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183-160
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 01/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: PBU 09-21 PTD: 183-160 API: 50-029-21036-00-00 Definitive Directional Survey - Definitive Directional Survey 03/04/2010 Main Folder Contents: Please include current contact information if different from above. 183-160 T39957 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 10:43:41 -09'00' By Grace Christianson at 8:04 am, Dec 18, 2024 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.17 16:12:44 - 09'00' Sean McLaughlin (4311) 324-705 * SFD 10-404 SFD 12/18/2024 SFD JJL 12/19/24 * Not a Plug for Redrill: The PBU 09-21 wellbore beneath the whipstock will not be isolated until the liner for PBU 09-21A is cemented. That portion of PBU 09-21 will be considered open and retain the status of "Oil" until it is permanently isolated. SFD Window milling not included on this sundry approval, see PTD forPBU 09-21. DSR-12/20/24 10-407 Approved alternate plug placement per 20 AAC 25.112(i) MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.24 12:03:40 -09'00'12/24/24 RBDMS JSB 123024 15523' To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: December 17, 2024 Re:09-21 Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 09-21 wellbore as part of the drilling and completion of the proposed 09-21A CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper, and MIT. E-line or coil will mill the XN-nipple. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 3-1/2"x7" whipstock. A single string 2.80" window + 10' of formation will be milled. The well will land in Ivishak Zone 2 and target Zone 2 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Dec 30th 2024) x Reference 09-21 Sundry submitted in concert with this request for full details. 1. Slickline : Drift, Caliper, MITs 2. Coil/E-line : Mill XN 3. wellhead/TS : Tree prep and pad prep Rig Work: (Estimated to start in February 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 3-1/2' x 7" Whipstock at 13,636' MD at 0 deg orientation. Mill 2.80” Window. 3. Drill build section: 3.25" OH, ~442' (40 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~1441' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr liner. RIH with 1" CSH and sting into ORCA valve. 6. Pump primary cement job: 28 bbls, 14.8 ppg Class G, 1.332(ft3/sk),TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Sundry approval for procedure above this line only. Steps below line will be addressed on PTD - JJL Per CTD discussion meeting on 12/9/24 variances to regulationsneed to requested. - JJL JJL Not a Plug for Redrill: If approved as proposed, the PBU 09-21 wellbore beneath the whipstock will not be isolated until the liner for PBU 09-21A is cemented. That portion of PBU 09-21 will be considered open and retain the status of "Oil" until it is permanently isolated. SFD Per CTD discussion meeting on 12/9/24 variances to regulations need to be requested. - JJL Post Rig Work: 1. Valve Shop : Valve & tree work 2. 1.5" Coil : CBL, perforate 1500' 3. Slickline : GLRD and/or LTP 4. Testing : Portable test separator flowback. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 324-705 SFD 12/18/2024NA PBU 09-21 Not a Plug for Redrill: If approved as proposed, the PBU 09-21 wellbore beneath the whipstock will not be isolated until the liner for PBU 09-21A is cemented. That portion of PBU 09-21 will be considered open and retain the status of "Oil" until it is permanently isolated. SFD SFD 12/18/2024 183-160 NA P8cA_oti-zl Rit 1631600 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, June 10, 2013 10:32 AM ) e q '/i'(,3 To: Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS F'S2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Well Integrity Coordinator Subject: UNDER EVALUATION: Drill Site 09 Producers with Sustained Casing Pressure on the Inner Annulus During Plant Shutdown Attachments: DS09 TIO and Wellbore Schematics.zip All, The following wells were found to have sustained casing pressure above MOASP on the inner annulus on 06/08/2013 during a plant shutdown . Each well is listed with the tubing/inner annulus/outer annulus pressures. The wells are reclassified as Under Evaluation to facilitate evaluation. 09-01 (PTD#1750760),TIO: 1810/2010/640 psi 09-11 (PTD#1760840),TIO: 2340/2340/140 psi 09-13(PTD#17700),TIO: 2050/2110/690 psi t 009-21 (PTD#1831600) TIO: 2000/20166/650 psi 9-46(PTD#19 30),TIO: 1380/2010/180 psi SCANNED ` Plan forward: 1. DHD: Place wells on production and perform TIFL If any of the TIFLs fail, the AOGCC will be notified separately for each failure. A copy of the TIO plots and wellbore schematics are included in the attached zip file for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator @bp.com 1 Q 40p FA0000 c., _O M � - I O 8 (51 O M 0) N 8 3 1 _ 3 r- O r3 I C7 co rJ '1 0 - i _ o co z N M co H u 25 co 8 O a C+1 CV r m1- O p CL 0_ co H TREE= FMC GEN 3 WELLHEAD= FMC 09-21 SAFE. !NOTES:***FLH/TIW HBBP PKRS HAVE ACTUATOR- . AXELSON REDUCED PRESSURE LIMITS IN SOME CASES. KB.ELE = 55' CONTACT(X5102)***-1/2"CHROME TBG*** B.E V.. ._..._ _'. BF.EL V= 17(' P= '.-.__._900' • Max Angle= 63°@ 4600' Q I 2199' I—J3-1/2°CAM BP61 SVLN SSSV NIP, ID=2.812" I Datum MD= 13569' Datum TV = 8800'SS GAS LIFT MANDRELS ST MD TVD DE GAS VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80, ID= 12.347" -I 2846' 1 3563 3117 58 TGPD DMY RK 0 01/06/10 2 4373 3527 61 TGPD DOME RK 16 01/06/10 3 8207 5899 53 TGPD SO RK 20 01/06/10 4 9100 6418 56 TGPD DMY RK 0 03/03/97 5 11717 7813 62 TGPD DMY RK 0 01/06/10 Minimum ID = 2.75" @ 13025' 6 12916 8441 54 TGPD DMY RK 0 10/27/98 3-1/2" HES XN NIPPLE f __ 12989' 1-13-1/2"X 4-1/2"XO,ID=2.992 12990' I--{9-5/8"X 4-1/2"TM/HB-BP T PKR,ID=3.950" I { 12995' I-14-1/2"X 3-1/2"XO,ID=2.992" I 13025' --I3-1/2"HES XN NIP, ID=2.75" 3-1/2"TBG,9.3#, 13CR FOX, --I 13050' I__ 13050' H 3-1/2"X 4-1/2"XO, ID=2.992" I .0087 bpf, ID=2.992" 10359' 1-18-1/4"X 4-7/8"UNIQUE OVERSHOT I 4-1/2"TBG STUB(03/01/97) -I 13046' d'V 13082' I-I4-1/2"BKR PBRASSY I 13101' I-I9-5/8"X 4-1/2"BKR FHL PKR, ID=3,958" I TOP OF 7"LNR —I 13180' I TBG-PC, 12.6#, L-80 BTRS 13202' I 4-1/2" 13191' I-f4-1/2"OTIS XN NIP, ID=3.725" 13201' I-14-1/2"BAKER SHEAROUT SUB I .0152 bpf, ID=3.958" f 13202' —I4-112"TUBING TAIL,ID=3.958" I 13193' -j ELMD TT LOGGED 09/26/92 I 9-5/8"CSG,47#,L-80,ID=8.681" —I 13506' P PERFORATION SUMMARY ' REF LOG: BHCS ON 01/07/84 ANGLE AT TOP PERF:47°@ 13620' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 13620-13640 O 05/05/85 3-1/8" 4 13651-13656 0 05/05/85 3-1/8" 4 13671-13711 0 05/05/85 3-1/8" 4 13717-13722 0 05/05/85 13783' I--I FISH-(2)4"X 1/2"SPRINGS FROM KO TOOL I 1111111114 PBTD 13783' 11111111 OA•AA,•A 7"LNR,29#,L-80 BTRS, .0371 bpf, ID=6.184" -I 13830' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/14/84 ROW 35 ORIGINAL COMPLETION WELL: 09-21 03/04/97 D16 LAST WORKOVER PERMIT No: 1831600 09/17/09 PJC DRAWING CORRECTIONS API No: 50-029-21036-00 02/03/10 DAV/PJC GLV C/O(01/06/10) SEC 1,T1ON, R15E,289'FSL&299'FWL BP Exploration(Alaska) • Pti& 0`7 -ZI P7-6 15.3 /6co Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] j� 1 (0(Z11, z Sent: Sunday, October 28, 2012 9:01 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C); Clingingsmith, Mike J Subject: OPERABLE: Producer 09 -21 (PTD #1760350) OA Pressurization Confirmed As Manageable By Bleeds Attachments: 09 -21 TIO Plot 10- 09- 12.docx; 09- 21.pdf ✓' All, Producer 09 -21 (PTD #1831600) passed an Outer Annulus Repressurization Test (OART) that was conducted 10/13 - 10/18/2012. During the test, the OA pressure increased "'94 psi /day making it manageable by bleeds. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy SCANNED APR 4 9 20 BP Alaska - Well Integrity Coordinator • WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, October 09, 2012 1 :23 PM J� To: 'jim.regg @alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2, Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe,,Chidiebere Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 09 -21 (PTD #1760350) Sustained Ca ing Pressure Above MOASP on OA All, Producer 09 -21 (PTD # 1831600) has confirmed sustained casin pressure on the OA above MOASP. The tubing /IA /OA pressure were equal to 216/1680/1020 psi on 1 /07/2012. The well is reclassified as Under Evaluation and may remain online while further diagnostics re performed. The plan forward: 1. Wellhead: PPPOT -IC • PBU 09 -21 PTD # 1831600 10/28/2012 TIO Pressures Plot Well 09 -21 4 - • ■ 3G . ■ II-- Tbg f IA k- OA � 2.0 4 - r .- ; -.• ---- .- .-a-;� • • • r -- f• - •- •- -a -• - �l J OOA 1 - - ' ' ' \. - • •- •-- •.•.a- •- •- •-•-•-f r • On OA i I • rr ...........-e" - i I 1 071 tt72 0721112 47 13+72 00+4472 0 81712 4f'�SB;12 0 8725, 09167112 09'30'72 09 4912212 4912912 7014612 TREE = FMC GEN 3 • SAFETY NOTES: * * *FLH/ TIW HBBP PKRS HAVE -ACTUATOR; AD = FMC A 09-2 _— „ry REDUCED PRESSURE LIMITS IN SOME CASES. ACTUATOR = AXELSON CONTACT (X5102) * * * -1/2" CHROME TBG * ** KB. ELEV = 55' BF EL - — KOP = 900' Max Angle = 63° @ 4600' r 1 2199' H3 -1/2" CAM BP61 SVLN SSSV NIP, ID = 2.812" 1 Datum MD = 13569' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" J—{ 2846' (---di 1 3563 3117 58 TGPD DMY RK 0 01/06/10 2 4373 3527 61 TGPD DOME RK 16 01/06/10 3 8207 5899 53 TGPD SO RK 20 01/06/10 IIIP 9100 6418 56 TGPD DMY RK 0 03/03/97 5 11717 7813 62 TGPD DMY RK 0 01/06/10 Minimum ID = 2.75" @ 13025' 6 12916 8441 54 TGPD DMY RK 0 10/27/98 3- 1 /2 " HES XN NIPPLE I 12989' H3-1/2" X 4-1/2" X0, ID = 2.992 �_� - 12990' 1- 19-518" X 4 -1(2" TIW HB -BP T PKR, ID = 3.950" 1 12995' H4-1/2" /2" X 3-1/2" XO, ID = 2.992" 1 a 1 13025' 1-13-1/2" HES XN NIP, ID = 2.75" I 3 -1/2" TBG, 9.3 #, 13CR FOX, -1 13050' 1 13050' 1--13 -1/2" X 4 -1/2" X0, ID = 2.992" 1 .0087 bpf, ID = 2.992" 10359' H8-1/4" X 4-7/8" UNIQUE OVERSHOT 1 14 -1/2" TBG STUB (03/01/97) H 13046' 1 13082'- 14 -1/2" BKR PBRASSY 1 2ib 1"‹ 13101' 1- 19-5/8" X 4 -1/2" BKR FHL PKR, ID = 3.958" 1 TOP OF 7" LNR H{ 13180' . i 1 13191' 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 13201' 1- 14-1 /2" BAKER SHEAROUT SUB ( 4 -1/2" TBG -PC, 12.6 #, L -80 BTRS H 13202' 1 .0152 bpf, ID = 3.958" 13202' H4 -1/2" TUBING TAIL, ID = 3.958" I 13193' H ELMD TT LOGGED 09/26/92 1 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 13506' 1-- PERFORATION SUMMARY I REF LOG: BHCS ON 01/07/84 I ANGLE AT TOP PERF: 47° @ 13620' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -1/8" 4 13620 -13640 0 05/05/85 I 3 -1/8" 4 13651 -13656 0 05/05/85 3 -1/8" 4 13671 -13711 0 05/05/85 3-1/8" 4 13717 -13722 0 05105185 Illilir 13783' 1 -{ FISH - (2) 4" X 1/2" SPRINGS FROM KO TOOL 1 0, 4 1 PBTD 1 13783' j1 1 j L 1 111111 A 1 7" LNR, 29 #, L -80 BTRS, .0371 bpf, ID = 6.184" H 13830' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/14/84 ROW 35 ORIGINAL COMPLETION WELL: 09 -21 03/04/97 016 LAST WORKOVER PERMIT No: 1831600 09/17/09 PJC DRAWING CORRECTIONS API No: 50- 029 - 21036 -00 02/03/10 DAV /PJC GLV C/O (01/06/10) SEC 1, T10N, R15E, 289' FSL & 299' FWL BP Exploration (Alaska) • Pet cT -Zl Regg, James B (DOA) 183 ibec From:• AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] ".0,0 Ial Sent: Tuesday, October 09, 2012 1:23 PM To: Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS 2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 09 -21 (PTO -iii*IN13:53:) Sustained Casing Pressure Above MOASP on OA tS 3 i600 Attachments: 09 -21 TIO Plot 10- 09- 12.docx; 09- 21.pdf All, Producer 09 -21 (PTD # 1831600) has confirmed sustained casing pressure on the OA above MOASP. The tubing /IA /OA pressure were equal to 216/1680/1020 psi on 10/07/2012. The well is reclassified as Under Evaluation and may remain online while further diagnostics are performed. The plan forward: SCANNED APR 0 9 2013 1. Wellhead: PPPOT -IC 2. Downhole Diagnostics: IA & OA gas samples, OA Repressurization Test to determine if OA build up rate is manageable TIO plot and wellbore schematic are attached for reference: «09 - 21 TIO Plot 10 09 12.docx» «09 21.pdf» Thank you, OA- 5 of Mehreen Vazir ,. • ' s s '5CP = to Zrip; BP Alaska - Well Integrity Coordinator « OLE Object: Picture (Device Independent Bitmap) » P - 6-3?P" ° l C !ply f' WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.VazirPBP.com 1 ■ PBU 09 -21 PTD # 1831600 10/9/2012 TIO Pressures Plot Well 09 -21 ■ 1 I 4.000 - 1 I • i 3,000 - 1 i I I 1 1 —1 Tb0 M ■ —a— OA I 2.000 - OOA ■ ■ 07)14112 07121/12 07/2 08.04112 08+11112 08n8'12 0825'12 09101112 09'0812 09115 0922 +12 09/2912 1040612 TREE = FMC GEN 3 I S_ -! A OTES: ***FLH/ TIW HBBP PKRS HAVE WELLHEAD = FMC 09-21 ACT REDUCED PRESSURE LIMITS IN SOME CASES. UATOR = AXELSON CONTACT (X5102) -1 /2" CHROME TBG KB. ELEV = r 55' BF. ELEV =� - KOP = 900' Max Angle = — 63° @ 4600' I 2199' I— I3 -1/2" CAM BP61 SVLN SSSV NIP, ID = 2.812" I Datum MD = 13569' 1 Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD DEV TYPE V LV LATCH PORT DATE 113 -3/8" CSG, 72 #, L -80, ID = 12.347" 1—i 2846' I-4 1 3563 371/11D7 58 TGPD DMY RK 0 01/06/10 i j "1 f n — , 36OP5/ 2 4373 3527 61 TGPD DOME RK 16 01/06/10 � 3 8207 5899 53 TGPD SO RK 20 01/06/10 IIP 9100 6418 56 TGPD DMY RK 0 03/03/97 5 11717 7813 62 TGPD DMY RK 0 01/06/10 Minimum ID = 2.75" @ 13025' 6 12916 8441 54 TGPD DMY RK 0 10/27/98 3-1/2" HES XN NIPPLE 129 89' _I — I3 -1/2" X 4 -1/2" XO, ID = 2.992 I m� ∎ M. 12990' 1-19-5/8" X 4 -1/2" TIW HB -BPT PKR, ID = 3.950" I --1 12995' H4-1/2" X 3-1/2" XO, ID = 2.992" 1 13025' H 3-1/2" HES XN NIP, ID = 2.75" I 3 -1/2" TBG, 9.3 #, 13CR FOX, -I 13050' I--- ( 13050' H 3 -1/2" X 4 -1/2" XO, ID = 2.992" I .0087 bpf, ID = 2.992" 10359' H 8-1/4" X 4 -7/8" UNIQUE OVERSHOT I I4 -1/2" TBG STUB (03/01/97) I-I 13046' I L 13082' 1-14-112" BKR PBR ASSY I I 13101' I-19 -518" X 4 -1/2" BKR FHL PKR, ID = 3.958" I I TOP OF 7" LNR I-I 13180' y i i 13191' 1-14-1/2" OTIS XN NIP, ID = 3.725" 4 -1/2" TBG -PC, 12.6 4, L -80 BTRS -I 13202' I I 13201' 1- I4 -1/2" BAKER SHEAROUT SUB I 0152 bpf, ID = 3.958" 13202' - I4 -1/2" TUBING TAIL, ID = 3.958" I I 13193' I I ELMD IT LOGGED 09/26/92 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 13506' 1--41 • PERFORATION SUMMARY I REF LOG: BHCS ON 01/07/84 ' ANGLE AT TOP PERF: 47° @ 13620' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -1/8" 4 13620 -13640 O 05/05/85 ' 3-1/8" 4 13651 -13656 O 05/05/85 3 -1/8" 4 13671 -13711 O 05/05/85 3 -1/8" 4 13717 -13722 0 05/05/85 Ilk ( 13783' I-I FISH - (2) 4" X 1/2" SPRINGS FROM KO TOOL I • ►1 PBTD I 13783' �IIIIIIII 1 I 7" LNR, 29 #, L -80 BTRS, .0371 bpf, ID = 6.184" H 13830' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/14/84 ROW 35 ORIGINAL COMPLETION WELL: 09 -21 03/04/97 016 LAST WORKOVER PERMIT No: 1831600 09/17/09 PJC DRAWING CORRECTIONS API No: 50- 029 - 21036 -00 02/03/10 DAV /PJC GLV C/O (01/06/10) SEC 1, T1ON, R15E, 289' FSL & 299' FWL BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission �C�3 333 West 7 Avenue ( Anchorage, Alaska 99501 09 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator III • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ I Well Name PTD # API # cement pumped cement date inhibitor , sealant date ft bbls ft gal 09-01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 , 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09-14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09-16 1//u370 50029202570000 Sealed conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09 -18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA -4 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09-22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09-23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09-25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09-29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 , 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 , 1901150 50029220830000 0.2 NA 02 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 _ Dust Cover NA NA NA 3.4 10/20/2011 -~-. STATE OF ALASKA ---~ ALASKA _,IL AND GAS CONSERVATION CC..,~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing I--~Alter Casing [] Repair Well I--I Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. 4. Location of well at surface 289' NSL, 299' EWL, SEC. 01, T10N, R15E, UM At top of productive interval 3485' NSL, 3952' EWL, SEC. 06, T10N, R16E, UM At effective depth 3485' NSL, 4072' EWL, SEC. 06, T10N, R16E, UM At total depth 3485' NSL, 4107' EWL, SEC. 06, T10N, R16E, UM Type of well: 6. [] Development [] Exploratory 7. [] Stratigraphic J--J Service 8. 9. 10. 11. Datum Elevation (DF or KB) 55' RKB Unit or Property Name Prudhoe Bay Unit Well Number 09-21 Permit Number / Approval No. 83-160 APl Number 50-029-21036 Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13830 feet true vertical 9031 feet Effective depth: measured 13783 feet true vertical 8999 feet Casing Length Structural Conductor 80' Surface 2846' Intermediate Production 13506' Liner 651' Size Plugs (measured) Junk (measured) Sand Plug at 13457' (03/97) 0R 0 t AL Cemented MD TVD 20" 1985# Poleset 13-3/8" 3800 sx CS III, 400 sx CS II 9-5/8" 500 sx Class 'G' 7" 475 sx Class 'G' 80' 80' 2846' 2653' 13506' 8811' 13830' 9031' Perforation depth: measured true vertical 13620' - 13640', 13651' - 13656', 13671' - 13711', 13717' - 13722' 8890' - 8959' (four intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.3#, 13Cr to 13052'; 4-1/2", 12.6#, L-80 13052' - 13202' Packers and SSSV (type and measured depth) at 2199' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Baker FHL packer at 13101 '; TIW HB-BP-T packer at 12990'; Camco BP61 SVLN JUN 24 1997 ~ ~ & Gas Cons. 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 116. Status of well classifications as: [] Copies of Logs and Surveys run I J~ Oil J--J Gas [--J Suspended [] Daily Report of Well,,J~5'erations .-~ I 17. I hereby certify that t~ fo,.~goi~orrect to the best of my knowledges_. Signed Dan Stoltz ~, //.~f,.~ ~./"~ Title Senior Drilling Engineer / .... ' ' - ~ Prepared By Name/Number: Service Form 10-404 Rev. 06/15/88 Date ~::~' Z ~-- .~/.~ Terrie Hubble, 564-4628 Submit In Duplicate~ Facility Date/Time 20 Feb 97 21 Feb 97 22-Feb 97 23 Feb 97 24 Feb 97 PB DS 09 Progress Report Well 09-21 Page 1 Rig Doyon 16 Date 16 June 97 12:00-12:30 12:30-18:00 18:00-18:30 18:30-05:00 05:00-05:30 05:30-06:00 06:00-08:00 08:00-08:15 08:15-09:30 09:30-10:00 10:00-18:00 18:00-18:30 18:30-22:00 22:00-23:00 23:00-00:00 00:00-02:00 02:00-02:15 02:15-06:00 06:00-06:30 06:30-07:00 07:00-11:00 11:00-11:30 11:30-15:30 15:30-15:45 15:45-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-01:00 01:00-05:30 05:30-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-16:15 16:15-16:30 16:30-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-00:30 00:30-00:45 00:45-02:15 02:15-06:00 06:00-06:30 06:30-10:00 10:00-10:30 10:30-11:30 11:30-12:00 Duration 1/2 hr 5-1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 1/2 hr 2hr 1/4 hr 1-1/4 hr 1/2 hr 8hr 1/2 hr 3-1/2 hr lhr lhr 2hr 1/4 hr 3-3/4 hr 1/2 hr 1/2 hr 4hr 1/2 hr 4hr 1/4 hr 2-1/4 hr 1/2 hr 3hr 1/2 hr 3hr 4-1/2 hr 1/2 hr 1/2 hr 5hr lhr 1/2 hr 1/2 hr 1/2 hr lhr lhr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 2hr 1/4 hr 1-1/2 hr 3-3/4 hr 1/2 hr 3-1/2 hr 1/2 hr lhr 1/2 hr Activity Held safety meeting Rig moved 40.00 % Held safety meeting Rig moved 100.00 % Held safety meeting Rigged up Chicksan lines Cleared Chicksan lines Held drill (H2S) Worked on BOP - Lubricator Held safety meeting Reverse circulated at 13018.00 ft Held safety meeting Circulated at 13018.00 ft Flow check Rigged up Lubricator Removed Permanent guide base Held drill (Fire) Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Rigged down Lubricator Circulated at 3138.00 ft Held drill (H2S) Laid down 1600.00 ft of Tubing Held safety meeting Laid down 1530.00 ft of Tubing Installed Sub sea tools Made up BHA no. 1 Singled in drill pipe to 3080.00 ft Circulated at 3080.00 ft Held safety meeting Circulated at 8500.00 ft Rigged up sub-surface equipment - Slickline / braided cable Held safety meeting Prepared & fired cutting charge at 6055.00 ft Prepared & tn:ed cutting charge at 6055.00 ft Pulled out of hole to 0.00 ft Circulated at 6050.00 ft Flow check Held drill (Spill) Pulled Drillpipe in stands to 0.00 ft Held safety meeting Laid down 2858.00 ft of Tubing Held safety meeting Conducted electric cable operations Held drill (H2S) Made up BHA no. 2 R.I.H. to 3000.00 ft Held safety meeting R.I.H. to 6027.00 ft Circulated at 6027.00 ft Fished at 6046.00 ft Installed Chemical cutter Facility PB DS 09 Progress Report Well 09-21 Rig Doyon 16 Page 2 Date 16June97 Date/Time 25 Feb 97 26 Feb 97 27 Feb 97 28 Feb 97 12:00-12:30 12:30-15:30 15:30-15:45 15:45-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-23:30 23:30-23:45 23:45-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:30 10:30-11:30 11:30-12:30 12:30-12:45 12:45-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-03:00 03:00-04:30 04:30-04:45 06:00-06:30 06:30-10:00 10:00-10:30 10:30-11:00 11:00-11:15 11:15-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-23:30 23:30-23:45 23:45-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-10:30 10:30-11:00 11:00-11:15 11:15-18:00 18:00-18:30 18:30-18:45 18:45-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-09:30 09:30-14:00 14:00-15:30 15:30-16:30 Duration 1/2 hr 3hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1/2 hr 5hr 1/4 hr 4-3/4 hr 1-1/2 hr 1/2 hr lhr lhr 2hr lhr lhr 1/4 hr 5-1/4 hr 1/2 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1/4 hr 3-3/4 hr lhr 2hr 1/2 hr 5hr 1/4 hr 6-1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 1/2 hr 1/4 hr 6-3/4 hr 1/2 hr 1/4 hr 6-3/4 hr 1/2 hr 4hr 1/2 hr 3hr 4-1/2 hr 1-1/2 hr lhr Activity Held safety meeting Functioned Chemical cutter Held drill (Fire) Circulated at 13030.00 ft Tested Casing - Via string Pulled out of hole to 12630.00 ft Held safety meeting Pulled out of hole to 7030.00 ft Held drill (Spill) Laid down fish Rigged down Handling equipment Held safety meeting Made up BHA no. 3 R.I.H. to 3150.00 ft Singled in drill pipe to 5000.00 ft Circulated at 5000.00 ft Serviced Block line Held drill (Kick while tripping) Singled in drill pipe to 9500.00 ft Held safety meeting Singled in drill pipe to 13030.00 ft Circulated at 13030.00 ft Circulated at 13030.00 ft Circulated at 13030.00 ft Flow check Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 4 Held drill (Spill) R.I.H. to 13030.00 ft Tested Casing - Via annulus Circulated at 13030.00 ft Held safety meeting Circulated at 13030.00 ft Held drill (Kick while tripping) dUN 2q 1997 ~ ~.Gas Cons. Laid down 8430.00 ft of 5in OD drill pipe Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Rigged up Tubing handling equipment Held safety meeting Held drill (H2S) Ran Tubing to 9500.00 ft (3-1/2in OD) Held safety meeting Held drill (Fire) Ran Tubing to 10700.00 ft (3-1/2in OD) Rigged up sub-surface equipment - SCSSSV control line Ran Tubing to 13010.00 ft (3-1/2in OD) Held safety meeting Installed SCSSSV control line Circulated at 13036.00 ft Installed Other sub-surface equipment Rigged up sub-surface equipment - Pulling tool Facility Date/Time 01 Mar 97 02 Mar 97 03 Mar 97 PB DS 09 Progress Report Well 09-21 Page 3 Rig Doyon 16 Date 16 June 97 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-22:00 22:00-00:00 00:00-01:30 01:30-03:00 03:00-04:00 04:00-04:15 04:15-06:00 06:00-06:30 06:30-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-04:45 04:45-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-01:00 01:00-02:30 02:30-05:30 05:30-05:45 05:45-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-19:00 Duration lhr 1/2 hr 1/2hr 1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1-1/2 hr lhr 1/4 hr 1-3/4 hr !