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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-11 PRUDHOE BAY UNIT 09-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 09-11 50-029-20236-00-00 176-084-0 W SPT 8359 1760840 2090 844 840 844 846 51 58 63 68 4YRTST P Adam Earl 5/26/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-11 Inspection Date: Tubing OA Packer Depth 53 2326 2228 2203IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220529073032 BBL Pumped:7.7 BBL Returned:6 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 0,7GXH ZHOOZDV6,VLQFH QRWLFHRI LQWHQWWRSXWRQLQMHFWLRQUHF GMEU James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 15:01:41 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector 09-11 (PTD #1760840) will need AOGCC MIT-IA when POI Date:Wednesday, May 25, 2022 9:27:55 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, May 20, 2022 6:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector 09-11 (PTD #1760840) will need AOGCC MIT-IA when POI Mr. Wallace, Injector 09-11 (PTD #1760840) was made Not Operable in 2019 after it lapsed on the 4-year AOGCC MIT-IA. Operations is ready to resume injection, the well is now classified as OPERABLE. An AOGCC witnessed MIT-IA will be scheduled when the well is on stable injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, September 30, 2019 11:02 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 09-11 (PTD #1760840) Will not be brought online for 4 year AOGCC MIT-IA All, Injector 09-11 (PTD #1760840) is due for its 4 year AOGCC witnessed MIT-IA on 9/30/2019. The well is currently shut in and there are no plans to bring it on injection in the near future. At this time the well is reclassified as Not Operable and will remain shut in. Once the well is ready to be placed on injection it will be reclassified and witnessed MIT-IA will be performed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable Injector 09-11 (PTD #1760840) slow IA re-pressurization Date:Tuesday, October 19, 2021 9:09:30 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 8, 2021 2:15 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Not Operable Injector 09-11 (PTD #1760840) slow IA re-pressurization Mr. Wallace, Injector 09-11 (PTD #1760840) is currently Not Operable for lapsing on its 4-year AOGCC MIT-IA. The well has not been on Injection since 07/15/18. On 02/13/21 live gas lift valves were installed and a temporary flowback was performed from 02/19/21 – 03/20/21 utilizing artificial lift gas to assess the possibility of converting the well to a full-time producer. The production rates did not justify the conversion and the well has remained shut-in with the live gas lift valves installed. During a review of the AOGCC Quarterly Not Operable Injector report, it was discovered the well had an increasing IA pressure trend. This notification is to satisfy Rule 7 of AIO 4G. Plan forward: 1. Slickline: Replace live gas valves with dummy gas lift valves 2. Well Integrity: Monitor TIO pressures/fluid levels and perform additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, September 30, 2019 11:02 AM To: AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: NOT OPERABLE: Injector 09-11 (PTD #1760840) Will not be brought online for 4 year AOGCC MIT -IA All, Injector 09-11 (PTD #1760840) is due for its 4 year AOGCC witnessed MIT -IA on 9/30/2019. The well is currently shut in and there are no plans to bring it on injection in the near future. At this time the well is reclassified as Not Operable and will remain shut in. Once the well is ready to be placed on injection it will be reclassified and witnessed MIT -IA will be performed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 • • 176084 24057 WELL LOG TRANSMITTAL #904979149 To: Alaska Oil and Gas Conservation Comm. August 28, 2018 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 09-11 Run Date: 7/15/2018 ��ANID p a 8 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 09-11 Digital Data (LAS), Digital Log file 50-029-20236-00 GEIv ED RE o�B p,11G, 31 2 AOGCC I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com and GANCPDC@USAANC.hou M/� I Date: Signed: RECEIVED • • �-,�-�� OCT 19 2017 WELL LOG TRANSMITTAL#904236429 AOGCC To: Alaska Oil and Gas Conservation Comm. October 9, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOi GED ‘•2. %2017 K. BENDER RE: Leak Detect Log: 09-11 Run Date: 8/17/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 09-11 Digital Log Image files 1 CD Rom 50-029-20236-00 Leak Detection Log SCANNED `. 2 1 Color Log 50-029-20236-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed:/ ,M(f2ct hcv / .-ef.teeft • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, September 11, 2017 1:09 PM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Chamansingh,Ann Marie; G GPB FS2 Drillsites; Nottingham, Derek;Ohms, Danielle H; Stechauner, Bernhard; Regg,James B (DOA); Wallace, Chris D (DOA);AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras 1 Subject: OPERABLE: Injector 09-11 (PTD# 1760840)Well barriers restored, MIT Passed All, Injector 09-11 (PTD# 1760840)was made Not Operable after a failed MIT-T. A leak detect log was performed and a gas lift dummy valve was changed out. The well passed a MIT-IA on 9/10/17 along with a PPPOT-T on 02-9-17. The passing pressure tests confirms two competent well barriers. At this time the well is reclassified as Operable. Please mind fluid packed annuli when placing the well on injection. Plan Forward/Work Completed: 1. DHD: MIT-IA- Failed 2. Fullbore(Contingent): Load and Kill Well-Complete 3. Slickline (Contingent):Set downhole plug-Complete 4. Fullbore: MIT-T—Failed 5. Slickline: Leak detect log, replace dummy valve 6. Fullbore: MIT-IA—Pass 7. Well Integrity Engineer:Additional Diagnostics as Needed Please respond if in conflict with plan. Thanks, Matt Ross E® EP �Q l (Alternate: Josh Stephens) S`AN� Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, May 28, 2017 10:47 AM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK,OPS FS2 Field OTL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; Drotar, Mark; Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS FF Well Ops Comp Rep Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras 1 Subject: NOT OPERABLE: Injector 09-11 (PTD# 1760840)Tubing by Inner Annulus Communication All, Injector 09-11 (PTD#1760840)was placed Under Evaluation on 05/07/17 after exhibiting anomalous IA pressure trends. Attempts to bleed the inner annulus on 05/07/17 showed rapid repressurization indicating possible TxIA communication. An attempt to MIT-IA failed on 05/12/17. Kill weight fluid was pumped along with setting a tubing tail plug. During an attempt to MIT-T the well showed rapid tubing by inner annulus communication.The well is now classified as Not Operable. Plan Forward/Work Completed: 1. DHD: MIT-IA- Failed 2. Well Integrity Engineer: Additional Diagnostics as Needed 3. Fullbore(Contingent): Load and Kill Well 4. Slickline (Contingent):Set downhole plug 5. Fullbore: MIT-T—Failed 6. Well Integrity Engineer:Additional Diagnostics as Needed Please respond if in conflict with plan. SCANNED MA!" 3 0 _ i 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, May 7, 2017 2:39 PM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL;AKOpsProdEOCTL; AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; Regg, James B (DOA);Wallace, Chris D (DOA);AK, OPS FF Well Ops Comp Rep Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington, Aras J Subject: UNDER EVALUATION: Injector 09-11 (PTD# 1760840)Anomalous IA Pressure Trend All, Injector 09-11 (PTD# 1760840) has begun to exhibit an anomalous IA pressure trend. Attempts to bleed the inner annulus on 05/07/17 show a rapid repressurization indicating possible TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. DHD: MIT-IA 2. Well Integrity Engineer:Additional Diagnostics as Needed 3. Fullbore(Contingent): Load and Kill Well 4. Slickline (Contingent): Secure well with downhole plug Please respond if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9038 V � 1 • • • 4,000 3,500 - ■ •■ ■ ■• • 3,000- 2,500 - 2,000- 1,500Nem-1'4i ilk- 1,000 - l 500 11111111 i i i . i . i . i • i . A ,,...A . • i i i i J i i i i i s 01/07/17 01/1417 01121/17 01/28/17 02104/17 02"11/17 02x'1$'17 0225117 1,600 -,•••. 1,400 - 1.200 a.1,000 :�� 800 600 400 200- 01/07/177 01;14/17 01121/17 01/28/17 02/04/17 02111117 02'18117 0212511; 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Thursday,October 08,2015 Jim Re P.I.Supervisor � � �( (� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-11 FROM: John Crisp PRUDHOE BAY UNIT 09-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J/- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-11 API Well Number 50-029-20236-00-00 Inspector Name: John Crisp Permit Number: 176-084-0 Inspection Date: 9/24/2015 Insp Num: mitJCr150930102406 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09 11 T e In' w'ITVD 8359 Tubing 1407 ` 1400 -T 1400 1400 • YP J PTD 1760840 ' ,Type Testi SPT!Test psi 2090 IA 562 2510 • 2483 - 2470 Interval INITAL 1P/F P ✓ OA 71 64 - 66 69 • Notes: 3.7 bbls pumped for test satitiEU Thursday,October 08,2015 Page 1 of 1 • • Brooks, Phoebe L (DOA) ?TD 1760$g10 From: AK, D&C Well Integrity Coordinator <AKDCWeIllntegrityCoordinator@bp.com> Sent: Tuesday, October 06, 2015 4:42 PM To: Brooks, Phoebe L (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: RE: September 2015 AOGCC MIT forms Attachments: PSI-Ol (PTD #2021450) Directional Survey.xls; PSI-01 (PTD #2021450) Wellbore Schematic.pdf; 09-11 (PTD#1760840) Directional Survey.xls; 09-11 (PTD#1760840) Wellbore Schematic.pdf Phoebe, For PSI-01 it appears the SSTVD was entered into the injector database instead of the true TVD.Are you calculating the TVD to be 8040'TVD? I've attached the directional survey for PSI-01 as well. Perform MD/TVD/SS Depth Conversions Bore Name: PSI-01 `✓ MD Depth:1[ 9083 - TVD Depth: 8,04023 SS Depth: -7,989.18 SCOW MAY 2 2O 6 X Coord: 704,956.22; Y Coord:1 5,968,498.05 Inclined 19.02 Submit Quer Reset Reset All j The packer depth for 09-11 matches the depth on the submitted forms and depth convertor. I've included the directional survey and schematic for reference as well. Perform MD/TVD/SS Depth Conversions Bore Name: [09-11 MD Depth: 10956 TVD Depth:[ 8,359.37 SS Depth: -8,305.37 X Coord: 724,028.31 Y Coord: 5,943,058.15 Incline. 43.38 Submit Query j 1 Reset i Reset All Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator Gvki ��aac�r WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 • TREE= 7-1/16'CNV • 0 9_1 1 soy NOTE "4-1/2"CHROME TB73"' WELLHEAD= FMC ACTUATOR= OTIS OKE.ELEV 54' N ► 27' l—7"X 5-1/2'X©,D=4.892" 13-3/8'CSG, 50' ♦� ►♦1' BF.EI-EV= 68#,L-80,BTC, �4 ►. KOP= `W 3057' ►• 2088' —9-518'1 CS ES CEINE3NT13R D=12.415 Max Angle= 63°@ 12347' Datum MD= 11782' 2204' H5-1/2"I E...•X NIP,D=4.562" ' Datum TV D= 8800'SS 20"CONDUCTOR 94#,1--40,D=19.124" MM. 2296' H9-5/8"FOC 2418' H9-5/8'FOC 9-5/8"CSG,40#,L-80,TC11,ID=8.835' -1 2098' - GAS LFT MANDRELS 13-3/8"CSG,72#,MN 80,D=12.347 — 2702' fff ST MD I V D DEV TY PE VLV LATCH R)RT DATE 5-1/2"X 4-1/2"XO,D=3.938" — 3994' 5 3387 3377 15 MAG DMY RK 0 04/22/15 4 6524 5602 54 KGB2 DMY BK 0 04/22/15 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 BRN TIEBACK SLV w/6 EXT,ID=7.688" — 4387' 2 9583 7391 49 KG82 DMR' BK 0 04/03/07 [9-5/8 X 7-5/8'BKR FLIX-LOCK HGR D=6.875" — 4395' -4 '-� 1 10740 8201 42 KGB2 DMY BK 0 04/03107 Minimum ID = .40" @ 11043' �� 10935' 4-T-172"HES X NP,D=3.813• 4-1/2" XN LOCK CHOKE I Imo; " _1,I W 10956' —17-5/8"X 4-1/2"BKR S-3 PKR,D 3.875" N► V. A 10980' —14-1/2"HES X NP,D=3.813" 9-5/8"CSG,47#,S0095 XO N-80 10990' g I•• ,• NI AI 11043' —4-1/2"FES XN NP,D=3.725" iii r: 11043' —4-112"XN LOCK,D-I CHOKE ASSY, �j ►j ID=.40"(09/16/15) ♦ 4112'TBG, 12.6#,13CR-80, H 11055' i Al11055' —4-1/2"WLEG,D=3.958' VAM TOP,.0152 bpf,D=3.958" k• j♦ j 11055' —E3M3 LOGGED ON 06/11/07) 4. 