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Home My WebLink About175-057By Anne Prysunka at 11:06 am, Aug 09, 2022 By Samantha Carlisle at 7:17 am, Apr 14, 2022 o o o o o o o o o o CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] SCU 12A-10 322-542 - WITHDRAWAL/CANCEL Date:Friday, December 15, 2023 9:20:58 AM FYI, logged in 2022-403 Excel log From: Donna Ambruz <dambruz@hilcorp.com> Sent: Friday, December 15, 2023 9:12 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com> Subject: FW: [EXTERNAL] SCU 12A-10 322-542 - WITHDRAWAL/CANCEL Please withdraw/cancel the above-referenced sundry. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com From: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov> Sent: Tuesday, September 20, 2022 10:10 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Cc: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Subject: [EXTERNAL] SCU 12A-10 322-542 Anne Prysunka Executive Secretary| AOGCC Alaska Oil and Gas Conservation Commission Direct: (907) 793-1230 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. 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$33/,&$7,21)25681'5<$33529$/6 $$& )('$ +LOFRUS$ODVND//& 6ZDQVRQ5LYHU+HPORFN2LO &2%6ROGRWQD&UHHN8QLW6&8$ $QFKRUDJH$ODVND /HQJWK 6L]H 1 1 79'%XUVW SVL 0' SVL 3HUIRUDWLRQ'HSWK0'IW 6HH$WWDFKHG6FKHPDWLF 6HH$WWDFKHG6FKHPDWLF 6HSWHPEHU %DNHU)+5HWUL3NU 0' 79' SVL 3 W VV )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Anne Prysunka at 1:43 pm, Sep 13, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH '65 ; 0,77 DQG &0,7 7[,$ WR SVL 3URYLGH KUV QRWLFH IRU $2*&& RSSRUWXQLW\WR ZLWQHVV %-0 %23 WHVW WR SVL GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.09.20 09:59:10 -08'00' RBDMS JSB 092022 tĞůů͗^hϭϮͲϭϬ ZtK tĞůůEĂŵĞ͗^hϭϮͲϭϬW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϮϬϲͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗>ŽŶŐdĞƌŵ^/KŝůWƌŽĚƵĐĞƌWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϳϱͲϬϱϳ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϮϮϵͲϰϴϮϰ;Ϳ DĂǆ͘ǆƉĞĐƚĞĚ,W͗ Ϯ͕ϳϴϴƉƐŝΛϭϬ͕ϲϰϳ͛ds ^ƚĂƚŝĐ,WŵĞĂƐƵƌĞĚϴͬϭϬͬϮϮ;ϭϮĚĂǇƐ ĂĨƚĞ ƌdŽƉĞƌĂƚŝŽŶƐĐŽŶĐůƵĚĞĚͿ 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COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:13 DATE: 7/19/22 Rig Rep.: Rig Phone: 907-398-9190 Operator: Op. Phone:907-690-2854 Rep.: E-Mail Well Name: PTD #11750570 Sundry #322206 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:n/a Valves:250/3500 MASP:2179 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" Top Load P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75" B/S P Flow Indicator NA NA #2 Rams 1 1.75" B/S P Meth Gas Detector NA NA #3 Rams 1 1.75" Slips NA H2S Gas Detector NA NA #4 Rams 1 1.75" Pipe Ram P MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA Quantity Test Result Choke Ln. Valves 1 2" 2x2 P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2" 2X2 P Check Valve 1 2" FMC P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORT P Time/Pressure Test Result System Pressure (psi)2900 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)26 P No. Valves 5P Full Pressure Attained (sec)92 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): n/a NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:3.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7/18/2022@1718 Waived By Test Start Date/Time:7/19/2022 11:00 (date) (time)Witness Test Finish Date/Time:7/19/2022 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger Bryson Lowe Hilcorp Cole Bartlewski SCU 12A-10 Test Pressure (psi): cbartlewski@hilcorp.com Form 10-424 (Revised 02/2022)# Schlumberger-Private 2022-0718_BOP_Schlumberger13_SCU_12A-10 9 9 9 9999 9 9 9 9 MEU -5HJJ 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU&7&21 2SHUDWRU1DPH&XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ"<HV 1R 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Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l o s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, L-l----�� J1sie L. Chmielowski Commissioner DATED this 2. JTday of February, 2020. 4BDMS (1� VFEB 2 5 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVE® FEB 12 2020// ,AO6CCL� 1. Type of Request: Abandon Q > 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: Convert to Injection ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC r Exploratory ❑ Development D Stratigraphic ❑ Service 175-057 ' 3. Address: 3800 Centerpoint Dr, Suite 1400El6. API Number: Anchorage Alaska 99503 50-133-20206-01-00 / 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Will planned perforations require a spacing exception? Yes El No No Q ' Creek Unit (SCU) 12A-10 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 0 Swanson River/ Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,065' 10,909' 10,968' 10,813' -386 psi 9,123' (tbg) 10,909' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 50' 22" 50' 50' Surface 2,090' 10-3/4" 2,090' 2,090' 3,130psi 1,580psi Intermediate Production 8,480' 7" 8,480' 8,372' 6,340psi 3,830psi Production 4,861' S. 11,063' 10,907' 1 10,140psi 10,490psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 3-112", Tubing Grade: 9.2# / N-80, Tubing MD (ft): 6,042'; See Attached Schematic See Attached Schematic 2-7/8" 8 2-3/8" 6.4# / N-80 8 4.6# I N-80 10,628'& 10,744' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Retri For 10,668' MD/10,516' TVD 12. Attachments: Proposal Summary a Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 1, 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ElOp Shutdown 11Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operations ag Contact Email: tor9IT101 Dhilcoro com Contact Phone: 777-8420 Authorized Signature: Date: Y rs v.J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 390-077 Plug Integrity [� BOP Test Mechanical Integrity Test ❑ Location Clearance &,Vk SI T F Other: * ZSf)o / s, 13 O Q C %Cs i �' •i'un '�-'P- /-nnJLeiJ.o- . /�gpMS Post Initial Injection MIT Req'd? Yes ❑ No ❑ (" FEB Z 5 2020 Spacing Exception Required? Yes E] No [ r Subsequent Form Required: rO "- y Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:Z J5 ZZ _�7pZD n ///'''�� '1 26 Submit Form and Form -403 Revised 4/2017 Approved applicatid�o' y� r� fArr�he date of approval. Attachme s in Duplicate's VVVVVV 1 ` v H L pa4iat R Hilum Alaska, LU Well Prognosis Well: SCU 12A-10 Date:02/07/2020 Well Name: SCU 12A-10 API Number: 50-133-20206-01 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: March 1, 2020 Rig: 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-057 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Current Bottom Hole Pressure: — 5,076 psi @ 10,732' TVD (0.473 psi/ft pressure gradient) Maximum Expected BHP: — 5,076 psi @ 10,732' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 386 psi (Based on the Max. Exp. BHP and a 0.437 psi/ft fluid gradient to Surface) Brief Well Summary Soldotna Creek Unit 12A-10 (SCU 12A-10) was completed as a Hemlock oil well in January 1976. SCU 12A-10 produced oil from the Hemlock formation from January 1976 through December 1996. The well has remained shut-in since January 1997. 0 The purpose of this Sundry is to permanently P&A the SCU 12A-10 wellbore. Pre - Rig Work: 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160G, 2. RU Pump Truck. RU on IA and perform a pressure test to 2,000 psi on chartfor 30 min. Bleed down pressure. Note: Hilcorp RIH with slickline (on 12/2/19) to pull the Tubing Packoff Plug, reportedly at 9,123' SLM. Numerous runs reported fill/debris as high as 9,069'. Eventually the plug was engaged at 9,096' and POOH (less its rubber elements). A subsequent run engaged the G -slip stop at 9,074' (which the packoff was set in), which was then POOH. Following removal of the plug, Hilcorp attempted an injectivity test and was unable to inject any fluid into the well. It is uncertain as to whether the tubing string is plugged below 9,074' or if the Hemlock perforations are plugged off. 3. MIRU Slickline. RIH with Gauge Ring to 10,750' to verify no obstruction in the tubing string. -Y: Note: SCU 12A-10 completed with a tapered tubing string (3-1/2" on top, 2-7/8" in middle, & 2-3/8" on bottom). b. Bottom of tubing tail is at 10,744'. 0 Hil.m Alaska, LU Well Prognosis Well: SCU 12A-10 Date: 02/07/2020 Rig #401: 4. MIRURig 401. 5. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2,600 psi high, annular to 250 s� psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Notify AOGCC �11500 r and BLM 24 hours in advance of test to extend the opportunity to witness. g.P T a. Perform Test. b. Test VBR rams on 3-1/2", 2-7/8", & 2-3/8" test joints. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. PU tension on the tapered tubing string (3-1/2" on top) to release the Baker FH packer (set @ 10,668'). a If the packer releases, go to Step 7. —� If the packer does not release, go to Step 9. RU pump truck and circulate hole with a 9.8 ppg heavy kill weight fluid. a. If circulation can't be established, bullhead kill fluid down the backside. 8. POOH with tapered tubing string, laying down GLM, bottom -hole assembly and both the 2-7/8" and 2-3/8" joints of tubing. Stand back the 3-1/2" tubing string, which will be used as a work string �during the surface casing shoe P&A. Go to Step 16. . RU E -line. PU and RIH with tubing cutter to "'10,650'. Cut tubing and POOH. RD E -line. 10. PU tension on the tapered tubing string. a. If tubing is free, circulate hole with 9.8 ppg kill weight fluid. b. If tubing is not free, repeat Steps 9 & 10. 4�P 11. POOH with tapered tubing string, laying down GLM and tubing (both the 3-1/2" and 2-7/8"). ~ 12. PU and RIH w a set of Jars on a work string g (most likely straight 2-7/8")and engage tubing stub @ -10,650'. 13. PU w/ Jars to release FH packer. 14. RU pump truck and circulate hole with a 9.8 ppg heavy kill weight fluid. 15. POOH with tubing and packer assembly, standing back the tubing work string and laying down Gy I packer assembly and 2-3/8" tubing tail. /�►�^ 16. RU E -line. PU & RIH w/ 5" CIBP to 10,700' (+/-) and set same. POOH. 17. PU Dump Bailer and dump bail 35' of cement from 10,700' up to 10,665'. WOC. ,)dU Note: From this point forward, all perforations are isolated from the wellbore. L �0 18. Pressure test well to 2,000 psi, for 30 minutes. —;�p Ala tdw ^cPc 19. If the pressure test is successful, go to Step 23. y C A�L Cl S 20. If the pressure test is not successful, PU & RIH with 7" CIBP to 6,200'?just above" line! r p) JSet same depth and POOH. 21. PU Dump Bailer and dump bail 35' of cement from 6,200' up to 6,165'. WOC. 22. Pressure test well to 2,OQ0 psi, for 30 minutes. Note: There is no record of a cement bond log (CBL) having been run across the surface casing shoe interval. The only CBL on record logged the interval 6,100'- 10,966'. Hilcorp will proceed with the SCU 12A-10 abandonment assuming that there is no cement behind the 7" casing (across the surface shoe interval). �i(�1�-Pk 23. PU & RIH w/ 7" CIBP to 2,240' (+/-) and set same. POOH t - 0 24. PU 1't set of casing punches and RIH to 2,239'. Punch casing from 2,239 to 2,235'. POOH. 25. PU 2"d set of casing punches and RIH to 1,980'. Punch casing from 1,980' to 1,976'. POOH. RD E - line. 0 Hilrarl, Alaska, LL, Well Prognosis Well: SCU 12A-10 Date:02/07/2020 26. RIH w/ 3-1/2" tubing to 2,239'. 27. RU Cementers. Spot a 15.8 ppg cement plug from 2,240' up to 1,890' (350' of cement). 28. PU above cement plug and clean out tubing. 29. Pressure up to 500 psi and hold for 30 minutes, to force cement in behind 7" casing to isolate the S� U surface casing shoe. WOC. a_ t 30. RU Slickline. RIH and tag top of cement (TOC). Ensure TOC is at or above 2,140' (to ensure at least 100' of cement above surface casing shoe). POOH & RD Slickline. 31. POOH w/ tubing, laying down. —32, Pr s ur test well to 1,000 psi for 10 minutes _ 33. RU E -line. PU & RIH w/ 7" CIBP to 160'. Set same. POOH. 34. PU Casing Punches and RIH to 159'. Punch 7" casing from 159' to 155'. POOH and RD E -line. 35. Rig up cementers to back side. Establish circulation down the IA through the casing punches and S up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. p 36. Place dry hole tree on well. 37. RDMO Workover Rig. Post Rig Abandonment Procedures: 38. Excavate cellar, cut off casing 3' below natural GL. 39. Notify AOGCC and BLM 48hrs in advance. 40. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 175-057 c. Welt Name: SCU 12A-10 d. API: 50-133-20206-01 41. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 42. Photo document casing cut-off and Welded Plate install. 43. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form D'v SCHEMATIC Swanson River Field Well # SCU 12A-10 Hilwra Alaeke, LLC Actual Completion 12/15/96 RKB to TBG Head = 23.00' PBTD = 10,968'/ TD = 11,065' MAX HOLE ANGLE = 25° @ 8,000' JEWELRY DETAIL NO. Depth Item 23' CASING AND TUBING DETAIL TOP SIZE WT GRADE CONN TOP BOTTOM 22" dummy, RK latch 2 2,982' Surf 50' 10-3/4" 40.5 K-55 dummy, RK latch Surf 2090' 7" 29 N-80 Buttress Surf 81' 7" 23 N-80 Buttress 81' 2905' 7" 29 P-110 8rd LT&C 2905' 8480' 5" 18 N-80 9 6202' 11063' Tubing: 10 10,744' 2-3/8" shear out sub 3-1/2" 9.2 N-80 Butt AB Surf 6042' 2-7/8" 6.4 N-80 Butt SC 6042' 10,628' 2-3/8" 4.6 N-80 Buttress 10628' 10,744' JEWELRY DETAIL NO. Depth Item I to 10,909' with rig WO 12/14/96 23' 3-1/2" buttress tbg hgr w TOP BTM ZONE SPF DATE COMMENTS Cameron Type H-3 BPV profile 10774 1 1,662' Cameo 3-1/2" KBUG glm w/ I" dummy, RK latch 2 2,982' Cameo 3-1/2" KBUG glm w/ 1" dummy, RK latch 3 4,14P Cameo 3-1/2" KBUG glm w/ 1" dummy, RK latch 4 5,109' Cameo 3-1/2" KBUG glm w/ 1" dummy, RK latch 5 5,996' Cameo 3-1/2" KBUG glm w/ 1" dummy, RK latch 6 6,042' 3-1/2" x 2-7/8" crossover 6A 9,123' SLM Packoff Tubing Plug 08/04/17 7 10,628' 2-7/8" x 2-3/8" crossover 8 10,668' Baker Model FH Retr. Pkr, 2-3/8" x 5" (10,516 TVD) 9 10,711' 2-3/8" "X" nipple 1.875" ID 10 10,744' 2-3/8" shear out sub I to 10,909' with rig WO 12/14/96 SCU 12A-10 Schematic 01-13-20 Updated by DMA 08-15-17 DRAWN BY: TAB PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10752 10774 H-1 4 1/6/94 10823 10838 H-3 4 1/16/76 10860 10886 H-5 4 1/15/76 SCU 12A-10 Schematic 01-13-20 Updated by DMA 08-15-17 DRAWN BY: TAB DV PROPOSED Swanson River Field SCHEMATIC Well # SCU 12A-10 Hila,rn Akeke, LLC Actual Completion 12/15/96 RKB to TBG Head = 23.00' TD =11,065' MD 1'M D = O' MD (10,909' TVD) (0' TVD) MAX HOLE ANGLE = 25° @ 8,000' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 50' 10-3/4" 40.5 K-55 7" 29 N-80 7" 23 N-80 7" 29 P-110 5" 18 N-80 Tubing: 3-1/2" 9.2 N-80 2-7/8" 6.4 N-80 2-3/8" 4.6 N-80 P&A PLUGS & CEMENT f5 NO. Death Item 1 Surf 2090' Buttress Surf 81' Buttress 81' 2905' 8rd LT&C 2905' 8480' 4 6202' 11063' Butt AB Surf 6042' Butt SC 6042' 10,628' Buttress 10628' 10,744' P&A PLUGS & CEMENT f5 NO. Death Item 1 —155' Casing Punches from —155' — 159' 2 —160' 7" CIBP w/ Cement to Surface 3 1,976' Casing Punches from —1,976'— 1,980' 3a —2,235' Casing Punches from —2,235'— 2,239' 4 2,240' 7" CIBP w/ 250' of Cement on top (TOC @ or above 1,990') 5 10,700' 5" CIBP w/ 35'of cement on top to 10,909' with rig WO 12/14/96 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10752 10774 H-1 4 1/6/94 10823 10838 H-3 4 1/16/76 10860 10886 H-5 4 1/15/76 SCU 12A-10 Proposed Schematic 01-13-20 Updated by PMW 01-13-20 DRAWN BY: TAB 1 2-1/16" 5M MANUAL GATE VALVE 2-1/16" 5M HCR wxc w"e wre "-. 7-1/16" 5M ISA SPHERICAL ANNULAR 7-1/16" 5M TRIPPLE RAM IE BOP (BLINDS INSTALLED IN BOTTOM BORE) 15M DRILLING SPOOL W/ 2-1/16" =TS STACK SOP, "„B" - 5K YELLOW ACKET LD �$ Hfl3019 annie�e se nvicee MATERIAL: SEEBOM Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 12A-10 (PTD 175-057) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com UG 0 5 2009 Al2skn Oil & Gas Cons, Commit;ginn ,. n.RnPpWa Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, ak, Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase 1 Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platfonn life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -O no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -O no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 444 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -Ono known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life ALASKA 011L AND GAS CON►7'illRVAT161V C®MMS►7Yf.YN June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 \-1S-o5`t SARAH PALIN, GOVERNOR r p 333 W 7th AVENUE, SUITE 100 ` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 _ Union Oil Company of California 168-012 Granite Pt St 18742 18 _ Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 _ Trading Bay Unit D-06RD _ Union Oil Company of California _ 169-004 _ Trading Bay Unit D-18 Union Oil Company of California 188-098 _ Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 Trading Bay Unit D-40RD Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California _ 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 _ Trading Bay Unit K-09 Union Oil Company of California 179-016 _ Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 _ Trading Bay Unit K-23 _ Union Oil Company of California 165-038 MGS St 1759505 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 _ Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595"30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 _ Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 STATE OF ALASKA ALASKA vIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (UNOCAL) Development: X Exploratory: 14V KB feet 3. Address 7. Unit or Property name P. O. Box 196247 Stratigraphic: Soidotna Creek Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 684 FNL & 576' FEL of Sec. 9, T8N, R9W, SM SCU 12A-10 9. Permit number/approval number At top of productive interval 356 south and 45T east of surface 75-57/396-225 10. API number At effective depth 356' south and 45T east of surface ORIGINAL 50- 133-20206-01 11. Field/Pool At total depth 356 south and 45T east of surface Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11065 feet Plugs (measured) true vertical 10904 feet Effective depth: measured 10909 feet Junk (measured) true vertical 10752 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 50' 22" Yes 50' 50' Surface 2090' 10-3/4" 1300 sx 2090' 2090' Intermediate Production 8480' To 700 sx 8480' 8456' Liner 4861' 5" 357 sx 6202'-11063' 6179-10902' Perforation depth: measured 10757-10774,10823!-10838!, 10860'-10886 true vertical 1059,C -10616,10668'-1068Z, 10704-10730' Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 to 6042', 2-7/8" 6.4# N-80 to 10628', 2-3/8" 4. et V 1:U Packers and SSSV (type and measured depth) Baker FH 2-3/8" x 5" packer at 10668' JAN p 3 1997 13. Stimulation or cement squeeze summary Alaska ON & Gas Cats. CommiWon Intervals treated (measured) AfIftW Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil -BBL Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 57 603 656 800 gas lift 275 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge: ORIGINAL Signed: !� °'� r n Title: Date: 12 230 o Imo . Form 10404 Rev 06/15/88 v ' SUBMIT IN DUPLICATE Summary of Rig Workover Operations Soldotna Creek Unit No. 12A-10 11/26/96- ACCEPT RIG @ 15:00 11/26/96. ND TREE, NU BOPS. 11/27/96- TEST BOPE. FILL ANNULUS WITH 99 BBLS LEASE WATER. PULL TUBING SEALS FROM UPPER PACKER, PUMP SIZED SALT PILL W/LITTLE EFFECT, STILL LOSING 35-40 BBLS/HR. PUMP 2ND SALT PILL, LOST RETURNS ELIMINATED. CIRC BU. POOH AND LAY DOWN 3-1/2" TUBING. 11/28/96- FINISH LD 3-1/2" TUBING, POOH AND STAND BACK 2-7/8" TUBING. MU METAL MUNCHER PILOT MILL ASSY. RIH WITH TAPERED WORK STRING OF TWENTY 3-1/8" DRILL COLLARS, 137 JTS 2-7/8" DRILL PIPE AND 3-1/2" DRILL PIPE. 11/29/96- RIH WITH MILL. TAG TOP OF UPPER PACKER c@ 10,684' dpm. PU KELLY, MILL PACKER FROM 10,684' TO 10,6869, PACKER RELEASED AND FELL. CIRC OUT GAS BUBBLE BENEATH PACKER. RIH AND SET DOWN AT 10,781' dpm (IN UPPER PERFS). JAR LOOSE WITH 45K OVERPULL. POOH WITH MILL. 11/30/96- RIH WTH SPEAR, TAG TOP OF FISH AT 10,834' DPM. PUSH FISH TO 10,840' AND ENGAGE FISH. POOH WITH FISH, OCCASIONAL DRAG OF 10-30K. RECOVERED UPPER PACKER AND ALL OF TAILPIPE ASSY. RIH WITH 4-1/8" X 3-1/8" MILL. 12/01/96- REAM TIGHT HOLE FROM 10,765' TO 109795'. RIH AND MILL FROM 10,859' TO 10,864' dpm. CIRC HI -VIS SWEEP. POOH, HEAVY OD WEAR ON MILL, MINIMAL ID WEAR INDICATING MILL DID NOT SWALLOW FISH. RIH WITH NEW 4-1/8" X 3-1/8" MILL. 12/02/96- CLEANED OUT FROM 10,862' TO 10,8641. MILL OVER TOP OF FISH FROM 10,864' TO 10,8669. BROKE THRU AND PRESSURED UP. CIRC HI VIS SWEEP. POOH WITH MILL, ID WEAR ON MILL INDICATES IT HAD BEEN OVER FISH. RECOVERED IRON, SCALE AND A FEW CHUNKS OF CEMENT. RIH WITH OVERSHOT. 12/03/96- OVERSHOT ASSY HUNG UP AT 10,781' dpm. JAR LOOSE WITH 60K OVERPULL. ATTEMPT TO ROTATE THROUGH TITE SPOT, NO PROGRESS. POOH WITH OVERSHOT. RIH WITH 4-1/8" STRING MILL. REAM AND DRESS CASING FROM 10,772' TO 10,782' dpm. NO RESISTANCE FROM 10,782' TO TOP OF FISH AT 1 "eULffV HI VIS SWEEP, POOH WITH STRING MILL. JAN 0 3 1997 Alaska Oil & Gas Cons. Commission Anchorage 12/04/96- RIH WITH 4-1/8" MILL SHOE WITH 2.8 FT SWALLOW. HYDROMATIC BRAKE FAILURE ON RIG, 9 HOURS DOWN TIME. TAG AND CLEAN OUT OVER FISH AT 10,8651, BOTTOMED OUT WITH PRESSURE INCREASE. 12/05/96- CIRC HI VIS SWEEP, POOH WITH MILLING SHOE. RIH WITH OVERSHOT ASSY. TAG FISH AT 10,865' dpm, ENGAGE FISH WITH OVERSHOT. JAR TO ATTEMPT TO RELEASE PACKER, DROP BALL AND SHEAR OUT CIRC SUB, CONTINUE JARRING. MAIN DRUM CLUTCH FAILED, CONTINUE CIRC WHILE REPAIRING CLUTCH. 12/06/96- REPAIRED RIG (11.5 HOURS DOWN TIME). RESUMED JARRING ON PACKER, CAME FREE, PULLED HARD (210k OVERPULL) FROM 10,865' TO 10,8501. CIRC BU, NO GAS. POOH TO 10,737', PACKER CAME FREE. CIRC SMALL AMOUNT OF GAS OUT. POOH WITH PACKER ABOVE 5" LINER TOP AT 62029. MONITOR WELL, HOLE TAKING ONLY 1 BBL/HR. 12/07/96- CONT POOH WITH PACKER. RETRIEVED PACKER BODY BUT LEFT LOWER MANDREL OF PACKER (+/-10") AND SHIFTING RING PLUS 23' OF TAIL PIPE. ALSO LEFT PACKER RUBBERS IN HOLE. THE BREAK IN LOWER PACKER MANDREL WAS RAGGED INDICATING FAILURE OCCURED RECENTLY, DURING JARRING. TEST BOPS, WITNESS WAIVED BY AOGCC AND BLM. RU SLICKLINE, TAG TOP OF FISH AT 10,872' WLM. RD SLICKLINE. RIH WITH 4-1/8" X 2-3/8" MILL SHOE TO DRESS FISH. 12/08/96- PU KELLY AT 10,8571, UNABLE TO CIRC OR SHEAR OUT. TAG FILL AT 10,8671, MILL DRY FROM 10,867' TO 10,8731, HARD MILLING OVER LAST 2'. PULL 40K OVER TO PU. POOH WET, LAST STAND PLUGGED WITH ASPHALTENES, LOWER 2' OF MILL PACKED WITH FINE SAND, METAL PIECES AND RUBBER, NO WEAR ON CARBIDE MOUTH. RIH WITH SAME MILL SHOE ASSY. BREAK CIRC AT 20 STAND INTERVALS TO 10,7009. CIRC IN WITH SINGLES, HOLE TRYING TO PACKOFF. CIRC TO MOVE FILL ABOVE BHA. 12/09/96- CIRC IN WITH SINGLES TO 109857'. PU KELLY AND MILL OVER FISH FROM 10,8739-10,876.5'. CIRC HI -VIS PILL. POOH, WEAR ON BOTTOM AND INSIDE OF MILL BUT NOT ON 2-3/8" THROAT. RIH WITH OVERSHOT TO 10,8559, ROTATE AND CIRC AND ATTEMPT TO CATCH FISH AT 10,8761. POOH. 12/10/96- CONT POOH, NO RECOVERY, THROAT AND FACE OF 2-3/8" GRAPPLE INDICATED START OF FISHING NECK. RIH WITH 4-1/8" X 3- 1/16" MILL. TAG FISH AT 10,8749, MILL TO 10,8799. PUMP HI -VIS SWEEP, POOH. 12/11/96- POOH WITH 4-1/8" X 3-1/16" MILL, GOOD WEAR ON BOTTOM OF SHOE AND THROAT, RECOVERED PIECE OF SHIFTING RING IN TOP OF SHOE. RIH WITH 3-1/16" OVERSHOT, WORK THRU TITE SPOT AT 10,700'. ENGAGE FISH AT 10,878'. JAR UP TWICE WITH 35K OVERPULL AND 50K OVERPULL, APPEARED TO FREE FISH. HOLE TAKING FLUID AT 11 BBL/HR. DROP BALL TO SHEAR OUT CIRC SUB, CIRC BU, NO GAS, LOSSES AT 12 BBL/HR. POOH AND RECOVERED 7.35' OF FISH INCLUDING "S" NIPPLE AND 5.36' PIECE OF BLAST JOINT. BOTTOM OF FISH WAS WASH CUT AND BURRED SLIGHTLY. 12/12/96- RIH WITH WASHPIPE /OVERSHOT ASSY. WASH FROM 10,889- 109895'. QUIT DUE TO HIGH TORQUE AND LACK OF PROGRESS. CIRC HI -VIS SWEEP AND POOH. HEAVY WEAR ON BOTTOM OF SHOE. RIH WITH 3-1/16" OVERSHOT. 12/13/96- ENGAGE FISH AT 10,8851, JAR WITH 60-80k OVERPULL. FISH CAME FREE, DROP BALL AND SHEAR OUT CIRC SUB. CIRC BU. POOH, RECOVERED ENTIRE REMAINING FISH INCLUDING MULESHOE. IRON STRIP 24" LONG X 1-1/2" WIDE WRAPPED AROUND BLAST JOINT. TOP OF FISH INTERNALLY PACKED OFF WITH 1.25" od PIPE INSIDE AND SMALL BRAIDED LINE. RIH WITH CLEANOUT JUNK MILL ASSY. WASH FROM 10,8539-10,8861, COULD WASH NO DEEPER. PU KELLY. 12/14/96- MILL FROM 10,886'-10,904'. HIGH TORQUE AND PULLED TIGHT WITH 65K OVERPULL TO GET FREE. CIRC HI -VIS SWEEP. POOH LD DRILL PIPE. RUN COMPLETION: 2-3/8" X 5" PACKER, 2-3/8" JEWELRY, 2-7/8" TUBING, 3-1/2" TUBING. 