/2 hr 10hr 1-1/2 hr 1/2 hr 2hr 8-1/4 hr 1-1/4 hr 1/2 hr 6hr lhr 4hr 1/2 hr 1/2 hr 1-1/2 hr 5hr 1-1/2 hr 3hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 2hr 10hr Activity Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Conducted slickline operations on Slickline equipment - Tool run Circulated at 13052.00 ft Conducted slickline operations on Slickline equipment - Tool run Rigged up Tubing handling equipment Removed Tubing handling equipment Conducted slickline operations on Slickline equipment - Setting run Rigged up Tubing handling equipment Held drill (H2S) Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Tested Permanent packer - Via annulus and string Held safety meeting Tested Permanent packer - Via annulus and string Conducted slickline operations on Slickline equipment - Setting run Tested Permanent packer - Via string Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Tested Permanent packer - Via string Conducted slickline operations on Slickline equipment - Setting run Tested Tubing - Via string Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Rigged down BOP stack Tested Tubing hanger Rigged up Fluid system Held drill (Fire) Installed Hanger plug Held safety meeting Removed Fluid system Rig moved 5.00 % Rig waited: Cranes shut down .o STATE OF ALASKA ,~'-, ALAS~.,-~ OIL AND GAS CONSERVATION ~,,JMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate , , , Pull tubing Alter casing Repair well Other X · , 2. Name of Operator ARCO Alaska, Inc· 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 299' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1796' FNL, 789' FEL, Sec. 6, T10N, R16E, UM At effective depth At total depth 1796' FNL, 634' FEL, Sec. 6, T10N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 55 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-21 9. Permit number/approval number 83-160 10. APl number 50 - 029-21036 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 13830 feet 9031 feet Plugs(measured) Tagged Fill @ 13658' MD (4/12/95) Effective depth: measured 13783 feet true vertical 8999 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1985 Poleset 80' 80' Surface 2791' 13-3/8" 3800 sx CS III & 400 sx CS II 2846' 2644' Production 13451' 9-5/8" 500 sx CIG & 300 sx CS I 13506' 8819' Liner 651' 7" 475 sx CIG 13830' 9013' Perforation depth: measured 13620-13640'; 13651-13656'; 13671-13711'; 13717-13722' true vertical 8894-8907'; 8914-8917'; 8927-8953'; 8957-8961' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, PCT @ 13202' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 13101' MD; Otis HXO SSS,~ (~ 2203' MD V LL,/ 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) see Attached J UN - 7 1,9,95 Treatment description including volumes used and final pressure Alaska IJJj & Gas Corls. C01TIITi/$SJ0rl .Representative Daily Averaqe Production or Iniectioo Data OiI-Bbl Gas-Mc'f Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1042 1650 3815 297 Subsequent to operation 533 637 806 291 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas .. Suspended . Service , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S. igned . __ Title Engineering Supervisor Form 10-404' Rev 06/15/88 SUBMIT IN DUPLICATE r,r,' 14'7 . IWP 9-21 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED I I/22/94' RIH & set a 2.687" ID Alpha Soft-Set Tubing Patch from 3162' to 3183' MD (seal to seal), over leaking GLM #1 located at 3175' MD. POOH. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED dUN - 7 1995 Alaska 0il & ~as Co/is. COlTIITliSs[Ofl Anchor~ ~ GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9142 Company: 12/12/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 3-18A'~~ ~~ PERF RECORD (11-28-94) 1 1 D.S. 4-37 (o ~ EST (11-26-94) 1 1 , , D.S. 9-21 ~ TaG PATCH RECORD (11-22-94) I 1 D.S. 13-3 ~~ ~ ~ LEAK DETECTION (11-25-94) I 1 D.S. 14-11~-~ ~ ~ J BO~OMHOLE PRESS SURVEY (11-25-94) I 1 D.S. 14-12 ~(~ I~ ~ BO~OMHOLE PRESS SURVEY (11-25-94) I 1 D.S. 16-21 ~~ ~ I~ LEAK DETECTION (11-22-94) I 1 D.S. 17-07 ~' [ ~ ~ PACKER SE~ING RECORD (11-29-94) I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: 12/5/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar PWDW 3-1 "~ ~'--- ('3 ~ o/ STATIC BHP SURVEY (11-15-94) I 1 D.S. 3-7 7~_,~-- t'0 ~--~ PERF RECORD (11-20-94) 1 1 D.S. 3-10 ~ ~-O~-/ INJEC PROFILE (11-17-94) I 1 D.S. 3-32A ~ ~/-r"~-d ,~- ~" PROD PROFILE (11-14-94) I 1 D.S. 4-19 ~ -O "~-I DUAL BURST TDT-P (11-21-94) I 1 D.S. 7-19 ~"2---~-17 CNL ((11-13-94) I 1 D.S. 9-21 /'/ ~' ~--//~. O LEAK DETECTION (11-11-94) I 1 D.S. 9-21 4,,,~, ~ .- / ~. O TUBG PATCH RECORD (11-22-94) I 1 D.S. 9-47. .~) O ,- /~ PROD PROFILE (11-15-94) I 1 D.S. 9-49 .~,, ~ '~-- ~/~ ~' PROD PROFILE (11-14-94) I 1 D.S. 11-31-(~. ~,'c~..---~'2-7 R.O.P.E. PERF RECORD (11-14-94) I 1 D.S. 11-32 ~ ~ ~'~-//--/.~ / R.O.P.E. PERF RECORD (11-15-94) I 1 D.S. 15-41 / "~. ~?~--- ~97 GR-CCL (11-11-94) I 1 D.S. 16-21 ~.,~-~/"/_ LEAK DETECTION (11-22-94) I 1 D.S. 17-7 ,~'/'--d~ LEAK DETECTION (11-16-94) I 1 D.S. 17-13 .~Fc~,-/?~ LEAK DETECTION (11-16-94) 1 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest $00 W. International Airport Road Anchorage, AK 99518-1199 ATrN: Shenle NO. 8979 Company: I I Alaska Oil & Gas Cons Comm Affn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 10/11/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1-07A ~ ("l' cO""'~ POGLM SETTING RECORD 49-27-94) 1 1 D.S. 1-9AC~ ~ -" ,~ _'~ DUAL BURST TDT-P (9-25-94) 1 I D.S. 3-11 ~'7 '- ~ '7' INJEC PROFILE (9-21-94) 1 1 D.S. 3-18A ~' ~- ~ ~._ INJEC PROFILE (9-27-94) 1 1 D.S. 3-35 ~ I '- ~"O PROD PROFILE (9-22-94) 1 1 D.S. 4-38 ~/'- I / ~ LEAK DETECTION 49-24-94) 1 1 D.S. 9-7 "7~',,-_ ~ ~ PERF RECORD (9-26-94) 1 1 D.S. 9-07 ?,,('~ - 5- ~ PROD LOG 49-23-94) 1 1 D.S. 9-21 ~'% '- IL/~ STATIC PRESSURE SURVEY 49.23.94) 1 1 D.S. 9-26 ~'~(" .~ '7 LEAK DETECTION (9-26-94) 1 1 D.S. 9-45 ~P - / ~ ~ PROD PROFILE (9-24-94) 1 1 D.S. 17-15 _ ~ ~- - lo _O STATIC PRESSURE SURVEY (9-23-94) 1 1 D.S. 7-23 "'6'- ~ .-- ~ 5'~ USIT (9-30-94) 1 I , Please sign and retum one copy of this transmittal to Sherrle at the above address. Thank you;. " ..-., STATE OF ALASKA ,.----.., A. LASKA _ AND GAS CONSERVATION C( .,llSSION REPORT (JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing . Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 299' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1796' FNL, 789' FEL, Sec. 6, T10N, R16E, UM At effective depth At total depth 1796' FNL, 634' FEL, Sec. 6, T10N, R16E, UM 12. Present well condition summary ,, Total depth: measured true vertical 13830 feet 9031 feet 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 55 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-21 9. Permit number/approval number 83-160 10. APl number 50 - 029-21036 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Tagged Fill @ 13540' MD (7/31/93) feet Effective depth: measured 13540 feet true vertical 8842 feet Casing Length Size Conductor 80' 20" Surface 2791' 13-3/8" Production 13451' 9-5/8" Liner 651' 7" Junk(measured) Cemented Measured depth 1985 Poleset 80' 3800 sx CS III & 400 sx CS II 2846' 500 sx CIG & 300 sx CS I 13506' 475 SX CIG 13830' True vertical depth 80' 2644' 8819' 9013' Perforation depth: measured 13620-13640'; 13651-13656'; 13671-13711'; 13717-13722' true vertical 8894-8907'; 8914-8917'; 8927-8953'; 8957~8961' Tubing (size, grade, and measured depth) 4-1/2", 12.6¢f, L-80, PCT @ 13202' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 13101' MD; Otis RQM SSSV @ 2203' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. SEP ~ 3 1993 Treatment description including volumes used and final pressure Alaska 0il & 6as Cons. C;0nn'niss~o" Representative Daily Average Production or Iniection Dat~ Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 167 745 887 -- 258 Subsequent to operation 897 3398 1442 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations . Oil x Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 307 Service Signed Title Form 10-4( 5/88 lf}4R/R MJB cc,: SW. JWP Engineering Supervisor SUBMIT IN DUPLICATE 9-21 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE lB 7123/93: RIH & tagged bottom fill at 13707' MD. 7~27~93: MIRU & PT equipment to 8100 psi. Pumped an Acid Preflush followed by a Datafrac and a Hydraulic Fracture Treatment using 12/18 mesh proppant, through the perforations located at: 13620 - 13640' MD (ZIB) 13651 - 13656' MD (ZIB) 13671 - 13711' MD (ZlB) 13717 - 13722' MD (ZIB) Ref. Log: BHCS 1/7/84. Pumped 50 bbls 7.5% HCl Preflush @ 5 bpm, to pickle the tubing & clean the perforations, then proceeded pumping a Datafrac: a) 150 bbls 20# Pre Pad Gel @ 5 bpm, followed by b) Shutdown. ISIP @ 916. Resumed pumping Datafrac: c) 200 bbls 20# Pre Pad Gel @ 50 bpm, followed by d) 170 bbls 30# Pre Pad Gel @ 30 bpm, followed by e) 215 bbls 20# Flush, followed by f) Shutdown. ISIP @ 1534. Resumed pumping Hydraulic Fracture Treatment: g) 100 bbls 30# Crosslinked Pad @ 30 bpm, followed by h) 400 bbls Cross Linked Slurry w/proppant stages @ I - 10 ppg, followed by i) Shutdown. Placed a total of 57,000 lbs of proppant into the formation. Rigged down. 7~28~93: RIH & performed a proppant fill cleanout to 13550' MD. 7131193: RIH & tagged bottom proppant fill at 13540' MD. Returned well to production w/gaslift & obtained a valid welltest. SE P 1 J t99J Alaska Oil & Was (,o,'~. Anchora.qe ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO CASED HOI.~'- FINALS 10-3-92 Prod Profile Run 1. [~' Camco 9-28-92 Leak Detect (Flexstak) Run 1. [~' Camco 9-14-92 InJ Profile Run 1. ~' Camco 9-21)-1)2 InJ Profile Run 1. [~' Camco 10-2-92 Prod-InJ (Flexstak) Run 1. [~' Camco 9-19-92 Leak Detect Run 1, [~' Camco 9-26-92 GR/Collar Run 1, ~' Camco 9-27-92 (IR/Collar Run 1. [~' Camco 9-25-92 Prod Profile Run 1, [~' Camco 9-14-92 Prod Proffie Run 1. ~' Camco 10-2-92 InJ Profile Run 1, ~' Camco 9-4-92 Prod Profile Run 1. [~' Camco 10-4-92 InJ Profile Run 1, [~' Camco 9-26-92 Prod Profile Run 1. [~' Camco 9-26-92 (IR/Collar Run 1, ~' Camco 10-5-92 InJ Profile/PITS Run 1. [~' Camco 9-27-92 InJ Profile Run 1. [~' Camco 9-19-92 Leak Detect Run 1. [~' Camco 9-27-92 Prod Profile Run 1, fi' Camco 10-4-92 InJ/Shut-In Temp Run 1, ~' Camco 10-2-92 InJ Profile Run 1. [~' Camco 10-2-92 InJ Profile (Flexstak) Run 1, [~' Camco 10-1-92 InJ Profile Run 1, [~' Camco 9-15-92 InJ PrOfile Run 1. [~' Camco 9-17-92 Prod Profile (Flexstak) Run 1, ~' Camco 10-1-92 Prod Profile Run 1. [~' Camco 9-28-92 GR/Collar Run 1, [~' Camco 9-28-92 Prod Profile Run 1, [P' Camco 9-15-92 Prod Profile Run 1, ~' Camco 10-1-92 Prod Profile Run 1. [~' Camco Please sign and returnee .t~z~d copy as ,eceipt_~of ~~ E] V E D RECEIVEDB~~~~_~ .... ' MAR 0 9 1993 ~ve A Nice ~~ ~s~a Oi~ a aaa 00,s. ~om~issb~ Anch~agN ~n~ W~ce AP P ROY E D_~~_ ATO- 1529 ~s~ 92245 ~ # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILF~ # BPX # STATE OF ALASKA D A'f' E · ~.J.:.:.'~ 'n u. ~ 'r y ! 6, i 9 8 6 F::EFtEi-':.:EN CE ' A R L": 0 P'r e.-'-:': ~ u_'r' e Alaska Oil & ua$ {j~,~, uuiflmlltSion · Anchorage J::' J !. ,7.'.:, :ii: ARCO Alaska, Inc. Post Office Box 100360 , Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 26, 1985 Reference: ARCO CH Finals 1-13-~/Dual Spaced Neutron 5-17-85 Run I 5" Welex 1-1.%/ Epilog 5-17-85 3-9 ~/Epilog 5-15-85 6-14 ~/Dual Spaced Neutron 5-10-85 6-24/Epilog 7-26 ~Epilog 9-21 JSpinner 9-25 JSpinner 14-13 ~pinner / 15-1J Epilog 5-18-85 5-16-85 6-19-85 6-19-85 6-10-85 5-16-85 i 5" DA i 5" DA i 5" Welex I 5" DA 1 5" DA I 5" Camco I 5" Camco I 5" Camco 1 5" DA 16-11/Temperature Log 6-8-85 1 5" Camco as receipt of data. Received by . Pam Lambert ATO 1429C Trans 180 f. / _ /. //'1/ .-"' ~/ ~-~ A~_ska. 011 8 0~$ Oun3 C0mmissi0r~ Anchorage - _ ARCO Alaska, Inc. Prudhoe Bay E,.,~,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 10, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-21 Permit No. 83-160 Attached is the completion report for work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Enclosures cc: SOHIO Alaska Petroleum Co. Pi(DS 9-21)W4-3 ARCO Alaska, Inc, Is a Subsidiary of AtlanllcRIchfieldCompany R£CEIVF_D JUN l Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~---.~ ALASKA C.