11194' —BRN 7'TEBACK SLV,ID=7.50' 7-5/8"SCAB LNR,29#,L-80,FL4S,.0459 bpi, 112(!U' •/� 11201' —19-5/8"X 7"BRN HYFLA LNR HGR,ID=6.184' wBRNTYPE'PA'LOCA1EJ- &SEALS,ID=6.875" 10 ►f OP l'i 1120T —9-5/8"X r BRN MOD"H'LTP,D=6.196" ♦♦ •1 't• 11208' —17"X 4-1/2"X0,D=3.958" 7"LNR 29#,MN-80,.0565 bpf,D= h_ - 6.182' 11282' !�♦j t�♦ 11282' 1—9-5/8'X 7"PKR w I I-IGR,D=7 12 al Pq ril ••1 i� 9-5/8"CSG,47#,N-80,D=8.681" —I 11595' rA r ri 1'I t •� • PERFORATION SLL?,4 RY 1 • REF LOG: BHCS ON 04/20/77 '1 . ANGLE AT TOP 1t1T:57'@ 11780' ♦� ir ate:Refer to Rod uction CB for historical perf da A SIZE SPF INTERVAL OR,YSOZ SHOT SQZ % v. See Page 2 for Ftrforation Data ;►� •� i.. FBTD I 12214' 12212' HFISH- PUSH COP TO BTM(03/02/01) 4-1/2"SCAB LNR 12.6#,L-80, — 12257' ' 12213' —FISH-BP RUBBER ELEMENTS BTC,.0152 bpi, D=3.958" j41144' 4,:4 (10/6/92 and 07/10/94) 7"LNR 29#,MN-80, .0371 bpi,D=6.182" H 12342' 4.44644! DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNTT 05/01177 ROWAN 34 ORIGINAL COMPLETION 06/20/13 RKT/JMD GLV C/O(06/16/13) WELL: 09-11 06!17/86 RWO 05/04/15 JLS/JI D GLV C/O(04/22/15) PERMIT No: 1760840 02/06/90 PAA-102 RWO SUSPENDED 05/26/15 PJC PERF/GLV/LEGEND CORRECTION All No: 50-029-20236-00 03/03/90 N2ES -RWO 09/01/15 SWC/JMD SET DH CHOKE(08/24/15) SEC 1,T1 ON,R15E Ulu!, 1463N,50E OF SWCR 06/28/94 D16 RWO 09/23/15 JLS/JMD RESET DH CHOKE(09/16/15) 04/08/07 N2E9 RWO BP Exploration(Alaska) • • 09-11 • PERFS • •, A L • 2c it • �4 • 4 i� 7 i • • P • PERFORATION SUM MARY 4 REF LOG: BHCS ON 04/20/77 .� ANGLE AT TOP R3ZF:57°@ 11780' •• Note:Refer to Production DB for historical perf data i►' SEE SR= INTERVAL ORySQZ SHOT SQZ • ^4 �# 3-1/8" 2 11780- 11790 S 05/07/84 01/27/90 ,4 A 3-3/8" 2 11782-11786 0 07/13/92 1- 1 3-3/8" 1 11804-118010 0 07/13/92 3-1/8" 2 11810- 11840 S 05/07/84 01/27/90 I4 a 3-1/8" 1 11810- 11840 0 07/13/92 4.'• �� • 3-1/8" 4 11880- 11885 S 09/03/77 01/27/90 • • ��• •3-3/8" 2 11910-11916 0 07/13/92 •a, l•�� 3-1/8" 4 11910-11920 S 09/03/77 01/27/90 .' 1., 3-3/8" 1 11928- 11936 0 07/13/92 • 3-1/8" 4 11933- 11961 S 09/02/77 01/27/90 I� It: 3-3/8" 4 11984- 11996 0 02/18/95 A �� k 3-1/8" 4 11994- 12028 S 09/02/77 01/27/90 • 3-1/8" 4 12043-12060 S 09/01/77 01/27/90 4 � 3318" 1/4 12043-12060 0 03/25/90 /V 3-3/8" 6 12094- 12112 0 02/18/95 3-1/8" 4 12096- 12110 S 09/01/77 01/27/90 4 • 3-1/8" 1 12096-12110 0 03/25/90 4 3-1/8" 4 12117- 12121 0 03/25/90 V 3-1/8" 4 12117- 12121 S 09/01/77 01/27/90 V r. 11 3-1/8" 4 12153- 12159 0 03/25/90 1 II 4 12153- 12159 S 09/01/77 01/27/90 j• I. 3-1/8" 4 12175- 12185 0 03/25/90 V i' 3-1/8" 4 12175-12185 S 09/01/77 01/27/90 4 . WI 7 Pet .e.e.1.i DATE REV BY COM.BJTS DATE REV BY - COMMENTS PRUDHOEBAY UNIT 05/01/77 ROWAN 34 ORIGINAL COMPLETION 06/20/13 RKT/JfVD GLV CIO(06/16/13) WELL: 09-11 06/17/86 RWO 05/04/15 JLS/JM) GLV C/O(04/22/15) PERMT No: 1760840 02/06/90 PAA-102 RWO SUSPENDED 05/26/15 PJC ITRF/GLV/LEGEND CORRECTION AR No: 50-029-20236-00 03/03/90 N26 RWO 09/01/15 SWC/JM) SET DH CHOKE(08/24/15) SEC 1,T1ON,R15E LL 1463N,50E OF SVVCR 06/28/94 D16 RWO .0923/15 JLSIJM) RESET DH CHOKE(09/16/15) 04/08/07 126 RWO BP Exploration(Alaska) • 0 MD TVD Inclination Azimuth Dog Leg Geo X Geo Y 0.0 0.0 0.0 36.00 0.0 0 0 814.0 814.0 0.8 36.00 0.0 3 4 1,600.0 1,600.0 0.8 194.00 0.2 5 4 2,750.0 2,749.8 1.0 189.00 0.0 2 -14 2,805.0 2,804.8 2.0 264.00 3.6 1 -14 2,868.0 2,867.8 4.3 73.00 9.9 2 -14 2,930.0 2,929.5 7.0 75.00 4.5 8 -12 3,057.0 3,055.0 10.3 82.00 2.7 26 -8 3,369.0 3,359.7 14.5 92.00 1.5 93 -3 3,677.0 3,654.3 19.5 102.00 1.9 182 -13 3,767.0 3,739.2 19.0 96.00 2.3 211 -17 3,798.0 3,768.6 18.8 84.00 12.5 221 -16 3,829.0 3,798.0 18.5 87.00 3.2 231 -15 3,860.0 3,827.2 19.8 86.00 4.2 241 -14 3,890.0 3,855.4 21.0 84.00 4.8 252 -13 3,921.0 3,884.3 21.5 82.00 2.8 263 -11 3,952.0 3,913.0 22.5 79.00 4.9 274 -9 3,983.0 3,941.5 23.5 83.00 6.0 286 -7 4,014.0 3,969.9 24.5 83.00 3.2 299 -5 4,046.0 3,998.9 25.0 84.00 2.0 312 -3 4,180.0 4,118.4 28.8 90.00 3.5 372 2 4,302.0 4,222.6 34.0 92.00 4.4 436 2 4,458.0 4,350.4 36.0 94.00 1.5 525 0 4,766.0 4,582.5 46.0 94.00 3.3 727 -8 4,954.0 4,705.5 52.3 95.00 3.4 869 -15 5,079.0 4,778.7 56.0 96.00 3.1 970 -22 5,130.0 4,806.6 57.8 96.00 3.4 1,012 -25 5,353.0 4,930.3 55.0 87.00 3.6 1,198 -25 5,510.0 5,020.0 55.3 87.50 0.3 1,326 -15 6,158.0 5,390.5 55.0 86.50 0.1 1,856 28 6,685.0 5,695.6 54.3 88.00 0.3 2,284 61 7,520.0 6,164.1 57.5 91.00 0.5 2,975 87 8,185.0 6,531.1 55.5 89.00 0.4 3,529 103 8,750.0 6,864.2 52.3 89.00 0.6 3,985 124 9,410.0 7,278.4 50.0 90.00 0.4 4,498 144 10,259.0 7,851.8 45.0 92.00 0.6 5,124 151 10,757.0 8,213.1 42.0 96.00 0.8 5,466 138 10,974.0 8,372.4 43.5 98.00 0.9 5,613 124 11,286.0 8,577.9 54.0 101.00 3.4 5,845 91 11,417.0 8,652.6 56.5 102.00 2.0 5,951 73 11,530.0 8,714.9 56.5 103.00 0.7 6,043 55 11,600.0 8,753.6 56.5 103.00 0.0 6,101 44 11,734.0 8,827.5 56.5 102.50 0.3 6,210 22 11,827.0 8,878.2 57.5 102.50 1.1 6,287 8 11,922.0 8,928.3 58.8 103.00 1.4 6,366 -8 12,015.0 8,975.5 60.3 103.00 1.6 6,445 -24 12,108.0 9,020.3 62.3 103.50 2.2 6,525 -40 12,201.0 9,063.2 62.8 103.50 0.5 6,605 -57 12,232.0 9,077.3 63.0 103.50 0.8 6,632 -63 12,263.0 9,091.4 63.0 104.00 1.4 6,659 -68 12,284.0 9,100.9 63.0 105.00 4.3 6,678 -73 12,347.0 9,129.5 63.0 105.00 0.0 6,732 -86 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMB, _3ION MAY 2 2 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon E Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ �'� —iioQshutdown ❑ Performed Suspend E Perforate ❑ Other Stimulate ❑ Alter Casinng Change Approved Program ❑ Plug for Redrdl n'erforate New Pool n Repair Well ❑ Re-enter Susp Well n Other Convert To Injection n 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑✓ Exploratory ❑ 176-084-0 3 Address P 0 Box 196612 Stratigraphic E Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20236-00-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028345 PBU 09-11 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10.Field/Pool(s). PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12347 feet Plugs measured None feet true vertical 9129 54 feet Junk measured See Attachment feet Effective Depth measured 12214 feet Packer measured See Attachment feet true vertical 9069 15 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"94#H-40 30-109 30-109 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet - same I)�� y j 2 U 1 J True Vertical depth See Attachment feet ��,j�►AA Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 261 1188 10783 1798 304 Subsequent to operation 0 0 0 0 0 14 Attachments(required per 20 AAC 25 070 25 071,&25 283) 15 Well Class after work Daily Report of Well Operations ❑., Exploratory❑ Development ❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work. Oil U Gas u WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt. 314-083 Contact Nita Summerhays Email Nita.Summerhays(U7bp.com Printed Name Nita Summer / Title Data Manager Signatur y-�/7411��. z`/ �� Phone 564-4035 Date 5/22/2015 I TL. 5_I/z,_/i 5 RBDMSJN MAY 2 9 2015 f/��/f� Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028345 ACTIVIr >DATE . .,.. ��. a�v� ***WELL SHUT IN ON ARRIVAL*** SWCP 4522 STANDBY FOR SNOW REMOVAL 4/20/2015 ***CONT ON 4/21/15 WSR*** T/I/0=1950/1950/40 SI Assist SL as directed (INJECTION CONVERSION) Pumped 5 bbls meth followed by 362 bbls KCL, 110 bbls 60/40 down IA to load for SL. SL set DMYGLV. ***WSR 4/21/2015 continued to 4-22-15*** ***CONT FROM 4/20/15 WSR*** SWCP 4522 STANDBY FOR SNOW REMOVAL SWCP 4522 R/U SET WCS (44)AT 11,015'SLM, 11,043' MD. PULL BK-OGLV FROM ST#4 AT 6,524' MD. PULL RK-LGLV FROM ST#5 AT 3,387' MD. SET RK-DGLV IN ST#5 AT 3,387' MD. LRS LOAD 368 BBLS OF KCL AND 110 BBLS OF 60/40 DOWN I/A(see LRS log) SET BK-DGLV IN STA#4 AT 6,524' MD. 4/21/2015 ***CONT ON 4/22/15 WSR*** ***WSR continued form 4-21-15***Assist SL as directed (INJECTION CONVERSION) MIT-IA PASS to 2500 psi. Pumped 45 bbls 60/40 down IA to achieve test pressure of 2500 psi. IA lost 36 psi 1st 15 min and 10 psi 2nd 15 min for a total loss of 46 psi over the 30 min test. Bled—3.5 bbls back. AFE sign hung on master valve,fluid packed caution tags hung on IA and wing valve. Fluid packed annulus watch for thermal expansion noted on permit. SL in control of well notified DSO upon departure. FWHP= 1494/294/38 SV/WV/SSV/MV=SL 4/22/2015 IA/OA= OTG ***CONT FROM 4/21/15 WSR*** LRS PERFORM PASSING MIT-IA TO 2,500 PSI (see LRS log) PULL EMPTY WCS(44) FROM 11,043' MD I/A FLUID PACKED W/60/40 WATCH FOR THERMAL EXPANSION 4/22/2015 ***WELL S/I ON DEPARTURE*** FLUIDS PUMPED BBLS 5 METH 1 DIESEL 155 60/40 METH 362 1% KCL 523 TOTAL Perforation Attachment ADL0028345 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09-11 7/13/1992 SQZ 11780 11782 8852.74 8853.83 09-11 7/13/1992 RPF 11782 11786 8853.83 8856.01 09-11 7/13/1992 SQZ 11786 11790 8856.01 8858.18 09-11 7/13/1992 APF 11804 11810 8865.77 8869.01 09-11 7/13/1992 RPF 11810 11814 8869.01 8871.17 09-11 7/13/1992 SQZ 11814 11840 8871.17 8885.14 09-11 1/27/1990 SQZ 11880 11885 8906.37 8909.01 09-11 7/13/1992 RPF 11910 11916 8922.1 8925.22 09-11 7/13/1992 SQZ 11916 11920 8925.22 8927.3 09-11 7/13/1992 APF 11928 11933 8931.45 8934.03 09-11 7/13/1992 RPF 11933 11936 8934.03 8935.58 09-11 7/13/1992 SQZ 11936 11961 8935.58 8948.39 09-11 1/22/2001 BPP 11984 11994 8960.04 8965.07 09-11 1/22/2001 BPP 11994 11996 8965.07 8966.07 09-11 1/22/2001 BPP 11996 12028 8966.07 8981.96 09-11 1/22/2001 BPP 12043 12060 8989.31 8997.54 09-11 1/22/2001 BPP 12094 12096 9013.72 9014.66 09-11 1/22/2001 BPP 12096 12110 9014.66 9021.2 09-11 1/22/2001 BPP 12110 12112 9021.2 9022.13 09-11 1/22/2001 BPP 12117 12121 9024.46 9026.32 09-11 1/22/2001 BPP 12153 12159 9041.14 9043.91 09-11 1/22/2001 BPP 12175 12185 9051.28 9055.88 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF a) Q 0 0 0 0 0 0 0 0 0 0 0 0 0 N 0) O N 0) CO CO CO CO N-- 'r 00 O N- f) O LO O N- O N CO V N Ln O - V N r— co U) N N L LC) n CO U N 0 0 0 0 0 0 0 0 0 0 0 0 0 L. M6) CO CO LC) l() r- In (N CO V CO 7 in co c— N- c- CO c- O CO N N- 'Cr CO ,— CO CO CO Ln CO CO CO Ln In N- N- a0 61 C)) N COcy) Ln CO CO O N 6) CO O) . a) co 6) O Ln CO N- O 0) N r ` v r- Lo co LNn O CO N O N c M N co 0) V CO O 6) N N CO N CO CO CIIIIIIIIIIIIII I-- co co N- 6) N LO Ln CO N O CO O) CO O N co co (O 6 N O O co M 6) N r` N a0 CO V CO CO (N CO LC) N Ln Ln O N Ni- 6) V CO CO N N CO CO C O No N r- a0 C) O N N C° CD CV O in O E N N O N a0 M d7 O r N N N CO co inI , I Q �T O N- O M O o0 °) 1,(3") a0 CO r- 0 o O co 6) CO M C N O N M CO N CO 6) a) N N N M = O la O = J 0 00 C0 C0) oo neo Q4 °J00,r° oo _ 0O? O °° Za0O a) _ ' -10Z0 2aQM, - C LV r- CO *O * 000 # J *k 'N V N CV V # V # CO N. CO RS - - N CO V = V 60 00 CV U N - Ln 00 00 C j r-- N - V O 6, '— 10 V t +' co co co MV N CO r M M _ C N. 00 CO CO CO M o0 N Ln co Co 6O) O aU (fl N `- CO 10 N CO N- --1 J CC ZZZZ a)0 0000 .CH HHRH- ww CUD DDDD<< 00 U a Q' C[ Q' a 0 a CiLL LL Z Z Z Z w w w 0 0 0 0 W CCm m m O Z_ Z_ Z_ CCc c c D D D D D UJJJa. CI_ a. a- U) U) HI- H Packers and SSV's Attachment ADL0028345 SW Name Type MD TVD Depscription 09-11 PACKER 10959 8361.55 4-1/2" Baker S-3 Perm Packer 09-11 PACKER 11207 8529.99 7" Baker H-Isolation Packer 09-11 PACKER 11282 8575.54 7" Top Packer 09-11 176-084-0 Junk Attachment SW Name MD Date Description 09-11 12212 3/2/2001 Mill CIBP 09-11 12213 10/6/1992 IBP Rubber Elements TREE=` 7-1/16"CM WELLHEAD= FAC 09-1 9-1 1 SAI OTE "`4-1/2"CHROME TBG"' ACTUATOR= OTiS INITIAL KB.ELE 54' B = 13-3/8'CSG, H 50' ? ` �� F.EEV : I 27' --17"X 5-1/2"XO,D=4.892" KOP= — 3057' 68#,L-80,BTC, ♦. • Max Angle= 630 @ 12347' D=12.415 •V 11�,` '2088' -9-5/8"HEWS E S CEVENTER Datum MD= 11782' , 2204' 1--15-1/2'FES X NIP,D=4.562" Datum TVD= 8800'SS 20"CONDUCTOR,94#,H-40,D=?1-1 79' 2296' H FOC 2418n--1 FOC 9-5/8°CSG,40#,L-80,TC11,D=8.835" —1 2098' , 13-3/8"CSG,72#,MN-80,D=12.347 2702' GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT, DATE 5-1/2"X 4-1/2"XO,D=3.938" 1— 3994' 5 3387 3377 15 MM1G DMY FE 0 04/22/15 4 6524 5602 54 KGB2 DM1' BK 0 04/22/15 BRN TIEBACK SLV w/6'EXT,D=7.688" H 43$7' • 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 2 9583 7391 49 KGB2 DMY BK 0 04/03/07 19-5/8"X 7-5/8"BKR FLEX-LOCK HGRID=6.875" H 4395' I ►4C1 10740 8201 42 KGB2 DMY BK 0 04/03/07 Minimum ID = 3.725" 11043' :� �; 10935• -{41/2*Fps xNIP,D=3.813• 4-1/2" NES X NIPPLE % '�• •�/.1 /�1.