12/15/96- FINISHED RUNNING COMPLETION. DROP BALL AND PRESSURE TUBING TO 1500 PSI TO SET PACKER AT 109668'. PRESSURE UP TO 2450 PSI TO SHEAR BALL. TEST ANNULUS TO 1500 PSI. ND BOPS, NU TREE AND TEST TO 5000 PSI. RELEASED RIG AT MIDNITE 12/15/96. FINAL REPORT. RIG STACKED ON 12A-10 PAD. UNOCALID D` RKB to TBG Head = 23.00' PBTD =10968' TD =11065' MAX HOLE ANGLE = 25* @ 8000' Swanson River Field Well # SCU 12A-10 Actual Completion 12/15/96 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" 10774 1 1662 Surf 50' 10-3/4" 40.5 K-55 dummy, RK latch Surf 2090' 7" 29 N-80 Buttress Surf 81' 7" 23 N-80 Buttress 81' 2905' 7" 29 P-110 8rd LT&C 2905' 8480' 5" 18 N-80 x 5" 6202' 11063' Tubing: 10 10744 2-3/8" shear out sub 3-1/2" 9.2 N-80 Butt AB Surf 6042' 2-7/8" 6.4 N-80 Butt SC 6042' 1028' 2-3/8" 4.6 N-80 Buttress 10628' 10,744' JEWELRY DETAIL NO. Death Item r��t�►tivtD 11 to 10,909' with rig WO 12/14/96 p►� 3 1997 AIMMI01 & Gas Cons'WM' p► dow 23.00 3-1/2" buttress tbg hgr w/ TOP BTM ZONE SPF DATE COMMENTS Cameron Type H-3 BPV profile 10774 1 1662 Camco 3-1/2" KBUG ghn w/ 1" dummy, RK latch 2 2982 Camco 3-1/2" KBUG glm w/ 1" dummy, RK latch 3 4141 Camco 3-1/2" KBUG glm w/ 1" dummy, RK latch 4 5109 Camco 3-1/2" KBUG glm w/ 1" dummy, RK latch 5 5996 Camco 3-1/2" KBUG glm w/ 1" dummy, RK latch 6 6042 3-1/2" x 2-7/8" crossover 7 10628 2-7/8" x 2-3/8" crossover 8 10668 Baker Model FH Retr. Pkr, 2-3/8" x 5" 9 10711 2-3/8" "X" nipple 1.875" ID 10 10744 2-3/8" shear out sub r��t�►tivtD 11 to 10,909' with rig WO 12/14/96 p►� 3 1997 AIMMI01 & Gas Cons'WM' p► dow SC1210AC.DOC REVISED: 12/27/96 DRAWN BY: TAB PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10752 10774 H-1 4 1/6/94 10823 10838 H-3 4 1/16/76 10860 10886 H-5 4 1/15/76 SC1210AC.DOC REVISED: 12/27/96 DRAWN BY: TAB W UNOCAL706 P. O. Boz 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax December 30, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Soldotna Creek Unit Well #12A-10 API #50-133-20206-1 Form 10-404, Report of Sundry Well Operations Dear Commissioner Johnston: ORIGINAL Enclosed is the Form 10-404 Report of Sundry Well Operations for Soldotna Creek Unit Well No. 12A-10. Also attached is a post-workover wellbore schematic and a daily summary of the rig workover operations. The rig workover on this well pulled tubing, removed an upper packer assembly and then removed a lower packer assembly which contained a stuck plug preventing production from the Hemlock H-5 perforations. A single completion was then run and production resumed on gas lift. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, Dale Haines V Drilling Manager JAN p 3 1997 Unocal -Anchorage Araeim ON & Gas Cone. Comm; Anchorage u AOGCPOST.DOC 1 12/27/96 f� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x Exploratory: 14Y KB feet 3. Address 7. Unit or Property name P. O. Box 196247 Stratigraphic: Soldotna Creek Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 684' FNL & 576' FEL of Sec. 9, T8N, R9W, SM SCU 12A-10 At top of productive interval 9. Permit number 356 south and 45T east of surface 75-57 At effective depth 10. API number 356 south and 45T east of surface 50- 133-20206-Q r S 11. Field/Pool At total depth 356 south and 45T east of surface Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11,065 feet Plugs (measured) true vertical 10,904 feet Effective depth: measured 10,968' feet Junk (measured) ORIGINAL true vertical 10,811' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 50' 22" yes Surface 2090' 10-3/4" 1300 sx 2090' 2090' Intermediate Production 8480' T' 700 sx Iwo$ 8456' Liner 4861' S" 357 sx 6202'-11063'1� A Perforation depth: measured 10752'-10774', 10823'-10838', 10860'-10886' RECEW'ED true vertical 10594-10616, 10668'-10682', 10704-10730' 2 1 1996 Nov Tubing (size, grade, and measured depth) 3-1 /2" 9.2# N-80 to 608T, 2-7/8" 6.4# N-80 to 10,630' �mm►asion Packers as Cons. A188kS OH & pnchorape and SSSV (type and measured depth) Baker FH 2-3/8'x 5" packer @ 10670' 13. Attachments Description summary of proposal: Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 11/25/96 Oil: X Gas: Suspended: 16. If proposal well verbally approved: Name of approver Date approved Service: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: 4QaAlc4tw. Dale Haines Title: Drilling Manager Date: AR C l FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Testes Location clearance --aat) Mechanical Integrity Test Subsequent form required 10- 11.D4{ unginai DaVid W. Johnsluv Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 Approved COPY 03 td SUBMIT IN TRIPLICATE urn UNOCALIS P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax November 21, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Soldotna Creek Unit Well #12A-10 API #50-133-20206-1 Form 10-403, Sundry Notice to Repair Well Q i kt Dear Commissioner Johnston: Unoc proposes al ro oses to restore production to the Soldotna Creek Unit Well # 12A-10 with a rig workover. This workover will remove a plug which is stuck in the lower packerand coiled and production from the Hemlock H-5 perforations. Several tubing fishing attempts have been unsuccessful in removing the plug. detailed operations Attached in triplicate are the 10-403 form with BOPafter schematic, swork. Estimated start program and wellbore schematics of before ean and consideration of this proposal would be date is November 251 1996 so your timely appreciated. This will be the last rig workover for 1996 at the Swanson River Field. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, 7�Y 4 RECEIVED Tim Billingsley NOV 2 1 1996 Alaska Oil & Gas Cons. Commisslon Anchorage 1 11/20/96 u aocccovE.voc UNOCAL Swanson River Field SCU 12A-10 Workover Program 11/20/96 Objective: Workover SCU 12A-10 to remove a stuck plug in the lower packer assembly. Status: Hemlock producer, H-5 perfs are shut-in due to a plug stuck in the lower packer assembly. Well design: Pull tubing, remove upper permanent packer assembly, remove lower packer assembly containing stuck plug, rerun single packer completion Estimated BHP of Hemlock in all benches is 3200 psi @ 10596 TVD top pert = 5.8 ppg I. Rig Workover Procedure 1 Just prior to rig move, pump sized salt pill and displace to perforations with lease water. Note: Notify BLM and AOGCC 24 hours in advance of BOP tests. 2 MIRU Alaska Well Service RIG 5. . jOQ �.is r � 3 ND tree and NU BOPE with 3-1/2" and 2-7/8" pipe rams. 4 Pressure test BOPE to 3000 psi. Maximum surface pressure expected is less than 3000 psi. (Hemlock reservoir pressure is only 3200 psi) 5 . Pull 3-1/2" x 2-7/8" tapered tubing string above Model D packer at 10,670'. "pQ-r P\"x 6 RIH with 4-1/8" metal muncher mill assembly and mill packer at 10,6701 . 7 Circulate out any gas beneath packer. 8 RIH and tag released Model D packer on top of lower packer assembly. 9 POOH with mill assembly. 10 RIH with 2" spear assembly with 2.688" grapple. 11 Engage released Model D packer with spear and POOH slowly. 12 RIH with 4-1/8" x 3-1/16" ID milling shoe assembly. 13 Mill/dress top of lower packer assembly a minimum of 12" (1 foot) to leave a stub for overshot. ldwarr IA4 e /046a�c 14 POOH with milling shoe assembly. u AOGCPRO.DOC 1 11/20/96 UNOCAL Swanson River Field SCU 12A-10 Workover Program 11/20/96 15 RIH with 3-1/16" overshot assembly with circ ports and engage stub with overshot. 16 Attempt to release Baker FH packer with 40K lbs overpull at the packer. If pulling does not release packer, attempt to release by 12-15 turns at packer. 17 After packer releases, circ out gas bubble underneath packer. 18 POOH slowly with lower packer assembly. 19 RIH with 4-1/8" mill/casing scraper cleanout assembly. 20 Circ and rotate if necessary to clean out fill to approximately 10,918. 21 POOH laying down drill pipe. 11. Run 2-3/8" Completion: 1 Run 3-1/2" x 2-7/8" tapered tubing with a 2-3/8" x 5" retrievable packer at 10,670. (4 GLMs in the 3-1/2" section) 2 Drop ball and set packer. Pressure test annulus to 1500 psi. 3 ND BOPE, NU tree. Demobilize rig. III. Post -rig Work: 1 RU slickline. 2 Run GI -Vs as specified by production engineer. 3 Gas lift well and turn over to production. u AOGCPRO.DOC 2 11/20/96 UNOCALIS D` RKB to TBG Head = 23.00' PBTD =10968' TD =11065' MAX HOLE ANGLE = 25" @ 8000' Swanson River Field Well # SCU 12A-10 Proposed Completion 12/96 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" 3000 Camco 3-1/2" MGG glm with dummy la Surf 50' 10-3/4" 40.5 K-55 2a Surf 2090' 7" 29 N-80 Buttress Surf 81' 7" 23 N-80 Buttress 81' 2905' 7" 29 P-110 8rd LT&C 2905' 8480' 5" 18 N-80 6202' 11063' Tubing: 3-1/2" 9.2 N-80 Butt AB Surf 6087' 2-7/8" 6.4 N-80 Butt SC 6087' 10,630' 2-3/8" 4.6 N-80 Buttress 10630' 101710' RECEIVED Prov 2 1 1996 JEWELRY %qC& Gas Cons. Commission NO. Denth Item Anchorage 1/96 - 10,918' WLM 23.00 3-1/2" buttress tbg hgr w/ TOP BTM Cameron Type H-3 BPV profile 1 3000 Camco 3-1/2" MGG glm with dummy la 4500 Camco 3-1/2" MGG glm with dummy 2 5400 Camco 3-1/2" MGG glm with dummy 2a 5978 Camco 3-1/2" MGG glm with dummy 3 6087 3-1/2" x 2-7/8" crossover 4 10630 2-7/8" x 2-3/8" crossover 5 10670 Baker Model FH Retr. Pkr, 2-3/8" x 5" 6 10700 2-3/8" "X" nipple 1.875" ID 7 10710 2-3/8" shear out sub 1/96 - 10,918' WLM SC12AIOP.DOC REVISED: 11/20/96 DRAWN BY: TAB PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10752 10774 H-1 4 1/6/94 10823 10838 H-3 4 1/16/76 10860 10886 H-5 4 1/15/76 SC12AIOP.DOC REVISED: 11/20/96 DRAWN BY: TAB LX Last tag- 2/1/96 at 10,918' WLM 7 JEWELRY DETAIL 10843 NO. Depth Item Swanson River Field 8 UNOCALO 4 Well # SCU 12A-10 f 1\1 E Cameron Type H-3 BPV profile 5 1 Actual Completion 12/93, L. Pkr 1/76 RKB to TBG Head = 23.00' 10 2 CASING AND TUBING DETAIL Camco 3-1/2" MGG glm with dummy Tree connection: TC -3 Uni-bolt SIZE WT GRADE CONN TOP BOTTOM 10670 Baker Model D pkr w/SBE, �i (1.968" min ID in seal assy) 22" 5 Surf 50' 2-3/8" blast joint 6 10696 2-3/8" Wireline entry guide 12 10874 10-3/4" 40.5 K-55 Surf 2090' 2-3/8" blast joint 7" 29 N-80 Buttress Surf 81' 1 7" 23 N-80 Buttress 81' 2905' 7" 29 P-110 8rd LT&C 2905' 8480' 5" 18 N-80 6202' 11063' 2 3 Tubing: 3-1/2" 9.2 N-80 Butt AB Surf 6087' DV tool @ 2-7/8" 6.4 N-80 Butt SC 6087' 10,670' 7503 2-3/8" 4.6 N-80 Buttress 10682' 10,697' 2-3/8" blast joint tubing tail 10854' 10885 LX Last tag- 2/1/96 at 10,918' WLM 7 JEWELRY DETAIL 10843 NO. Depth Item 8 8 23.00 3-1/2" buttress tbg hgr w/ 4 f 1\1 E Cameron Type H-3 BPV profile 5 1 3 744 Camco 3-1/2" MGG glm with 3/8" orifice 10 2 5978 Camco 3-1/2" MGG glm with dummy 6 3 6087- 3-1/2" x 2-7/8" crossover 10852 4 10670 Baker Model D pkr w/SBE, �i (1.968" min ID in seal assy) 10,853'Cons. 5 10689 2-3/8" "X" nipple, min ID = 1.875" 2-3/8" blast joint 6 10696 2-3/8" Wireline entry guide Top of Fill Last tag- 2/1/96 at 10,918' WLM 7 7 10843 2-3/8" wireline entry guide connected to 10,849' PERFORATION DATA 8 8 BTM Brown "CC" safety joint, ID=1.937" 10/19/96 f 1\1 E 9 10844 Otis "XA" sleeve, ID=1.875" L.+ 10823 10 10 10847 Baker Model FH pkr, ID 1.978 10886 H-5 4 21 1996 11 10852 Otis S nipple, ID=1.875" with PS plug Stuck Plug, N �i (no pup between pkr and "S" nipple) 10,853'Cons. �amm1�&1°�` 2-3/8" blast joint Alas a 01t►s ra a 3 00 8 12 10874 2-3/8" Camco "D" nipple, ID = 1.562" PP 2-3/8" blast joint 13 10885 Bottom of 2-3/8" blast joint mule shoe MAX HOLE ANGLE = 25" @ 8000' SC12A10B.D0C REVISED: 11/20/96 DRAWN BY: TAB Last tag- 2/1/96 at 10,918' WLM PERFORATION DATA " TOP BTM ZONE SPF DATE COMMENTS 10752 10774 H-1 4 1/6/94 10823 10838 H-3 4 1/16/76 PBTD =10968' TD =11065' 10860 10886 H-5 4 1/15/76 MAX HOLE ANGLE = 25" @ 8000' SC12A10B.D0C REVISED: 11/20/96 DRAWN BY: TAB UNOCAL19 Fill -up -� Kill Line 2" 5000 psi Double Gate Single Gate Alaska Well Services Rig #5 10" BOP Stack 5000 psi Flow RECEIVED NOV 2 1 1996 Oil & Gas Cons. Comm,ssi J�%,fe Vim'" sr Anchorage a Choke Line 3" 5000 psi BOPSCRDOC REVISED: 11/20/96 DRAWN BY: TAB STATE OF ALASKA ALA: . OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ _ Perforate X_ Pull tubing _ _ Alter casing_ Repair well X_ Pull tubing _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X _ Union Oil Company of Califomia Unocal Exploratory __ Stratigraphic_ _ 149' KB feet 7. Unit or Property name 3. Address P.O. Box 196247 Anchorage, AK 99519 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 684' South and 576' East of NE Comer, Section 9, T7N, R9W SCU 12A-10 9. Permit number/approval number At top of productive interval 356' South and 457' East of surface 75-57/93-322 At effective depthORIGINAL 10. API number 356' South and 457' East of surface 50 133 20206-1 11. Field/Pool At total depth 356' South and 457' East of surface Swanson River—Hemlock 12. Present well condition summary Total depth: measured 11,065' feet Plugs (measured) true vertical 10,904' feet Effective depth: measured 10,978' feet Junk (measured) true vertical 10,821' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 50' 20" Yes 50' 50' Surface 2090' 10-3/4" 1300 sx 2090' 2090' Intermediate Production 7503' 7" 700 sx 7503' 7479' Liner 4861' 5" 357 sx 6202'-11063' 6202'— 110907' Perforation depth: measured 10760'-10772';10623'-10638'; 10860'-10866' true vertical 10594'— 10616'; 10668'— 10682; 10704'-10730' 0 Tubing (size, grade, and measured depth) See Schematic R C Ev Packers and SSSV (type and measured depth) See Schematic SRR 11 1994 13. Stimulation or cement squeeze summary Utl & Gas on Anchorage Intervals treated (measured) None Treatment description including volumes used and final pressure None 14. Representative DailV Average Production or Iniection Data Oil—Bbl Gas—Mcf Water—Bbl Casing Pressure Tubing Pressure Prior to well operation 1641 05 24 1325 2125 Subsequent to operation 292 9797 52 1400 3300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations x _ Oil x- Gas Suspended _ _ Service 17. 