-AND GAS CONSERVATION COl ;ISSION WELL cOMpLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL []]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-160 3. Address 8. APl Number . P. O. Box 100360, Anchorage, AK 99510 50- 029-21036 ' 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 299' FWL' Sec.01, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1796' FNL, 789' FEL, Sec.6, T10N, R16E, UM 9-21 At Total Depth 11. Field and Pool 1796' FNL, 634' FEL, Sec.6, T10N, R16E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 55' RKB[ ADL 28345 12. DateSpudded12/09/83 13. DateT.D. Reached01/08/84 14'DateC°mp"Susp'°rAband' 115' Water Depth' if °ffsh°re 116'N°"°fc°mpleti°ns01/21/84 N/A feetMSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13,830'MD,9031'TVD 13,783'MD, 8999'TVD YES [~ NO [][ 2303 feet MD 1900' (Approx) 22. Type Electric or Other LOgs Run DIL/BHCS/GR/SP, LDT/C~/GR/Cal, CBL, Gyroscopic Snzwey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 91,5# H-40 Surf 80' 30" 1985# Poleset 13-3/8" 72,0# L-80 Surf 2846' 17-1/2" 3800 sx CS III + 400 sx CS II 9-5/8" 47.0# L-80 Surf 13:506' 12-1/4" 500 sx Class "G" + 300 sx CS I 7" 29.0# L-80 13:179' 13~830' 8-1/2" 475 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 13620' -13640 ' MD (20 ' ) 13651'-13656' MD ( 5') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13671'-13711' MD (40') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13717'-13722' MD ( 5') N/A ?erf'd on 5-5-85 w/4 SPF TVD of perfs: 8890'-8959' 27. N/A PRODUCTION TEST Date First Production ] Method of Operation (Flowing, gas lift, etc.) 5-5-85I Flowing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE sIZE GAS-OI L RATI© TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lith 'olog'y, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUN 1 2 Form 10-407 Rev. 7-1-80 A,t~i~L~ duplicate CONTINUED ON REVERSE SIDE STATE8 ' ...30.. ' ~ :: .:, , . .,,, ~:,,,,' .-.-~. 29. :_ : .,.:~ :,~: .,, ..... ~:.,,,.~:.;~;~.,,~...~.___ ..... ~.':: ~:,¥/. ?,': ~' :=, ~ ?:~*' G EO EOO'I~'~'~'S - 'FOR M AT IO N'T EST~ · ~ . . · ,. . NAME Include interval tested, pressure data, all fluids recover~ and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . . · op Sad~e~ocbSt ~3, ~l¢.~. 8887 ' ~O~ _.~ . ~ase Sad~e~ocbSt . 13~7201 8956' :. . . : = . . . .. . , : . · : 31. LIST OF A~ACHMENTS None . ,. 32. ~ hereby certify ~ha~ ~he foredoom9 ~s ~ue amd co~eq~ ~o ~he bes~ o~ m~ kno~edge Si~ned ~~~~~-.. Title Reg~°nal ~or' Engr'Date INSTRUCTIONS. General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay E,~,,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 5, 1985 Mr. C. V. "Chat,, Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-21 Permit No. 83-160 Attached is the completion report for Work COmpleted on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Enclosures cc: SOHIo Alaska Petroleum Co. PI(Ds 9-21)W4-3 ,,, :CEIVED u N 1 0 1985 Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary o1 AtlanllcRIchfleldCompany STATE OF ALASKA ALASKA£ .AND GAS CONSERVATION COl IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-160 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21036 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 299' FWL, Sec.01, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1796' FNL, 789' FEL, Sec.6, TiON, R16E, UM 9-21 At Total Depth 1 1, Field and Pool 1796' FNL, 634' FEL, Sec.6, TLON, RL6E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 55' RKBI ADL 283~5 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore ] 16. No. of Completions 12/09/83 01/08/84 01/21/84I N/A feet MSL 17. Total Depth (MD+TVD} 18. Plug Back Depth (MEM-'rVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13,830'MD,9031'TVD 13,783'MD, 8999'TVD YES [~ NO [] 2303 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP~ LDT/CNL/GR/Cal, CBL, Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-f0 Surf 80 ' 30" 1 qR 5~ po1 ~.q~ t 13-3/8" 72,0# L-80 Surf 28~6' 17-1/2" 3800 sx CS TTT + 400 .~x CS TI 9-5/8" 47.0# L-80 Surf 13.506' 12-1/M' 500 .~x Cl~.q.q "C.,' + 300 .,× CS T 7" 29.0# L-80 13,179' 13:830' 8-1/2" 475 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 13620'-136Z,0' MD (20') 13651'-13656' MD ( 5') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13671'-13711' MD (40') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13717'-13722' MD ( 5') NIA Perf'd on 5-5-85 w/4 SPF TVD of perfs: 8890'-8959' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5- 5- 85] Flowin~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure !CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None J[JN 1 0 1885 ;.i:~:.'.,:.a Oil & Gas Cons. C0mmissi0~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE STATE8 . , NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time-of each phase .... -. : Top Sadlerochit 13:, 617' 8887' NO~ Base Sadlerochit 13'720' 8956' ~,- "' i ~ ..;~'.. ' "'.' '~ ' - , ' ' . ...... · : ~ . . . . .. . .- 31. LIST OF ATTACHMENTs .. ~o~e 32. I hereby certify that the fo(egoing is true and correct to the.best of my knowledge - Si~ned _ Title RegSonal Oper. Engr. ~ate INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and 10g on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay ~-.,9ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-21 Permit No. 83-160 Enclosed is the "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Attachments cc: SOHIO Alaska Petroleum Co. File PI(DS 9-21)Wl-3 J U N 1 0 1985 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER'x~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 290' FSL 302' FWL, Sec. 1, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 55' 12. 7. Permit No. 83-160 8. APl Number 50- 029-21036 9. Unit or Lease Name Prudhoe ;Bay Unit 10. Well Number D.S. 9-21 11. Field and Pool Prudhoe Bay Field I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool ADL 28345 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORI OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 5-5-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 13691'-13711' MD (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 13671'-13691' MD (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 13620'-13640' MD (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun #4, shot select-fire interval 13717'-13722' MD (4SPF); pulled up and shot select-fire interval 13651'-13656' MD (4SPF). Shut in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 1-7-84 RECEIVED J U N l 0 ]985 Af~ch0rage 14. I hereby c~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~/Yd~/~'[/ ~/~~ Title The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1 ~0 and "Subsequent Reports" in Duplicate ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: May 29, 1985 Reference: Arco Pressure Data 1-4 Static Test 1-16 Static Test 2-1A Static Test 2-5 Static Test 3-8 Static Gradient 3-14 Static Gradient 3-15 Static Gradient 3-25 Static Gradient 5-3 Static Test 7-2 Static Gradient 9-21 Static Gradient 9-23 Static Gradient 13-26 Gradient 12-8 Static' Gradient · 12-8B Gradient 13-14 Static Gradient 14-15 Static Gradient 14-31 Static Gradient 5-19-85 5-19-85 5-20-85 5-20-85 4-24-85 4-24-85 4-24-85 4-24-85 5-19-85 4-27-85 5-6-85 5-6-85 5-4-85 4-29-85 4-18-85 4-21-85 4-26-85 4-26-85 ARCO ARCO ARCO AECO Oamco Camco Camco Camco ARCO C~mco Camco C~mco Camco Camco Camco C~mco Camco (~mco Please sign as receipt of data. Received by Pam Lambert Chevron ATO 1429C D & M Trans 123 Expl. Services Ext..Exploration Exxon Marathon Mobi 1 · 4Jaska Oil & 63s Co,qs. Commission Anchorage Phillips PB Well Files R&D Sohio State ·of Alaska Texaco ARCO Alaska, Inc. Prudhoe Bay _.,~lineering Post Office Box 360 ~ Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 2, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-21 DS 9-22 DS 9-23 DS 9-25 Permit No. 83-160 Permit No. 83-173 Permit No. 84-3 Permit No. 84-28 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dh Attachments CC: Sohio Alaska Petroleum Company File P1 (DS 9-21)Wl-3 File P1 (DS 9-22)Wl-3 File Pi(DS 9-23)W1-3 File Pi(DS 9-25)W1-3 RECEIVED Alaska Oil & Gas Cons. C0mmissl0~ Anch0ra[/e ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany STATE OF ALASKA '---' ALASKA OIL AND GAS CONSERVATION COIwMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LL~42~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of Well Surface: 290' FSL, 302' FWL, Sec.1, TION, R15E, UN 7. Permit No. 83-160 8. APl Number 50- 029-21036 9. Unit or Lease Name Prudhn~. Bny Ilnlt' 10. Well Number 9-21 11. Field and Pool Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 55' IADL 28345 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well at 1330 hrs., 12-9-83. Drilled 17-1/2" hole to 2908'. Ran, cemented, and tested 13-3/8" casing with shoe ~ 2846'. Drilled 12-1/4" hole to 13,535'. Ran, cemented and tested 9-5/8" casing. Drilled 8-1/2" hole to 13,830'. Ran logs. Arctic packed 13-3/8" x 9-5/8" annulus. Ran, cemented and tested the 7" liner. Ran 4-1/2" completion assembly. Secured well and released rig at 1000 hfs, 1-14-84. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associate Engineer The space below~r Commission use Date Conditions of Approval, if any: Approved by Form 10-403 (JG) 5N/163 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well COMPLETED WELL [] OTHERx[~ Surface: 290' FSL 302' FWL, Sec. 1, T10N, R15E, UM 7. Permit No. 83-160 8. APl Number 50- 029-;21036 9, Unit or Lease Name Prudhoo_ Ray Tin'if- 10. Well Number D-g- 9-21 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. :PZ~LdhOe :Bay Oil :Pool RKB 55' I ADL 2R345 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Aba ndonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate well 9-21 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation intervals: 13620-13640~ MD (20') 13651-13656' MD (5') 13671-13711' MD (40') 13717-13722' MD (5') Ref: BHCS 1-7-84 RECEIVED MAY o Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the fore. g,oing is true and correct to the best of my knowledge. Signed ~C~J~ ~,~~ Title Reqional Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by BY Ih~I~RY VI. KIIGL[il COMMISSIONER Approved CoF'Y ~eturned By Order of the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well R]:I,~i' T S ~[ ON Classification of Service Well OIL E~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2'. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-160 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21036 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 299' FWL, Sec.01, T10N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1796' FNL, 789' FEL, Sec.6, T10N, R16E, UN 9-21 At Total Depth '-ilf.*"-i '~[;i.. ~ '~'' v~"~' ~-~-~.~-,~'~'~' ' ~ ~ ~, ~ ~ 11. Field and Pool 1796' FNL, ~-F'EL, Sec.6, T10N, R16E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 55' RKB 'I ADL 28345 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/09/83 01/08/84 01/21/84I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 13,830'MD,9031'TVD 13,783'MD, 8999'TVD YES r-~ NO [] 2303 feetMDI 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyroscopic Survey '~3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2U~ ~1. b# H-40 Surf 80' 30" 1985# Pol eset 13-3/8" 72.0# L-80 Surf 2846' 17-1/2" 3800 sx CS Ill + 400 sx CS II 9-5/8" 47.0# k-80 Surf 13,506' 12-1/4" 500 sx Class "G" + 300 x CS I 7" 29.0# L-80 13,179' 13,830' 8-1/2" 475 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 4-1/2" 13,203 13,101 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I FlowTubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIV[D JUL261 84 Alaska ~Cons. Commission Form 10-407 ~ Submit in duplicate Rev. 7-1-80 JMM/WC09 CONTINUED ON REVERSE SIDE ....................................................... ~ . . ..:- .... . ... NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DE~TH GOR, and time of each phase. ... . . . Top Sadleroehit 13}619~ 8887~ NONE . . ~e Sadlerochi~- -~13~720~ ~56~ . . . . - ~ : .,. · r . - . . - . . ' ~ · 31. kIST OF ATTACHM~TS '- ' , ..... Drillino History. Cvroseonie Survey f2 eO6ies) 32. I hereb? certifY that the f~r~infl is true and correct to the. best of mg knowledge Signed J. - _ Title Date INSTRUCTIONS General: This form is designed for submitting a comPlete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (Where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion); so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval 'to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". STATE Of ALASKA .... ALASKA. _AND GAS CONSERVATION CC MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [J(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-160 / 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21036 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 299' FWL, See.01, T10N, R15E, UM OCATioNI~ Prudhoe Bay Unit At Top Producing Intervali VEP, I£1ED I 10. Well Number 1796' FNL, 789' FEL, Sec.6, T10N, R16E, UM 13uff. ~ i 9-21 At Total Depth ~ ,0 ~ r ¢:L~ ,, ~.;~' !"''.