� 10956' F-7 5/8"X 4-1/2'BKR S-3 PKRD=3.875' ♦. , �� 10980' —14-1/2"HES X NP,0=3.813' 9-5/8°CSG,47#,S0095 XO N-80 r_ 9 ♦. �.--10990' �� lir r. ♦ 11043' H4-112'FES XN NP,D=3.725' • 4-1/2'TBG,12.6#,13CR-80, H 11055' t4, .♦• 11065' --14-1/2"WL.E3;,D=3.958"1 VAM TOP,.0152 bpf,D=3.958" ♦4 .. ►♦ 11055' H ELMD LOGGED ON 06/11/07) � �l ' 11194' HBRN 7'TEBACK SLV,ID=7.50" I 1 _► • 7-5/8"SCAB LNR 2911,L-80,FL4S,.0459 bpf, - 1 11200' ► 11201' —19-5/8"X 7"BRN HY FLA LI4,4 HGR,D=6.184" w/BRN TYPE'PA'LOCATER&SEALS,13=6.875' 0 ►Z 16 1120T —19-5/8"X 7"BRN MOD"Fr LTP,D=6.196" i�.� SAO 41, .♦�♦ ••�♦♦ 11208' —Jr X 4-1/2"XO,D=3.958" ♦♦ ♦♦ ♦♦♦ •♦♦♦ 7'LNR,29#,MN-80,.0565 bpf,D=6.182" H 11282' �_�♦ ��♦ 11282' —9-5/8'X 7'PKR w/HGR,D=? �� r4 t 6 t n 9-5/8"CSG,47#,N-80,D=8.681" 11595' t n 1 tit • • t PERFORATION SUMMARY t / REF LOG: BHCS ON 04/20/77 t t ANGLE AT TOP PERF:57"@ 11780' t • III Note:Refer to Production DB for historical perf data t SIZE SPF MHRVAL OR'/SQZ SHOT SQZ t t See Page 2 for Farforation Data t . • 1' t t, PIM H 12214' . 12217 --1 FISH- PUSH CEP TO BTM(03/02/01) I 4-1/2"SCAB LNR,12.6#,L-80, — 12257' lot 't- 12213' FISH-IBP RUBBER ELEMENTS BTC,.0152 bpf,D=3.958" w►���464.' (10/6/92 and 07/10/94) 7'LNR,29#,MN-80,.0371 bpf,D=6.182" — 12342' •.1.1.1.<t.•.♦.♦ DTE REV BY OOOA ENTS DATE REV BY COMMENTS PRODHOE BAY UNIT 05/01/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWCIPAG GLV C/O WELL: 09-11 06/17/86 RWO 06/05/07 JGMPJC DRLG DRAFT ODRISECTIONS PERMIT AT No:'1760840 02/06/90 4 PAA-102 RWO SUSPENDED 10/23/10 KL/PJC ELME)TT 8 XO CORRECTION AR No: 50-029-20236-00 03/03/90 ti N2E:3 RWO 06/20/13 RKT/JMD GLV C/O(06/16/13) SEC 1,TION,RISE UM,1463N,50E OF S M2R 06/28/94 0716 RWO 05/04/15 JLS/JMD GLV C/O(04/22/15) 04/08/071 N2ES RWO BP Exploration(Alaska) 09-11 i PERFS i 4 1 • I , • _ c ♦ • • • • i • • •• ♦ i• •♦ •♦ • • ♦ •• • • i PERFORATION SUMIWkRY • P REFLOG: BHCS ON 04/20/77 �• • '• ANGLE ANGLE AT TOP PERF:57"@ 11780' 4— _ Note:Refer to Production DB for historical perf data 4 • SCE SPF FNTERVAL OPN/SQZ SHOT S()7 2 ki 31/8" 2 11780-11782 S 01/27/90 `� •II. 3318" 2 11782-11786 0 07/13/92 ••• •••• • 3118' 2 11786-11790 S 01/27/90 �•i i i• i• • 3-3/8" 1 11804-11809 0 07/13/92 ♦,.♦ ►♦•♦ • 3-1/8" 4 11880-11885 S 01/27/90 t j• 3-3/8" 2 11910-11916 O 07/13/92 ► • 3-1/8" 4 11916-11920 S 01/27/90 A i L 3-3/8" 1 11928-11936 0 07/03/92 t t. 31/8" 4 11936-11961 S 01/27/90 ►• • ► • 3-3/8" 4 11984-11996 0 02/18/95 o♦ i • 3-1/8" 4 11994-12028 S 01/27/90 ► 3-1/8" 4 12043-12060 S 01/27/90 • BO 33/8" 1/4 •12043-12460 O 03/25/90 t 3-3/8" 1 12085-12094 0 03/25/90 � 33/8" 6 12094- 12112 0 02/18/95 �• 3-1/8" 4 12096-12110 S 01/27/90 ►• 31/8' 4 12117-12121 O 03/25/90 j♦ 3-1/8" 4 12153-12159 0 03/25/90 •• 3-1/8" 4 12175-12185 0 03/25/90 ►• • i• C kg 6.6.414.01416 DATE REV BY COMMENTS DATE REV BY COMVENTS PRIAF-IOE BAY UNIT 05/01/77 ROWAN 34 ORGFNAL COMPLETION 05/05/07 SWC/PAG GLV C/O WELL: 09-11 06/17/86 RWO 06/05/07 JGMPJC DRG DRAFT CORRECTIONS PERMT No:'1760840 02/06/90 PAA-102 RWO SUSPENDED 10/23/10 KL/PJC ELM)TT&XO CORRECTION API Nb: 50-029-20236-00 03/03/90 N2ES RWO 06/20/13 RKT/JM? GLV C10(06/16/13) SEC 1,T1 ON,RISE L 1463N,50EOF SWCR 06/28/94 D16 RWO 05/04/15 ,LS/JM) GLV CIO(04/22/15) ' 04/08/07 N2E5 RVVO BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, January 04, 2015 2:55 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Regg, James B (DOA); AK, OPS FS2 Field OTL; AK, OPS FS2 Field OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer 09-11 (PTD #1760840) Passing TIFL demonstrates competent barriers Attachments: image001jpg All, Producer 09-11 (PTD #1760840) had a passing TIFL performed on January 02, 2015, demonstrating the presence of competent barriers. At this time the well has been reclassified as Operable, and may remain online as needed. Thank you, Laurie Climer (Alternate: Jack ]Xshroi ) BP Alaska - Well Integrity Coordinator i is G Org3 'izat, M Y on SCANNED JAN 0 8 2015 WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, December 31, 2014 9:44 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; 'chris.wallace@alaska.gov'; 'Regg, James B (DOA) Uim.regg@alaska.gov)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: UNDER EVALUATION: Producer 09-11 (PTD #1760840) IAP exceeded MOASP All, Producer 09-11 (PTD #1760840) inner annulus exceeded MOASP on December 28, 2014 with T/I/O = 2110/2100/100 psi. An inconclusive cold TIFL was performed on December 30, 2014 prior to severe weather setting in. The well has been reclassified as Under Evaluation for additional diagnostics once the weather clears. Plan Forward: DHD: Re -attempt TIFL WIE: Additional diagnostics as needed A copy of the wellbore schematic and TIO plot have been included for reference. Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator G� It 1 Garai Wells 1/11 Organizat-w WIC Office: 907.659.5102 WIC Email: AKDCWelllntegritVCoordinator@BP.com Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, December 31, 2014 9:44 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: UNDER EVALUATION: Producer 09-11 (PTD #1760840) IAP exceeded MOASP Attachments: 09-11 Wellbore Schematic.pdf; 09-11 TIO Plot 12-31-14.docx; image001jpg All, Producer 09-11 (PTD #1760840) inner annulus exceeded MOASP on December 28, 2014 with T/I/O = 2110/2100/100 psi. An inconclusive cold TIFL was performed on December 30, 2014 prior to severe weather setting in. The well has been reclassified as Under Evaluation for additional diagnostics once the weather clears. Plan Forward: DHD: Re -attempt TIFL SCANNED JAN 0 6 2015 WIE: Additional diagnostics as needed A copy of the wellbore schematic and TIO plot have been included for reference. Thank you, Laurie Climer (Alicrnale: Jack Disbrow) BP Alaska - Well Integrity Coordinator G O:xi 1 4'&'!!s GWofUa^d261aon WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 7-1/16" CNV WELLHEAD = FMC ACTUATOR = OTIS INITIAL KB. 13.E 54' BE. ELEV = PORT KOP = 305T Max Angle = 63" @ 1234T Datum MD = 11787 Datum ND = 8800' SS 13-3/8' CSG, 50' 68#, L-80, BTC, D = 12.415 120" CONDUCTOR 94#, H-40, D = ?J—L__19 f 9-5/8" CSG, 40#, L-80, TC11, D = 8.835' 2098' 13-3/8' CSG, 72#, MN 80, D = 12.347 2702' 5-1/2" X 4-1/2' XO, D = 3.938" 3994' BRN TIEBACK SLV w / 6' EXT, D = 7.688" 430 �9 518" X 7-5/8- BKR FL6-LHGR D = 6.875' 43 OCK 95' Minimum ID = 3.725" @ 11043' 4-112" HES X NIPPLE 9-5/8" CSG, 47#, S0095 XO N-80 1-1 10990' 4-1/2" TBG, 12.6#, 13CR-80, 11055' VAM TOP, .0152 bpf, D = 3.958' 7-5/8" SCAB LNR 29#, L-80, FL4S, .0459 bpi, 11200' w /BRN TY PE'PA' LOCATE3R & SEALS, ID = 6.875" 7" LNR 29#, MN 80, .0565 bpf, D = 6.182" H 11282' 9-5/8" CSG, 47#, N-80, D = 8.681" 11595' PERFORATION SLMAAARY REF LOG: BFKS ON 04/20/77 ANGLE AT TOP PERF: 57' @ 11780' Note: Refer to Production DB for historical perf data SIZE I SPF I NTEfRVAL 1 OPWSOZ I SHOT I SQZ See Page 2 for Pt'rforation Data FPB—TDI-4 12214' 4-1/2" SCAB LNR 12.6#, L-80, 12257' BTC, .0152 bpf, D = 3.958" 7" LNR 29#, MN -80, .0371 bpf, D -76 18 12342' 09-11 SAFETY NOTE """4-112- CHROME TBG... 2T -17' X 5-1/2" XO, D = 4.892" 2088' 9-518" FES ES CEMENTER 2204' +1/2" HES X NIP, D = 4.562- -----EK 2418' FOC GAS LIFT MANDRELS ST MD I V i) DEV TY PE V LV LATCH PORT DATE 5 3387 3377 15 MMG DOME RK 16 05/05/07 4 6524 5602 54 KGB2 SO BK 28 06/16/13 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 2 9583 7391 49 KGB2 DMY BK 0 04/03/07 1 10740 8201 42 KGB2 DMY BK 0 04/03/07 10935' --{4-112" HES X NP, D = 3.813" 10956' �7-518" X 4-112" BKR S-3 PKR D = 3.875" 10980' --{4-1/2- HES X NP, D = 3.813" 1 11043' 1-+-1/2" FES XN NP, D = 3.725" 11055' —14-1/2" WLEG, D = 3.958" 11055' ELMD LOGGED ON 06/11/07) 11194' BRN T TIEBACK SLV, ID = 7.50' 11201' 9-518" X 7" BRN HY FLA LNR HGR, ID = 6.184" 1120T 9-5/8" X 7" BRN MOD "K LTP, D = 6.196" 11208• 7" X 4-112" XO, D = 3.958" 11282 9-5/8" X 7" PKR w/ HGR lD= 7 12212• -� FISH - PUSH CIBP TO BTM (03/02/01) 12213' FISH - BP RUBBER B-E RENTS (10/6/92 and 07/10/94) DATE REI/ BY DATE REV BY COMMENTS 05101/77 ROWAN 34 OR05/05/07 SWGPAG GLV GO 06117/86 RW06/05/07 JGNVPJC DRLG DRAFT OORRECTIONS 02/06190 PAA -102 MMPLEMnON RW10/23/10 KUPJC ELMDTT&XOCORRECTION 03103/90 N2ES RW06/20/13 RKT/JMD GLV GO (06/16/13) 06/28/94 Dib RW04/08/07 N2ES RW PRUDHOE BAY UNIT WELL: 09-11 PERMIT No: 1760840 API No: 50-029-20236-00 SEC 1, T10N, R15E UM, 1463N, 50E OF SWCR BP Exploration (Alaska) PERFORATION SLAWRY REF LOG: BHCS ON 0412Or77 ANGLE AT TOP PERF: 57° @ 11780' Note: Refer to Production DB for historical pert data SIZE I SR= INTERVAL OFNSQZ SHOT SO2 3-1/8" 2 11780- 11782 S 01/27/90 RWO 3-318" 2 11782 - 11786 O 07/13/92 RWO SUSPENDED 3-1/8" 2 11786 - 11790 S 01/27/90 RWO 3-318" 1 11804 - 11809 O 07/13/92 IRWO 3-1/8" 4 11880- 11885 S 01/27/90 IRWO 3-3/8" 2 11910 - 11916 O 07/13/92 3-1/8" 4 11916- 11920 S 01/27/90 3-3/8" 1 11928- 11936 O 07/03/92 3-1/8" 4 11936 - 11961 S 01/27/90 3-3/8" 4 11984 - 11996 O 02/18/95 3-1/8" 4 11994- 12028 S 01/27/90 3-118" 4 12043 - 12060 S 01/27190 3-3/8" 1/4 12043- 12060 O 03/25/90 3-318" 1 12085- 12094 O 03/25190 3-3/8" 6 12094- 12112 O 02/18/95 3-1/8" 4 12096 - 12110 S 01/27/90 3-1/8" 4 12117 - 12121 O 03/25/90 3-1/8" 4 12153 - 12159 O 03/25/90 3-1/8" 4 12175 - 12185 O 03/25/90 09-11 PERFS DATE REV BY COMMENTS DATE REV BY COK*AwrS 05101/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWC/PAG GLV CJO 06/17186 RWO 06/05/07 JGWPJC DRLG DRAFT CORRECTIONS 02106190 PAA -102 RWO SUSPENDED 10/23/10 KUPJC ELMD TT & XO CORRECTION 03/03190 N2E8 RWO 06/20/13 RKT/JMD GLV CJO (06/13/13) 106128IS41 D16 IRWO 104/08/071 N2ES IRWO PRUDHOE BAY LMT WELL 09-11 PEFW No: 1760840 AR No: 50-029-20236-00 SEC 1, T1 ON, R1 5E UM, 1463N, 50E OF SWC R BP Exploration (Alaska) Producer 09-11 (PTD #1760840) TIO Plot December 31, 2014 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Sunday, September 28, 2014 7:00 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Igbokwe, Chidiebere; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: OPERABLE: Producer 09-11 (PTD #1760840) Passing TIFL demonstrates competent barriers Attachments: image001jpg; image002jpg All, Producer 09-11 (PTD #1760840) had a passing TIFL performed on September 27, 2014, demonstrating the presence of competent downhole barriers. At this time, the well has been reclassified as Operable and may remain online as needed. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator GW! 6r(ga9iQavoll SCANNeD WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, September 01, 2014 5:52 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Drillsite 09 Producers with IAP Over MOASP during TAPS All, Three Drillsite 09 producers have been reported with inner annulus pressure above MOASP. These wells were shut in for TAPS. The wells are reclassified as Under Evaluation for additional diagnostics once the wells can be brought back online. The following wells were found to have sustained inner annulus pressure above MOASP: 09-11 1760840 2300/2080/160 09-28A 1930430 S1/2040/745 09-41 1900740 271/2160/180 The surface safety was closed on 09-28A, so tubing pressure was unavailable at this time. Plan forward: 1. Operations: Put wells online 2. DHD: Perform TIFL after the wells are stable 3. WIE: Additional diagnostics as needed Copies of the TIO plots are included for reference. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator GinuaI'Nells GW Qryarn2al7on WIC Office: 907.659.5102 WIC Email: AKDCWelllnteprityCoordinator@BP.com 2 RECEIVED AUG 2 12014 AOGCC BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-091, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-101, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-111 B-241 B-251 C-10, L2 -07A, 0-02, M-04, M-05, U-14 ,_ 1 I " - '___ -, - - 1� �N ,y The information on this CD ` is to be used for BP Exploration (Alaska) l n Inc. business only. If you are not the owner licensed ✓c�`-C�'�,rC�y user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this An eta I�. S CD by error, please return the CD to the address shown g / below. BP will pay the postage. Thank you. Please Sign and P gancpdc@bp.com If found please return CD to: Doug BP Exploration by r 1 Dortch i PO Box 196612 � Petrotechnical Data Anchorage, AK0 99519-6612 For External Distribution Attn: State of Alaska CD 1 of 1 -_-.-- Attn: Makana Bender BPXA OH Log Data 333 W. 7th Ave, Suite 1 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, e, Anchora Alaska 99501 t`:• 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, Anchorage, 4 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, C-10, L2 -07A, L3-02, M-04, M-05, U-14 r 18 -AUG -2014 Petrotechnical Data enter R-14 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, August 05, 2014 5:55 AM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer 09-11 (PTD #1760840) Passing TIFL demonstrates competent barriers Attachments: image002.jpg; image003.jpg All, Producer 09-11 (PTD #1760840) had a passing TIFL performed on August 03,2014. This test demonstrates the presence of competent downhole well barriers. At this time the well has been reclassified as Operable and may remain online as needed. Thank you, Laurie Climer (.1 hriwt�:.I�t�?: hishtv��rl BP Alaska - Well Integrity Coordinator SCANNED OCT 0 92014, jti�J!► G!anal'fiells VV 1Yr 1YI Orgarnzatson WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, July 24, 2014 9:32 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) Uim.regg@alaska.gov)'; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer Subject: Under Evaluation: Producer 09-11 (PTD #1760840) IAP exceeded MOASP during TAR All, Producer 09-11 (PTD #1760840) was reported to have sustained inner annulus casing pressure above MOASP on 07/22/2014 with IA/OA = 2180/170 psi during planned facility maintenance. The well has been reclassified as Under Evaluation for further diagnostics. Tubing pressure could not be read, as the surface safety valve was closed for well safe out. Plan forward: 1. Operations: Place well on production post TAR activities 2. DHD: Perform TIFL A copy of the TIO plot and wellbore schematic have been included for reference. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator Gto:ka;M?iis GWOlga» zatton WIC Office: 907.659.5102 WIC Email: AKDCWelllntesrityCoordinator@BP.com Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Thursday, July 24, 2014 9:32 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer Subject: Under Evaluation: Producer 09-11 (PTD #1760840) IAP exceeded MOASP during TAR Attachments: 09-11 TIO Plot 07-24-14.docx; 09-11 Wellbore Schematic.pdf; image001.jpg All, Producer 09-11 (PTD #1760840) was reported to have sustained inner annulus casing pressure above MOASP on 07/22/2014 with IA/OA = 2180/170 psi during planned facility maintenance. The well has been reclassified as Under Evaluation for further diagnostics. Tubing pressure could not be read, as the surface safety valve was closed for well safe out. Plan forward: 1. Operations: Place well on production post TAR activities 2. DHD: Perform TIFL A copy of the TIO plot and wellbore schematic have been included for reference. Thank you, Laurie Climer BP Alaska Well Integrity CoordinatorSCAW GW organizat.on WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com 1 Producer 09-11 (PTD #1760840) TIO Plot 07/24/2014 1t = 1-1/10 UVV WELLHEAD = FMCI ACTUATOR = OTIS'. INITIAL KB. E LE 54'' BF. ELEV = DATE KOP = - 305T N6x Angle = 63'@ 1234T Datum ND = 11787 Datum TVD = 88001SS 13-3/8" CSG, 50' 68#, L-80, BTC, D = 12.415 -------------- 20 CONDUCTOR, San, H-40, ID = ?79' 1-5/8" CSG, 40#, L-80, TC11, D = 8.835' I—{ 2098' r 13-3/8" CSG, 72#, MN -80, D = 12.347 2702' 5-1/2" X 4-112" XO, D = 3.938" 3994' BRN TIEBACK SLV w / 6' EXT, ID = 7.688" —1 4387• 9-5/8" X 7-5/8" BKR FLEX -LOCK HGR D = 6.875 4395' Minimum ID = 3.725" @ 11043' 4-112" HES X NIPPLE 9-518" CSG, 47#, S0095 XO N-80 I—{ 10990' 4-1/2" TBG, 12.6#, 13CR-80,- 11 X055, VAM TOP, .0152 bpf, D 7-5/8" SCAB LNR, 29#, L-80, FL4S, .0459 bpf, H 11200' w /BRN TY PE'PA' LOCATER & SEALS, ID = 6.875" 7" LNR, 29#, MN -80, .0565 bpf, D = 6.182" H 11282' 9-5/8" CSG, 47#, N-80, D = 8.681" 1-1 11595' PERFORATION SUMMARY RET LOG: BHCS ON 04/20/77 ANGLE AT TOP PERF: 57' @ 11789 Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I OPN/SOZ I SHOT I SOZ See Page 2 for Plrrforation Data PBTD 12214' 4-1/2" SCAB LNR, 12.6#, L-80, 12257' BTC, .0152 bpi, D = 3.958" 7" LNR 29#, MN -80, .0371 bpf, D = 6.182" 12342' 09-11 SAFETY NOTE: "'4-1/2" CHtOMETBG"' i 27' L_._ 208"J I'-"/8" FES ES CBNBYfS2_ - 2204' 5-1/2' 1 -ES X NIP, D = 4.562" 2296' FOC 2418' FOC GAS LIFT MANDRIELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3387 3377 15 MM1G DONE RK 16 05/05/07 4 6524 5602 54 KGB2 SO BK 28 06/16/13 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 2 9583 7391 49 KGB2 DMY BK 0 04/03/07 1 10740 8201 42 KGB2 DMY I BK 0 04/03/07 10935' .1-44-1/2' HES X NIP, 0=1813* 10956' 17-5/8" X 4-1/2" BKR S-3 PKR, D = 3.875" 10980'1-4-1/2' FES X NP, D= 3.813' 1104T_1-44 -1&F XN NP, D = 3.725' 11055' 14-1/2" WLEG, D= 3.958' 11055' E3MD LOGGED ON 06/11/07) 111W BRN 7' TRACK SLV, ID = 7.50' 11201' 9-5/8" X 7" BRN HY FLA LNR HGR, ID = 6.184" 1120T 9-5/8" X 7" BRN MOD "K LTP, D = 6.196" 11208'7' X 4-1/2" XO, D = 3.958" 11282' 9-5l8" X 7" PKR w / FEGR D = ? 12212' - , FISH - PLtSH CSP TO BTM (03/02101) 12213' FISH - BP RLIBBE R ELEMENTS (1016/92 and 07/10/94) DATE REV BY COMMENTS DATE REV BY COMMENTS 05/01/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWCJPAG GLV CIO 06117/86 RWO 06/05/07 JGMPJC DRLG DRAFT CORRECDONS 02/06t90 PAA -109 RWO SUSPENDED 10/23/10 KUPJC ELMD TT & XO OORRECTION 03/03/90 N2E S RWO 06/20/13 RKT/JND GLV CIO (06/16/13) 061281941 D16 IRWO W081071 N2E S IRWO PRLDHOE BAY U [T WELL: 09-11 PERWT No: 1760840 API No: 50-029-20236-00 SEC 1, T10R R15E L*4 1463N, 50E OF SWCR BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: BRCS ON 04/20/77 ANGLE AT TOP PERF: 57` @ 11780' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OP"SQZ SHOT SO2 3-1/8" 2 11780 - 11782 S 01/27/90 06/05/07 3-3/8" 2 11782 - 11786 O 07/13/92 KUPJC ELMD TT & XO OORRECTION 3-1/8" 2 11786 - 11790 S 01/27/90 06/28/94 33/8' 1 11804 - 11809 O 07/13/92 N2E6 31/8" 4 11880 - 11885 S 01/27/90 33/8" 2 11910 - 11916 O 07/13/92 31/8" 4 11916 - 11920 S 01/27/90 33/8" 1 11928- 11936 O 07/03/92 31/8" 4 11936 - 11961 S 01/27/90 33/8" 4 11984 - 11996 O 02/18/95 31/8" 4 11994- 12028 S 01/27/90 31/8" 4 12043 - 12060 S 01/27/90 33/8" 1/4 12043 - 12060 O 03/25/90 33/8" 1 12085- 12094 O 03/25/90 33/8" 6 12094- 12112 O 02/18/95 31/8" 4 12096- 12110 S 01/27/90 31/8" 4 12117 - 12121 O 03/25/90 31/8" 4 12153 - 12159 O 03/25/90 31/8" 4 12175 - 12185 O 03/25190 09-11 PERFS DATE REV BY COMMFTfTS DATE REV BY COMu NTS 05/01/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWCIPAG GLV CJO 06/17/86 RWO 06/05/07 JGWPJC DRLG DRAFT CORRECTIONS 02/06/90 PAA -102 RWO SUSPENDED 10/23/10 KUPJC ELMD TT & XO OORRECTION 03/03/90 N2ES RWO 06/20/13 RKT/JMD GLV CJO (06/13/13) 06/28/94 D16 RWO 04/08/07 N2E6 IRWO PRUDHOE BAY LMT WELL- 09-11 PEFMT No: 1760840 AR No: 50-029-20236-00 SEC 1, T1 ON, R1 5E LM 1463R 50E OF SWCR BP Exploration (Alaska) J ' e.,,\\V/7,,,,, �� 1 HE STAT h -a :_1 ._ ,-,C i �, f: a 1:' ? Anchorage Alaska 9`, Avenue �•e° 950 372 �� k , �C �.RIC)12 41.,1 ( x. 2 _,1._ �lu5u� r,r - cry 27c 1/' ?, Chidiebere Igbokwe S� tip: 0 9 ZMMM Petroleum Engineer f0 BP Exploration (Alaska), Inc. I 7 — O''7 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-11 Sundry Number: 314-083 Dear Mr. Igbokwe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .. / l'241_(..,t,i(4._ Cathy P Foerster �� Chair DATED this /u y of February, 2014. Encl. RECEIVED STATE OF ALASKA FEB 12 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION +DT s 2t t7 fly APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing El Other: Convert to Injector Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory El Development Q • 176-084-0 • 3.Address: Stratigraphic LI Service Li6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20236-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? PBU 09-11 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Properly Designation(Lease Number): 10.Field/Pool(s): ADL0028345 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): II 12347 • 9130 12214 9069 None See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"94#H-40 30-109 30-109 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None Nam I . Production See Attachment See Attachment ' See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment ' See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment 1 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed r 12.Attachments: Description Summary of Proposal LI 13.Well Class after proposed work: 4 Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development .TP,l2Service 0 '(4 14.Estimated Date for 15.Well Status after proposed work: v-P,'' Commencing Operations: Oil ,-,,,,, Gas LI WDSPL LI Suspended Li16.Verbal Approval: Date: WINJv0 INJ Li WAG LI Abandoned Li Commission Representative: 'L GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chidiebere lgbokwe Email Chidiebere.Igbokwe@BP.Com Printed Name Chidiebere lgbokwe Title Petroleum Engineer Signature .` hone 564-4795 Date Prepared by Garry Cat=564-4424 Ut2•jZe\14. COMMISSION USE ONLY C' Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 7 \'— (3 3 Plug Integrity El BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: St—ai- wl i-✓, z5,3c6 M 1T- /fl revJfrcc/ Gt ftcv �fab� l�3cd 1% rcflo "). RBDMSAke21714AY 0 9 2014 Spacing Exception Required? Yes CI No a Subsequent Form Required: 4 c L�- �0 At7 q� APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: _4_-, _/ • JUNK ATTACHMENT ADL0028345 SW Name MD Type Date _ ND 09-11 12212 JUNK 3/2/2001 9068 09-11 12213 JUNK 10/6/1992 9069 • O O ODD 0 0 0 0 0 0 0 O O N � 0000 ODao0QO(..) o 0 _ J J J Z Q Q J (vj M Ci) c r 1- N p 0 0 0 0 0 0 0 0 0 0 0 O_ • NO 53 O N- O O U) N 53 N U N o o o o o o 0 0 o o 0 o o M (O O) M ll) f- LC) 0 00 N MNt 7 LC) r- co N. co • M 0 T}' N- N m 00 CO OD 1.0 (O 00 00 1.0 UC) 00 N- N a) N f0 N- (O 0) 1 M N O N CV 1' CV m OU) 0 0 N- N N- CO 'V 0) M 1- O CO O) N 00 CO N N CO M Q O ~ co N- 0 N co N- CO- O O U co O M 0 T In 00 N N CO N co M M co N E 't w E co - N N 6-O [t f� 00 f_ N m o ( N N O O I 0 N O 0 Cr) '- N ' '- (N CO O) CO COO '- '- V N '- N N T M CD n Q H ocoo a) co r- � cog0 0 rn � co U 0 M N N O 0 CO M M M N r r r 0 O 0 OO p p O) O 00 O °° 00 0 0 00 Oo °° Z O O Z 0 U 0 000 N OJ O (n cn *k *k J in N r _ N. N- N- - CO O - - Tr Tr - OO .