1 herelev ce tify t th fo goi true and correct to the best of my knowledge. Si ned G. Russell Schmidt Title Drilling Manager Date 04/04/94 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE SWANSON RIVER FIELD SCU 12A ->O ACTUAL GAS LIFT MANDRELS AS DETAILED 3/10/94 5" 18# N-60 @11,063' TD @ 119065' PBTD @10,978' RECEIVED L3 s CD A 1994 N Aa uc! & Gas Cons. Commissior' Anchorage y v a W A 3 1/2" 9.2# N-80 AB MOD 6087' (186 JTS) 10 3/4" 40.5# L 02090' TOP OF 5" @6202' 7" 29# N-80 BUTRESS B B) 2 7/8" 6.4# N-80 BUTRESS (147 JTS) @7503' X1 1) BAKER MOD "D" PKR @10,670' 2) SEAL BORE EXT. 010,673' 3 3) 6' 2 3/8" PUP JOINT 01002' X 4 4) ")' NIPPLE 010,689' 5 5) 6' 2 3/8" PUP JOINT @10,690' 6 6) WIRELINE RE-ENTRY GUIDE @10,696t 7) NEW PERFS @10,750-10,772' PERFS FROM 10,823-10,838' 6 8) WIRELINE RE-ENTRY GUIDE 010,643' 0 9) BROWN "CC" SAFETY JNT. @109844' 10 10) OTIS "XA" SLEEVE 010,844' 11 11) BAKER "FIS' PKR @1098459 12 12) OTIS "S" NIPPLE 010,852' PERFS @ 10,860-10,886' 13 13) 2 3/8" BLAST JNT. @109854' 14 14) 2 3/8" CAMCO "D" NIPPLE @10,874' 15 15) 2 3/8" BLAST JNT. @10,875' 5" 18# N-60 @11,063' TD @ 119065' PBTD @10,978' RECEIVED L3 s CD A 1994 N Aa uc! & Gas Cons. Commissior' Anchorage y v a W SCU 12A-10WO DAY 1 (11/23/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN INSPECT TUBING HEAD. DAY 2 (11/24/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN INSPECT TUBING HEAD. DAY 3 (11/25/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN R/U SLICKLINE UNIT. RUN 1.7" GAUGE RING TO 10,791'. R/D SLICKLINE UNIT. PREPARE & LEVEL (PAD FOR RIG). DAY 4 (11/26/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN R/U WIRELINE UNIT. RUN 2-3/8" CHEMICAL CUTTER, HUNG UP & WOULD NOT GO PAST 6810'. SET PLUG IN "S" NIPPLE AT 2'& TEST TO 1000 PSI. R/D WIRELINE UNIT. REMOVE FLOWLINES. DAY 5 (11/27/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN RECEIVEF RIGGING UP NORDIC RIG NO. 5,80% COMPLETE. APR 1 1 1994 iAi,3k 2Oil & Gas Cans. CoffillH,wL- .Anchorage SCU 12A-10WO DAY 6 (12/02/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' WELL SHUT IN RIGGING UP NORDIC RIG NO. 5,90% COMPLETE. DAY 7-9 (12/03-05/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER COMPLETED RIG UP ACCEPTED NORDIC RIG 5 AT 1300 HRS ON 12-3-93. MADE SLICK LINE GAUGE RING RUN TO 10,790'. R/U ATLAS WIRELINE TRACE GROUND FAULT. HOLD NUMEROUS PROBLEMS WITH ATLAS DEPTH COUNTER. SHOT CIRCULATION HOLES AT 10,761'. KILL WELL W/8.5 PPG LEASE WATER W/4% KCL. SET W.L. PLUG IN TUBING N/D TREE. N/U BOP. ATTEMPT TO TEST, HAD REPAIR LEAKS. DAY 10 (12/06/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER ATTEMPT TO TEST BOP, REPAIR VARIOUS LEAKS. DAY 11 (12/07/94) 10-3/4" a@ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER ATTEMPT TO TEST BOP, REPAIR VARIOUS LEAKS. TESTS HYDRIL, CHOKE MANIFOLD & UPPER PIPE RAMS. WELL BEGAN TO FLOW THROUGH PLUG. INSTALL LUBRICATOR. RECEIVED APR 1 1 1994 titasi,:a 0;11 & Gas Cons. Commissit Anchorage SCU 12A-10WO DAY 12 (12/08/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER RU SLICKLINE PULL PLUG. BULLHEAD 75 BBLS IN WELL TO KILL. RESET PLUG. FINISH BOP TEST. RETRIEVE PLUG. RIH W/CHEMICAL CUTTER. DAY 13 (12/09/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER CUT TUBING AT 10,7771, ATTEMPT TO P/U HANGER. HANGER STUCK IN WELLHEAD. CUT TUBING AT 3513'. PULL HANGER FREE. CIRCULATE POOH L/D HANGER AND 250' OF TUBING. P/U HOMCO STORM PACKER. N/U ON TUBING RIH SET AT 186'. TEST TO 1000 PSI. N/D BOP CHANGE OUT TBG SPOOL. DAY 14-16 (12/10-12/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER TEST BOP'S. RECOVER STORM PACK AT 189'. POOH L/D TUBING, RIH W/O.S. LATCH AT 3510'. PULL FREE. POOH L/D TUBING (TOF AT 10,777'). P/U 3-13/16" WASH PIPE. RIH PICKING UP 2-7/8" TUBING AS WORKSTRING. DAY 17 (12/13/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER TAG TOF WASH FILL TO TOP OF PACKER AT 10,794'. POOH L/D WASH PIPE. RIH W/O.S. DRESSED W/2-3/8" GRAPPLE. RECEIVED APR 1 1 1994 Aipska Oil & Gas Cons. Commis, SCU 12A-10WO DAY 18 (12/14/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER RIH LATCH FISH AT 10,777'. UNSET PACKER BY ROTATION. COULD NOT GET C.C. SAFETY JOINT TO BACK OFF. RIH W/STRING SHOT ON ELECTRIC LINE SHOOT ACROSS 'CC' SAFETY JOINT. SAFETY JOINT BACKED OFF. POOH. DAY 19 (12/15/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER POOH RECOVERING TOP PACKER, BLAST JOINT AND TOP HALF OF 'CC' SAFETY JOINT. P/U 'CC' RE-ENTRY GUIDE. RIH AND SET SAME IN 'CC' SUB AT 10,842'. POOH. R/U ELECTRIC LINE. DAY 21-22 (12/17-18/94) 10-3/4" @ 2090' 7" @ 6202' 5" LINER 6202' TO 11065' 8.5 FILTERED LEASE WATER RAN 3-1/211 TBG. (HYDRO -TESTED @ 5000 PSI). SPACED OUT. DISPLACED TO PKR FLUID. LANDED TBG. SET PX PLUG IN TBG TAIL. TESTED CASING @ 1500 PSI -OK. SET BPV AND REMOVED BOPE. INSTALLED AND TESTED X- MAS TREE. FREEZE PROTECTED TREE AND ANNULUS. R/D AND RELEASE RIG @ 2400 HRS 12/18/93. RECEIVE APR 1 1 1994 U;I & Gas Cons. Anchorage r.- 3 �ERFOR,_,_ATING RECORD COMPANY: GUN TYPE: IWELL:,,Poa=W FIELD: SIZE: y APS; -- - - o CHARGE: AFE#; ,2 S"/ SHOTS/FT: SERVICE CO: PHASING: • ENGINEER: M s UNOCAL WITNESS: Ao COMPANY: LAST PBTD TAG DATE: TYPE: ACA4, DEPTH: DATE: SLICKLINE OR E -LINE PROPO,ED INTERVALS TO BE PERFORATED PICKED BY: . 2S7LIr -.AAV-d DATE: DIL SAND/ TIE - IN LOG DEPTHS TOP BOTTOM BENCH TOP BOTTOM FEET a140, Wr 14 77Z z TOTAL: ACTUAL INTERVALS PE!&FORATEQ DATE COMPLETED: /-4_ f f WELL TEST DATA I � I TOTAL. •t•Z. j �OVER - RECEIVED Anchorage ALASKA: ,L AND APPLICATION STATE OF ALASKA GAS CONSERVATION FOR SUNDRY CG :FISSION APPROVALS 0,6 1. Type of request: Abandon Suspend Operations shutdown— Re—enter suspended well_ I' / _ _ Alter casing_ Repair well X Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California dba Unocal Development X_ Exploratory _ Sft igmphic _ 149' K.B. feet 3. Address 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 service Soldotna Creek Unit 4. Location of well at surface 8. Well number 684' South and 576' East of NE Corner, Section 9, T7N, R9WSCU 12A-10 9. Permit number At top of productive interval RECEIVED' 356' South and 457' East of Surface -5-.S' 10. API number At effective depthV -� i 356' South and 457' East of Surface 50-133-20206-1 At total depth o12.31ka Oil & Gas Cons. Commission 11. Field/Pool 356' South and 457' East of Surface Anchoraaa Swanson River -Hemlock 12. Present well condition summary Total depth: measured 11,065 feet Plugs (measured) true vertical 10,904 feet Effective depth: measured 10,978' feet Junk (measured) true vertical 10,821' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 50' 20" Yes 50' 50' Surface 2,090' 10-3/4" 1,300 SX 2,090' 2,090' Intermediate Production 7503' 7" 700 SX 7503' (See Diagram) 7479' Liner 4,861' 5" 357 SX 6,202'-11,063 6,202'-10,907' Perforation depth: measured 10,823'-10,838', 10,860'-10886' true vertical 10,668-10,682', 10,704'-10,730' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80,10,759'; 2-3/8% 4.7# N-80,10,759'-10,886' Packers and SSSV (type and measured depth) 18# Baker "FH" Packer @ 10,845, and 10,795' (SEE ATTACHED FCR DETAILS) 13. Attachments Description summary of proposal _ Detailed operations program_ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: December 5, 1993 Oil X Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17.1 her yrtiffy t the re ing t e and correct to the best of my knowledge. Signed Title ) �k(-U4G l t NK�AGE�- Date G , M N ,- 3 ry . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug Integrity _ BOP Test _ Location clearance _•? Mechanical Integrity Test Subsequent form required 10- 1w!& Approved Copy Returned Jriginal Signed By f' -f-y- V1 7 Approved by the order of the Commission I`nviri W Anhnofnn Commissioner Date it Form 10-403 Rev 06/15/88 SUBMIT A TRIPLICATE M �� 1-1 Swanson River Field SCU 12A-10 Workover Procedure 1. Rig up electric line and jet cut tubing @ 10,785'. 2. NMU. 3. Kill well. Set plug in "S" Nipple at 25'. 4. Nipple down tree and nipple up B.O.P. Test B.O.P. to 5,000 psi. 5. Retrieve tubing and fish top packer. 6. RM with wireline and perforate the casing at 10,750'-10,772.' 7. RIH with completion string 8. Pressure test tubing/casing annulus to 1,500 psi. 9. Install BPV; nipple down B.O.P. Nipple up tree; pressure test to 5,000 psi. 10. Release Rig. RECEIVED NO 18 1903 .�4.-1,a Oil & Gas Cons. Commission Anchorage ELEV 149+ K.80 _ �.` . �.• K.0. to TUBING 11ANGER ( 10" nHAFF WING HANOER W/ 3Y 23.Oc •, EUS THREAD3 ( TUD"O HANGER HAS u_ 8'UKKING NLUO HRS RATION) 07t 24.39+ 24" x * SUE X -OUR NIPPLE .61 24" OILS "S" NIPPL8, Position 13 1.61 50+ • 3 PUP JTS, 21" EUE 60,q N-•80 TUBING . . ' ( 8.00+ 10.00+ .10,000 1) 28.00 51 JIS. 21" EUS 6.51 H-80 TUBING 1693.47 1,657.ti7' CAMCO MM MANDREL W/DUMMY INSTALLED 8090 20090' 4? JT3, An Eus 6051 N-•80 TUBING 1320.44 2,986.61+ CAMCO MM MANDREL W/DUMY INSTALLED 8.68 33 JTS, 21" Eux 6.51 N -8o TUBING 1030.54 ---- 4.026.03+ CAMCO MM MANDREL W/DUMMY INSTALLED _ 9.03 23 JTS. 21" EUS 6.51 N-80 TUBING 719.85. ^ 4,754.91+ CAMCO MM MANDREL W/DUMMY INSTALLED 8.85 ' 16 JTS. 21". EUB 6051 11-80 TUBING 500.38 : 50 264' 14 + CAMCO MM MANDIM W/bffl Y INSTALIED 8.80 • 12 JT3. 24" . EUS 6.51 N•-80 TUBDiG 375.51 5,648.45+ CAMCO MM MANDREL W/DUW�Y INSTALLED 8.99' 10 JTS. 21" EUS 6.51 N-80 TUBU'0 315.30 •---- 5,972.74+ wico MK MANDnA W/CEV INSTALLED 8.89' -TOP b" $202' 8480% s s.: • 830' w1wDow . h 152 JTBi 2�," EU8 b.51 N-80 TUBING 4777.65, .e RECEIVED • J40V 18 1993 ----•-10,759.28+ " " ��_� CSI & Gas Cons. Commission 1.08 2% x 2 EUS X-OVFR : ;''..:.E Anchorage • 1 JT, 2%" EUE 4.71 N-80 TUBING 31.63+� 10,791.99+ OTIS "XA" SLEEVS 2088 10,79b.87� 24.1 x 5" a 181 BAKER "FH" PACKER(ROTATIN3 RELEASE) 5 47' 4 10,800.34+ OTIS "SO RIPPL90 Position A 1.54 •i 24" BLAST JT. 40.6, :1 823 io�b z.S2; " BROWN "CC" SAFETY JT. 1.42ke ' . 43.94 oris xA sLFiwl; 2081, 10,845.x1+ 2%" x y", 181, BAKtR' "FH" PACKER(ROTATINO ULe:ASE) 5•.47' 1o,85a.28+ OTIS "S" NIPPLE, Position 13 •1052+ 20301 � �•� •10, 874.10 + ?,111 CAlICO "D© N•I PLS � �+ :ion10,885,40+ 240 BUST JT. =X0.00 MULE SH09 COLLAR • •' t ~� TOP OF PLUG 10,978+ S.C.U. 12Am I ------ a CASING 81 TUBING DETAIL • SECTION 10 T. 7 N.R. 9 W.•:•� • -?*Do 11 065 +%r" _.-.�►rarac •,�►.� •itl►`vt,ev �,. 000 0 ........•, Y/�•,� . JV/.fi . hi Asoc w-,- Jww 4.11.7 Swanson River Field Proposed SCU 12A -1a 11/16/93 Gas Elft Mandrels as Specified 10-3/4" 40.5# 40 2,090'-j, 3-1/2" 9.2# N-80 Buttress @ 6100' Top of 5" 0 6,202' 7" 29# N-80 Buttress 0 7503' 2-7/8' 6.4# N-80 "em Downhole Jewelry 1 1. Baker Model D Packer a 10,700' 2 3 2. Seal Bore Extension 4 3. 101' 2-3/8" Pup Joint 5 4. X -Nipple 6 T 5. 101' 2-3/8" Pup Joint 6. Wireline Re-entry Guide 7A 7. New Paerfs a 10,750'-10,772' 8 7A. Old Perfs a 10,823'-10,838' 9 8. Wireline Re-entry Guide 10 9. Brown CC Safety Joint a 10,884' 11 10. Otis XA Sleeve a 10,884' 11. Baker FH Packer a 10,845' 12 12. Oils S -Nipple a 10,852' 13. Paerfs a 10,860'-10,886' 14. 2-3/8" Blast Joint 13 15. 2-3/8" Cameo D Nipple 16. 2-3/8" Cameo D Nipple 14 15 16 5" 18# N-80 0 11,063 'TD 0 11,085 PBTD @ 109978' RECEIVE[ Nov 18 191S3 tail & Gas Cons. Commission Anchorage Contract Exhibit E OPTION 1 FLOW FILL -UP KILL LINE 3„ 5000 psi ANNULAR BOP 10" 3000 psi PIPE RAMS 10" 5000 psi BLIND RAMS 10" 5000 psi DRILLING l SPOOL 10" 5000 psi PIPE RAMS 10" 5000 Dsi CHOKE LINE--� 3" 5000 psi UC�,�OQ��aO BOP STACK 10. 5000 psi RECEIVED 140V 1 1993 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/ New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wel Is in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of -the Bureau of Land Management Regulations. All 39 of the wells mentioned in -the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed i n Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB: JWR: ch:0006, v� �C� R Attachment -� r 1_ � ASG Gomm�ss10n cc.. C. V. Chatterton, Chairman Cots• Alaska Oil & Gas Conservation Commission p��& Pas a%$ Form approved. Form 3160-5SUBMIT IN Th.. &.ICATRO uMTED STATES Budget Bureau No. 1004-0135 Expires August 31, 1985 jNovember 1983) (Other Instructions on re- (Formerly 9-331) DEPARTMENT OF THE INTERIOR verse side) 5. LEASE DESIGNATION AND EERLL NO. BUREAU OF LAND MANAGEMENT S. IF INDIAN, ALLOTTEE OR TRIES NAME SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plus back to a dlQerent reservoir. Use "APPLICATION FOR PERMIT—" for such proposals.) 1. 7. UNIT AGRERIIENT NAME GAR WILL fa WRLL OTHER Soldotn Creek/Swanson River Uni 2. NAME OF OPERATOR 8. FARM OR L/ARE NAME ARCO Alaska, Inc. 3. ADDaiss or OPERATOR 9. WELL No. P. 0. Box 100360 Anchorage, AK 99510-OlAn 4. LOCATION Or WELL (Report location clearly and u accordance with any State requirements.