~i 11. Field and Pool 1796' FSL~~ FEL~ Sec.6~ T10N~ R16E~ UH ' Prudhoe Bay F~e]d 5. Elevation in feet (indicate KB, DF, etc.) ( 6. Lease Designation and Serial No. Prudhoe Bay 0i ] Pool 55~ RKB] ADL 283~5 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore ~ 16. No. of Completions 1 2/09/83 01/08/8~ 01/21/8~~ N/A feet MSL~ 1 17. Total Depth (MD+TV~) 18. Plug Back Depth (M~D) 19. Directional Survey ~ 20. Depth where SSSV set 21. Thickness of Permafrost 13~830~HD~90~1 ~TVD 13~783~ND~ 8999~TVD YES ~ NO ~~ 230~ feet MD 1900~ (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP~ LDT/CNL/GR/Cal ~ CBL~ Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-~0 Surf 80~ 30" 1985~ Po1 eset 13-3/8" 72.0~ L-80 Surf 28~6~ 17-1/2" 3800 sx CS III + ~00 sx CS II 9-5/8" ~7.0~ L-80 Surf 13~506~ 12-1/¥~ 500 sx Class "G" + 300 ~x CS I 7" 29.0~ L-80 13~179~ 13~830~ 8-1/2" 475 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE ~-1/2" 13~203 13~101 ~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED N/A .... 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I Date of Test ~ours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c0rr) Press. 24-HOUR RATE ~ 2'~. CORE DATA Brief ~escription of lithology, porositv, fractures, apparent dips and presence of oil, gas or water~ Submit core chips. None RECEIVED J u L. I ;' Z~aska 0i~ & ,~a~ Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 JNM/WC09 CONTINUED ON REVERSE SIDE . . . · . · NAME ~ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of.each phase. .. .- Top Sadl e rochi t 13,619' 8887 ' NONE .: ' Base Sadlerochit ! ~3,720' 8956' .-.' ' ~".:' ...' : "' · .'" : · ~ : · :.. . 31. LiST OF ATTACHMENTS . Drillino History. Cvroseonic.Survev (2 conies) . 32. I hereby Certify that the foregoing is true and correct to the best of my knowledge 'Area Drilling Engr. Signed '7~'- '~- ' Title Date . . , INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached suppleme~.tal records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". A.TLAt~,!T~"C t~,I:.CF.IE'IE!.~[) CO~'tPANY 2000,0('~ I 95l). 72 '2100. O0 2041 ' 28 2200.0 ,:~ 21. 2 q. c, 2300,0o 2216'50 54 2500,0() 2382.75 9 (; 260 o, n (:': 2 462,42 270()' O0 2542. 2900 O0 26gg' C () ~s.'i P l, 't A ti' .t r'l ~4 i)A TE: 14 - F E: B- ~l 4 45.00 (.; .r, S 1 30 E 0.09 145.00 ;,') 0 ;3 17 1P,, E (},23 .?.4%.0/) o O .3 37 35 ~ 444.qq 0 34. S 79 14 E 0,49 5,~4,97 ~ 43 ~,~61 38 F "L,85 a44.R5 4 2~.1. N 53 17 E 3.94 7.44,3~ ~ 28 r; 51 33 E 1..24 R43.54. R 33 4 49 18 E 2,67 q,41,,o% '~ i 27 ,',!4~ 24, E 1,60 1039.37 t¢ J9 % 46 29 E 0.94 1.!,36,!.1. ~.4 lt~ ,.' 54 28 E 3.5'7 1233.oB 13 45 r,~ 59 35 E 1.38 1330,32 14 3 ~',~52 22 ~ 4,92 1425,9q 18 54. ~,! 44 41 ~: 2.1:1 l~2u,J. 3 lq 2~{ 'a 50 a F 5,:t:1 1614.84 18 2(') ~ 58 26 E ,:).94 ].7,')9,69 ] ~:~ 33 ;',~55 42 ~' ?.i~1 J.~03.70 2t 5'7 ~ 53 17 E 4.65 1,795.72 2';! 3° .,,~ 53 17 t£ 2.29 19B6,28 26 2q t'~ 51. 3~ E 2.31 2nv4..9~t 2~ 3~ ,,, 5b 15 E; 7.'86 2161,~'..~(,1 3~ 3(I ~',~62 23 ~t 4,11 23'27:75 ,~5 ,14 i'~ 61 52 ~: 2.76 2/~'97,°(': '~7 1.4 ,,. 60 44 F: (),RS 24~:;~7,42 .37 44 ? 6(l 9 g O,bl. DATE CtP $l!rVF¥: 6-FEB-84 KE[,,L.f PU,qhlNG ELEVATION: 61 ,~i ~'.; ! r,, Fi ~: R: d O H N $ 0 N '...t F i',: i-: A S iJ E !~: [) ;) ~:.: P T !~ R F: C'P A t~.' G !.t L ,~ e NORTH/Sf]UTH PAGE ! 0,0 (') O. 17 0.57 0.80 0,99 1.33 0.70 1.97 7,9-~. 1. 6.05 55,00 I Ko NORIZ. DEPARTURE Ci,OPDIr,iAT e EAST/WEST DISTANCE AZIMUTH FEET FEF:T DEG MIN 28,03 43.62 60,05 72,78 85,39 105.31, 147:15 163,93 o,00 F. 0.19 W 0.20 w 0,01 W 0,10 k 0,28 E 1.99 E 5,94 E ! 3,57 E 23,55 E 0.00 N 0 0 0.26 S 47 42 0.60 5 19 15 0.80 S 1 0 1.00 S 5 43 1,36 S 11 45 2.11 S 7O 29 6,26 N 71 36 15,72 N 59 39 28.50 N 55 43 20 '7,3 9 233.l 9 261.39 286.39 310.94 337. Il 3~)5, ag 395,94 426,93 459. 16 36,5~ 52.75 ;~.0~ ,86 112,49 133,52 157,77 184.0~ 21. O,8~ 2,3~.30 46,08 N 52 31 68.46 N 50 24 93,78 N 50 11 117.98 N 51 54 141,23 N 52 47 170,05 N 51 4.4 ~03.60 ~ 50 47 235.62 N 51 ~! 267,10 N 52 8 301.12 n 52 1.8 269 76 E 303 38 E 339 9 '1. E 383 .32 E ~:..tl 63 E 482 18 E 5~'7,2,5 64 ('), 4. 1. 693; 8 ~. B: 34.0,27 k 52 26 382.6,4 N 52 27 428 79 N 52 26 478,~9 N 53 14 5.31,97 a 54 588°34 a 55 647,81 N 55 36 708,26 N 56 0 769,~7 N 56 18 832.02 N 56 30 494,16 ',~ 149,65 E 897,87 r,.~,30.62 t'~ 809,63 E 968.01. 563,gR :'4 874,59 E 104.0,67 595,94 '.'4 946,19 K 1118;22 627,9S :',~ 1o21,67 E 1199;23 ~6 1281,77 725 03 N 1254,97 E 1449 75'1,R3 ~l 1333,25 E 1533,58 790.'~4 :v 14~2.13 E t~ 56 36 N 56 45 n 57 11 N 57 47 d 58 25 t~ 58 59 n 59 31 m 59 59 t:,t 60 23 N 60 44 'T ¢,', i., Vt:7. P T I(' [-', 1 4. ! O 0 .. O 3 42 O0 ,, ri:) 4,1[t0. ~ :') 4.5¢;0., 4700, q 0 4 .'q- 0 ('; , (~ () .¢ q 00.03 3?95.65 59 3345.94 3542,01 6 3635.93 3733.q2 69 2 ~ b6 27 F' 51 0 (!, 5200, 5300, 5 '.i 00, 5500. 5700, 59OO. 3~99.3~ 4028. ,44 4093. ~: 4 4, 15 ~ . 4 .~.~ 88.76 a,. 419.16 PAGE 2 PATE OF' SURVEY: 6-FEB-84 I<r:L,L¥' IatJSHIlqG EbE;VATI'ON: ,£ ,'; (.; r ]'~ F ~.i' 9 ,, d 014 fq S 0 .N 55,00 1. C: 0 ~': .:;:, E 'i' ~. i V i'< E: A S i.l R ~": i) [. c, W T t.i l) O 2 L, i?, a. R E C 't' ,~. ;'~ C d L .a, R SEVER :.t T'Y :,lO~, Tlq / $OilTH [) f;: G t I 0 (.," F .~2 E; 'r OCPDImA'FES NOR!Z. DEPARTURE ~';AST/WEST .DISTANCE AZIMUTH FEEl' FEET DEG alN ',). 39 g 23,91 0.5,9.. 856.89 I .05 922~ 10 0,41 9~5.0! 0.90 988.02 l..ul t021.3o 1.72 1055,06 o,~6 1123.36 1491.58 E 1704.00 N 61 5 1571.47 E 1'789,91 h 61 23 lb51,57 E 1875.86 ~ 61 41 1732.15 E 1962.30 N 61 58 1813.12 E 2049.26 N 62 1.3 1894.49 E 2136.65 m 62 27 197b,33 E; 2224,62 ~'~ 62 40 2057.~9 E 2312.59 t~ 62 51 213~.54 E: 2399,90 i'~ 63 0 2218.30 E 2486,52 N 63 8 5.31 1157,35 5'05 1188,38 0,96 121.6,36 (3,67 1.244,38 ,59 1272,63 1,,11 1301.03 O.e~O 1329 44 0~34 1357 98 0,79 1386 75 2,21 1.415 89 2296,64 2371,48 2442,89 2513.62 2584,1.'7 2654,65 2725,02 2795..28 2865,22 2935.43 2571,77 2652.57 2728,97 2804 78 2880 54 2956 32 3032 O2 3107 68 3183 16 3259 06 r,i 63 15 N 63 23 a 63 31 N 63 39 N 63 46 N 63 53 N 63 59 N 64 5 N 64 10 N 64 14 3C*05,30 E 33.34,71 3074,82 E 3,11.0,04 3144,1,0 E 34~5,23 3213,47 E 3560,64 3282,72 E 3635 '~7 3351.88 E 371.1~ 3420,9~ E 3786,08 3490"31 E 3:860,60 3559.96 ~ 3935,15 3630'00 4009'91 N 64 a' 64 N 64 N 64 N 64 N 64 ~,~ 64 N 64 N 64 N 64 19 22 26 29 3 37 ,42 46 51 .1729,40 1,754,78 177 9 72 1,804 66 1829 69 1854 75 ;!. 879 90 1905 08 3700,54 E; 408.4,71 ,3771;58 E 4159,81, 3843,34 E 4235'41 3915,64 E 4:311'50 3987,95 E 41387'65 4060;00 E 4463'60 413 ~, 90 ~:.'. 4539, .45 4203'82 E 4615.35 4276,16 E 4691,55 4349,44 E 4768,57 N 64 N 65 N 65 N 65 N 65 N 65 N 65 N 65 N' 65 N 65 57 2 9 15 21 26 37 4'2 47 J, 4 .. F E ::I.- .R 4 1 O0 PEE'.r OF DATE OF SURVEY: 6-FED-84 K~;LI..Y ~l. J S ii .l !,J (.; KI,,EvA'rlON: PAGE 3 55.00 1,.31, 1 0.75 0.96 {'). '1.7 0 , 8'1 0.4 2 0,90 DEPA R'I'I, iRE A Z DFC, !979.57 2003.94 2',')2~. 02 ~'~: 2052.32 2<')76.61. 2100.64 2124.56 ~,~ 2148.~4 2173.12 2197,54 · 4a22.d7 g 4845,66 4490,'79 F 4923.10 4571,81. [; 5001'43 4048'21E 5081.13 4725.27 E: 5161.44 4802.50 E 5241.82 497q,90 E 5322.33 4957.25 g 5402.95 5034.53 E 5483,52 511~..94 E 5564.27 n 65 53 N 65 58 ~ 66 4 N 66 N 66 16 N 66 22 N 66 28 N 66 33 N 66 39 N 66 44 ]. , {.I 8 0,23 l..08 0.50 1. , ",47 0.62 ! ,, 4:'7 O, 69 (:. 86 O, 54 0 ,,58 1,68 '1., 4 I. 0.50 0.32 0,13 2222.22 >~ 51B9.74 g 5645,50 2247.1.3 N 5268,12 g 5727,36 22'72,48 ~] 5346,77 E 5809,66 · 52 E 589.2,17 2298,13 M 5425, 2324,2g N 5504,35 ~ 5974,97 2350.21 ~ 5583'55 g 6058,0~ 2376 16 TM 5662, , .! 71 g 614!,04 2402'28 N 5742.31. g 6224*56 24.28.32 N 5821,96 E 2451.25 N 5891~24 E 6380,85 2481,44 ~ 5082,23 E 6476.46 2508.47 N 6062,61 ~ 6561;07 2535,90 ~ 6142,87 g 66.45,73 2563.63 N ~222,~6 E 6730~25 2591,75 ~,; 63()~,77 E 6814.84 2620,04 N 6387'48 g 6899;32 264.8,4:1 N 6461.,98 E 6983.65 2676.48 N 6541,20 E 7067~59 2'704'38 N 6i.>20,09 E 7151,17 2'732"13 N 6698i67 E 7234;41 66 66 66 67 67 6.7 67 67 67 67 N 67 N 67 ~ 67 N 67 N 67 N 67 N 67 N 67 t:q 67 n 67 49 58 2 6 10 14 17 2.1 24 28 34 36 38 4O 42 44 46 1.,76 2759.60 :' 6777,3'7 E 7317,,66 1'62 2786.75 N 6856',49 E: '1401.18 2,02 281..3,52 N 69.36,~',1 E 7485,66 0.9';! 2a39;84 N' 701 .ag E; 7570.,70 t,2'2 2965,50 ~.';~ 70q9,65 E 7656,11. 2,91 2 ~:~ 90" 57 r,: 7:1 a 2,60 ~::: 7742 ', ,i2 0.92 291,~.,77 N 726b.45 E 7829,26 0,.77 2938.52 ~ 73 ,09 E 7916',65 0.,%~ 2961..8.3 t',~ 7435,86 E 8004.03 I..'()'~ 29~4:.74 ?4 7520,.40 E 8091,05 67 6!I 67 67 68 68 68 68 68 5O 55 58 ,t 4 8 1,6 LJ'~ I~l l I 1 i i 1 iI:-t~ [:-11 i) plT,l.., $I~['F~ q-91 '"C~L 5 i,? :-~ - S ~< .A C O c k S E vERT.IiCAI... DE'.VJ' l't'l'lrC'i.~,] AZTt',':UTk{ I; ~,, ? ';" ~i I) < (,; ~ Ir N F! !q G ~'~ [ % 12O00. l 21 O0, .. l ~ 2 C,;O, ! 23O0. 125or~.o0 127(:'0, 1280C-', Od 1.2900. 7976 a026 8~77 $1~2 8235 22a9 ~345 8458 .4 !5 .6k .3~ .~3 q 5 ,20 .Sb il, 1.31.00.00 13200. o 0 13300,00 13400 O0 13soo ~ oD 13600. oD 13700.00 13782. O0 85 ~ '7 . 19 25'17.13 ~63~, '70 · . ~;'? 01.89 ~ 767. o 7 2834.00 Lf q 01.. 61 8969.6~ 9O25.62 4 E 3~ E 25 g 39 E 39 E 3O E 39 E 39 E 14- F P'; !3- a 4 SEVER !'FY t)F.G/.t OO PAGE DATE OF' SURVEY: 6-FEB-84 ~ELbY ~:~US. HIaG ELEVATI. O~: 55.00 R FiCT A ~.~GO [.,AR NORTH/SOUTH EAST [~" E E'Y .t.O7 3007.03 N 7604, 1,99 3028.57 ~ 7688. 9,59 3049.01 N 7772. 0°84 3068.65 ~ 7~55, 1,48 3088.21 a 7937. 0.65 3107.53 N 8020. 1,31 3126.50 ~i 8!02. 1,73 3144.96 ~! 8183. 0.77 3162,84 t~ 8264, 0.25 3180,1,6 N 8344. DINAYES HORIZs DEPA~TUR~ /WEST DISTANCE AZIMUTH ET FEET DEG 'lq E 8177,72 i, 68 25 80 E 8263."17 ~ 68 30 23 E 8348,89 ~ 68 34 23 E 8433,34 N 68 39 94 E 8517,50 N 68 44 21E 8601,19 N 68 49 13 E 8684,44 a 68 53 41. E 8766,93 N 68 58 04 E 8848.61 N 69 3 16 E 8929;64 N 69 8 2,84 3196.72 a 8423.67 El 1;90 321.1,30 N 8502.38 g 2,4'1. 3224.76 N 85~0,02 E 3,00 3236.93 N 8656.56 E q5 3247,05 N S73!,7~ E 2.03 3255,57 ~l 8805.52 E 2,69 3262.2.4 N b878.89 E 4,76 3265,42 N 8952.10 E 0.0~ 3267.76 N 90%]..98 E 9009.85 ~ 69 13 9088.61 N 69 18 91.66,01 t~ 69 24 9241.96 N 69 29 9315,92 ~1 69 36 9388.07 ~ 69 42 9459,22 ~ 69 49 9529.06 N 69 57 95~6,!4 ~; 70 4 v F~P.q'i 9 '.-) 6,. 95 .~'774.5a. ., 33b0.65 3R40.F~3 44t¢4.43 5739. (; 8 6~:2.92 693~.~3 V R* R T .[ C A 1~ r~ ~!: v I h '? I © :'.! A Z I i4 ~ IT H i'~ f.) (.; '[., r.. G gEV .~:R I TY D E g / I .90 1 2,29 2,9~ 0,39 5,31 0.2:2.. 1. ~')6 0, 7 7 t ,{)~ 9,58 DATE OF SURVEY: 6-FEB-84 KEI.LY BUSHING EbEVATION: RECTAt'~GtJLAR f'~ t'] R T H / SOUTH [" EET (.". r", (I R P 14 A T E S E.A S't'/w EST F I":; E T PAGE 5 207.39 494.16 823.91 11.57.35 lq45.15 !.729 40 1979157 2222'22 2481,44 269.76 749,65 1491.58 2296.64 3005,30 3700 54 4422i87 5189 74 5982.23 55.00 t 10'I'~0 . f) 0 120 00,00 130(.)0. O0 t 37 ~2. 7473.5g 7976,48 8517.]9 9025,62 '74!.8.5~ 56 ,13 ~,: tl 2 F; 7921,48 60 ~4 ~4 75 3 E ~462.1a 53 24. ~., 79 4. E 89'70,6~ 46 58 ~ 87 3~ E 1,'16 1.07 O'O0 2'159,60 3007,03 3196.72 3267~76 6777.37 7604'79 94.23,67 9011.98 HORIZ. DEPARTURE DISTANCE AZIMUTH FEET I)gG MIN 46,08 340.27 89'1,87 1704.00 2571.77 3334'7~ 4084,7] 4845.66 5645,50 6476.46 N 52 31 N 52 26 N 56 36 N 61 5 N 63 15 N 64 19 ~ 64 57 ~ 65 53 a 66 49 N 67 ~8 7317,66 N 67 50 81.77,72 ~ 68 25 9009,85 N 69 13 9586.14 ~ 70 4 .vl[ !', ~ ~.! P [:' I'; V t,: R !" I C A b ¥ v' p ,r 1 C A L r: ,r,: v ]: A T Y 0 ,~ ~', Z l t.: [] I' H n.t'!:3 c.O0 -55.0¢, ,) 0 ~' 0 0 E 59.00 55.00 O.O0 0 0 S 23 41 ~ !55.0n, 155 0(; 100,o0 n 0 s 2 15 ~ 255,n0 255:C0 PO0,O0 0 O S 38 51 E 455.0t. 455.06 aO0.O0 o 34 S 44 l E 655.0~ 655.00 600,00 2 51 ~,~55 28 E 755.37 75%.0U 70o.00 5 ,[3 :'~51 ~3 E '1059.41 1055.00 1000.00 13 18 1162 ..... 67 1155,00 l. lO0,OO, .... 14 5 ~ ,',,50 .... 2 E J26[':i,ql 1255.00 1200,00 13 46 ,:q59 "13 E 1472,ng , 4. :.~, 1455200 1400,00 17 5~ :x~ ~4 J, E 157';"' ~:,3 1555 o~;, 150n DO 2 16['i4,36 1665.()0 !6(i0,00 1896.0 i I ~55. O0 t 8o0. O0 2 2115 35 2055 (~.) 20:)0 nO 26 55 :,,~ 51 33 E 222R.(51 21. b5.~')~> ~l. on.no 29 ~7 ~,~ 5q 5 K 2345,56 2255.('~0 '220o.00 32 39 ~,~ b3 1 F: 2465,9(.) ~355 n~.:~ 23{':"),00 35 1. I. ,., ~2 27 F: 2590.00 z455'.00 2400.0f.) 37 1.4 ~.x~60 44 E 2843 (')~: 265s.00 26o0.00 38 23 ~,,~:c 2973.2:'~ 2755.uu 27(',0.00 42 24 ~.,~57 b2 E 3!13'~'1 2855.o0 2Bno.o0 45 50 ~ 60 50 E IQ0 FEI;_:T [)F DATE OF SURVFY: 6-FEB-84 Ki~]i.,l~¥ r',U$~ING KLEVATION: DOGf. EC-; .P EC T]', N G IIL.~ R C. :iC, R 1.31FtA TRS HORIZ. SEVMRI'rY NORT)f/$OUTH KAST/WEST DISTANCE nE(:; / [ 00 [--MET FF]F.T FEET 0,00 0,00 i',] ¢,00 fi. 0.00 1,07 0.01 N 0.19 h 0.19 0,16 0.38 S 0,22 ~i 0,44 0.48 0.74 S 0.09 W 0.75 .:.),15 0.