- CO_ N 0b LO 60 60Cq N ti O O N r i O) 0) ' UP • C) M M M M M N C N- CO co CO CO 000 N OO 0 0 0 0 . I (O N co - '— N N- Z Z Z Z Q 0 0 0 0 rn H H H H H W W � > >j >j Q Q 0 0 0 V 0cecece0000LLLL. ZZZ Z W W W 0 0 0 0 W CLm m m Q Z Z Z W W W W D , > > D UJJaa (2- CL U) - E-- ►- Perforation Attachment ADL0028345 Well Date Perf Code MD Top MD Base TVD Top TVD Base 09-11 - 7• /13/92 SQZ 11780 11782 8853 8854 09-11 7• /13/92 RPF 11782 11786 8854 8856 09-11 _ 7/13/92 SQZ 11786 11790 8856 8858 09-11 _ 7/13/92 APF 11804 11810 8866 8869 09-11 7• /13/92 RPF 11810 11814 8869 8871 09-11 _ 7/13/92 SQZ 11814 11840 8871 8885 „._ 09-11 1/27/90 SQZ 11880 11885 8906 8909 09-11 7/13/92 RPF 11910 11916 8922 8925 09-11 7/13/92 SQZ 11916 11920 8925 8927 09-11 7• /13/92 APF 11928 11933 8931 8934 09-11 7/13/92 RPF 11933 11936 8934 8936 09-11 7/13/92 SQZ 11936 _ 11961 8936 8948 09-11 1• /22/01 BPP 11984 11994 8960 8965 09-11 1/22/01 BPP 11994 11996 8965 8966 09-11 1• /22/01 BPP 11996 12028 8966 8982 09-11 1/22/01 BPP 12043 12060 8989 8998 09-11 1/22/01 BPP 12094 12096 9014 9015 09-11 _ 1/22/01 BPP 12096 12110 9015 9021 09-11 1• /22/01 BPP 12110 12112 9021 9022 09-11 ' 1/22/01 BPP 12117 12121 9024 9026 09-11 ' 1/22/01 BPP 12153 12159 9041 9044 09-11 ' 1/22/01 BPP 12175 12185 9051 9056 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED 1 FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF in in O o O 't3 0 co O O O o O) O) 00D o Co 0`0 0 m q co w w co 0 0 o co 0 = Z J J J ' U U C7 g ZOOgJce) � J CI) Q 0 0 0 0 o 0 o O O 0 O O _O O h. 1.0 O � CO CO CD N CD N p f' M in N N N- CO Co U 1) 0 0 0 o 0 0 o O O O O O o M CO 0) CO Co I� if) CD CO N M d' to - 00 t1 N- co - - M O N- N CO '— CO CO CO to CO 00 CO Co CD CO I,- I,- a) (C) • I,- CO A) - Co) N o N N 03 6 L00 W CO O N- N N- co �0 d)Cv) it) co O) N OD 00 N N ;;;or a ~ O• N- OM) N CO O- ct CO o o CD '— CO O M CO cr O N N COCr CD O Cl 00 CO M M N I-- CO ILO E t a) Cn Ca O N CO N- " CO m O M N O 0 0 0 0 O 1 - N N O r c- N 00 O CO O " N N e M C J U 0 C C N N o N CO Cc) M M co 2 Lo to O O O 000 000 O O 9 9 OO O OD vaooJJppCDOOZ00UCjo = Z *k *k J Z O O 2 M ao a) *k 2 h• CO 4O **t co fnco* (n d' (Ni N- N- N CO to CCD N - - 00 00 -0 C r '- N O - -0`O CV CD C M - CV N r•-• ` O O L9 M7 O) CA '— 4 CD M _M co M N •- CO 0) CO CO CD CO CO0N 0 CCOO CD CO O J 1- CO •- N CO M '— N N- M Z Z Z Z Q O O O O a) H H H H H w w U U 3• 00LIYIY00001aiuiZZZ U Z w w w 0 0 0 0 X CLm m Q Z Z Z CCCCCLCCD = D D D 0 :3n aaaacnc) HHH Packers and SSV's Attachment ADL0028345 Well Facility Type MD Top Description TVD Top 09-11 PACKER 10959 4-1/2" Baker S-3 Perm Packer _ 8362 09-11 PACKER 11207 7" Baker H-Isolation Packer 8530 09-11 PACKER 11282 7" Top Packer 8576 Prudhoe Bay 09-11 (Ivishak) (Permit To DriII# 1760840) Current Status Well 09-11 was drilled and completed in 1977 as a Zone 1 and 2 producer in the Eastern part of the field supported by offset injectors 09-22, 09-12, 09-10, and 09-17. In March 1990 a RWO installed a 4.5" scab liner. Later that same year, in August 1990, a Cretaceous leak was discovered and a 7-5/8" scab liner was installed. In July 1994, a RWO swapped out corroded L-80 tubing to tapered 7"x 5'/z" x 4% " chrome tubing. A 2007 RWO was performed on 09-11 to mitigate IAxOA communication. The well currently produces —231 bopd 98%WC and a GOR of 2994 scf/stb. 09-11 has no known casing problems, the April 2007 RWO had the OA cemented to surface The Base Management team's (with approval from the Reservoir Management) plan forward is to convert the 09-11 to a zone 1 and 2 injector in the Ivishak horizon. This conversion from producer to injector is necessary to complete a proposed pattern reconfiguration from current 9-spot to a 5-spot pattern. 2 new producers sidetracks are currently underway that would benefit from injection support that would come from converted 09-11 injector. (� oon f gcra//, fro Q,oJvctiO� f 1� ` Completion dein o rAr OW - ,r Sc,cvo/ f cprf, ( tf 7 ePollt9rt."419 ,' a waf ix) Ilift f dr Tie /Jew. il9)t1114 09-11 (Permit To Drill # 1760840) crosses the Ivishak formation 11788'/8803' /i/ie. /404,i',181, MD/TVDss, The surface hole was completed with 13-3/8" casing to 2702' and and re co,.. cemented to surface with 5650-sx of Arctic set cement. A 9-5/8" production casing string was run from surface to 11595' MD and cemented with 1000-sx class G cement. An .%5/ extra 15 bbls was pumped when plug did not bump, and still could not get plug to bump- 7 opened casing valve floats-held ok- cement in place. A second stage job was performed 300sx of arctic set cement. 7" liner was run from 11282'-12342' and and cemented in place with 450-sx class G. A March 1990 a RWO had a 4 %" scab liner cemented from 11208'-12257' md. Later that same year, in August 1990, a Cretaceous leak was discovered and a 7-5/8" scab liner was installed from 4387'-11200' MD. In July 1994, a RWO swapped out corroded L- 80 tubing to tapered 7"x 5%" x 4%" chrome tubing. Another RWO was performed in 2007 to mitigate IAxOA communication. On 11/30/2012, a Borax log was run on to verify zonal isolation ahead of proposed producer injector conversion that verified no indication of channeling between zones. Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Pressure test 9-5/8" casing to 4,000 psi. 3) Demo and then, blind 09-11 annulus & lateral valve and, the production &NL line. 4) Fabricate and install piping to set-up 09-11 for PWI and WAG injection. 5) Place well on water injection (confirm AOGCC approval prior to injection) 6) AOGCC witnessed MITIA once injection has stabilized . Area of Review — Greater Prudhoe Bay Well 09-11 in the Ivishak Formation (Permit# 1760840) 09-11 (Permit To Drill # 1760840) crosses the Ivishak formation 11788'/8803' MD/TVDss. This Area of Review is required prior to the conversion of well 09-11 from a producer to a water injector. This AOR discusses wells within % mile of the well's entry point into the Ivishak Formation to the bottom of 09-11 well bore completion. 09-11 is a corner producer between the 09-10i, 09-12i, 09-17i, and 09-22i patterns. Due to the truncation of Zones 3 and 4 by the LCU, this well is completed and perfed in Zones 1 and 2 only. Recent PPROFs suggest that this well is only producing from Zone 2, mostly from Z2B because of its higher quality rock. This is also the zone where it likely receives most injection support from 09-12i and 09-17i. This well likely receives injection support in the 21 P from 09-10i and possibly from 09-22i, which may be responsible for the higher watercut in this zone. There are currently no other wellbores within % mile radius of 09-11 entry point into the Ivishak formation. The closest wells to 09-11 are 09-22 and 09-47 of which both wells are within 2080' (-0.4 miles) radius. Completion:The surface hole was completed with 13-3/8" casing to 2702' and and cemented to surface with 5650-sx of Arctic set cement. A 9-5/8" production casing string was run from surface to 11595' MD and cemented with 1000-sx class G cement. An extra 15 bbls was pumped when plug did not bump, and still could not get plug to bump- opened casing valve floats-held ok- cement in place. A second stage job was performed 300sx of arctic set cement. 7" liner was run from 11282'-12342' and and cemented in place with 450-sx class G. A March 1990 a RWO had a 4 %" scab liner cemented from 11208'-12257' md. Later that same year, in August 1990, a Cretaceous leak was discovered and a 7-5/8" scab liner was installed from 4387'-11200' MD. In July 1994, a RWO swapped out corroded L- 80 tubing to tapered 7"x 5'/2" x 4%" chrome tubing. Another RWO was performed in 2007 to mitigate IAxOA communication. Currently there are no known integrity issues with 09-11. On 11/30/2012. A Borax log was run on to verify zonal isolation ahead of proposed producer injector conversion that verified there were no indications of channeling between zones. _...iiiii tow_ zx i ,QA45 0 i ,,, .t _______,,,,, ,,,, ii, -*\ ... .„A��_ 09-22 \ -%.11111 Vf ii) 1174111.1117 11101144,.. .."111111k ik IlWik, -02 091. ` 09_23• ;. G.d-<3 1.000 fees It30o meter, Figure: Map showing wells within 0.25 mi radius from 09-11 TREE- 7-1/16"CNV o WELLHEAD= FMC � SAFE ITE ""4-1/2"CHROME TBG"` ACTUATOR= OTIS INITIAL KB.ELF 54' BF.ELEV= 13-3/8•CSG, 50' !, I ►•♦.• ►♦: I r 27 1-7"X 5-1/2"XO,D=4.892'1 KOP= — 305T 68#,L-80,BTC, ►♦i ♦. Max Angle= 63"@ 12347' D=12.415 Its. 6:•'i 2088' 1 9-5/8"I-ES ES CEM3s1TER 1 Datum MD= 11782 , ___--_--- 2204' -5-1/2'HES X NP,D=4.562" Datum TVD= 8800'SS 20"CONDUCTOR,94#,1-40,D=? -F 79' II 2296' 1 FOC 2418' H FOC 9-5/8"CSG,4(14t,L-80,TC11,D=8.835' -1 2098' 13-3/8"CSG,72#,MN-80,D=12.347 1 2702' GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5-1/2"X 4-1/2"XO,D=3.938" f- 3994' 5 3387 3377 15 MING DONE RK 16 05/05/07 4 6524 5602 54 KGB2 SO BK 28 06/16/13 BRN TACK SLV w I 6'EXT,D=7.688" 1 4387' 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 2 9583 7391 49 KGB2 DMY BK 0 04/03/07 9-5/8"X 7-5/8"BKR FLEX-LOCK HGR,D=-7078-7571-1 4395' I 0 C 1 10740 8201 42 KGB2 DMY BK 0 04/03/07 i♦ ►i Minimum ID = 3.725" @ 11043' 10935•-141n"rsxr�,D=3.813• 4-1/2" HES X NIPPLE % li; C ••.�� ���.. 10956 H7-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 1091W-1-14-1/2"FES X NP,0=3-813" 9-5/8"CSG,47#,S0095 XO N-80 1 10990' •.• II ►♦ ♦ ► .! I 09-11 PERFS • •; 1 • 1 ►_ • • • • I• .• ••►'I 0 t • • • • • • • ♦ • ; • • ♦ • • ; • • • i PERFORATION SUMMARY • i • REF LOG: BHCS ON 04/20/77 ^ • ANGLE AT TOP PERF:57"@ 11780' '• Note:Refer to Production DB for historical perf data ' SIZE SPF INTERVAL OPMSQZ SHOT SQZ 2 C 3-1/8" 2 11780-11782 S 01/27/90 'II I 33/8' 2 11782-11786 0 07/13/92 ��•• ••r• 3-1/8" 2 11786-11790 S 01/27/90 •�•� '•••• 3-3/r 1 11804-11809 O 07/13192 ♦••••• �•••• • 3-1/8" 4 11880-11885 S 01/27/90 •• 3-3/8" 2 11910-11916 O 07/13/92 ► • ►4 i< 3-1/8- 4 11916-11920 S 01/27/90 A ►: ►: k // „„ 33/8" 1 11928-11936 0 07/03/92 • q a V 3-1/8- 4 11936- 11961 S 01/27!90 � • t 3-3/r 4 11984- 119% O 02/18/95 �• • 3.1/8" 4 11994- 12028 S 01/27/90 ►• . 3-1/8" 4 12043-12060 S 01/27/90 • • 3-3/8" 1/4 12043-12060 0 03/25/90 1 3-3/8" 1 12085-12094 0 03/25/90 ►• II 33/8" 6 12094- 12112 O 02/18/95 �• 3-1/8' 4 12096-12110 S 01/27/90 � 3-1/8" 4 12117- 12121 0 03/25/90 • 3-1/8" 4 12153-12159 0 03/25/90 ► • i. 3-1/8- 4 12175-12185 0 03/25/90 � • ►• Pr/Wevvi, Nj \S 4.4.1.4.4.4.E DATE REV BY CONVENTS DATE REV BY CONVENT'S PRUDHOE BAY UNIT 05101/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWC/PAG GLV C1O WELL: 09-11 06/17/86 RWO 06/05/07 JGMYPJC DRLG DRAFT CORRECTIONS PERK T No: 1760840 02/06/90 PAA-102 RWO SUSPENDED 10/23/10 KUPJC ELM)TT 8,XO CORRECTION AR Na: 50-029-20236-00 03/03/90 HIIES RWO 06/20/13 RKT/A43 GLV C1O(06/13!13) SEC 1,T1ON,R15E UM,1463N,50E OF SVVCR 06/28/94 D16 RWO 04/08/07 N2ES RWO BP Exploration(Alaska) Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, August 26, 2013 6:21 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: OPERABLE: Producer 09-11 (PTD #1760840) TIFL Passed Ail, Producer 09-11 (PTD #1760840) passed a TIFL on 08/24/2013 after breaking inner annulus MOASP. The passing TIFL confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Jack Disbrow (Alternate Laurie Climeri BP Alaska - Well Integrity Coordinator Iobal Wells SCANM OCT 0 9 2014 Organization Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, August 21, 2013 4:08 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; AK, D&C Well Integrity Coordinator; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer 09-11 (PTD #1760840) Sustained Inner Annulus Casing Pressure Above MOASP All, Producer 09-11 (PTD #1760840) was reported to have inner annulus casing pressure above MOASP on 08/19/2013. The pressures were tubing/inner annulus/outer annulus of 2300/2300/100. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: Operations: Place well on production DHD: Perform TIFL Copies of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator©bp.com] Sent: Wednesday,August 21, 2013 4:08 PM To: 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; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere;AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D(DOA) Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; AK, D&C Well Integrity Coordinator; Regg, James B(DOA) Subject: UNDER EVALUATION: Producer 09-11 (PTD#1760840)Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer 09-11 (PTD#1760840)TIO Plot docx; Producer 09-11 (PTD#1760840)Wellbore Schematic.pdf All, Producer 09-11(PTD#1760840)was reported to have inner annulus casing pressure above MOASP on 08/19/2013. The pressures were tubing/inner annulus/outer annulus of 2300/2300/100. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. Operations: Place well on production 2. DHD: Perform TIFL Copies of the TIO plot and welibore schematic are included for reference. Please call with any questions. Thank you, SCANNED r. Jack Disbrow BP Alaska-Well Integrity Coordinator GW Global Wells Organizatior. Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator @bp.com 1 Producer 09-11 (PTD#1760840)TIO Plot • Well:09-11 4.000- ♦—Tbg f IA 2.000- -A-OA 00A —41—000A On 1.000- 052913 0601/13 0606'13 0515'13 0627113 0629113 07/06+13 07/13113 07/20/13 07/27/13 08/03/13 08/10113 08/17/13 • • • ` Pth Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellIntegrityCoordinator @bp.com] Old Sent: Monday, June 10, 2013 10:32 AM I To: Regg, James B (DOA); 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; 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: 1810/2010040 psi 09-11(PTD#1760840),TIO: 2340/2340/140 psi 09-13(PTD#1770080),TIO: 2050/2110/690 psi SCANNED 09-21 (PTD#1831600),TIO: 2000/2010/650 psi _. 09-46(PTD#1901330),TIO: 1380/2010/180 psi 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 G IA! OGlobal Wells rclanizat on Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator(a)bp.com 1 a a 4rsllOOOl€ TT� f C7 1 c2 1 O I cp 1 C� _If7 to P, O M Q1 O � M 1 � I r M_ M_ � M A � M 0 CO L p O O a V M N r p co o H O CL a TREE= • 7-1/16"aw VVELLFEAD= RIC 09-11 A OTIS SA Ft i N ..,,,TE: '**4-1/2"C FROM E TBG*** CTUATOR= KB.ELEV= BF.ELEV= 13-3/8"CSG, H 50' 4" I 27' H7"X 5-1/2"XO,D=4.892" • , KOP= 3057 68#,L-80,BTC ir # . Max Angle= 63'@ 12347' 40 ■■ it 2088' 1-19-5/8"HES ES CI3v1ENTER 1 ID 12.415 ..• .* Datum MD= 11782 r 2204* -15-1/2"FES X NIP,13=4.562" i Datum 1VD= 8800'SS 120"CONDUCTOR,94#,14-40,ID=? 1 79 2296* -FOC 2418' --I FOC 19-5/8"CSG,40#,L-80,TC11,D=8.835" H 2098' ■ 13-3/8"CSG,72#,MN-80,D=12.347 - 2702' GAS LIFT MAKS ST hi) TVD DEV TYPE VLV LATCH PORT DATE 5-1/2"X 4-1/2"XO,ID=3.938" -1 3994' 5 3387 3377 15 WIG DOME RK 16 05/05/07 BRN TIEBACK SLV WI 6 B<T,ID=7,688" -I 4387' ID 4 6524 5602 55 KGB2 SO BK 24 12/30/12 3 8299 6597 55 KGB2 DMY BK 0 04/03/07 2 9583 7391 49 KGB2 DMY BK 0 04/03/07 19-5/8"X 7-5/8"BKR FLEX-LOCK HGR ID=6.875" 1-- 4395' 1 ri 1 10740 8201 42 KGB2 MY BK 0 04/03/07 N A •• • •• 1,A1 •■ 10935' 1-14-1/2"HES X NIP,El=3.813" Minimum ID = 3.725" @ 11043' 1 k• ir r' 4 • : 4-1/2" HES X NIPPLE .• u *4 10956' 1-17-5/8"X 4-1/2"BKR S-3 PKR ID=3.875" I :.4 IS •■ [ 10980' 1-f4-1/2*HES X NIP,13=3.813" 1 ,4 WO f 1104 9-5/8"CSG,47#,S0095 XO N-80 H 10990' •1 •-■ • o• ■4 •■ • ■•• 04 Y -4-1/2"HES XN NP,D 3.725' N . *I •. .• . •. ,,• . . 11055' H4-1/2"WLEG,0=3958' 4-1/2"TBG, 12.6#,13CR-80, - 11055 c. V ■• 14 VAM TOP,.0152 bpf,0=3958' •. • ■• •I 11055' HELM)LOGGED ON 06/11/07) •■ • ■• 14 4.■ ;04 11194' -I BRN 7'TIEBACK SLV,ID=7.50" I 7-5/8'SCAB LNR,29#,L-80,FL4S,.0459 bpf, - 11200' ;1'..• I 11201' H9-518-X 7"BRN HY FLA LNR FIGR,ID=6.184" 1 ■ w/BRN TYPE'PA`LOCATER&SEALS,ID=6.875' •1,4 es,"1 I loj 11207' H9-5/8"X 7'BRN MOD"H"LW,ID=6.196' V. A ••1 11208' --17"X 4-1/2"X0,113=3.958' 4 ■•• .4 t, ■ . ••4 7"LW,29#,MN-80,.0565 bpf,D=6.182" H 11282' EV ri • 11282' -19-5/8"X 7"PKR w/HGR,ID=? •.4 :44 pi • • pi r4 A A 9-5/8.CSG,47#,N-80,ID=8.681" H 11595' X X • • pi .4 • „• PERFORATION SUMV1ARY •" •" ja REF LOG: BRCS ON 04/20/77 •" ANGLE AT TOP PEW:57'@ 11780' •" ill •" pi ■ Niate:Refer to Production DB for historical perf data N $. SIZE I SPE INTERVAL I OPN/SQZ .. DATE ti al •'4 .4 V • 4 See Page 2 for Perforation Data •" •'4 111 •'4 0 I. .4 • 4, .4 •4 1313TD --1 12214' N III 12212' --IFISH- PUSH CEP TO BTM(03/02/01) • * I: • . • 4-1/2"SCAB LNR 12.6#,L-80, - 12257' 11.4 to 12213' -FISH-EP RUBBER.ELEMBNTS re v ir.! BTC,.0152 bpf,ID=3.958" 44 (10/6/92 and 07/10/94) te 1 7"LNR,29#,MN-80,.0371 bpf,D=6.182' - 12342' ' • - - - - • DATE REV BY (X/I■A -vENTS DATE REV BY COMMENTS FRLDFOE BAY UNIT 05/01/77 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SVVC/PAG GLV C/O WEIL: 09-11 06/17/86 RWO 06/05/07 JONI:0C DRLG CRAFT CORREC11ONS PERT No:'1760840 02/06/90 PAA-102 RWO SUSPENDED 10/23/10 Kt/MC ENID TT&X0 CX/RRECTION ' AR No: 50-029-20236-00 03/03190 N2ES RWO 01/16/13 lvt3MUIAJ GLV 00(12/30/12) SEC 1,T10N,R15E MI,1463N,50E OF SWCR 06/28/94 016 RWO 04/08/07 N2ES RWO . BP Exploration(Alaska) , . 09-11 . PERFS I :: 4 .4 .• OA t4 'e1 A ■ Ts r I r 4 9.4 • 4• PERFORATION SUIVMARY I 4 •4 • '• 1 4 •I REF LOG: BS ON 04/20/77 ANGLE AT TOP PERF:5700 11780' • .• 1 4 •1 • ■* 1 4 •I Note:Refer to Production DB for historical perf data 0 A •4 SE SIT 2 11780- 11782 S 01/27/90 NTERVAL OFNISQZ DATE I 4 A .. .• 3-1/8" A • •■ 1 4 •*4 3-3/8" 2 11782- 11786 0 07/13/92 I ■4 .40 3-1/8" 2 11786- 11790 S 01/27/90 V ■ •4 .• 3-3/8 1 11804- 11809 o 07/13/92 ■ :,44 1 4 •"I 3-1/8" 4 11880- 11885 S 01/27/90 1,.4 •4 3-3/8" 2 11910- 11916 0 07/13192 ■4 •4 3-1/8" 4 11916-11920 S 01/27/90 * 1 4 .• •4 '• 3-3/8" 1 11928- 11936 0 07/03/92 A ". •■ ,• ■• A g 3-1/8" 4 11936- 11961 S 01/27/90 I —■ 4.• I 04 3-3/8" 4 11984-11996 0 02/18/95 4 0 4111 3-1/8" 4 11994- 12028 S 01/27/90 ICI 0 3-1/8" 4 12043- 12060 S 01/27/90 01 I' 4• , 3-3/8" 1/4 12043-12060 0 03/25/90 I• • ‘•4 •• 1 • ••4 3-3/8" 1 12085-12094 0 03/25/90 •' •• •• ••• 11114 • 3-3/8' 6 12094- 12112 0 02/18/95 I•• &■•■ •4 I•• I-4 •■• VII 3-1/8" 4 12096-12110 S 01/27/90 Ell• , . * . 3-1/8" 4 12117- 12121 0 03/25/90 V V ■• 3-1/8" 4 12153- 12159 0 03/25/90 ■ A • • 3-1/8" 4 12175-12185 0 03/25/90 V V V V oN 0. • V III ■41 k.- • V 1- 1 4 • V 0 4 • 0 4 04 ,44.4..1 PO 04: r'4117■7•`•`■1 1 , DATE REV BY CONIVENTS DATE REV BY CX)MMENTS PRUDHOE BAY UNIT 05/01177 ROWAN 34 ORIGINAL COMPLETION 05/05/07 SWC/PAG GLV C/O WELL: 09-11 06/17/86 RWO 06/05/07 JGIVVPJC DRLG DRAFT CORRECTIONS PEWIT No:'1760840 02/06/90 PAA-102 RWO SUSPENDED 10/23/10 KUPJC ELMD TT&X0 CORRECTION AR No: 50-029-20236-00 03/03/90 N2ES RWO 01/16/13 tvEINVALI GLV 00(12130/12) SEC 1,T1ON,R15E LA 1463N,50E OF SVVCR 06/28/94 D16 RWO ., 04/08/07 N2ES RWO BP Exploration(Alaska) 0 [f) oG' c) .in o 0 o 0 0 0 0 0 0 0 0 0 0 .:z F. 0000000000000 r r r r r r r r r r r r r 1, W d rr, (120 11 H ty O (3 — ra O (G V o Lo E2r . . . . . . . . r r r r Q .,.., 5 iv c) c,..2 •--I ,i 0 t/'') M a) W tvI go 49 U � -271i o Urn r) ul as X00L 0- ' (f1 43 0 ,—I M N c N M M M M c CM M M r r r Mrrrrrrr LteN Q a+ N 4J ZC40 " W rc r .- ° 7 CO m pp,_ CUm •c O :+ O O I-- O rc ~ co J ^ coN r . 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The well is reclassified as Operable and may remain on production. Thank you, Mehreen Vazir BPXA Well Integrity Coordinator SCANNED JUL 2 9 2013 907 -659 -5102 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, December 25, 2012 7:49 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Igbokwe, Chidiebere Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer 09 -11 (PTD #1760840) Sustained IA pressure over MOASP All, Producer 09 -11 (PTD # 1760840) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were T /IA/OA equal to 2300/2300/100 psi on 12/24/2012. A TIFL was performed on 12/24/12 which resulted in a fail. The well has been reclassified as Under Evaluation and may be brought online while work is conducted to attempt to restore integrity. Plan forward: 1. S: c/o OGLV 2. D: Re -TIFL 3. SP /FP: Pressure Test for Gas Lift Integrity if TIFL fails « File: 09 -11 TIO plot.docx » « File: 09 -11 Schematic.docx » • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ! EO FEB 2 4 2 Mr. Tom Maunder ' 0 Alaska Oil and Gas Conservation Commission 1 333 West 7th Avenue I Anchorage, Alaska 99501 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 extemal 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/ 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 "11 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 1770370 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 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 32 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 1.2 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 0.2 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 f 09-4( Pry i ?60640 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] � t2J z66, Sent: Tuesday, December 25, 2012 7:49 AM 11 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Igbokwe, Chidiebere Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer 09 -11 (PTD #1760840) Sustained IA pressure over MOASP Attachments: 09 -11 TIO plot.docx; 09 -11 Schematic.docx All, Producer 09 -11 (PTD # 1760840) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were T /IA/OA equal to 2300/2300/100 psi on 12/24/2012. A TTFL was performed on 12/24/12 which resulted in a fail. The well has been reclassified as Under Evaluation and may be brought online while work is conducted to attempt to restore integrity. Plan forward: SCANNED APR 1 1 2013 1. S: c/o OGLV 2. D: Re -TIFL 2P Z, b7Q 3. SP /FP: Pressure Test for Gas Lift Integrity if TIFL fails , �tP . 5 ?5Ops, «09 - 11 TIO plot.docx» «09 - 11 Schematic.docx» % hLzyP = 4 ( - ) ` ✓ Filling in for Mehreen Vazir (Well Integrity Coordinator) Greg Walker (Alt. Shane Wills) Well Integrity Engineer - Wells Group Phone : 907 - 659 -5525 Harmony: 2378 1 • PBU 09-11 PTD 1760840 12/25/2012 TIO Pressures Plot Men: 09-11 2.0a OA 00A .■.■22.2j 7 000A 1 MO • Zonieromaimc 12/3 0111 01/28/12 02/1/2 0225/12 031 012 04/0 0421/12 ' 001O ' 5/12 05412 0642/12 061 06/30712 07/1 . 071213.12 0E01/12 . 08/2 . 5/12 . 09A09/12 . 096/12 10)06/12 10120/12 . 11/03112 11/1 12/01;12 .12/1.5/12 S 4111 IRE Es 7-1/18' C2W WELLHEAD = R4C 09-11 I SAFETY mare –*4-112' CHROM ETEIG""" CIU I A ATOR = OTIS kii riW = 54' aF B_EV = 13-31EF CSG, 50 •p • s 27' T x 5-irr xo, cp. 4 ear I V 0: K KOP= 305r 684, L-80, BTC, ° 0 ' it 2088' 9 HES ES CE9ENTBR Max Angle 63 12347' = ' ft c = 12 415 t4t :41 Dottrn MD = 11752' T3iti TVD = --esoif–ass r IIi I 2204' Hs- yr HES X NP 0= 4 567 I 20' CONOL 940,1440, 0 = 7 79' II 2296' 2418' 1-(= / 719-5/r CSG 40#, L-80, rci 1,13 = 8.835' H 2098' 13-318' CSG 72# 1.04-81), Et 12.347 H 2702' GAS LET AV, NORB_S ST MD TVD DB/ TYPE L VLV LATCH PORT DATE 5750rs7 5 1/7 X 4-1/7 X0, ID = 34138' 3994 5 3387 3377 15 WAG COVE RE 16 05106/07 H BRN TEBACK S_V w / 8' EXT. c = 7 888' 438r in 4 8524 5602 55 KGE2 SO BK 24 05/05/07 I 3 8299 6597 35 KGB2 DON BK 1) 04'03417 2 9583 7391 49 KG82 MAY BK 0 04/03/07 19-5/8" X 7-518' B401 F LE(-LOCK HGR, D. 6.878' 4395' 1 10740 8201 42 (4282 DMY BK 0 0410307 Vt CI 10935' 4-1/7 HES X HP, ID= 3 813* I 4-1/2" HES X NIPPLE Minimum ID = 3.725" 40 11043' V • on V .. elii II i * ..11 CI 04 cl 1 0956' 7-6/8' X 4-1/2" BKR S-3 PKR, (3 = 3 875' I 4 I:t■ 1 09w s ki 1 of.$ 10980' 4-1 /7 HES X NP D 3 813" I 19-518 CSG, 47#, S0095 XO N-80 V ..., 11043' 4- 1/2 HES XN NP. 0 = 3 725 1 k A .*: 4-1.7 TBG, 12.66, 13CM-80. 