* 10. FIELD AND POOL, OR WILDCAT See also space 17 below.) At surface Swanson River Field 11. EEC., T., R., M., OR EL=. AND Soldotna Creek Unit - 15 EVR.E oa .EEA Swanson River Unit - 22 wells _ 14. PERMIT NO. 15. ELRVATIONs (Show whether Dr, ", GE. etc.) 12. COONTtr OR FART/E 1 STATE I Kenai I Alaska 18. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Date NOTICE Or INTENTION TO: ou"549ENT R"OR? or: TEST WATER SHUT-OFF PULL OR ALTER CASING WATER SHOT -OFF R1PAIaINO WELL rRACTURE TREAT uULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASINO SHOOT OR ACIDIZR ABANDON* SHOOTING OR ACIDMINO AEANDONMENTO REPAIR WELL CHANGE PLANS (Other) ( Other)( NOTE : Report results of multiple completion on wo Temporarily abandon Completion or Recompletion Report and Log form.) 17. DESCRISF. PROPOSED OR COMPLETED OPERATIONS (Clearlystate all pertinput details, and give pertinent dates, Including estimated date Or starting anjj proposed work. If well is directionally drilled. Sive subsurface locations and measured and true vertical depths for all markers and stones per - nent to this work.) • As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 SRU 34-10 SRU 22-23WD SCU 13-4 SCU12A-10 SRU 14-15 SRU212-27 SCU323-4 SCU343-33 SRU 21-15 SRU314-27 SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 SCU 24-5 SCU 14-3 SRU 432-15 SRU331-27 ,v� SCU 33-5 SCU23B-3 SRU 34-15 SRU 34-28� SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 -- 'oiA I SCU21A-4 SRU43A-15 SRU 24-33 PUS � �mjssjon SRU312-22 SRU 12-34 g,GO SRU 21-22 SRU 21-34 jj & Gas �e P�ag�``a' �► 18. 1 hereby cert at the for in g i trae and correct SIGNET} Q , �" TITLE Rea�C1I181 Etlairleer Dsrs (This space for Federal or State once ase) APPROVED BY TITLE DATE CONDITIONS OF APPROVAL, IF ANY: 'See In*vctions on Reverse Side -r;«to tg tt,S.C_ Section 1001. makes it a crime for any person knowingly and willfully to make to any department or agency of the t Wells u.nder Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE 1 Wells being Evaluated for P&A/Future Utility 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until Blowdown 43A-15 314-27 331-27 343-33 6s � o � 74 G � 0 m � s o -- 3. N. 7 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until Blowdown 43A-15 314-27 331-27 343-33 6s TRANSMITTAL Al!'ACKNOWLEDGEMENT OF RECEIPT OF I�ERIAL - (ALASKA) TO: /, 1 %,e5l— & L DEPT.A(Ad PLACE: DATE FD - Folded R - Rolled . S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL S� CA L-.., S COj`'(PL 71 DIy S'cu 3y-(7 ;3(:�- DcT&I L j X ��C ( q - cr ROO g (-Tueal6y TV'6k FiL, -11. 7MA� A!. ,r 1-10 i,' BY RECEIVED BY REMA S ON OTHER SIDE, THIS SHEET HISTORY LOG 2" 5" 1 1 100 200 v TRANSMITTAL AND'` Y.NOWLEDGEMENT OF RECEIPT OF MA` ""- IAL - (ALASKA) TO:`iz,, r. iZ. Marshall State of Alaska. DEPT; D.z.vzs:.o� of oil i. 9()l Por_ Cu} 4 ne D-r.•ive PLAC2 Anc'.ioriz,_e, Alaska .99504 i DATE 'L- i�2, �f FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE'FOLL.OWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" .5" 100 200 S'c1CVEX Al 8 RD)� F Cu' It.vil 17 7F,S V- U11. AND GAS BY RECEIVED BY RE -ARKS ON OTHER SIDE, THIS SHEIET r - SUBMIT IN D!-_,.LICATE• STATE OF ALASKA ; See other In- structions on OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE reverse side; 50-133-20206-01 WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 6 LEASE DESIGNATION AND SERIAL NO. A-028997 Ia. TYPE OF 0 L GAS VELI, WELL � DRF ❑ Other 7. IF INDIAN, ALLOTTEE OR TRIBE NAME b. TYPE OF COMPLETION: NEW (—; WORK 71 DEEP- j� PLUG ❑ DIFF. ❑ Redrill ILI'T.,r i OVER l �I FN L_J BACK BESV Other _ — UNIT,FARM OR LEASE N. 2. Ir'AIfE OF OPERATOR PRODUCTION MI II10D (Flowing, ga.3 lift, Soldotna Creek STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. WELL STATUS (Producing or 9. WELL NO. S'C,'U 12A-10 3. ADDRESS OF OPERATOR __ P. O. Box 7-_839 Anchorage, Alaska 99510 10. FIELD AND POOL, OR WILDCAT Swanson River Hemlock 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* 1-23-76 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) At surfac 764' South and 576' West of the Northeast Corner of Sections T -7N, R -9W, S.B.&M Producing At top prod. interval re rterd below HOURS TESTED" Sec. 10, T -7N, R -9W, 3b3 364' South and East of surface location OIL—BBL. GAS—MCF. S.B.&M At total depth ' South and 446 East of surface location 'PEW PERIOD 12. PERMIT NO. 3S4 4J7 75-57 13. DATE SPUDDED 14. -DATE T.D. REACHED 15. DATE'COMP SUSP pR ABAND. 16. ELEVATIONS (DF, RKB, RT, GR, LTC)* 17. ELEV. CASINGHEAD 11-14-75 1 1-9-76 11 1-19-76 1 14 KB OIL—BBL. GAS--T,/ICF. WATERT--BBL. I&. TOTAL DEPTH, MD & TVD 9.'PLUG,, BACK MD & TVDr. IF MULTIPLE COMPEL.,21. INTERVALS DRILLED BY 10968' MD HOW MANY' ROTARY TOOLS CABLE TOOLS 11065' MD 10904' T1 1 1291 22. PRODUCING INTERVAL(S), OF THIS COMPLETION—TOP, BOTTOM, NAME (MD AND TVD)• WAS DIRECTIONAL Top 10823' MD 10668' TVD 123. t SURVEY MADE Bottom 10886' MD 10712' TVD Hemlock Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, BCS, FDC-CNL, CBL 25• CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, LB; FT. F GRADE DEPTH SET (MD) HOLE SIZE CEIALNTING RECORD A.'.4GUNT PULLED 20" 85# B 50' 2611 2 cu. ds. ready mix None 10 3/411 40.5# K-55 2090' 1511 1300 sks , None 711 )IQIQR M-00 1 1 7nr- L a'7 /019 IShoe w s s G cmt. AT--- r-ii wiI1UL) ILL1-11eU IUqtsU—OD.3a for reur111 26. LINER RECORD 27. TUBING RE ,URD SIZE Tpp ( ID) LOTTOPJI (MD) SACKS CEMENT* SC 'EEN (MD) SIZE DEPTH SET (MD) I PACKER SET (.MD) 5"1 6202 1 11063 1 357 1 See a tached 28. PERFORA'T'IONS OPEN TO PRODULMUN (interval, 10823 - 10838' Four 1/2" jet 10860 - 10886' f 4- 41. 111 CI 141 JOT, F;:A21 URE, C.'E'.ILNT SQJZ2ZE, ETC. DEiL' I INT (MD) Ail- )UNr AMID KIND OF MATE:1,IAL USED per oo - DIVISION OF Olt AND GA -3 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION MI II10D (Flowing, ga.3 lift, parnping—size and type of pump) WELL STATUS (Producing or :;,IuL-in) 1-23-76 <Flowin - _ Producing DATE OF TEST. HOURS TESTED" CI-IO_SE SIZEPI?OD'I'T FOR OIL—BBL. GAS—MCF. W,,'I'ERr-BBL. GAS -OIL RATIO 'PEW PERIOD 1-26-76 ____FLOW, 4 ' 215.17 1 46.3 1.0 215 TUBING CASING PRESSURE CALCULATED OIL—BBL. GAS--T,/ICF. WATERT--BBL. OIL GRAVITY -API (CORR.) PRESS. 24-HOUR RATE 260 1 1291 278 1 6 35.6 31 DISPOSITION OF GAS (Sold, used for Itel, vented, etc.) TEST WIT`tESSED By Injected back into field 32, LIST OF ATTACHMENTS DIL, BCS, FDC-CNL. CBL Tubina Detail TITLE Area Enaineer DATE *(See Instructions and Spaces For Additional Data on Reverse Side) 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attac htnents. Items 20, and 22:: If this well is completed for separate production from, more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcdocing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and; the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). AT1Y OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL. GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME h1EAS. DEPTH j"AUTt VIMT. DEP'I91, '16. C(ME DATA, AVI'ACH BRIEF DESCMR.MONS OF LITIIOLOGY, POROSITY. FRACTUT=. APPARENT" IMPS �� AND DVtTCC-rEI) SIIOWS OF OIL, GAS Oil WATER. COMPLETION REPORT REDRILL STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, I.NC. AREA: Swanson River Field LAND OFFICE: Anchorage Alaska PROPERTY: Soldotna Creek Unit LEASE NO: A--028997 WELL NO SCU 12A-10 ...API NO: 50-133-20206-01 LOCATION AT SURFACE: 684South and 576' West of NE corner Section 9 T.7N., R.9W. SM ..LOCATION .AT DEPTH: 356' South and .457' East of Surface ELEVATION: 149' K.B.. BY: R. . McKinley DATES February 4, 19.76 Area Engineer DRILLED BY: Nabors -Rig #5 DATE COMMENCED DRILLING: November 14, 1975 RIG RELEASE January 19, 1976 DATE OF INITIAL PRODUCTION January 19, 1976 SUMMARY TOTAL DEPTH: 11,065 PLUGS: 119065' - 109978' EFFECTIVE DEPTH: 101978' S. T. Plugs 8,512' - 8,533' 89533' - TD (412-10) CASING: 20" Cemented at 50` 10 3/4" Cemented at 2,090' Milled Window in 7" 8,480' -8,530' C.P. at 79503' 5" Liner Cement at 112063' Top of Liner at 6,202' S.T. 2,698.' of 7" Cement at 11,228 399' of 5" Cement at 11,555' PERFORATIONS: Four 1/2" hole per ft. 109860' - 102886' 10,823' - 101,838' LOGS: Schlumberger Dual Induction Log 8,459' - 11,042' 2" &-511 Borehole Sonic 82459' - 119042' 2" & 5" Formation Density 85,459' - 113,042.1 Compensated Neutron 89459' - 119'042' Go International Cement Band Log. 6,100' - 109966' 5" INITIAL PRODUCTION: Method: Flowing OIL: 1291 B/D WATER: 6 B/D GAS: 278 MCF/D GOR: 215 C F/D a . November .14, 1975 Rigged up to commence operations at 10:00 P.M. Mixed mud to 74 pcf. November 15, 1975 Killed well. Could not install Cosasco as it would not screw into tubing hanger. Made up safety valve on 2 7/8" tubing with 3 1/2" x -over. Removed-x-mas tree and installed safety valve and secured B.O.P..E. 74 pcf mud November 1.6, 1975 Completed B.O.P.E. and tested rams and choke manifold to 5000 psi. Tested Hydrill to 3000 psi along with Kelly cock and mud manifold, OK. Rigged to remove tubing string. November 17, 1975 Jet cut 2 7/8" tubing at 10,943' and recovered to 10,960'. Made up 5 3/4" ca ing scraper with Basket Grapple and started down hole. 74 pcf mud November 18, 1975 Engaged fish and recovered.563'-pulling fishing tools and total fish out. Prepared to run 368' of 2 3/8" tubing. November 19, 1975 With 2 3/4" tubing hung at 11,512' mixed and equalized 40 sacks of Class "G" cement blended with ,75% 353 sacks 0.31 to a slurry weight of 118 cu/ft. Displaced with 460 cu/ft of drilling mud. With #1 plug i.nplace, pulled up to 11,112' and reverse out 2 cu/ft of good cement. With 2 3/4" tubing at 11,112 mixed and equalized 60 sacks of Class "G" cement with .75% D-31. Displaced with 445 cu/ft of drilling mud. Cement in place, pulled up to 10,730' and circulated out.- Built mud weight and top plug with 30,000 lbs. at 10,887'. Close Rams and pressure tested plugs to 3000 psi for 15 minutes. Pulled out of hole. 74 pcf mud November 20 1975 ...Made up rolling equipment and started window in 7" casing at 8,480' A and milled to 8,509' (291). • 84 pcf mud November•21, 1975 Continued milling to 8,530' then pulled out to cement. With 3 1/2" drill.pipe at 8,580', mix 73 sacks of Class "G'.' cement blended with .75x D-31 to :a slurry weight of 123 pcf. Equalized plug with 432 cu/ft of drilling mud, cement in place in fifteen minutes. Pulled four stands and removed 20 cu/ft of cement. Re-entered hole, located top hard cement at 8,402' and drilled to 8,483'. Circulated and condition mud. 84 pcf mud November 22, . 1975 Drilled on cement from 8,483' to 8,533'. Circulated and pulled out to prepare for cement job #2. Mix and equalize 45 sacks of Class "0' cement blended with .75% D-31 with a slurry weight of .1.23• pcf. Equalized with 340 cu/ft drilling mud. Pumped :15 cu/ft.•. caustic water ahead and 20 cu/ft bentonite. Top cement at 8,,444". drilled out to 8,477'. 84 pcf mud November 23, 1975 Drilled 6" hole 8,4471 to 89512' (351) 85 pcf mud November 24, 1975 Drilled 6" -hole 6,402' where tool stuck. Worked free and pulled out to rig up new -6" bit and 7"x29# casing scraper. Ran in hole to 5000' circulated and circulated down to 8,474', pulled out. Checked B.O.P. 85.5 pcf mud November 25, 1975 Re-entered and oriented Dyna Drill drilling to 83,5451. 85.5 pcf mud November 26, 1975 Drilled 6" hole 895451 - 896011 (56t) 85. pcf mud November 27, 1975 Drilled 6' hole 8,6011 89639' (381) 85 pcf mud • December 7, 1975 Circulating and conditioning mud, pulled and repaired compound chain. Replaced 0il lines and Checked B.O.E. 97 pcf mud December 8, 1975 Drilled 6" hole ✓ 9,;20.3' - 9,326' (23') 97 pcf mud December 9, 1975 Drilled 6" hole ( Check B.O.E. ) 93,326' - 92390' (34') 97 pcf mud December 10, 1975 Drilled 6" hole 92390' - 99425' (35') 97 pcf mud December I1,- 1975 Drilled 6" hole 92425' - 99,458' (33') 97 pcf mud December 12, 1975 Drilled 6" hole 9,458' - 91534' (76') 97 pcf mud December 13, 1975 Drilled 6" hole 9,534' - 91553' (191) 97 pcf mud December 141 1975 Drilled 6" hole 9,553' - 91624' (711) 97 pcf mud December 153, 1975 Drilled 6".hole 996.24' - 9,752' (1281) 97 pcf mud November 28, 1975 Drilled 6" hole 82639' - 82715' (76') 85 pcf mud November 29, 1975 Drilled 6" hole 82715' - 82795' (801) 85 pcf mud November 30, 1975 Drilled 6" hole 82795' - 8.1895' (100') 85 pcf mud December 1, 1975 Drilled 6." hole • 8,895.' - 82971' (76') 85 pcf mud December 2 1975 Drilled 6" hole 8,9711 -.9,.1,0131t (60') 85 pcf mud December -3, 1975 Drilled 6" hole ( Check B.G.E. ) 92031' - 9,128' (97') 85 pcf mud _ December 4, 1975 Drilled hole _ 9,128' - 92161 (33') 85 pcf mud December 5, 1975` Drilled 6" hole 9,161' - 9,246' well started to flow water. Layed down drill pipe. Made up drilling assembly circulated out thru choke and raised mud to 90 pcf. drilling to 9,203'. December 6, 1975 Well still flowing, circulated with 94# cu/ft mud followed by a build up of 97# cu/ft mud. 97 pcf mud L December 16, 1975 Drilled 6" hole from 9,752' to 9,812' (60'). Well has been flowing water cut mud off and on during drilling. Have had to correct mud weight 98 pcf. December 17, 1975 Drilled 6" hole 91812T 9-,920' (1081) 98 pcf mud December 18, 1975 Drilled 6" hole from 9,920' to 10,115' (195'). Repaired air compressor. 