~7 S 0.06 t.~ 0.87 0,41 1.20 S 0.01 E 1,20 2,14 1.,21 S 0,98 E 1,56 3,13 0.39 N 3.76 ~.; 3,78 !.26 4,9'9 ~.~ 9,85 E 11,04 1,86 12o20 N 18.89 E 22,49 PAGE 6 2, '7 4,76 2.30 l.ll !.71 I. '19 t. 03 55.00 ?. , 78 2.51 0.76 3.96 0.75 ~,10 4,13 22.38 36.78 54,27 68,62 81,16 99,06 123,95 1.44.55 183.1.9 DEPARTURE AZIMUTH DEG 0 0 87 54 30 8 6 43 3 49 0 30 38 57 84 0 6.3 6 57 8 3().61E 37,92 45,64 E 58.61 64.,57 E 84,34 85,76 E 109,83 106,55 F 1.33,94 127,37 E I61.36 152,3g E 196,43 179.~3 £ 230,72 20~.1,~ E 263,85 237.10 E 299,63 20B,52 237.48 26 ~ , 7 g M 297.49 tq 32'1 84 362 99 400 8O 435 ~2 484 44 535 29 ~ 53 t~ 51 N 49 N 51 N 52 ~; 50 a 52 ~ 52 49 8 57 20 42 7 52 12 5 18 271 ,27 :t08.75 351 t~6 q, 05 02 4,64 b6 529 36 ~95,65 655.02 734°28 8.1,7,82 342,16 389.52 442 62 502 53 568 a7 6,41, 86 717 94 786 65 879,~8 977..3 .....~ ';;4 '"~,):'~4,7(:~i 920,50 E 1090,53 1.19 640.55 N '1,051.60 E 1231,,33 ~t. 3~ 700. 34 N 1195,62 E t,()1 762,31 N 1343,95 E 1545,10 u,.55 fl26.75 N :1q, 98'44 E 1,711.,39 O,'''~''o~ 291,98 N :1657,76 8: 1882,50 ~).2a 959,uC) r~ 18'22,95 E 2059,81 2.22 1996,10 E 1029,38 ~'.~ 224~,90 4.20 1165,54 N 2.i15.89 E 2592.64 ~ 52 N 52 ~'~ 52 a 53 N 54 N 55 N 56 ~ 56 27 26 36 42 47 33 3 22 35 47 N 57 N 58 ~'~ 59 N 60 N 61 N 62 N 63 N 63 34 39 26 6 43 1,5 43 3 1,7 :'1~ ~'1 III ill ilq i[! lq ill V }< R T l C ik i~ 534 O. f;~ .l ,5494.7 56'48.30 58(;1 5954 () 107 , 44 6259.62 a41 ~, 8') ~563, 39:3 q' 255 4355 4455 45b'5 ~165~ 4755 4 q :,S S, 00 5055.00 5 l. 55,0 f: 5255,00 535 5. (.> 5455. eO 5655.00 575 ~, n { 5855,00 62 S 5. o 0 6355, n 64S5. O0 6555,0 o 6 fi 55. o 0 6.855,oo '.1. 'l O0 F'!::]h':f :'}F [30 g l.., !.': G S~.:V i!:;R ITY D k: G / [ 00 ,:). 5 7 · .). 95 0,44 .'). 81 ,'.),71 ,3 , .39 ,:t,75 I.. <) 7 1,67 t :'> ,90 0,93 "), 36 1.,56 32 O. ]9 't 0 , 81 1 ::3.99 l.,28 I ,2'1 O. 97 1,. 53 0.48 PAGE D A :r' i'.!? <.'~ 1T $ U k V F: tr: 6- F E B- 8 4 KE[,I,,Y ,~[iSP, ING E[.jEV/~TI(')N: E "~ G [ ~'.! F t-:: R: . ] O H .N S i'_1F~ 121.2.70 4 2433,56 E 2718,98 iq 1255.87 !q 2542.40 E 2835.66 h 1299.53 N 2050,93 E 2952,33 i,~ 1343.22 r.J 2759.00 E 3068,60 ~ 1~87,11 N 2866,09 E 3184.10 N 1431.97 N 2973.8~ E 3300,69 ~ 1476,5~ N 3079,98 E 3415,64 N 1521.55 N 3185.51 E 3530,24 N 1566.a4 ~ 3290,~9 E 3644,85 a 1611,64 N 3395.81 E 3758.84 N 1.653.67 t~ 3500,05 E 3871.,04 1694.37 N 3605,16 E 3983,4'1 17.)3,54 ~ 3711,97 E 4090.82 177:1.96 N 3820,95 E 4211,83 1810.b7 ~t 3933,03 E 4329.81. 1849,50 N 4044.97 E 4447,74 I28~.34 ~ 4155,92 E 4564,21. 1927.09 N 4267.55 E 4682.~8 !.966,33 N 43~3,37 E .4~04.20 2005.18 ~ 4500.59 F 4927.07 55,00i PARTIIRE AZIMUTH 2o44,87 ~,,~ ,:~324,,71 E 5056.62 2026.07 N 4755.53 E 5192.96 2126,80 N 428'7,10 F:. 5329,82 216d.24 N 5o19.03 E 5467.35 2210.24 r,,~ 51.51,g~ El 5606 04 225~.93 ~: 5289,29 E 5749 51 2299 45 N 5429,bl ~': 5896 36 2346' .41 ~ 5571.89 E 6045 79 2393,67 ~x' 57~.09 E 6197.04. 2441.75 N 5862.63 E 6350.79 2491 ,71 N 6012,88 E 6508,72 2543.32 hl 6164,39 E 6668.,44 2595,96 N b31.,~.62 F. 6827,40 2648.~9 N 6463,29 E 6985.03 2'700.32 Fl 660~.,60 E 7139,?t 2'750,36 N 675(),7~ E 7289. 9 2800.09 bJ 6i~96,26 E 74.43.05 2~50.42 N' 7051,09 E 7605,45 2900,4~ ~{ 7216.20 E 7777,27 2949.97 N 7392.49 E 7959,34 63 63 64 64 64 64 64 64 64 64 64 65 65 65 65 65 N 66 N 66 N 66 n 66 N 66 N 67 N 67 ~, 67 }~ 67 N 67 N 67 N 67 N 67 N' 67 ~51 67 N 67 N 67 30 42 53 2 10 17 28 32 36 42 49 58 7 !,6 25 33 41 5O 59 8 18 28 38 46 55 2 9 23 29 34 39 42 46 49 54 59 b 14. ~1956.33 79jS.Uu 1'2.156.37 20'-~fi.O0 1'234~. 26 b 155,00 127!7.5t 12893.31 2455.00 13226.00 13'3BI.6~ C O ;q P k; T A T I (') ~w b A T id: ,S !; t:~ - $ F A C [': i.i R S F f) O (; [, F. G '1900.00 ~}O 4,4 ~"i: 75 3 E 2,58 ~300.0,) 56 R ~.~ 77 20 E 0,77 8400.00 55 0 ;~600.00 50 59 ~.~ %{0 47 E 4,27 6700,00 48 4:2 ~' 22 59 E'. ~.24 ~OO.O0 .<~7 3 ~,~ ~)4 13 E 2.82 ~g'70.62 46 58 ~',~ 87 39 E 0,00 PAGg 8 DA'r~ C,F~ SURV~;Y: 6-FP28-84 kELLY 31]SHING ELEVATION: 55,00 JOHNSON 9ECTAi~*GUI,AR CE]OR NORTH/SOUTH FEET OINATES HORIZ /WEST DISTANC ET FEET DEPARTURE AZIMUTH DEG 2997,32 N 7568. 3040.21 ~J 7735. 30'10'11 N 7895, 3114.29 N 8049. 3148,12 N 8197. 3179.03 ~ 8338, 3206.07 N 2473. 3228.08 N 8600, 32~b,35 N 8718, 325'7,98 6! 8S2~, 03 E ~139.96 88 g 8311.84 19 E 8474,01 38 E 8630.83 56 E 8781 27 81 E 8924:24 49 E 9059 72 O1E 9185:89 05 E 9302,51 O3 E 94~0.02 N 68 23 N 68 32 ~ 68 42 N 68 5O N 68 59 N 69 7 ~ 69 16 N 69 25 ~g 69 34 N 69 44 3264.83 3267.76 8936.37 9011'98 9514.08 9586.14 N 69 N 70 55 4 P~i.IOHCC P~ A P,, K I-'~ 7~ ,vt E7 ~% $ L,~ E P PF]PT~I TVD ~472.33 DATE Or SURVEY: 6-FEB-~4 K~:I,,[,Y BLJ$itIN(; ~':LEVATI(JN: 55.00 I SURFACE LOCATION ORIGIN= 81T10W R15E RECTANGULAR COORDINATES NOPTH/St]UTH EAST/WEST 3169,00 N 8292.14 E 3199.25 N 8437.09 E 3266.93 N 8991.52 E · ,7'0 P .I' 0 ~? ,~ % I> ~ p T,-i ( ['~ I~ .[ [., L g ~;. ) ~ 301 '7. O0 ,! "~754. O0 ti. Il ',!-:~ AR Y LtV D FRO~,", KG ~527.33 9006.52 DATE OF SURVEY: 6-FE8-84 PAGE 10 55,00 I g366.51 8472,33 8951.52 S~IR~'ACE LQCATION AT ORIgld: S1 TI. OW R15E RECTANGULAR COORDINATES i,~OF~TH/SOUTH EAST/WEST 3169,00 a 8292.14 g 3199.25 a B437 09 g 3266.93 N 8991~52 E S~J[tVEY DATE]: 6,-FE:'B-84 June 7, 1984 ~. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-40002 Well: #9-21 (S~C 01 T10N R15E) Prud~ Bay Field North Slope, Alaska Survey Date: January 21, 1984 Operator: Samec Mr. Ruedrich: Please find enclosed the "Original" copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures RI:~Y"-'-::}.';UIq WEI...I_ SL. IF;:VEY I IqG COMF:'~IqY (9 ("7) ~/;; ~ .......... , ............................. . : : .':. r:,~:'r.'...~. ........ .: ~.~.::*~.,: ';~: ': ~ % ~"/~.) '~ f,~l,lf....I...l~...tl-~..~..~l::: AL. Ab, K,A : '~' '.;:~ : :,' '.~i:~:'.:'::'.~' :.:::;.~ :~ :::':(.'.'~..: F~RF:n ALASKA? INC:. '¢~? ~ ~'~. [,ATE: C)F suRVEy. D'.B '?--'21 (SEC: O1 'T'i()I'4 F'IRI_IEfHOE BAY ~.. dANI.AF:(Y 2:'.~:, :L'784 ,JOB NLIMBER AK-BCI-.4C)O02 ' :,( ', VERTICAl... sEr":'rI(')N C:AI_F:IJLA"rED AL(]I'qG (::: I_ O :::; L. RF-': MEA:.:.;LIRF.~:D Ii E' F:' 7' H 0 1 O0 ......................... 200 ::300 40C~ VF:RT I F:AL. VERT I C:AL. I IqCL I NAT I ON If I REC:'T' 101',1 S E V EI.':;~ I 'TV REC:'T'AIq(31...II_AF:~ ('-: r3 0 F;: [f I NATE'.'-:; VERT I f":P~ \ liEF'TH DEF"i"H I]Et::i r,'l I Iq I)[!!:GREE'.ii!; DF'G/:1. 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O0 , ~ · ' ~ -1500.00 13830 9~'O~J. O0 ! HOBIZONTFtL PROJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40002 Well: ~9-21 (S~C 01T10N R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: January 21, 1984 Operator: Samec Scale: 1" = 1500' ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. k~-BO-40002 Well: ~9-21 (SEC 01 T10N R15E) prudhoe Bay Field North Slope, Alaska Sur~ey Date: January 21, 1984 Operator: Samec Scale: 1" = 2000' 2000. O0 4000. O0 6000. O0 ~no0 O0 ,.,~. , . J 0000. 00, 9633.25' @ N 70° 37' E 2000. oo ,~obo. oo 50~.o. co I 8000. O0 ] 0~00. O0 VERTICAL PROJECTION Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. O~erator, Wel 1-Name and Number Reports and Materials to be received by: J- Date Recuired Date Received Remarks · Completion Report Yes 7- /7" (~ ~ ~?L.~ _. · · /~ ~~. ~ .... _ .... Core ~scr~p~n . Registered Smey Plat Inclina~on S~ey ~ . Drill St~ Test Re~s ~j,~~ ~-~ ~/~ u , ~~0n T~t Re. rte DS 9-21 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 1330 hrs, 12/09/83. Drld 17-1/2" hole to 2908'. Ran 71 jts 13-3/8" 72#/ft, w/FS @ 2846'. Cmtd 13-3/8" csg w/3800 sxs CS III + 400 sxs CS II. ND 20" hydril & diverters. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 13,535'. Ran 331 jts 9-5/8" 47#, w/FS @ 13,506'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC, FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 13,830', 01/08/84. Ran DIL/BHCS/GR/SP f/13,800' - 13,495'. LDT/CNL/GR/Cal f/13,800' - 13,495'. Arctic packed 9-5/8" x 13-3/8" annulus w/50 bbl CS I + 136 bbl A.P. Ran 16 jts 7" 29#/ft, f/13,179' - 13,830' Cmtd 7" lnr w/475 sxs "G" cmt. Drld cmt to 13,783' (PBTD). Ran CBL f~13,783' - 10,050' Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran 4-1/2" completion assy w/tail @ 13,203' & pkr @ 13,101' & SSSV @ 2303'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diese. Dropped ball & set pkr. Secured well & released rig @ 1000 hrs, 01/14/84. JMM/DH17- tw RECEIVED J U L 1 7 lg84 Alaska 0il 8, Gas 0ohs. Gommission Anchorage, 'L ?... V!,cl~ ~'T'Y MA~ WEi.,L. J NORTH ALASKA DISTRICT' PRUDHOE BAY JDWG No, J ARCO Alaska, Inc. Post Office ~,~----360 Anchorage, .a 99510 Telephone 907 277 5637 April 26, 1984 Reference' ARCO Cased Hole Finals ? D.S. 1-25 j 3-18-84 / PFC/GR D.S. 3-19'''~ 4-7-84 f' Collar/Perf D.S. 3-22J 4-7-84 ?" Collar/Perf Log D.S. 3-23~--~'4-7-84z''~ Collar/Perf Log D.S. 5-9'~'~- 4-8-84Ji CFS/Temp Survey D.S. 7-16 ~ 3-10-84f EPL D.S. 9-14'''~ 4-6-84J~ Collar/Perf Log D.S. 9-17f 4-6-84'/~ Collar/Perf Log D.S. 9-20-"'~4-6-84z/ Collar/Perf Log D.S. 9-21 ~j' 1-11-84' ACBL/VDL/Signature/GR D.S. 9-23~ 3-8-84./ ACBL/VDL/Signature/GR D S. 9-25~ 4-2-84J "Epilog/Sandstone Analysis D S. 12-26-~,~2-19-84/ ACBL/VDL/Signature/GR D S. 12-27~,~-6-84 / ACBL/VDL/$ignature/GR D S. 12-28/ 3-28-84 ~' ACBL/VDL/Signature/GR D S. 12-28~ 3-30-84 Collar Log (used to cut tubing) ---D S. 13-11 4-4-84~ Collar/Perf Log --D S. 13-11 ,~-~. s. 13-98 S 13-98 I D .S. 13-98 D. S. 13-98 , D.S. 13-98 iD.S. 13-98 D.S. 13-98 iD.S. 13-98 !D.S. 1-3-98 5" DA Run ALL 5" GO Run 1 5" GO Run ALL 5" GO Run 3 5" GO Run 1 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" DA Run 1 5" DA 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" GO Run 1 5" GO 4-4-84 ~ Diff Temp Run 1 5" GO 5-8-83 / Epilog/Carbon-Oxygen 5-pass overlay5" DA 3-16-84/ CPL/GST/DIL (3 runs) w/listing 5" Sch · "" ~ 511 no date Epilog/overlay avg. CO, SI/CA SW DA 11-12-83/ Epilog/Carbon-Oxygen 6-pass overlay5" DA no date~~' 2-13-84" 2-19-84' 2-18-84" 3-30-84~ 2-14-84? 2-16-84~ Epilog/Compare Induction Curves 5" DA EPilog/Carbon-Oxygen 5-pass overlay5" DA GST Inelastic & Stations Run 3 5" Sch GST Capture & Activiation Run 3 5" Sch CH DIL Run 11 5" Sch CH CNL Run 4 5" Shc CH DIL Run 10 5" Sch ~ 13-98 14-32~ 4-1-84/~' Collar/Perf Log Run 1 5" GO · 16-5 ~ 3-10-84//' Completion Record Run 2 5" Sch se sign and return the attached copy as receipt of data. Have a Nice Day! DISTRIBUTION Mobil ' ~ ' J~;"~'~-~ :"' D & X Mobil g & P ' ii::/-~ "'" ..~.~f"L~..~.._~"~ ~ Dallas Phillips ' ~'>~1 ,-'~ -. "'~7';' ~ . .'7 , '-.i;.:.Z~ Drilling Prudhoe Bay Well Files Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Kelly McFarland ATO-1429F Chevron Marathon State of Alaska Trans. #171 ARCO Alaska, inc. Post Offic.--~ ~"'~60 AnchoraG , xa 99510 Telephone 907 277 5637 April 13, 1984 Reference' ARCO Cased Hole Finals A_ f. D.S. I-iA 2-3-84 D.S. 9-21 2-6-84 D.S. 9-22 2-1-84 D.S. 12-25/~ 1-29-84 D.S. 12-25,~ 1-29-84 D.S. 14-14- 1-12-84 D.S. 17-6f' 3-24-84 CBL/VD Gyro Continuous Tool GR CBL/VD CET EPL Collar/Perf Ran 1 5" Sch Run 1 Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO se sign and return the attached copy as receipt of data. · FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFarland ATO-1429F Trans. #144 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smit~ ~~!~~~p State of Alaska '~;~a ~;} & [~as Cons. Co~nmissio~ Anchorage ARCO Alaska, Iri ~' Post Offic= :,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 20, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - DS 9 Wells 21-22 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG6/L40'tw Enclosure RE£E VED N~.ka Oil &. Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, inc. Post O ffi c~--~-,~'"~.60 Anchorag. ,a 99510 Telephone 907 277 5637 March 19, 1984 Reference: ARCO Open Hole Finals D.S. 9-21 1-7 -84 1-7 -84 1-7 -84 1-7 -84 1-7 -84 1-6-84 1-7-84 CPL/Cyber look BHCS DIL/SFL LDT / CNL / GR ( Raw ) LDT/CNL/GR (Poro) Depth Determination/Collar Log GR in 9 5/8" casing Run 1 '5" Sch Run 1 2" & 5"' Run ! 2" & 5" Run 1 5" Run 1 5" Run 1 5" Run 1 5" .~~Please sign and return the attached copy as receipt of data. HAVE A NICE DAY Kelly McFarland ATO-1429F Trans. # 103 DISTRIBUTION Chevron Mobil D&M Mobil E & P Dallas Phillips Drilling Prudhoe Bay Well Files Ext. Exploration R&D Exxon Getty Marathon Carolyn Smith Anohoraoe ARCO Alaska, Inc. Post Office ? '~0 Anchorage. ~.