11055' A 11055' 4.1rr IALEG D =3 956" I 1.1 VAM TOP, 0152 btbf . D. 3 93,3 P s 7 4 _ ' A I 11055' HELM LOGGED ON OW 1/07) I ' $ i A .".. 11194' fri4 T TEBACK SLV D = 7 50 I .., 7-518' SCAB Lt4Ft, 294, L-80, FL4S, .0459 bpf, 11200' .1 - t 11201' 9-5/8' X 7' BRN HYFLA L244 HGR, 0 = 6.184' w ANN TYPE PA' LOCATB4 & SEALS, El = 6.075' 6 da LI lo; 11207' H9-513. x 7' BRIN A400 Pf Los, o = siors" I Wr:$ el 11208 x 4-172' XO, ID = 3 958' 4 4....4 Ir L RR, 294 PAJ4113 0565 60,10= 6 182' 11282' &AA Er ...... ..-.ffl 11282' 9518' X r PKR w/HGR, 0= I I9-5/8' CSG,47# 1 0.8 88,r h 11595' A i = ‘€6. 70r5: PERFORATION SUMMARY . REF LOG. BHCS ON 04/20/77 M A Nat E A T TOP FERE 9 ` 0 11780' ;. Note Reef to Alt.:Suction DB la' tostorical pert chilla II SIZE I SPF I INTBRVAL I OFT*SOZ I DATE Z '. See Page 2 to( %Haab:41 ()eta mi III r Pain 12214 M 12212' FISH- PUSH GBP TO BOA (03102/01) I A 4-1/2' SCAB LNR, 12.6$, L-90 12257' 1. t I 12213' H FSH. IBP RUBBER EL EVENTS BTC_0152 b14, 10 = 3.958' ; 0?7,44,i (10/6192 aid 07/10/94) 7' Ltft 234, A& 80, .0371 bp}, ID = JI 182' 12342' ' 44949.81 DA IL REV BY CO%LENIS DATE NOV BY COMMENTS PRUDHOE BAY JUT 05101177 ROWAN 34 ORIGINAL COMPLETION 05/05107 SWC/PAG GLV CiO WELL 09-11 06/17/% RWO 06/05/07 JGAAPJC DR_G DRAFT CORRECTIOAS PCf64T No P1760840 02/0010 PAA-102 RWO SUSPENDED 10123/10 KUPJC ELM) TT & XO CORREC'TON AR Pb 50-029-20236-00 03P93/93 ORES RWO SEC 1. T1014 RI SE LM 146314. 50E CE SWCR 96/24/94 016 RWO 04104/07 R2ES RWO BP Exptoration (Alaska) ScblumblPgep 1-1Co -O~t.¡ R,ECEPJt:I::; 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL 3 0 Z001 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Coos. Cornfnission 0 1 2007 Anchor&ge SCANNED AU G Field: Prudhoe Bay Endicott Well Job# Loa DescriDtion Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07 A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 US IT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: glP _ STATE OF ALASKA _ ~ RECE'VED A'-'Ir<A Oil AND GAS CONSERVATION CO~SION MAY 0 2 2007 REPORT OF SUNDRY WELL OPERATIONS . . Alaska Oil & Gas Cons. CommIssIon 1. Operations Performed: Ancnorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 176-084 ' 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20236-00-00 , 7. KB Elevation (ft): 54' / 9. Well Name and Number: PBU 09-11 ,-- 8. Property Designation: 10. Field / Pool(s): , ADL 028345 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12347 / feet true vertical 9130 feet Plugs (measured) None Effective depth: measured 12262 feet Junk (measured) 12212' true vertical 9090 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 73' 73' 1530 520 Surface 2702' 13-3/8" 2702' 2702' 5380 2670 Intermediate Production 11595' 9-5/8" 11595' 8751' 6870 4760 Liner 1060' 7" 11282' - 12342' 8576' - 9127' 8160 7020 Scab Liner 6813' 8-1/4" x 7-1/2" x 7-5/8" 4387' - 11200' 4293' - 8526' Scab Liner 1049' 4-1/2" 11208' - 12257' 8531' - 9089' 8430 7500 SCANNED MAY C'920D7 Perforation Depth MD (ft): 11782' - 12185' Perforation Depth TVD (ft): 8854' - 9056' 5-1/2",17# x 4-1/2",12.6# 13CR80 11055' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker 'S-3' packer ...... JJ.....,....'.__..u}"~.....:.:..'...........",;J1::. 1 0956' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cut and pull tubing, complete retrieval. Cut and pull 9-5/8" casing at -2104'. Cut and pull 13-3/8" casing at -78'. Cement 13-3/8" x 20" annulus with a top job of 17 Bbls Class 'G' Arcticset (95 cu It /102 sx). Run 9-5/8" tieback to surface, cement w/145 Bbls Class 'G' (814 cu It /696 sx). Run new chrome tubing. Treatment description including volumes used and final pressure: R8DMS 8Ft MAYO 8 2DD7 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Joshua Sudderth, 564-4342 307-043 Printed Name Terrie Hubble Title Technical Assistant Signature /fÔ ^~ . ~1 ~ 0SJoz/ 07 Prepared By Name/Number: Phone 564-4628 Date () Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 0 R , G , N A L ¥I~- Submit Original Only Digital Wellfile . . Page 1 of 2 Well: 09-11 Well Events for SurfaceWell - 09-11 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 09 -> 09-11 Date Range: 20/Jan/2007 to 10/Mar/2007 Data Source(s): AWGRS Events Source Well AWGRS 09-11 AWGRS 09-11 AWGRS 09-11 Date 02/17/2007 02/13/2007 02/09/2007 AwGßS 09-11 02/08/2007 AWGRS 09-11 02/08/2007 AWGRS 09-11 02/07/2007 AWG...ßS 09-11 AWGRS 09-11 AWGRS 09-11 AwGRS 09-11 AWGRS 09-11 AWGRS 09-11 .A wGKS 09-11 AWGRS 09-11 02/06/2007 02/06/2007 02/05/2007 02/05/2007 02/04/2007 02/04/2007 02/03/2007 02/03/2007 Description T/IA/OA = 0/0/0 Pre rig well head follow up. RWO will be going down to 13-3/8" casing went back out to cycle LDS on 20" FMC spool. {1} LDS was bent at a 90 degrees. Were able to move may have to back out with a pipe wrench to get on bend. All other LDS on 20" operate smooth, with no signs of any bent or broken LDS. Not able to test 20" void has been packed off with Seal Tite product. SET BPV PRE RIG WORK API VALVE SHOP T/I/O= 0/0/0 Pre rig Wellhead MIT. PPPOT-T failed PPPOT-IC failed Bled off void on tubing head to 0 psi circulated Aerokroil through void unable to build pressure. were able to break all LDS free but 1 . 1 LDS is seized to gland nut will need to be changed during RWO After all LDS were cycled, re tested void was able to achieve 5000 psi pressure would bleed off to 4000 psi after 30 min should be able to achieve BOP test. IC hanger bled void off to 0 psi, attempted to purge Seal Tite from test void, unable to get returns. broke LDS with pipe wrench. was able to cycle LDS in and out with an airgun 1 LDS was marked "unable to move" from prior well work. Were able to back out far enough to clear bowl and left out, LDS will be changed RWO per FMC. T/IA/OA=O/O/O Pre-rig well head MIT. Checked pressures on well head, installed heater on well head to heat well head. All LDS on both tubing spool and casing spool are twisted on the flats. TIO = 20/10/50. Temp = SI. AL spool dropped. WHPs (pre-Rig). ****WSR Continued from 02-06-07****T/I/0 = 0/0/620 Circ-Out CMIT TxlA to 3500 psi (PASSED) MIT OA to 2000 psi! (PASSED) (Pre RWO) Pumped a 5 bbl neat methanol spear down the flow line to ensure it is free and clear. Pumped a 5 bbl neat methanol spear followed by 1092 bbls. of seawater into tubing taking returns up the IA through jumper loop to the flow line. Freeze protect the tubing and IA with 150 bbls. of 75* diesel, U-Tube tubing and IA. CMIT TxlA passed on 3rd attempt, Pressured up with 8.5 bbls. diesel T/IA lost 80/80 in 1st. 15 min. and lost 40/40 in 2nd. 15 min. with a total of 120/120, PASSED.Bleed back pressures. MIT-OA passid on 5th. attempt, Pressured up with 4.9 bbls. crude OA lost 100 psi. in 1st. 15 min. and lost 50 psi. in 2nd. 15 min. with a total loss of 150 psi, PASSED. Freeze protect flow line through jumper loop and cassasco with 5 bbls. neat meth spear, 15 bbls. crude, 1.4 bbls. neat meth cap. Bleed WHp's.Final WHP's= 0/0/0 T/I/O = 0/0/620 Circ-Out CMIT TxlA to 3500 psi, & MIT OA to 2000 psi. (PRE RWO) Pumped a 5 bbl neat methanol spear down the flow line to ensure it is free and clear. Pumped a 5 bbl neat methanol spear followed by 1092 bbls of seawater into tubing taking returns up the IA through jumper loop to the flow line. Freeze protect the tubing and IA with 150 bbls of diesel. U-Tube the Tubing and IA. ****WSR Continued to 02-07-07**** ***CONTINUED FROM 5-FEB-2007*** RIG UP FOR 4-1/2" TUBING CUT. T/I/O 0/650/650 SMALL CHARGES TUBING PUNCH OVER 10,910-10,912 FT WITH 4 SPF, 0 DEGREE PHASING. 4-1/2" TUBING CUT WITH 3-5/8" CHEMICAL CUTTER AT 10,945 FT DEPTHS CORRECTED TO TUBING SUMMARY DATED 24-JUN-1994 ***JOB COMPLETE*** RIG UP FOR 4-1/2" TUBING CUT. T/I/O 0/650/650 *****CONTINUED 6-FEB-2007***** ***CONTINUED FROM 5-FEB-2007*** RIG UP FOR 4-1/2" TUBING CUT. T/I/O 0/650/650 SMALL CHARGES TUBING PUNCH OVER 10,910-10,912 FT WITH 4 SPF, 0 DEGREE PHASING. 4-1/2" TUBING CUT WITH 3-5/8" CHEMICAL CUTTER AT 10,945 FT DEPTHS CORRECTED TO TUBING SUMMARY DATED 24-JUN-1994 ***JOB COMPLETE*** T/I/0=0/625/675 MIT tubing to 2500 psi, PASSED / Test plug ( RWO Prep) - Pressure tubing to 2500 psi w/ 2.6 bbls meth, TBG loss 120 psi 1st 15 min, loss 80 psi 2nd 15 min, Re- pressurized tbg with 0.2 bbls meth, Loss 30 psi 1st 15 min & loss 30 psi 2nd 15 min, Bled down tubing. FWHP's=100/640/680 **CONTINUED FROM 3-FEB-2007*** RUN 1: SET HALLIBURTON 4-1/2" FAS DRILL BRIDGE PLUG MID ELEMENT AT 11000'. OVERALL LENGTH OF PLUG IS 2.41' RUN 2: 12' STRING SHOT WITH 2 STRANDS 80 GRAIN PRIMA CORD SHOT FROM 10946' - 10934'. UNABLE TO PT PLUG DUE TO FLUID LEVELS. WILL COMPLETE CHEMICAL CUT AFTER PLUG PRESSURE TESTED. RUN 1: SET HALLIBURTON 4-1/2" FAS DRILL BRIDGE PLUG MID ELEMENT AT 11000'. OVERALL LENGTH OF PLUG IS 2.41' RUN 2: 12' STRING SHOT WITH 2 STRANDS 80 GRAIN PRIMA CORD SHOT FROM 10946' - 10934'. ***CONTINUED 4-FEB-2007*** T/I/0=250/660/680 DisplaceTBG for E-Line Work (Shut In)(Pre-RWO) Pumped 5 bbls 60/40 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 4/3012007 Digital Wellfile AWGßS 09-11 02/03/2007 AWGRS 09-11 02/02/2007 AWGRS 09-11 01/29/2007 AwGRS 09-11 01/24/2007 AWGRS 09-11 01/24/2007 AWGRS 09-11 01/23/2007 AW~RS 09-11 01/23/2007 AWGRS 09-11 01/20/2007 . Page 2 of 2 . Meth, 303 bbls 2% KCL Water, and 95 bbls 60/40 Meth into TBG. Final WHP's=0/580/600 TIO = Vac/570/570. Temp = SI. No AL. WHPs, TBG FL (for EL, post bleed). TBG FL @ 650'. TBGP decreased 260 psi(EL on the well), lAP & OAP increased 150 psi overnight. TIO = 290/690/690. Temp = SI. AL disconnected. Bled WHPs < 300 psi (pre EL, pre Rig). IA FL @ 900'. Bled lAP to production from 690 psi to 360 psi in 30 mins, FTS, OAP @ 420 psi. Continued bleed. Bled for a total of 3.5 hrs. lAP & OAP @ 380 psi. TBG FL 130'. Bled TBGP from 290 psi to 250 psi in 10 mins, FTS. SI bleed. Monitored WHPs for 30 mins. lAP & OAP increased 40 psi, TBGP increased 10 psi. FWHPs = 260/420/420. T/I/0=300/700/700. Temp=SI. A/L dropped. TBG & IA FL (pre e-line). TBG FL @ 96' (1.5 bbls). IA FL @ 882' (23 bbls). ***WSR continued from 01/23/07*** T/I/O= 2100/560/560. ASSIST SLlCKLlNE W/ BRUSH & FLUSH. Pump 242 bbls of 180* crude into the TBG. FWHP's=450/600/600. *** CONTINUED ON 01-23-2007 *** ( PRE RWO ) B&F TBG W/ 3.5" CENT & BRUSH RAN 3.70 CENT, SB TO 12,050' SLM (BAILER EMPTY) ***TURNED WELL OVER TO DSO, LEFT WELL S/I*** ***WELL S/I ON ARRIVAL *** ( PRE RWO ) CURRENTLY PERFORMING B&F W/ 4 1/2 BRUSH, 3.625" GAUGE RING WHILE PUMPING HEATED CRUDE W/ LRS *** JOB IN PROGRESS *** T/I/O= 2100/560/560. ASSIST SLlCKLlNE WITH BRUSH & FLUSH. Pump 5 bbls of neat and 40 bbls of 180* diesel into the TBG. ***WSR continues on 01/24/07*** *** WELL SHUT IN ON ARRIVAL ***(pre-rwo) DRIFT WITH 4.75 CENT.TAG TRDP @ 2191' SLM. RIH WITH 4.75 CENT,XO, 9' 1.25 STEM, F.e. WITH 3.5 BRASS T.T.s TO 2191' SLM, TRDP APPEARS TO BE FUNCTIONING PROPERLY. RAN 3.805 G.RING AND 1.75 S.B TO 7762' SLM ( recovered sample of what appears to be asphaltines) RIH WITH 3.65 CENT. AND 5' x 2.25 D.D. BAILER TO 7762' SLM (recovered hard tar like substance) RIH WITH 3" x 10' P. BAILER (recovered hard tar like substance) ***LEFT WELL S/I*** DSO NOTIFIED http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 4/30/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/10/2007 18:00 - 21 :30 3.50 MOB P PRE Rig down floor,bridle up derrick, and prepare pits for move. 21 :30 - 00:00 2.50 MOB N WAIT PRE Wait on weather to layover derrick. 3/11/2007 00:00 - 00:00 24.00 MOB N WAIT PRE Wait on weather to lower derrick.Work on house keeping,rig repairs,and maintenance 3/12/2007 00:00 - 05:00 5.00 MOB N WAIT PRE Wait on weather to lower derrick.Work on house keeping, rig repairs,and maintenance 05:00 - 00:00 19.00 MOB P PRE Lay derrick down and move off N-22. Move rig from N pad to drill site 09. 