98 pcf mud December 19, 1975 Air compressor and air valves were giving some trouble. Repairs were made and drilling continued to 10,201'. 98 pcf mud December 20, 1975 Drilled Vii" hole 10,9201' - 10,2921 (91' ) December 21, 1975 Drilled 6" hole . - 10,292' - 102376' (84') December 22, 1975 Drilled 6" hole 10,376' - 10,433' (Reamed) (57') December 23, 1975 Drilled -6" hole 101433' - 102506' (73') December 24, +. Repaired. B.O.P.'s and tubing hanger tie downs. Drilled 6" hole -101,506` - 109610t (104' ) 98 pcf mud 98 pcf mud 98 pcf mud 98 pcf mud 98 pcf mud December 25, 1975 Drilled 6" hole 10,610' - 109691 (Reamed) (81') 98 pcf mud December 26, 1975 Drilled 6" hole 105691' - 10,807' (Reamed (1161) 98 pcf mud December 27, 1975 Drilled 6" hole to 10,873' (74') and pulled to repair pipe rams, moving rams to top position. 98 pcf mud December 28., 1975 Drilled 6" hole " 10,873' - 11,0351 (162') 98 pcf mud December 29, 1975 Attempted to pull up pipe and stuck at 11,055. Made an attempt to jar fish down but without success. Jarred up on fish with 280,000 # but would not come free. Mixed Black Magic oil base spotting fluid at 93 pcf. Displaced with 60 barrels of drilling fluid. Jarred on fish at five.minute intervals while moving fluid at one barrel each half hour. 98 pcf mud December 30, 1975 Continued working fish. Made up and ran freepoint indicator to top of jars at 9,782' encountered obstruction. Worked around same and pulled out. 98 pcf mud December 31, 1975 Circulated and conditioned mud working free and recovering 37 joints and jars. Made up fishing assembly with new set of Dailey jars and attempted recovery. 98 pcf mud January 1, 1976 Pulled to repair rig replacing clutch and brake. Re-entered circulating on bottom. Screw into fish, using Black Magic mix could not work fish free after three and half hours jarring. Rigged up Dia Log and ran free point and found to be strck at third.drill collar. After eight rounds of torque, backed off with string shot. Recovered all fishing assembly leaving top of fish at 10,640'. 98 pcf mud January 2, 1976 CEMENTED FISH Entered and tag fish at 10,640' and found well wet. Circulated and conditioned mud to 98 pcf. Prepaired to cement around fish. Cemented twelve 4 3/4 drill collars; bit .sub, float sub, three strings and one near bit stab, and one gammaloy drill collar, with 43 cu/ft Class "G" cement, 118# slurry, with .75% D-31. Preceded cement with 109 cu/ft of water followed by 35 cu/ft water and 411 cu/ft mud. Reversed out water and small amount of cement. Equalized 98 cu/ft Class "G" cement with .75% D-31 from 10,640' to 10,140'. Preceded with 80 cu/ft water, followed by 26 cu/ft water and 396 cu/ft mud. Reversed out cement and closed B.O.P., downsqueezed, circulated and condition mud and pulled out. 98 pcf mud January 3, 1976 Rigged up drilling assembly and ran into hole, tagging cement at .10,431'. Drilled on soft cement to 10,460'. Continued drilling and polished off hard cement at 10,500'. Pulled to await directional tools. 98 pcf mud January 4, 1476 Entered hole with Dyna Drill and drilled from 10,500 to 10,5751. Pulled and made up Build assembly, returned to drilling finding tight spot on bottom. Work pipe and circulated reaming through - Dyna Drill hole from 10,525' to 10,552'. Drilled on that seem to be formation had no cement cuttings. Dropped survey pulling out. 98 pcf mud January 5,1976 Recovered survey and prepared to drill. Could not get through' tight spot at 6,303' and became stuck. Removed roller reamer and replaced with string stab and drilled to 10,626'. 98 pcf mud January 6, 1976 Drilled 6" hole 10,626' - 109674' (52') 98 pcf mud January 7, 1976 Drilled 6" hole 10,674` - 10,830' (1561) 98 pcf mud January 8, 1976 Drilled 6" hole 109830' 109925' (95') 98 pcf mud January 9, 1976 Drilled 6" hole 10,925' - 119065' (1401) 98 pcf mud January 10, 1976 Rigged up to run Schlumberger logs. Ran Dual Induction, Borehole Sonic, Formation Density, Compensated Neutron, from 8,459to 11,042. Removed_ logging equipment and ran into hole with Baker retrievamatic cementer. Tested bad spot incasingat 6,303'. Was unable to get below 6,417' with .5906" O.D. tool. Pulled up one joint and tested to 3000# for 15 minutes, OAK. Circulated out. 98 pcf mud January 11, 1976 With retrievamatic ran in hole and circulated and condition mud for casing job. Mud Gas cut (air) to 91 cu/ft in spots. Rigged up to run casing. January 12, 1976 CEMENTED 6,202' - 111,063' V_ LINER Ran 4,861' of 5" liner with 239 cu/ft of Class "G" cement with .75% D-31. Preceded by 88 cu/ft of water, followed by 21 cu/ft water and 724 cu/ft of mud. Drill pipe wiper plug bump after 271 cu/ft. Displaced and sheared at 7000 psi casing wiper plug, bumped after 495 cu/ft more mud displaced. Held 3500 psi for 5 minutes. Pulled out of 5" liner and shut well in to obtain breakdown rate of formation at 6 cu/ft per minute with 800 psi. Squeezed liner lap with 100 cu/ft Class "G" cement with .75% D-31. Reversed out large amount of cement and cement contaminated mud. Pulled and made up drilling assembly. Re-entered-and hit hard cement at 4,736 drilling through cement to liner hanger. Well began flowing, pulled and shut well in. January 13. 1976 Shut well in to allow cement to harden, approx. 24 hours with 700 psi casing pressure. With 88 cu/ft of water -displaced, washed out hole from 9,370' to 9,500', 70' below high pressure water zone. Water migrated up hole to 9,000' - 9,300' over balance on high pressure zone was lightened 75 psi and well started flowing. Rigged up and squeezed liner lap with 75 sacks of Class "G" cement with .75% D-31 preceded cement with 100 cu/ft of water followed by 50 cu/ft of water and 268 cu/ft of mud. With cement in place, squeezed 12 cu/ft of mud down annulus to clear it. January 14, 1976 After,24 hours washed down to top of 5" liner at 6,202'. Tested casing and liner lap to 3000 psi for 15 minutes, OK. Pulled and checked B.O.P.E. repairing lock screws on tubing head. Re-entered and cleaned out hard cement to 10,968'. Circulated and recovered small amount of cement wiper plug. Prepared to cut mud weight. 98 pcf mud January 15, 1976 Decreased mud weight to 70 pcf. Rigged up to run Go International Cement Bond Log and ran same from 6,100' to 10,966'. Pulled and prepared to perforate 5" liner with Go International. Perforated four 1/2 holes from 10,860' to 10,886'. 70 pcf mud January 16, 1976 Continued perforations, perforating four 1/2 holes per foot from 10,823' to 10,838' Pulled Go International and ran in hole with -41/2" bit and tandum 5" casing scrapers to 10,978' circulated. Pulled out of hole and changed pipe rams to 2 7/8". 70 pcf mud January 17. 1976 Ran production string as programed. (See attached) Attempted to run Go International Neutron log but was unable to get below 10,840'. Pulled out and made up C.A. White wire line unit and ran sinker bars with spang and Hydraulic jars to 10,978', pulled out. January 18, 1976 Ran feeler gage to bottom. Re -rigged Go International and ran Neutron log from float collar to position packers. Pulled and removed B.O.P.E., installed x-mas tree and. tested to 5000 psi. Removed plug from "S" nipple and removed stop. Displaced well with Lease Crude in four hours. Closed well in. January 19, 1976 Re-entered hole with "D" plug on C.A. White wire line unit. Plug stopped high. Attempts to pump plug down cause it to shear off. Pulled and adjusted spring on retrieving tool. Entered and jarred plug free.. Changed plug, seated plug in "D" nipple, pressuring up to 3000 psi. Using B.J., bleed pressure off annulus to check packers. Packers set, pulled "D" plug. Completed trip out and ran in with shifting tool, opening bottom XA sleeve. Position 3 "S" plug set in profile below tubing hanger. Bleed off tubing annulus and released' rig, at 7:00 P.M. J. -W. Wilson - 4,026,03t _ 4,754.911 5,264.�4, 5,648.451 . 5, 972.741 - TOP 5" 6202' C.P . 75 03' 8480'. WINVOW 853©' 33 JTS. 2811 EUE 6,5# N-80 TUBING 1030.541 CAMCO MM MANDREL W/DUMMY INSTALLED 9eO3t" 23 JTS. 2 -T. -II EUE 6.5# N-80 TUBING 719.85, CAMCO MM MANDREL W/DUMMY INSTALLED ELEV 1491K,B. 16 JTS. 2%t1 EUE 6,5# N-80 TUBING 500.381 CAMCO MM MANDREL W/DUMMY INSTALLED 8.801 . 12 JTS. 2%11 EUE 6,5# N-80 TUBING 375051' CAMCO MM MANDREL W/DUMMY INSTALLED K.B. to TUBING HANGER ( 10/1 SHAFFER TUBING HANGER W/ Y41 23.001 1.. 8.891 EUE.THREAD ( TUBING HANGER HAS NO BLANKING PLUG PERFORATION) .78t ifl.,842.521 ` ^ 1'3,843.941 BROWN "CC" SAFETY JT. 1.421 k 10.s845 -81f OTIS t1XA" SLEEVE 21-11 x 5t1, le# BAKER 11 FH1I PACKER (ROTATING RELEASE) 2,871 5.47' o 2%11 x h1 EUE X -OVER NIPPLE .611 , a� N s t 20.301 . 3 2581{ CAMCO "D" NIPPLE 2411 BLAST JT. • 24-39121t1 OTIS 11S" NIPPLE, Position #3 1.611 - MULE SHOE COLLAR 4 1 S. G U 12A- 0 50, ;© ------- TOP- OF PLUG 10,0781 CASING & TUBING DETAIL . 3 PUP JTS. 2jII EUE 605,1 N-80 TUBING T.D. 11.o651 1 0: ( 8.001 10.001 10.001) 28.001 m o E 51 JTS. 21t1 EUE 6.5# N-80 TUBING 1693.47'. ;.tea o 1s657.ti7' CAMCO MM MANDREL W/DUMMY INSTALLED 8.901 �., 2.,0901 42 JTS. 2%11 EUE 6.5# N-80 TUBING 1320.441 2905' 2,986.81.' CAMCO MM MANDREL W/DUMMY INSTALLED 8.681= - 4,026,03t _ 4,754.911 5,264.�4, 5,648.451 . 5, 972.741 - TOP 5" 6202' C.P . 75 03' 8480'. WINVOW 853©' 33 JTS. 2811 EUE 6,5# N-80 TUBING 1030.541 CAMCO MM MANDREL W/DUMMY INSTALLED 9eO3t" 23 JTS. 2 -T. -II EUE 6.5# N-80 TUBING 719.85, CAMCO MM MANDREL W/DUMMY INSTALLED 8,85 16 JTS. 2%t1 EUE 6,5# N-80 TUBING 500.381 CAMCO MM MANDREL W/DUMMY INSTALLED 8.801 . 12 JTS. 2%11 EUE 6,5# N-80 TUBING 375051' CAMCO MM MANDREL W/DUMMY INSTALLED 8.991 10 JTS. 2111 EUE 6.5# N-80 TUBING 315e301 CAMCO MM MANDREL W/CEV INSTALLED 8.891 152 JTS. 2811 EUE 6,5# N-80 TUBING 4777.65' 10 759.28 s ' 218 it x 2s" EUE X -OVER 1,081 1 JT. 28'1 EUE 4.7# N-80 TUBING 31.63' 1.0,791.991 10,794.871 OTIS t1XAII SLEEVE 2.88, l©'800"34' 2VI x 5n 18# BAKER "FH" PACKER(ROTATING RELEASE) 5.47' - OTIS "S" NIPPLE, Position #4 1.54' 2411 BLAST JT. 40.64' . ifl.,842.521 ` ^ 1'3,843.941 BROWN "CC" SAFETY JT. 1.421 k 10.s845 -81f OTIS t1XA" SLEEVE 21-11 x 5t1, le# BAKER 11 FH1I PACKER (ROTATING RELEASE) 2,871 5.47' o _ 10,85.281 OTIS 'IS" NIPPLE, Position #3 1.521 10.,8711.101 2111 BLAST JT. 20.301 . tsS8fi 10,885..401 2581{ CAMCO "D" NIPPLE 2411 BLAST JT. 09u, 10,00 ._ _. - MULE SHOE COLLAR 4 1 S. G U 12A- 0 ;© ------- TOP- OF PLUG 10,0781 CASING & TUBING DETAIL . SECTION IO T. 7 N.,R. 9 W. T.D. 11.o651 GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB -SURFACE DIRECTIONAL SURVEY STANDARD OIL COMPANY COMPANY _ SCU 12A-10 & SCU 12-10 WELL NAME SWANSON RIVER FIKM LOCATION AL1 `25-D14 SINGLE SHOT_ JOB NUMBER TYPE SURVEY DATE THIS IS A RECORD OF A SUB -SURFACE SURVEY OF YOUR WELL a j We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence- Additional copies of your survey report can be made from the original by any blueprint company. E�ck�VE 0 FFH 91916 DIVISION OF {SII. AND GAS --CO E-LUI 4..d. RFP 4 RI JAN A R ;12# -UI -6 STANDARD 0I_L-0 M P A N Y O F C a -�.-Y_F Q.RN i_A W E L_L-N Q ._S_C_U-1 !_- -0 MAGNETIC SIN G E SHOT SURVEY K -S -E (,,,_E VAT -LO --1,5.8.-ET.. 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MllrshPall DATE _ DEPT.: D -; v _Ls a o;j o f: 0 J_ & C�a s FD - Folded 001 Porcia .i_n%;, R - Rolled p' nr. ive PLACE:_ Anchorage, A-aska 99504 S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" 5" 100 200 .71 r E"3 -T7 '. 6 ` IS!ON OIL AND GAS AWH60AC q RECEIVED BY BY REMARKS REMARKS ON OTHER SIDE, THIS SHEET 1 12. PERMIT NO. 75-57 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLFr CONDITIONS. December 1975 Directionally redrilled 6" hole from 8895' to 11.,065'. Stuck drill pipe at 110551. Fired string shot and backed off at 10640' leaving 415' of drill collar fish in hole from 10640' to 110551. JAN i-�C AE 14. I hereby certify that the foregoing is true SIGNED R. M. McKinley Area Engineer DATE _. NOTE—Report on this form is required for each c lendar month% regardless of the status of operations, and must be flied in duplicate with the oil and gas conservation committee brthe 15th of the succeeding month, unless otherwise directed. DIR Pbrrti No, P-4 STATE C. ALASKA SUBMIT IN DUPLICATE REV. 3-1-70 S. A I NUMERICAL CODE C. ENG, , - �---0 AND GAS CONSERVATION COMMITTEE 50-133-20206-01 MONTHLY REPORT OF DRILLING 6 6 LEASE DESIGNATION A\D S A-028997 A-028997 AND WORKOVER OPERATIONS 1 OIL® 'r. IF INDIAN, ALOTTEE OR TRIB NA. I-NG7 ❑ .. WELL LL OTHER WELL 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Standard Oil Company of California, WOI _ Soldotna Creek �_2.