~ ., 99510 Teiephone 907 277 5637 February 24, 1984 Reference: Arco Magnetic Tape D.S. 9-21 2-6-84 2-6-84 GCT #68978 w/listing GCT Directional Survey Run 1 Sch Sch se sign and return the attached'-dopY as receipt of data. HAVE A NICE DAY! .. ._ . Kelly McFarland ATO-1429F Trans. # 078 -~.. ; .... / Chevron D&M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R&D Caroline Smith Sohio - ' : ~.. ~STATE Ot: ALASKA .--.. ~f'u~ ~ ' ALASKA ;LAND GAS CONSERVATION C(. i'MISSION MON I'HLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellx~( Workover operation [] 2. Name of operator ARCO Alaska, lnc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 290' FSL, 302' FWL, Sec.1, TION, R15E, UM 7. Permit No. 83-160 8. APl Number 029-21036 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 9-21 11 Field and Pool · Pru~llioe Bay Fi eld Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 55' RKB ADL 28345 January 84 For the Month of , 19 12. Depth at end of month, footage drilled, fishing jobs, directional d~illing problems, spud date, remarks Spudded well ~. 1330 hfs, 12/09/83. Drld 17-1/2" hole to 2908'. Ran, cmted & tested 13-3/8" csg. Drld 12-1/4" hole to 13,535'. Ran, crated & tested 9-5/8" csg, Drld 8-1/2" hole to 13,830'. OH logs. Arctic packed 13-3/8" x 9-5/8" annulus. Ran, cmtd & tstd 7" lnr. Ran CBL. Ran 4-1/2" compl, assy. Secured well & RR ~ 1000 hfs, 01/14/84. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 79'. 13-3/8" 72.0#/ft, L-80, BTC csg w/FS @ 2846'. 9-5/8", 47.0#/ft, L-80 BTC csg w/FS ~ 13,506'. 7", 29#/ft, L-80 BTC csg f/13,179' - 13,830'. SEE DRILLING HISTORY Instld w/1985# Poleset. Cmtd w/3800 sxs CS III + 400 sxs CS II. Crated w/500 sxs "G" cmt + 50 bbl CS I. Cmtd w/475 sxs "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/GR/SP f/13,800' - 13,495'. LDT/CNL/GR/Cal f/13,800' - 13,495'. CBL f/13,783' - 13,050'. 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the fore/g~o, lng is true and correct to the best of my knowledge. SIGNED '~.~Z , , ...... TITLE Area Dri 1 1 ing Engineer DATE 7-- NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 D R N / M R 64 Submit in duplicate DS 9-21 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 1330 hrs, 12/09/83. Drld 17-1/2" hole to 2908'. Ran 71 jts 13-3/8" 72#/ft~,_w/FS @ 2846'. Cmtd 13-3/8" csg w/3800 sxs CS III + 400 sxs CS II. ND 20" hydril & diverters. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 13,535'. Ran 331 jts 9-5/8" 47#, w/FS @ 13,506'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 13,830', 01/08/84. Ran DIL/BHCS/GR/SP f/13,800' - 13,495'. LDT/CNL/GR/Cal f/13,800' - 13,495'. Arctic packed 9-5/8" x 13-3/8" annulus w/50 bbl CS I + 136 bbl A.P. Ran 16 jts 7" 29#/ft, f/13,179' - 13,830' Cmtd 7" lnr w/475 sxs "G" cmt. Drld cmt to 13,783' (PBTD). Ran CBL f/1'3,783' - 10,050'. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran 4-1/2" completion assy w/tail @ 13,203' & pkr @ 13,101' & SSSV @ 2303'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1000 hrs, 01/14/84. - DRN/DH56' tw ARCO Alaska, Inc. Post Office tr '0 Anchorage. A, .... a 99510 Telephone 907 277 5637 February 2, 1984 Reference: Arco Magnetic Tapes w/listings ~/D.S. 9-21 1-7-84 OH # 68908 w/listing ~, ~~6.~-~-~4-~-i-.7--~79 ...... ~DT--M~-Answer'~-#68 ' w./1--i,st ing Run 1 Sch Ruh- 2 sCh'' Run 1 Sch · z , ~sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. # 036 D & M Dallas Drilling Getty Marathon Mobil DISTRIBUTION Alaska 0ii & Gas Co.s. Cor/)mi~iot) North Geology Anchorag~ Phillips Prudhoe Bay R & D Caroline Smith STATE OF ALASKA ~ ~ .... ' -" .... ALASK"'-"~I L AND GAS CONSERVATION ( ~IMISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 290 Workover operation [] 7. Permit No. 83-160 8. APl Number 50-- 029-21036 FSL, 302' FWL, Sec.1, TION, R15E, UM 6. Lease Designation and Serial No. ADL 28345 5. Elevation in feet (indicate KB, DF, etc.) 55' RKB 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 9-21 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. December ,19.83 ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1330 hfs, 12/09/83. Drld 17-1/2" hole to 2908'. Ran, cmted & tested 13-3/8" csg. Drld 12-1/4" hole to 13,535'. Ran, cmted & tested 9-5/8" csg. RIH & drl 10' Form LOT as of 12/31/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40, weld conductor set ~ 79' ~13-3/8" 72.0#/ft, L-80, BTC csg w/FS @ 2846'. 9-5/8", 47'.O#/ft, L-80 BTC csg w/FS @ 13,506'. _ SEE DRILLING HISTORY Instld w/1985# Poleset. Cmtd w/3800 sxs CS III + 400 sxs CS II. Cmted w/500 sxs "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run N/A 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED 911 & Gas Cons. / , NOTE--Report on this form is required for each calendar month, regardless, of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate DRN/MR56 DS 9-21 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 1330 hrs, 12/09/83. Drld 17-1/2" hole to 2908'. Ran 71 jts 13-3/8" 72#/ft, w/FS @ 2846'. Cmtd 13-3/8" csg w/3800 sxs CS III + 400 sxs CS II. ND 20" hydril & diverters. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 13,535'. Ran 331 its 9-5/8" 47#, Wo/kFS @ 13,506' Cmtd 9-5/8" csg w/500 sxs "Gi' cmt. Tstd csg to 3000 psi - . Drld FC &'cmt. Tstd cs§ to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok, as of 12/31/83. DRN/DH50'tw RECEIVED :JAN '1 Oil & Gas MEMORANDUM State of Alaska TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATION COMMISSION C. V.~t~r t on · Lonn±e C. Smith ,--- ~-,. Commissioner Edgar W. Sipple, Petroleum Inspecto~.~~.~~ DATE: December 16, 1983 F,LENO: 51.2 TELEPHONE NO: SUBJECT: Check Diverter System and Witness BOPE Test on ARCO's DS 9-21, Sec. 1, T10N,R15E,UM, Permit No. 83-160, Rowan Rig 35. Tuesday: De'cemb~er_13'. 1983: I traveled this date from Anchorage via Alaska Airlines to Prudhoe Bay. Upon arrival at ARGO's DS 9-21, Rowan Rig 35, the drilling contractor was in the process of running casing. Wednesday, December 14, 1983: The BOPE test commenced at 8:00 am .~nd'-wa~ COncluded at 1~2~-55~pm this date. There was one failure: the seal on the blind rams door leaked; a new seal was instal-led, it tested to 5000 psi successfully. I checked out the diverter system on this rig and it was in compliance with API RP53 and State Regulations. I filled out the A.O.G.C.C. BOPE inspection report which is attached-to this report.- In summary, I witnessed the BOPE test on ARCO,s DS 9-21, Rowan Rig 35. Attachment 02-00IA(Rev. 10!79) 4/80 STATE OF AI,ASKA ALASFUt OIL & GAS CONSERVATiOr} COHMISSION B.O.P.E. Inspection Report Inspector operator Well :~': Location: _ -- Drilling Con tracto~r- Location, General Well Sign General Housekeeping Reserve pit Rig Rig ~-J3 BOPE Stack 1~<:'° "'"~" Annular?reventer Pipe Rams Blind -Rams C~oke Line Valves H.C.R. Valve Kill Line Valves Check~ Val~e Date_ /~2- /y-- ~ Test Results: Failures Repair or Replacement of __ ACCUt%U LA'FO R S'Y S Tlg'l ~ull Charge Pressure ~0~-~ Pressure After Closure Test Pressure ~'~ "'iiUppcr Kelly . ~ :fLower Kelly ~ Ball Type_ ft. ps.ig ps ig 200 psig Above Prechar9e Attained: ~[P min.-~_~sec _ Pressure Attained: ~ rain 3 ~sec Full. Charge . Cqntrols: Naster Remoto ~ Blinds swL~ql~_~_~. ~/ __ Ketl~ a~Floo~ Safe~LValve~ ' Pressure Inside BOP. Choke Manifold -~'~-' ~o. Valves /V' Test Pressure Test Pressure No. flangeS ,~'~J '' Adjustable Chokes_ / ~ /].AY- ilydrauically operated choke~ failed equipment tO be made within Inspector/Commission office notified. . . , ~.. t/ Distribution orig' - AO&GCC cc - Operator cc - Supervisor / '--t/ [ STATE OF ALASKA ALASKA v4L AND GAS CONSERVATION Cf ..... 'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER ~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-160 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21036 4. Location of Well Surface: 290' FSL, 302' FWL, Sec. 1, TION, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 55' Pad 21' 12. I 6. Lease Designation and Serial No. ADL 28345 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~[. Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.} 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to set the 13-3/8", 72#, L-80, BTC surface casing to a depth of 2700' TVD (3100'MD). Drilling of the well is in progress as of this date. Surface casing is estimated to be set sometime December 13, 1983. Verbal approval received on 12/12/83 from C. V. Chatterton 14. I hereby certify that t~he for,e~'ng is true and correct to the best of my knowledge. Signed ~ , ~ Title The space below for Commission use Area Drilling Engineer Conditions of APproval, if any: Approved by COMMISSIONER Approved Cop'/ R~turned By Order of the Commission Form 10-403 Rev. 7-1-80 GRU5/SN33 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate November 4, 1983 Mr. Mark A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re ~ Prudhoe Bay Unit DS 9-21 ~CO Alaska, Inc. Permit No, 83-160 Sur. Loc. 290'F~, 302'F~,TL, Sec. 1, TiON, R15E, Btmhole Loc. 1246'F~, I146'FEL, Sec. 6, T10N, R16E, UM. Dear Mr. Mai or ~ Enclosed is the approved application for permit to drill the above referenced well. If coring ia conducted, a one cubic inch chip from each foot of recovered core ia required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required sa per 20 AAC 25.050(b)(5). If available, a tape eontaining~ th~ digit~zed log infor_matio.n shall be submitted on all loga ~or copying except experimental l°g~, velocity ~urveys and dip~ter $~urv~ys. M~ny rivers in Alaska and their drainage syst~,ns have been e!a~$ified am important for the spawning or migration of anadromous fish. Operations in the~e areas are aubjeet to AS 16.05.870 and the regu!ationa promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing opmrations you may be contacted by the Habitat Coordinator's Office, Depar~ent of Fie~h and Game. Pollution of any waters of the Stat~ im prohibited by AS 46, Chapter 3, Article 7 and the regulationm promulgmted thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operationm you may be contacted by a representative of the Department of Environmental Conservation. To aid u~ in ~cheduling field work, please notify this office 24 hours Prior to com~encing installation of the blowout Mr. Mark A. ~:~jor Prud-hoe Bay Unit DS 9-21 -2- November 4, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe i~ drilled. ~R]ere a diverter system required, please al~o notify this office 24 hours prior to c~nmencing equipment installation ~o that the Commission ~tnes~ testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandor~ent, please give thi~ office adequate advance notification so that we ~ay have ~tne~ present. Very truiv / .. / (:- V. Chatterton BY ORDER OF THE Chairman of Alaska Oil and Gas Conservation Comn~ission be-. 5=}-;iA cc~ Depart~ent of '-'-'-~'~.~ & Came, Habitat Section. w/o encl . Department of Ena'ironmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 31, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 9-21, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 9-21 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on November 30, 1983, your earliest approval will be appreciated. Sincerely, ~.D~S. Sml 1 ey Area Drilling Engineer DSS/JG: tw GRU5/L20 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA O~L AND GAS CONSERVATION COI~,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL[~( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [~X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 290' FSL, 302' FWL, Sec.1, T10N, R15E, UM At top of proposed producing interval 1320' FNL, 1320' FEL, Sec.6, T10N, R16E, UM At total depth 1246' FNL, 1146' FEL, Sec.6, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 55', PAD 21' 6. Lease designation and serial no. ADL 28345 9. Unit or lease name Prudhoe Bay Unit 1~3. Well number 9-21 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 4 mi. E. of Deadhorse miles 290 feet 9-20 well 114'(~ 804'TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 13584' MD, 9058'TVD feet 2501 11/30/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3466 psig@__ Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 52 oI (see 20 AAC 25.035 (c) (2) /,L0_7_{TL~psig@_9058 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole I Casing Weight i0" 20" 7-1/2" [ 13-3/8" i2-1/4" I 9-5/8" I-1/2" I7'' 22. Describe proposed 91 .5# 72.0# 47.0# 29.0# program: CASING AND LINER Grade Coupling H-40 We] d[ L-80 BTC L-80 BTC Length SETTING DEPTH MD TOP TVD 80' 33' I 33' 2863 33' I 33' 13298 32' 13030' 554 I 32' i 18540' MD BOTTOM TVD 113'I 113' 2896' I 2500" ' 13330' I 8902 ' 1358~'19058' I I QUANTITY OF CEMENT (include stage data) 2000# Poleset ~300sx CSIII & 400sx CS I ;00sx Class G & 300sx CS I. 400 sx Class G ~iARC0 Alaska, Inc., proposes to drill this well to 13584' MD (9058' TVD) to produce the Sadlerochit zone. Logs i will be run across selected intervals. A surface diverter will be installed and operationally tested prior to ispud. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 4-1/2", 12.6#, L-80 tubing, packer, and gas lift mandrels will be run. The packer will be set above the Sadlerochit. Provisions for subsurface safety equipment will be run. A non-freezing fluid ~will be left in all uncemented annuli within the permafrost interval. A Sundry Notice will be submitted when the well is to be perforated. DS 9-21 will be 114' away from DS 9-20 ~ 804' TVD. There are no other close wellbores anywhere downhole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge CONDITIONS OF APPROVAL Samples required E~YES Permit number APPROVED BY Form 10-401 GRu5/PD05 x Mud log required I--J YES ~0 Approval date Directional Survey required (~YES I--]NO APl number 50- o"z,~ -'z..~ o ~ G SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 4, 1983 by order of the Commission Submit in triplicate 0 ~200 2400 ~800 4800 8000 7200 8400 96O0 10800 A : :i:i:i:i:i:i:i:i:!: :::::::::::::::::::::::::::::::::::::::: :i:i:i-!:i:i:i:!:i: :i:i:i:i:i:i:i:!:i: ::!:i:i:i:i:i:!:i:i: ::i:i:i:!:i:~:i:~:!: .'~:::::~:~:~:~:~:~: :~:~:~:~:~:~:~:~:~:: -:.:-:.;-:..=,6.;.:. I(,:~1R.1'.¥O:.~110.;.'.:.:.:.:.:.:..;.:.:.:.:-:.;-:.:. 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J '-.'.''*'. ..... .-.' .i.!.i.!.i.!.'.!.i..!.~[~.!.!~.:~:!.i.!.i.~.!.!.:.~.:.:.:.:.:..:.~.:.:.:.~.:.~.:..:.:.:.:.:.~.:.:.:-:-:-:-~-:-:-:-~.:--:-:-:-~.:-~-:-i-i--i-!-i-!-i-!.i.!. EAST 8676 .:-:i-!.:-:-!.!.:. :!ii: :i:!:i:!:i:!:i:!:i: :i:i:i:!:!:!:i:!:i: :!:!:i:!:i:i:i:i:i' :i:!:i:!:i:!:!:!:!: :i:!:i:!:i:!:ii!: ......... ~ .:.:.:.~....! .:~:.`.~.:.:.:.Li.:.-:..:.:.:.:.:.:j.:.:.~.=.:.:.:.:.:.:`=.:..:.i.:.:.:.:.:.:.~..:.:.:.:.:.i.:.:.: ..:~.!.i-:.i.~4..:.:.:.:-=.=.:a-~-.:.~-:.:.:.:.:.:.:.~-:.=.=.:.=-:.:.:.:.-:.:.:.:.:.:.:.:.:..:.::.:.:.:.:.:.:. .:.:.:~,~.~ .:~:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:...:::.:.:.:.:.:.:.:..L:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.. .:~.:.:.:.: ...... :.:.:.:.:.:.:.:.:..:.:.:-:.:.:.:.:.:.-:.:.:.:.:.:.:-:-:-:.:.:.:.:.:.:.:.:..:-::.:.:.:.:.:.:. ,d''''' ,i' ''''''''' ''''''''' I ..... 'l~ .l'''''''' ''llllll IIl~''''' ''''''''' ~'''' .... '~'~'' ''''''' ..... ':':':':':': ':':":':':':':-:-:':':-':':':':':':':':':' :':':':-:':':-:':":-:':':':':':':':":':':':':':':':': ':':':':':':':':':":' SHL' 290'FSL, 302'FWL, Sec i , .:~:~:~:~:~:~: ~ .:.:.:.:.:.:..:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.: .:.:.:.:.:.:.:.:.:..:. , ..:.:.:.:.:.:. I '' .... '' ''''''''' '''~''~'' ''*''*''" *''''''*" '~*''~'' ''''''''' ' . :i:!:!:i:i:i: :i:~: :!:!:i:i:i:~:!:i:!. :!:i:i:i:!:i:i:i:!: :i:!:i:i:i:i:i:i:i: :~:i:i:~:i:i:i:i:~: :!:~:!:i:i:!:i:i:i :i:i:i:i:!:i:!:i:~: :i: THL' 1320' FNL, 1320 ' FEL, Sec 6, . .:.:.:.:.:.: .:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:.:.,.:.:.:.:.:.:.:.:.:...:.:.:.:.:.:.:.:.: ,.:.:.:.:.:.:.:.:.:..: '-:-:-:-:-:-: ':-:--:-:-:-:-:-:-:.:-:--:-:-:-:-:-:-:-:-:--:-:-:-=-:'-:-:-:-:-t-:-:-:-:-=-:-:-:-:- -:-:-:-:-:.:.:.:-:-:-:.:-:-:-:-=-:-:.-: T10N, R16E, ~M :':':':':':':' '~'~'~'~'~'~ .~.~..~.~.~.~.~.~.~.~.~..~.~.~.~.~.H.~.~..~.H.~.~.~.~.~.~...~.~.~.~.~.~.~.~.~...~.~.~.~.~.~.~.~.~ ~-~-~-~-~-H-~-~-:~-~ :'~'~'~'~'~'~ . .:~:.:.:.:.: .:.:..:.:.:.:.:.:.:.: .:- -:.:.:.:.:.:.:.:.:..:.:.:.:.:-:.~.:-:..-:.:.:.:.:.:.:.:-:.~.........~-:-:-:-:':':-:-:-:-.-.-, .-.---.-.-.-~'-- -:-:-:-:-:-:~:-:-:-~ -:. . . ...... I ,,,,,, ,, ,,,,,,,,, ,,ill,ii; iiiiiiillll;Gill;i i~,,,i,,, iii,,,;;;';,,,G~,,I,,,,,,,,,I,,,,','''l'''''''''I -10~ 0 I~0 20~ 3000 4~0 50~ 8000 7000 80~ 9000 !00~ 11000 E - N COOROINflTES NOTE' WELL PATHS EXTEND BEYOND VIEWING WINDOW. · E - W 000ROINi=ITI-.~ - 1 O0 0 1 O0 200 300 ~00 500 600 ., I I I I I I I I i I I I I I I I I I I I I I I I I I I I l"l~, ',r .. , -~ ARC() .ALASKA,_ INC. _ ~ : -' '9-21 X 1,667 ' . ,7,~558 .. '~_4_R25 .' , ,, ~,~7~ , ~" ~51SO ~,'i325 . O ; I I I ANNUI...~, PREVENTER PIPE PJ~S SPOOL 13-5/8' BOP STACK OIAGa~ Acc~ul'ator Caoacity Test ~,. Check and fill accumulator reservoir ~o proper l~el wi~ h~raulic fluid. ~ Assure that mcc~ulator pressure is 3000 gsi with XSO0 psi downstre~ of the regulator. 3. Obs~e ti~, tb~ close mll units simult~e- ously ~d r~ord the ti~ ~d gressure rmeining after all ~its ere clos~ with Cherging p~ 4. Record on IAOC report. (~e ~ccept~le lo~r 11mit ts 45 seconds clostng ttme and ~200 psi rmmining pressure. 13-5/8' BOP Stack Test ~o Fill BOP stack and manifold with a non-freezing liquid. 2o Check that all hold down screws are fully retracted. Hark running Joint with predeter- mined plug seating depth. Run test plug on drill pi~e and seat in wellhead. Run in lock 'down screws. 3. Close annular preventkr and chokes and bypass valves on manifold. ¢. In each of the following tests, first hold &,250 psi low pressure test for a minimum of -3, minutes, then test at the high pressure. $. Increase presure to 3000 psi and hold for a minimum o(_ 3 minutes. Bleed pffessure to zero. . . 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. .' 8. O~en top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. ~0. Bleed pressure to zero. Open bBttom set of pipe ~l. Back off running joint a~d pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. ~Z. Bleed pressure off all equipment. O~en blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. ~3. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomeyp~. ~5. Check operation of Oegasser. 15. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOrE test once a week and functionally operate Bore daily. Rev. 5/13/81 SURFACE HOLE D IVERTER ARCO ,ALASKA SYSTEM INC'. SCHEMATIC IO" HYD. OPR. BALL VALVIE /..~.~--VVE,L,L BORE (SEE DETAIL) IO' HYD. OPR. BALL VALVE I ALL 90° TURNS ARE "TEE" CUSHION I ~LL QBORE 60' RESERVE PIT AREA NOTE · FLOW1_ INE DR ILL ING RISER ,, F L 20" 2000 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 202601020 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee /-"~""~- ,,~' ,.oc C, .(2 thru 8) (3) Admin .,~., ~, (,9 thru 11) (4) Ca sg ~ //-~o-~,~ (12 thru 20) (21 thru 24) (6) Add: ~.' ' ~ .//.,~. -,f3 YES , , , Is the permit fee attached ........................................ ~7~._~__ 2. Is well to be located in a defined pool .............. 3. Is well located proper distance from property lin~'iiiiiii ! 4. Is well located proper distance from other wells .. 5. ~~i~e~~~t~da~e~la~a~}~ti~n~e~Oli 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. NO Does operator have a bond in force .................................. ~- Is a conservation order needed ...................................... ~_.~ Is administrative approval needed ................................... · WELL ?'~ Is conductor string provided ...................................... Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation proposed ......................... Is a diverter system required .... ~ Are necessary diagrams of diver;g~';~ ~'~i~; ;;;;~ ~i~222 ~£1 Does BOPE have sufficient pressure rating - Test to ~-~ psig .. ~,f~/ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engineering HWK ___~ LCS~__ BEW~-- WVA ~' HJH rev: 12/06/82 - INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , ,, Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No 'special'effort has been made to chronologically organize this category of information. .. i,T$ '1'APl;: r,vp OlO,t4o2 vttw.rFitCatlq:,.~ !,'tSTttX~G PAGI.,T. I ** "l'hP? I~F:/',DI"'P ** g A','V F, ;,q4!O?l~ 4 ORIGIN : 68~'7 CONTINitATION ,$ ,'.0.1. PR~V .TO!,!8 TAPE : C,,.,~,,,~.~,N $ BEroO~R WF.',.I,[~ SF, PVI ...... S PROPRIETARY FIELD TAPE ********** EOF F I I.,F', N A g .F., :EDIT .001 SERVICE NANF; : V~RSlON ~ : ~AXI~t!~,1 I,,EMG~H : '~024 F l [,E~ TYPF ** IN~"OR~,~,~'elnN RECORDS ** CN : hTLANTTC RTCHFII?<LD CO. W~;~' : DR T[,L SIg'K T 0 W N: ~ 0 W S t;: C T: Stat: ST A'i.'F s I. Z E 1 66 73 65 TYPE C,aTM SIZE 000 000 022 065 0o0 000 015 065 000 000 011 055 000 OOO 003 065 000 000 003 065 0oo 000 001 065 000 000 006 065 0o0 000 0o5 065 g ,~,tT R Y 255 ~i 0 , '1 T b V p 0 ! r,. H 02 V t.,: r, l F' I C Z~ ';' I O ~':' t, ..T. $ T I N q P h .C, F 2 DEP'I' VDI<P CC? F~..t' DEVI ,qCT DE $ $ P R c: CZ "P F 'r EW.rDR GC? D C.; T, C; C .r P ',!,J ** l)gT!; ** DEDT 22.0000 GOEP DED']' .1 O0, O0r~0 DEVI 0.21,31, BEPT ~00,0000 GDEP DEVI O 20~5 N OEPT ~()0, OOnO DEVI 0,0769 DEPT 400. O0n~ GDEP DE]VI o. 7'25 ~. NSD~ D F', P T 600,0000 g r) P, P ..... ~ , , .~, . B E P'P 70 ~, DEPT 8uO. 0o0() GDEP DF;V I 7.0406 DEPT or) O, 0000 G OFPT 10oo. aoO0 G[)FP O~FP'..[' I l~fi Or)00 ,3,., V I 1 4.59 ~' ' DE'. P '.I' 1. 2()0. C)~nO g IT AP! APT APl (;' 0 0 0 0 0 o 0 0 0 0 0 0 0 0 O O 0 o C' 9 53,3083 0,0.1. ~. 7 1.29,3866 -0,7777 233,1765 32.5.3932 -0,~178 420,4962 526,o'271 -1 , 34~.9 6 ~. g, 7773 -~, 3773 3 ~ J 645 828.0O54 1, n.0072 97l .5j75 ~.~.21,42 025,6775 46.9378 21 5. n418 AP1 0 0 0 0 0 0 P I 1, E 0 0 0 0 0 SIZE 4 4 4 4.. 4 4 4 53,3075 -0,~941 120.38~3 -0,2058 233.174..':t -0.14,~ 5 325,39O9 -0.0177 4.20. 4934 -0.0770 5.2~,0216 ,K379 619.74.29 2.55~2 723 '.~'~29 7; 048 82,, 8 16, 5'4 919.¢258 26,0433 ..1. o22,0928 aO.33q6 1 ! i 3.00q:.,i 56,2n21 1206.4.519 75,292.~ PROCF. SK b [.': v E L 0 0 0 0 0 0 0 O. HI, hZ tD G I.: HLAZ OGl,, H h A Z P, GI, H bA Z H l..,.h Z DG I., H [..~ ~ Z ttl',AZ DGI', D ~ L D G H L A Z OGt, H f,,, A Z DGL H'LAZ DGI, r) (, ,,,,, SAMPLE CODP 68 68 68 68 6~ 209.4151 1.1234 194, 7644 0:3435 144,3754 0,3407 2,9042 220.4O96 163,041.7 0,J692 1. O53 58,~934, 5~:4572 4607 35 48,566~ ],8792 46,~313 1. 950 46.9509 1.1740 57.0O23 4.3092 D F: p !I': i 30 C! · 0000 C ~ F P DEV! .1.3,637,?.. ~"SPP OF:VI 15~a030 DB:PT 1500.00o0 GDFiP DEVI lq.4gb() OgVI 19,0016 OEP? 1700.o000 GDPP OF, vi lg.41f, 8 ~,~$DR 9EPT t. ROe), 0000 OgV! 1B,q'727 OF;PT 1900,0000 GDEP ..r) EV I 2'2 . 77 !. B l'!S DR DEPT 2000,0000 OgVl 24,3797 DEPT 2100,n000 dDEP OF:V I 2~. o679 ~,., S U P, O F: P T 22...() o, 0 () n 0 G f) F' p D F, V I 2 o. 412 () N'S D R DF:PT 2300 O0O0 CD F,'P .D E V ] 32: ~ g -q 3 t,I $ D o r)FlPT 240~ OOOO DEVI 3 ~ "g079 NSDR O E', P T 2500.00 n 0 C, D E P OEPT 2600, CoO0 C. DFO DEV I 37. ~ ,ii ..'5 g DEPT 2700 O El V I. 37 O E V I ~ B i 34:14 ~,,~ S D R D E',P T 2 q 00 o 0000 C, f)E P r). F. P T 3 n 00 0000 (; p r.~ P 1317 !.418.3367 88,~.1.64 1518,8516 109,7189 I61° 3428 I 32 ~ 6496 17~.7346 ! 50, l~20,272q l 92n, 9404 202! ,4233 212,61g~ 2122,1460 239,40~9 268,55J 2333,q146 99~, 650n ~4.1.~}.. ,5376 31 ,57~1 2510.5283 34,0. 0255 57~15.t372 370.35 ~ 0 27~0 59Sl 42q ' 0395 2921,3398 3005 49A:2310 130'5...0371 96 , 429"1 1403.0867 !16.03O0 1498.7874 137,R776 %593,4045 ~62,7347 16R8,560~ 1. R9,33?8 1783.R809 216.2173 1~7~.0623 244,7095 2061,0664 5 ,1860 2245.2036 39q, 3871. 436,8437 2391,2622 497 gl14, 24754 ~5714 2557.9395 597.6 t ,47 2626,4976 643.977~ 27~¢.,8677 7 , ·3776 277g.7~o~ 75~,9230 HL/~Z HLAZ DGL DGL DGL H LA Z HLAZ DGL ~LAZ [:) g I, HbA Z D(;L DGL D G I,., HLAZ Hr,AZ DGL ~ L A Z ~bAZ NIL, AZ D G L H L A Z 0 GL 59,3479 0,g081 49,751.4 9,8988 44,8554 3,2973 52,~764 2,g055 5~,5462 0,2644 54,382~. 2,7692 53,4421 ~., 8894 52,g61.0 3,0850 51..2~11 1,72~5 58 9847 5~2694 63,194q 1,5641. 63,1069 ] .9844 61 6210 ~;75~0 60 0:7715 59,9045 1. 0553 59,325~ 0,9158 58,1744 4.0048 57,8076 I, VP 0!L),H02 VF:~IFI('iaTIf')4 L3STI'NG PAGE BEPT DF'V! OF. VI D~PT DE, VI DEPT DEVI D~?PT D E P T DEV ] O~?PT D~]VI O~PT 0 E V I O Fi P T DEV D E P T DEVI D E V I, DEPT DF, PT O~V! 320 o. (; 0 ('; 0 C: I) Fl P 49.9a03 .~tSr)R 3300.0!)00 f;ll~P 5¢.09o3 tISDR 34 L) O , P: 00 '0 C ~,) P P 56.23'34 D~SDR 35(,0. 000. 0 GDFP 57.2.!09 '~$DR 3600 0{)00 GDFP 57:777a 3700.0000 5 ~, 109 () 3800 . 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