · 099' -999.~500 ~.6250 -099,2500 -099.~500 -qgg.~500 .,0~9:' 2500 -~99.9500 3.0547 -099.~5n0 4500.o000 -57.!875 -099,5500 NC~L ,99a.?SnO 4400.00n0 -60.4375 4300.0000 SFLU -6~,,.~500 -999.95n0 4900~0000 -60,.~500 -090.~500 ~CNL 4!00,0000 Srt, U 59.~000 '-OOO'~SnO 4000.000:0 -61,5000 ~500 ..... P. ~HOB ~PT 3800.0000 -099.2500 3100.00o0 6~,'0000 -999 ~500 .'09o~5:00 .-6g..~500 GR 099..~500 10~.93~5 115,0000 MPHT -999.~500 FCNL . 47.7500 ~PH! -999.~500 ~.494~ IL~ -~99.~500 FC~L -9~.~500 ~05.06~5 ~PHI -999.~500 ~.5919 IL~ ~16'~695 :ooo ~5oo 9~:~soo I bM NPH! ].I895 7L~ ,101.,1250 NPHI -999.~50o ~R, 6738 -99q,75~0 4.1641 I07.31~5 NpHT -099.9~500 2.7715 -099.9.500 -999.~500 -99q.~500 =999.2500 -990.2500 2,5957 -999.~500 -999.2500 -999.2500 2.4805 -999.~500 "999, ..500 3. 5 0 999. -999.9500 3'5156 - 999 ,. ~ 500 -999. -099 ~ ~500 ], ~ 945 -999,~500 ,548~ '99~- ~5:00 ,'~99. 3.6,367 -qqO,,~50 -990. ?508 -999.~5o0 I [,D. DRHO C t~ L I -999.2500 ~.~047 -090.2500 =99U.5500 3.0723 -999.2500 -999.~500 2.6523 -999.~500 -999.2500 -999:500 3750 -099.2500 ,3.0762 -9~.9.2500 -9:99, ~SO0 -990 ~500 ) -,5 2 i 5 -.99~,2500 999, 535 =999.~5on 3. 725'? 999 [,VP 010'.!40"; VgPIrTCAq".T,~H L,I$'r~NG PAGF, 8 ~HOB -999.7500 DEPT 3400'00~0 ~,U BP. 6g,~250 ~R ~HOB -~90.~5n0 NCNL NRAT -999.~500 PNRA 9EPT 3 O..OOnO ~HOB -099.~500 ~CNL ~RT -999.~500 -B4.~975 DEPT 311~.$000 gFt, U ~HO~ -999.~500 NCUL 3.7949 10q.4375 -999.~500 .99~.~500 7~.0000 -99~.9500 4.3008 JOJ.O000 -og~.~500 a,7813 93.18~5 -999.~500 9000.00~0 -999,.~00 VE~SlO~ DATE ***8****88 EOF 88.,TAPE TRAILE~ SERVTC'~ NA~K ~,F:DTT DA~E.:~/O~/~ OR,~g~N 10000 TAPE N,A~ DATE ~/02/2~ CONTINUATION # :01 3.9434 -099.25n0 -qgq,?500 -gqq.2500 -09g,2500 -q99.~500 -999.~500 -099.2500 -999,2500 -q99.~500 6.0000 -g99.~500 -QgQ.~500 -g99.~500 ~000.0000 999.2500 999 ~500 qg:g:~500 4.121,1 -099.2500 4.2~52 -99g.,2500 -q99.2500 2500 -q99.~500 6.0039 -q99. ~0 2000,0000 -9gg'~O0 -999.~500