``0L 3. ADDRESS OF OPERATOR 9. WELL NO P. O. Box 7-839, Anchorage, Alaska 99510 SCU 12A-10 _� __ RE" 4. LOCATION OF WELL 10. F AND POOL, OR WILDC T 684' South and 576' West of the Northwest corner of Swanson River - mlo . Sec. 10; T -7N, R -9W, SB&M 11. SEC., T., RI ., M.. BOTTOM HO p - _ Sec. 10; T -7N , R-9 , FIWB&M 1 12. PERMIT NO. 75-57 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLFr CONDITIONS. December 1975 Directionally redrilled 6" hole from 8895' to 11.,065'. Stuck drill pipe at 110551. Fired string shot and backed off at 10640' leaving 415' of drill collar fish in hole from 10640' to 110551. JAN i-�C AE 14. I hereby certify that the foregoing is true SIGNED R. M. McKinley Area Engineer DATE _. NOTE—Report on this form is required for each c lendar month% regardless of the status of operations, and must be flied in duplicate with the oil and gas conservation committee brthe 15th of the succeeding month, unless otherwise directed. November 1975 Commenced operations 10:00 p.m. 11-14-75. Killed well with 74 pcf mud. Removed christmas tree. Installed class III B.O.P.E. and tested OK to 5000 psi. Fished out tubing and packers. Bridged hole with class "G" cement from. 10,887 11,512' in two 40 and 60 sack stages. Milled section in 7" casing from 8480' - 8530'. Bridged hole with 120 sacks of class "G" cement from 8444' - 8580'. Drilled out cement from 8444' - 8494' and redrilled 6" hole from 84941 - 88951. D C E��' F 0 L AND- ', `- 14. 1 hereby certify that the foregoing is true A. SIGNED R. M. McKinley M4 Area Engineer DATE A// NOTE --Report on this form is required for soch c lendar month% regardless of the status of operations, and must to filed In duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. rot``' NO' P__4 STATE OF ALASKA SUBMIT IN DUPLICATE REV. 3-1-70 S. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEEc: 50-133-20206-01 I G�:d 6 LEASE DESIGNATION AND S IA 90111\11!1_7 MONTHLY REPORT OF DRILLING (3 � - AND WORKOVER OPERATIONS A-028997 L 7. IF INDIAN, ALOTTEE OR TRI N M OIL GA8 WELL WELL 0 OTHER 2. NAME OF OPERATOR 8. LNIT,FARM OR LEASE NAME Standard Oil Company of California, W01 Soldotna Creek � 3. ADDRESS OF OPERATOR 9. WELL NO P. 0. Box 7-839, Anchorage, Alaska 99510 SCU 12A-10 4. LOCATION OF WELL 10. FIELD A_'VD POOL, OR WILDIT Swanson River Hemc 1. f^,'; T 684' South and 576' West of the Northeast corner of 11. SEOC�T�., R..',M., BOTTOM HO - Sec. 10• T -7N R -9W S.B.&M 10, T -7N, R -r- CU�';r�r��: Sec. 12. PERMIT NO. 75-57 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE, CONDITIONS. November 1975 Commenced operations 10:00 p.m. 11-14-75. Killed well with 74 pcf mud. Removed christmas tree. Installed class III B.O.P.E. and tested OK to 5000 psi. Fished out tubing and packers. Bridged hole with class "G" cement from. 10,887 11,512' in two 40 and 60 sack stages. Milled section in 7" casing from 8480' - 8530'. Bridged hole with 120 sacks of class "G" cement from 8444' - 8580'. Drilled out cement from 8444' - 8494' and redrilled 6" hole from 84941 - 88951. D C E��' F 0 L AND- ', `- 14. 1 hereby certify that the foregoing is true A. SIGNED R. M. McKinley M4 Area Engineer DATE A// NOTE --Report on this form is required for soch c lendar month% regardless of the status of operations, and must to filed In duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. October 79 1975 Re Seo' dot na Creek SCU NoAZA-10 Mr. R. M. ftKiftley Area r rd oil Company of California o Anchorage,, Alasta 99510 Dear Sir, Enclosed is the approved applitation.for permit to drill the above referenced well ata location in Sectim lo, Township 7R, Range 9W, Sid. Well samples, core chips, and a mud log are not required. A directional survey is required. Many rivers in Alaska, and their drainage systems have been classified as imortant for the Spying or migration of a►nadrowus fish. operations in these areas are submit to AS 150.70 and .the regulations promulgated there- under Title S,. Alaska Administrative Code). Prior to commcing operations you may be contacted by the.Habitat Coordinator"s office, Departaent of Fish and Pollution of any waters of the State is prohibited by AS 4 , Chapter o3, Article and the lat promulgated thereunder Title 18, Alaska Administrative code* o and by thefederal Water Pollution Control Act, as amended. Cdr to co m%9 operations you may be contacted by a rpretatie of the Department of Environmental conservation. A complete report will be required on the hb.SCU 412.1 Q well showing it to be plugged and abandoned* In the event of sussoe or abandoment.please q i ve this office adequate advance noti fi "tion so that we may have a witness pr+esen t . YeTY truly yoursY o. K. Gilbreth Jr. Chairman Alaska oil and Gas Conservation Comittee Enclosure cc Dwartnent of Fish , and s Habitat Section w/o encl. Dep&rtment of Envirormntal..nservation w/o encl. Departawt of Labor., Supervisor Labor Lair Compliance Division o Wil. Form 10 — 401 REQ. I - 1- 71 SUBMIT IN TRIF,TE (Other instruction, reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE - PERMIT TO DRILL OR DEEPEN. Ia. TYPE Or WORK _ DRILL ❑ DEEPEN ❑ Redrill /X/ b. TYPE Or WELL OIL GAS WELL DI WELL El OTHER ZONELE ® ZONE F,TiFI.D r, 2. NAME OF OPERATOR U Standard Oil Company of Californai, WOI, up seator 3. ADDRESS OV OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 684' South & 576' West of NE corner Sec. 9 T7N R9W At proposed prod. zone 1100' South & O' East of NW corner Sec 10 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE' 16.5 miles (approx) from Kenai 14, BOND INFORMATION: 100,000 Statewide #451&36 Amount 150,000 TYPE Natlonwid4surety and/or No. SL 6205862 15. DISTANCE FROM PROPOSED* le. NO. OF ACRES IN LEASE 17. NO. ACRES ASSIGNED LOCATION TO NEAREST TO THiS WELL PROPERTY OR LEASE.LINE, FT. +1000' 80 (Also to nearest drig, unit, if any) _ i 2500 18. DISTANCE FROM PROPOSED LOCATION' 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. + 1500, 11,033' Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START* GL 135' November 1975 API#50-133-20206-01 6. LEASE DESIGNATION AND SERIAL NO. A-028997 I. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT,FARM OR LEASE NAME Soldotna Creek 9. WELL NO. SCU Swanson River u. SEC., T.. R.. M., (BOTTOM HOLE OBJECTIVE) Sec 10 T7N R9W 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH quantity of cement ? T-2/ (XQ1st *We propose to redrill SCU 412-10 as per attached program.Well to be redesignated SCU-12A-10. D 4 CT 6 1 r5- 01 51 ARD GAS IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen "give data on present productive zone and proposed new productive Zone. If Qro�osal is to. drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowou$ preventer program: 24. I hereby certip awe Foreg _-57 j%,ancfoCCorrect 1 SIGNL'D -'�.t � DATE TITLE Area Engineer (This space for State office use) rnwnrrTnNR nr APPRnVAL_ IF ANY - SAMPLES AND CORE CHIPS R.EQUIRM MUD LO'G OTHER REQUIREMENTS: o YES NO o YES NO SEE TRANSMITTAL LETTER DIRECTIONAL SURVEY REQUIRED A.P.I. NUM` ERICAL CODE YES NO �Y ®- �� T 2 © 2- 06 - UCzoQer , y/zi PERMIT N APPROVAL DATE E APPROVED B TITLE Chairman D�,I,* October 7, 1975 *See Instructions On Reverse Sid* 60 PROPOSAL FOR WELL OPERATIONS PRO 316-1` REWORK OF SCU 412-10 (TO BE REDESIGNATED 12A-10) DISCUSSION Proposal: Rework SCU 412-10 to a location approximately 600' north and 600' west of present bottom hole location at H4 point. This well will be an 850' upstructure stepout in a N451W direction. Complete well in Hemlock 1-5 sands and set packers for GOR control. Redesignate SCU 12A-10. History: SCU 12-10 was completed in the Hemlock 1, 2, & 3 sands January, 1970. The l sand tested wet @ 1000 BWPD and the 2 & 3 snads would not produce. The well was subsequently deepened and completed June, 1972, in the 1-10 sands for water injection. The well was redesignated 412-10. The well flowed 2060 BWPD on clean up, but would not take water at 4000 psi. The well was acidized and placed on injection late 1972. Profile surveys indicated a 15' thief in the top of the 10 sand. The well was reacidized in October, 1973, for profile improvement. Cummulative injection is 1,200,000 barrels in the 10 sand. Water breakthrough in upstructure SCU 21-9 was experienced in early 1974. Water injection in SCU 412-10 was terminated by mid 1975, as water production in SCU 21-9 was up to 800 BWPD without benefit. SCU 412-10 as a water injector has no future value toward optimizing field performance or oil recovery. The tubing and casing in this well are in communication via a hole near 9773'. Reservoir and Geology: As shown on attached H4 point structure map, SCU 412-10 is structurally the lowest well in the SCU Fault Block. The base of the Hemlock 5 sand is at -10,747' SS or 97' below the original H-5 O/W contact. The top of the Hemlock 1 sand is at -10,594' SS. Since completion in 1970, no significant oil production has been obtained. SCU 43-9 was completed in the Hemlock 1-5 sands (H4 points is -10,622' SS) and has never produced significant quantities of water. SCU 21A-16 was recently completed in the 1-5 sands at -10,592` SS. Water cut is 210. SCU 31A-16 was tested wet in the 5 sand (H4 point is 10,650' SS). Therefore, the present O/W contact at the proposed SCU 12A-10 location is estimated at -10,620' SS. It is proposed to rework SCU 412-10 upstructure to encounter the H4 point at -10,600' SS. Reserves: Based on the volumetric sweep as shown on the attached structure map, there are 490,000 STB of oil to be recovered from SCU 12A-10. As this oil cannot be recovered at any other location, it is considered new reserves. nr D r J oil Ai l G Proposal for Well Operations PRO 316-1 2 Rework of SCU 412-10 Discussion Economics: Reserves: 490,000 bbl Payout: 1.6 years Initial Prod. 1200 BOPD Rate of Return: 100% Initial GOR: 2000 CFB DPI @ 7 1/2%: 1.65 Well Cost: 11000,000 PWP @ 7 1/2%: $582,000 The well cost utilized for economic analysis was increased from the PRO -316 estimate by 25% to account for reservoir, drilling and completion risk. Alternates: No alternates to recover these reserves were considered prac- tical. A stepout from SCU 41-9 is more costly and this well is a candidate for an upstructure rework for the Hemlock 8 sand. Risks •A. Wet 5 sand - the present O/W contact in the 5 sand is estimated at -10,620' SS based on well performance and recent completions in the Hemlock 1-5 sands. To properly minimize this risk, -10,600' SS is proposed as the H4 target. :B. High GOR Production - SCU 43-9 and SCU 14-3 have relatively high GOR production. SCU 41-9 has 1-5 and 8 sand open and is immediately up - structure of the proposed SCU 12A-10. Present GOR in this well is 10,000 CFB. To account for the risk of finding high ratio production, the initial GOR is assumed as 2000 CFB rather than at solution ratio. Reserves are also based on an initial 2000 GOR. AMID 4 - 6'1.'x. ,,,f �� ,r� f+i• �..e� Proposal for We Operations PRO 316-1 ,..k, 3 Rework of SCU 4. -10 Field: Swanson River Property and Well: SCU 412-10 (to be redesignated 12A-10) Surface Location: 684' S and 576' W of NE corner, Section 9 T -7-N, R -9-W, SB & M Bottom HoleLocation(At H-4 Point - Target): (a) Existing: 1079' S and 1312' E of surface location (b) Proposed: 416' S and 576' E of surface location Elevation: 149' KB, which is 13' above G.L. Total Depth: 11,555' Plugs: 11,555' - 11,540' Casing: 20" cemented at 50' 10 3/4" cemented at 2090' 7" cemented at 11,246'; 700 sacks around shoe and 700 sacks with 4% Gel through DV.at 7503'. Bottom 8,260' - 29# P-110 LT&C Next 2,905' - 23# N-80 Buttress Top 81' - 29# N-80 Buttress 11,246' Perforations: 5 - 1/2" holes at 11,031' (squeezed) 4 - 1/2" holes/foot 11,037'-11,055' (squeezed) 5 - 1/2" holes at 11,050' 2 - 1/2" holes/foot 11,040'-11,048' (reperforated) 4 - 1/2" holes/foot 11,064'-11,097' (original) 2 - 1/21' holes/foot 11,064'-11,097' (reperforated) 4 - 1/2" holes/foot 11,116'-11,126' 2 - 1/2" holes/foot 11,116'-11,126' (reperforated)''- 4- 1/2" holes/foot 11,128'-11,1.38' D E C E W E ; 4 - 1/2" holes/foot 11,170'-11,208' 4 - 1/2" holes/foot 11,512'-11,401' 4 - 1/2" holes/foot 11,379'-11,254' 4 - 1/2" holes/foot 11,2121-11,174' DAY'. %dv'1`` EDF 0111 A1,10. G 2 - 1/2" holes/foot 11,142'-1111381 H(,',�P" E 2 - 1/2" holes/foot 11,138'-11,120' (reperforated) 2 - 1/2" holes/foot 11,098'-11,064' (reperforated) 2 - 1/2" holes/foot 11,0551-11,040' (reperforated) Directional: Drilled directionally below 6720'. Maximum angle is 241. Junk: None. Tubing: See attached mechanical detail.. All sliding sleeves are closed. Only the shoe is open. Hole in tubing at 9773'. ComEletion: June, 1972, in Hemlock 1-10 intervals. As a water injector. Last Injection: Idle. Proposal for Well Operations PRO 316-1 Rework Of SCU 412-10 Blowout Prevention Consideration: 1. Potential Problems: 4 A. Gas: Gas may be encountered any time after releasing packers, during cleanout of 7" prior to abandonment and while redrilling. Care must be exercised at all times not to swab well. B. Water Entries: Extreme caution must be exercised while rework- ing. A mud weight of up to 98 pcf may be required to overbalance potential high pressure entries above the Hemlock. This well was originally drilled with 90-98 pcf mud from 9000' to TD without entry problems. C. Lost Circulation: The programmed mud weight of 85 pcf at KOP is the minimum which can be used to provide adequate overbalance for the zones above the Hemlock. Because of the low Hemlock pressure (4200 psi) in this part of the reservoir, lost circu- lation in these zones could definitely occur. LCM should be kept on hand at all times. D. Precautions: Any kicks should be handled by normal procedures. Drilling crews should be made aware of these methods and care must be exercised by every member at all times. The hole must be kept full. 2. Maximum Anticipated Formation Pressure: Est. 4350 psi at Hemlock H-4 Point (Target) Est. 5000 psi in gas sands above Hemlock 3. Maximum Possible Surface Pressure: 3700 psi 4. Blowout Prevention Equipment: A. As per "Operating Instructions D-17." B. Class III, 10" - 5000 psi for all work. Estimated Correlations and Depths: Marker Subsea Vertical KOP -81222 8,371 H-4 (Base H5, Target) -108,600 101,749 T.D. -10,750 10, 899 tDF OIL At -10 GA'D AIN,ICE41'4✓` ".l�1-. Measured 8,485 10,883 111,033 Proposal for Well Operations PRO 316-1 5 Rework of SCU 412-10 PROGRAM 1. Prior to rigging uo, open XA sleeve at 10,971'. Check casing x casing annulus for pressure. 2. Move -in rig. Mix 74 pcf mud. 3. Kill well by pumping down tubing and up tubing x casing annulus. 4. Install Cosasco plug and remove tree. 5. Nipple up 10" - 5000# Class III BOPE including 5000 psi blow and kill lines. Pressure test to 5000# and remove Cosasco. 6. Release packers and pull production equipment slowly to minimize swabbing. Examine jewelry for damages and note depths. 7._ Cleanout to below bottom of perforations at 11,5121. 8. Equalize cement plug in stages, if necessary, from effective depth to 10,850'+. Downsqueeze 100 lineal feet. 9. Run bit and locate top of cement. If necessary, recement to 10,850'+. DOG to witness. 10. Pressure test the 7 casing to 3000 psi with rig pumps for 15 minutes. 11. Condition mud to 85 pcf. 12. Mill a 40' window in the 7", 29#, P-110 casing from 8453' to 84931. 13. Plug the window with densified cement (126-129 pcf). Top of plug is to be 150'+ above top of window. Downsqueeze, leaving top of plug 50'+ above window. 14. Drill out cement plug to 2' below top of window. 15. Sidetrack original hole and directionally redrill 6" hole to a total depth of 11,033'. A directional plat will be furnished, but the target is the base of H5 sand (H4 point) deviated 850'+ in a N 450W direction. Note: Redrill operations will start with 85 pcf mud. The system is to be continually monitored and mud weight is to be increased only as required to combat high pressure entry. Excessive mud weight will result in serious loss circulation while drilling the Hemlock. I"' D L'[� OIL t� Proposal for Well Operations PRO 316-1 6 Rework of SCU 412-10 16. At T.D., condition mud for logs. Obtain a 1/2 gallon sample of drill- ing fluid before pulling out of the hole. 17. Run Schlumberger Dual Induction Laterolog with SP, BHC Sonic with SP, and Compensated Neutron - Density Log from T.D. to the 7" casing. A. Use linear scale for 2" DIL and logarithmic scale for 5" DIL. B. Use +10 MV SP scale and 0-50 ohm -meters for the linear DIL. 18. Cement approximately 2700'+ of 5", 18#, N-80 Buttress liner at total depth with sufficient Class "G" cement premixed with 3/4o CFR -2 to obtain returns above top of liner. Equip liner with 5" x 7", 29# Burns liner hanger grooved for•cementing. Allow for 200' of liner lap. A. Run float collar and float shoe. Float collar is to be one joint above shoe. 19. Clean out cement to float collar. 20. Run variable density cement bond- neutron - collar log from effec- tive depth to above top of liner hanger. 21. Pressure test 7" casing, 5" x 7" lap and 5" liner to 3000 psig for 15 minutes. 22. Condition mud weight to 68-70 pcf. 23. Jet perforate selected Hemlock sand intervals for production. 24. Run tandem 5" casing scrapers and scrape the entire 5" liner. 25. Run and hydrotest to 5000 psig 2 7/8" x 2 3/8" tubing, gas lift mandrels, and completion jewelry. A detailed completion program will be provided after T.D. logs have been run. 26. Remove BOPE and install xmas tree. Pressure test tree to 5000 psig. Displace drilling fluid down the annulus and up the tubing with lease crude oil. 27. Set production packers and release rig. Place well on production as directed. o/S Area Engineer O/S Area Supervisor R. M. McKinley DR E (0,Lzc [ �� 0 ,1 kd I it e 4 CDIL AMD CA1 Ay ,,,'C F• `C'H(�i � c DRILLING FLUID PROGRAM REWORK OF SCU 412-10 SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Medium treated Lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES PROPERTY IN 7" AND 5" WHILE. REDRILLING Weight - pcf 68 - 70 85 - AR* Viscosity - sec/qt., API 43 - 47 43 - 47 Fluid Loss - cc, API 4 - 7 7 - 10 (See 4) Plastic Viscosity - CPS 10 - 14 20 - 30 Yield Point - Lb/100 ft2 8 - 12 8 - 12 Gel - Lb/100 ft2- 10 min 0 - 5 10 max. pH 9.5 8.5 - 10 Calcium - PPM 50 max. 50 max. Solids Content Vol 6 - 10 10 - 18 *AR - As Required REMARKS - 1. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate supply of barite and LCM on location. 3. During milling and redrilling operations continually monitor (on 24-hour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT WELL IN AND RAISE WEIGHT. 4. Maintain fluid loss between 4 and 7 cc below the top of the Hemlock. /ll 243 43 Rb•c Iu34I-i0,?NP 1a,4oa' — 43A �, i / �rrrnrreasrrlr� 34 f 14 1 v - 21 P/ROPO ED pomlp _ 12 BOT. H E LOCATION 412 ; ► "ter r a r rrr� r lrr� r 3'2 A --10,404' • 32ABN- - 10,420' 323 43 9 ' Io G � 0 0� •Ip 622 00O f 34 - 421• l - 9No. I0'�39 - V t N HCP A G E - 3� 21 ~ / -10,677- ---' PORTION OF STRUCTURE CONTOUR MAP 10'569, SAMSON RIVER FIELD, ALASKA o/w --10" -'' !CONTOURS ON THE H4 POINT) �rarr®ri�rl�erai SHOWING ESTIMATED CAS SWf~EP PATTERN TO THE PROPOSED S C U 12A -- 10 LOCATION AND THE PRODUCING AND INJECTING INTERVALS IN THE ; SURROUNDING WELLS i TO ACCOMPANY PRO. 316-1 FOR REWORK r r�rl r r r i r r r Scale 1' = 1000' DATE: &rPTEME3FR 197`• - �� r_F, . wrr.< `Y- - ((� ._l �Y_T• � y.. :J'I.- ..1 AM•.ti/._r -.r. � � � i� `�-+••r • .i wr.-•, � ' ✓ - (`syr _ ...� ..r.�r..- - �_ . � .� � 1 .- � ' •A.••^ ..�"_ � { « 1 !� 7t._ • ,�_.�} �` t. � t i� � � � 1. i f.�. ��1 _, 1-��Y _- •---_---'�r"^"_ 1, _ y ' � } �� • i '—.�—,�1Z'=.__+_+_� _ i! _----_–+_ . � � --� .tet –1� I I {- - . 1 a ! IVJ le ' it .��—��F.-•.•-.s+ Y... � `t . � I � r�-`1�e''l'7 1 � . —` �rosN1++F�,^.m'+.r��''uS�.�.ivti9'ti�"�?-1 O' i ��..�� .--'f `---�`—� ^.-�- J ft ice. !• 1 1 , -;� rw et Al GAS -a•e..a ��'.' - f+•r••.i..a •t. , r•�s. •: -�'_•—^moi ., .�... •r•..l_. .rte.• � � - , A - 028384 4 /4-22A-028077 0 1' H. P. *31-27 c 1 ¢/-� •2/-27 - SOCAL-ARCO SOCAL-ARCO�•�os,� /2-27 212-27 3227 H. P. 43-28 • ;� •23-27 �. AXFORD ESTATE A-028399 y •34-28 4j14-27 (SOCAL-ARCO) ,. . 0 A 028406 0 22/ 33 41.33 21-34 1 4/-33W/ w • H. P ®32-33 0 2-34 f 1 31J. H. P 1 A-028396 2'- 43 33®/s , 1 b "! , A - 028990 ' ! I4 -34 a';4 33,.* 34 0 1 4- 24 3_=' 921- 4 341-4 21-3• j F42- 5.AXD Q (SOC Asz ARC ® 32-A-5 NALASKO-K/NG F. AX FORD 43-5 •23-4 243-4 � 1 1, OIL co o J� e� j�.3' N AL -ARCO) 4-A 1 r4 -5 SOL 9 O TNA CREEK ,4.4 X34-5 • •34-4 •14 3qf UNIT 2/-9 • 0 4/-9 R _ /p 1 /2 �d r../ H. q3;2-9 H. P im '32-A- 32-8 9 0 so r,.* 33-80243-8 023-9 ®43-9 /L�'/L� J" 1 e 43-8 _ F 034-8 44-e _ _ -028997 - 896 - i 034-9 (SOCAL-ARCO) tom 02/ ;� A-029002(3-5-72 12-16'.40►A F. AXFORD F. AXFORD 1 (SOCAL-ARCO) �.' (ARCO) e F AXFORD - 1 _34-16 (ARCO) SOCAL) H. P. H. P. AA -5810 1 ' SOCA MINK cK UNI T 14-2o AA- 5809 3 SOCAI wLDoTNA clr !/NIT 22A 32 1 '21 22-32 HBU A 028993 1 1 Chevron t L ► t� ;� 7 Standard Oil Company of California, Western Operations, Inc.-3�;��' P. O. Box 7-839 1 u } Anchorage, Alaska 99510 October 8, 1975 Redrill Proposal SCU 12A-10 Swanson River Field Divisim of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Thomas R. Marshall Gentlemen: The proposed well is a redrill of well SCU 412-10, which will be accomplished by plugging the existing hole and sidetracking to a location approximately 600 feet north and 600 feet west of the present bottom hole location for a Hemlock zone reccmpletion. Since the well is a deviated hole, it ccoes within the supe of Regulation 11 AAC 22.050, which requires notification of an affected operator in a quarter section directionally or diagonally offsetting any quarter section upon which the operation is proposed to be conducted. The proposed well is within the Soldotna Creek Unit portion of the Swanson River Field. The lands affected by this regulation outside the unit boundary are subject to leases held by Standard Oil Company of California as to 50% and Atlantic Richfield Company as to 50%. By carbon copy of this letter we are requesting Atlantic Richfield Company to forward to you a letter of non -objection to the proposed operations. If you should need further information, please advise. V , truly yours, (L 4t-, 3� Y I P. F. McAndrews JET:nh cc: Atlantic Richfield Company Attn: Mr. L. V. 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B G 59cOO' 11 ?25.20 [ x i --- _" B:C01 i rsSr-EMY JOL 109' 11j,229.591 } 11, 2 2e 47 --_i F. IP .CJ—"R 231; 5 5 : /4t 11254 —1-)UP As Q 2-7r," EUE Srd TU1371•; G 4 Jt:3. 2a" ELU Srd TUBEM . IIxTF 113u2) c0 ., s �,-s 11 , tt S1=,-VZ � I:� j � �� 2 ` F''t '1A'�•9 Lpi-MR Fele FAC--E R 23[; x 5"18401 o� A. 2' It LUES £rd 1UBL G - IS, SLEFIV ,• C �� . r~�EC - ,2.1' t 1 qtr ' altr 20" 1AF3 Srd TUB 'G • . + , -1115254 r± . C1�•,CO 12U"' I.; 1I'I=x211' CAL At••ID GAS r. 2 Jt ETUE ,Ir 7 UR G - � • 1111! Z� . �. ..., , �. ..`.�,•� ., � � .`t • . -- 11:515044. _...�.._._....�.....�.. J-t r,101 TOP OF 11LUG S c u 4 1 .a'. �.� : `• __._ 'I t' - r i ... A C ( 1\1 (':`. n. •T' I I(-, I\ I ^ I V: -T' h I I -.._. _ ADO I.//,a / f_�' ��7��' `� _ � �_ __�__ ..._ _ �_ .:�,_ - ....______..________---- �. - - • ... •di— ug P19 _ T�y(, I a OF CIL AND -G -AS �`+wwww.n•ti-••••� ..+....�w.w+•rwww.++ww.a. ....w..w...r•+.r.w � h. Ft'° �li.Pa�,^^+w."•.•....r.•..•�•ww.r�www+ww...w.r./a w••a•.+w OL Cid AD � O v cj UESQ"20 '• �`,'. k9 -UL ug P19 _ T�y(, I a OF CIL AND -G -AS �`+wwww.n•ti-••••� ..+....�w.w+•rwww.++ww.a. ....w..w...r•+.r.w � h. Ft'° �li.Pa�,^^+w."•.•....r.•..•�•ww.r�www+ww...w.r./a w••a•.+w 3. Is conductor string provided . . . . . . . . . . . . /�S A. CHECK LIST FOR NEW WELL PERMITS Company c�i�t-rJa rcl 01-/ > Lease & Wel l No. 5. Will Yes No Remarks 1. Is the permit fee attached . . . . . . . . . . . . . . . . . . ... . . 2. Is well to be located in a defined pool . . . . ... . . . . . . . . 3. Is a registered survey plat attached . . . . . . . . . . . . . . . . . 4. Is well located proper distance from property line . . . . . . . . .,r�E 5. Is well located proper distance from other wells . . . . . . . . . . � . 6. Is sufficient undedicated acreage available in this Pool . . . . . 7. Is well to be deviated . . . . . . . . . . . . . . . . . . . . . . 8. Is operator the only affected party . . . . . . . . . . . . . . . . 9. Can permit be approved before ten-day wait . . . . . . . . . . . . . , 0. Does operator have a bond in force . . . . . . . . ... . . . . . . . ,6�C 1. Is a conservation order needed . . . . . . . . . . . . . . . . . . 2. Is administrative approval needed . . . . . . . . . . . . . . . . . 3. Is conductor string provided . . . . . . . . . . . . /�S A. Is enough cement used to circulate on conductor and surface . . . . 5. Will cement tie in surface and intermediate or production strinas 6. Will cement cover all known productive horizons . . . . . . . . . . 7. Will surface casing protect fresh water zones . . . . . . . . . . . 8. Will all casing give adequate safety in collapse, tension & burst 9. Does BOPE have sufficient pressure rating . . . . . . . . . . . . . ldditional Requirements: w, w Cti,,. �" Gam,_ L7 'V^+ � .,..w.,. 12- 4.x`'3 Approval Recommended: Geolo v Engineering: TP.M Hl1K?/� . OKG HHH JAL LCS J C M Revised 1/15/75