3/13/2007 00:00 - 09:00 9.00 MOB P PRE Move rig to 09-11. 09:00 - 22:00 13.00 RIGU P PRE Move rig over well. Move pits into place. Bring on seawater. Rig up sub, cuttings box, camp and all buildings. 22:00 - 00:00 2.00 WHSUR P DECOMP Hold pre spud meeting. Go over check list. Accept rig at 2200 hours. Rig up and prepare to test OA and IA x tbg to 2000 psi for 30 minutes. 3/14/2007 00:00 - 05:00 5.00 WHSUR P DECOMP Rig up double valves on OA and IA. Rig up LRS and pressure test OA and IA x tbg to 2000 psi for 30 minutes. Chart tests. Tests good. 05:00 - 06:00 1.00 WHSUR P DECOMP Rig down LRS. Rig up DSM and pull BPV with lubricator. 06:00 - 11 :00 5.00 WHSUR P DECOMP PJSM. Rig up circulating lines to tree. Reverse circulate out diesel freeze protection from tubing. Shut in and swap hoses to circulate down tubing. Displace diesel and change well over to clean seawater at 210 gpm with 250 psi. Monitor and verify well is dead. Blow down lines and rig down. 11 :00 - 12:00 1.00 WHSUR P DECOMP Install TWC with FMC dry rod. 12:00 - 13:00 1.00 WHSUR P DECOMP Test TWC from below and above to 1000 psi. Blow down and rig down circulating lines and suck fluid from tree. 13:00 - 15:30 2.50 WHSUR P DECOMP Bleed off and terminate control lines. Nipple down tree and adapter. 15:30 - 21 :00 5.50 BOPSU P DECOMP Function test rams. Nipple up BOPE. Change out lower rams from 2-7/8" x 5" variable to 7". Make up 7",5-1/2" and 4-1/2" test joints. Rig up test equipment. 21 :00 - 00:00 3.00 BOPSU P DECOMP Test BOPE and valves to 250 psi low, 3500 psi high. Test Hydril to 250 psi low, 2500 psi high as per AOGCC. John Crisp with AOGCC was notified and instructed us to proceed with BOPE test. 3/15/2007 00:00 - 04:30 4.50 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high. Test Hydril to 250 psi low, 2500 psi high as per AOGCC. Notified John Crisp with AOGCC and were instructed to proceed with test. 04:30 - 05:00 0.50 BOPSU DECOMP Blow down top drive. Rig down and lay down testing equipment. 05:00 - 06:30 1.50 BOPSU DECOMP PJSM. Pick up lubricator and rig up DSM. Pull TWC, rig down and lay down lubricator. 06:30 - 09:30 3.00 FISH P DECOMP PJSM. Pick up and make up spear on single joint of DP. Engage spear. Drain stack. Change out bad lock down screw and gland nut. Back out lock down screws. Unseat and pull hanger to rig floor. Max pull 185k. Up weight 175k. 09:30 - 10:30 1.00 FISH P DECOMP Circulate bottoms up at 450 gpm with 800 psi. Pick up spooling unit, power tongs and all tubing handling equipment. 10:30 - 12:00 1.50 PULL P DECOMP Disengage spear. Blow down top drive. Break out and lay down hanger. Service break spear and clear floor. PJSM. Re-hang rig tongs. Rig up power tongs, spooling unit and change out elevators. 12:00 - 00:00 12.00 PULL P DECOMP POOH with tubing and lay down 55 joints 7", 20 joints 5-1/2", Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/15/2007 12:00 - 00:00 12.00 PULL P DECOMP 180 joints 4-1/2" and one 4-1/2" cut joint at 36.90". Pulled 7 GLM's and SSSV. Cut was clean. Recovered 23 ss bands. Clear floor. 3/16/2007 00:00 - 03:00 3.00 CLEAN P DECOMP Continue clearing floor. Lay down tubing handling equipment. Pick up 9-5/8" scraper assembly tools. 03:00 - 04:30 1.50 CLEAN P DECOMP Pick up and make up 4" test joint. Test upper rams to 250 psi low, 3500 psi high and hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Jeff Jones with AOGCC. Pull break and lay down 4" test equipment. 04:30 - 06:00 1.50 CLEAN P DECOMP Pick up and make up 9-5/8" scraper assembly to 314'. 06:00 - 10:00 4.00 CLEAN P DECOMP PJSM. Pick up DP and RIH to 4295'. Up weight 110k, down 105k. 10:00 - 11 :30 1.50 CLEAN P DECOMP Wash down and tag 7-5/8" scab liner top at 4380'. Pump at 450 gpm with 920 psi. Circulate hi-vis sweep surface to surface at 500 gpm with 1150 psi while rotating and reciprocating. Pump dry job. Blow down top drive. 11 :30 - 13:00 1.50 CLEAN P DECOMP POOH to 314'. Change out handling equipment. 13:00 - 15:00 2.00 CLEAN P DECOMP POOH with scraper BHA. Lay down bit, boot baskets and scraper. Empty boot baskets and recover 2 ss bands. Clear floor. 15:00 - 23:30 8.50 EV AL P DECOMP PJSM. Spot E-line unit. Pick up and rig up wireline tools. RIH and log up from 4300' with USIT/GRlCBL in cement and corrosion modes. POOH. Break and lay down logging tools. Corrosion mode showed no significant corrosion in 9-518" casing. Top of cement at 2200'. Make up 4 strand string shot. RIH and fire shot across second free collar above cement at 2116' E-line measurement. POOH and rig down E-line. 23:30 - 00:00 0.50 DHB P DECOMP Change out elevators. Pick up RBP and break off overshot spring adapter. 3/17/2007 00:00 - 03:00 3.00 DHB P DECOMP Pick up RBP. Make up RBP and RIH to 3200'. Set RBP and verify with 15k down weight. Put 1/4 turn to the left and pull up. No overpull. Try to set back down on plug. RBP not in place. Prepare to RIH and retrieve plug. 03:00 - 07:00 4.00 DHB N DPRB DECOMP Chased RBP down to top of 7-518" scab liner top. Tagged up and stabbed into RBP. Pulled up 20' and set plug. Verified with 15k down, pulled up with 5k overpull. Pulled free. Set down 25k to verify set of RBP. Set was good. Stabbed back into plug and released. Pulled back up to 3200'. Circulate at 126 gpm with 61 psi. Shut down set RBP at 3193'. Verify set. Blow down top drive. 07:00 - 07:30 0.50 DHB P DECOMP Test above RBP to 2000 psi for 10 minutes and record on chart. Test good. Blow down top drive. 07:30 - 15:00 7.50 DHB P DECOMP PJSM. Dump 2000 Ibs sand on top ot RBP for 23' of coverage. Wait one hour for sand to fall out of pipe and settle. RIH to top of sand and tag at 3178',15' above RBP. PU and stand back 2 stands. Install blower hose and rotate at 20 rpm to facilitate the sand to fall out of the pipe. Run back in hole and tag sand at 3170'. POOH. Lay down RBP running tool. 15:00 - 18:00 3.00 BOPSU P DECOMP PJSM. Drain stack. Install test plug. Replace lower 7" rams with 9-5/8" rams. Fill stack. Close blind rams and test door seals to 250 psi low, 3500 psi high as per AOGCC. 18:00 - 19:30 1.50 CASE P DECOMP Pick up and make up casing cutter, XO, stabilizer and drill collars to 286'. Change out elevators. Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3n /2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/17/2007 19:30 - 22:30 3.00 CASE P DECOMP RIH to 2060'. Install blower hose. Circulate to open cutters, work down and tag string shot collar at 2099' DPM. Verify depth with SWS. Pick up to cutting depth at 2079'. PJSM. Cut 9-5/8" casing at 2079' pumping at 175 gpm with 715 psi. Torque 2.5k to 6.5k at 35 rpm. Make cut in 30 minutes. Shut down, pick up 3'. Run back down while circulating and verify cut. Monitor well. 22:30 - 00:00 1.50 CASE P DECOMP Pick up and clear tool joint. Line up cuttings tank. Close rams and break circulation through the 9-5/8" x 13-3/8" annulus at 1200 psi. Shut down, bleed off, open rams and monitor well. Pull one stand. Rig up head pin to stump. Rig up LRS to cement manifold. Pressure test lines to 2500 psi. Pump 18 bbls, 140 degree diesel to bottom of drill pipe taking seawater returns to pits. Close annular preventer and continue to pump diesel taking returns to the cuttings tank from the 9-5/8" x 13-3/8" annulus, displacing the Arctic Pac. 3/18/2007 00:00 - 04:30 4.50 CASE P DECOMP PJSM. Circulate 150 bbls, 140 degree diesel in the 9-5/8" x 13-3/8" at 84 gpm with 750 psi. Soak in annulus for one hour. Rig down LRS. Chase with 110 degree seawater at 154 gpm with 432 psi, taking returns to the cuttings tank. Increase rate to 184 gpm with 1894 psi and pump until clean as per Mud Man. 04:30 - 05:30 1.00 CASE P DECOMP Remove blower hose. POOH to 284'. 05:30 - 06:00 0.50 CASE P DECOMP POOH with cutter assembly. Lay down cutter, stabilizer and XO. 06:00 - 07:30 1.50 CASE P DECOMP Pick up tools for spear assembly. PU pack off retrieval tool and make up on DP joint. 07:30 - 08:30 1.00 WHSUR P DECOMP PJSM. Run in with pack off retrieval tool. Sting in back off lock down screws. Pull pack off to rig floor and lay down. Lay down tools. 08:30 - 09:00 0.50 FISH P DECOMP PJSM. Make up 9-5/8" spear assembly and rig up floor to lay down 9-5/8" casing. PJSM. RIH and spear 9-5/8" casing. 09:00 - 11 :30 2.50 BOPSU DECOMP Nipple down BOP stack to gain access to emergency slips. Pick up stack. Unseat 9-5/8" emergency slips from profile with up weight of 135k. Remove emergency slips and set stack back down. 11 :30 - 13:00 1.50 BOPSU DECOMP Nipple up BOP stack to wellhead. 13:00 - 13:30 0.50 BOPSU DECOMP PJSM. Line up and close rams to test flange break to 250 psi low, 2000 psi high against wellbore. Test OK. 13:30 - 14:30 1.00 CASE P DECOMP PJSM. Displace well with 9.8 ppg brine through the 9-5/8" and up the 13-3/8" annulus at 334 gpm with 400 psi. Take returns to the cuttings tank. Blow down and rig down cellar circulating lines. 14:30 - 00:00 9.50 CASE P DECOMP PJSM. Pull 9-5/8" casing to rig floor with 125k up weight. Break out single and XO. Blow down top drive. Change out elevators. Install lift sub. Pick up and rig up casing tongs. PJSM. Lay down top joint, (33.16'), and spear. POOH and lay down 9-5/8" casing from 2079'. Break every connection with rig tongs with 20-25k torque. Bow centralizers every 5th collar. Recovered 49 full joints, 10 Bow centralizers and the bottom cut joint of 22.15'. Left pieces of 4 broken Bows in the hole. Clear and clean hole. Last centralizer on collar at joint 49/50. Clear and clean floor. Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/19/2007 00:00 - 01 :00 1.00 CASE P DECOMP PJSM. Finish clearing and cleaning floor. 01 :00 - 03:30 2.50 CASE P DECOMP PJSM. Change out lower rams to 2-7/8" x 5" variables. Make up 4" test joint. Set test plug and test rams to 250 psi low, 3500 psi high as per AOGCC. Good test. Break down test joint and lay down. Clear floor. 03:30 - 04:30 1.00 CASE P DECOMP PJSM. Bring 13-3/8" scraper assembly up beaver slide. 04:30 - 06:30 2.00 CASE P DECOMP PJSM. Make up 13-3/8" casing scraper assembly to 313'. Change out handling equipment. 06:30 - 10:30 4.00 CASE P DECOMP PJSM. RIH to 1246'. Break circulation at 482 gpm with 454 psi. Slow down rate to 375 gpm with 277 psi. Up weight 65k, down 65k. Blow down top drive. Continue to RIH to top of stump at 2079' and tag with 5k down. Break circulation at 343 gpm with 346 psi. Up weight 75k, down 75k. Increase rate to 421 gpm with 490 psi. Circulate until clean as per Mud Man. Break out top drive and blow down. 10:30 - 11 :30 1.00 CASE P DECOMP PJSM. POOH to 313'. Change out handling equipment. 11 :30 - 14:30 3.00 CASE P DECOMP PJSM. Stand back collars. Break and lay down bit, junk baskets, scraper, XO's, Jars and bumper sub. Clear and clean floor. 14:30 - 18:00 3.50 EV AL P DECOMP PJSM. Pick up and rig up SWS e-line tools. Log in and out with CBL to 2079', Clean and laydown tools. Top of quality cement at 250'. 18:00 - 21 :00 3.00 DHB P DECOMP PJSM. Pick up Composite Bridge Plug and running tool. Make up running tool and single of DP. Make dry run through wellhead. Pull out and make up CBP. RIH to 970'. Up and down weight 40k. Circulate at 126 gpm to clean up set point. Set on depth at 970'. Rotate 25 turns to set. Pick up in 10k increments to 90k holding for 2 minutes each increment. Pull 100k and shear off. Rotate 35 more turns to right and set down 15k to confirm set. 21 :00 - 00:00 3.00 DHB N DFAL DECOMP Line up and test CBP to 2000 psi. Pump 22 strokes pressure held for 7 minutes then bled off 500 psi in 3 minutes. Double block surface equipment, still bleeding off. Bleed off completely and check sensator and lines to chart recorder, all good. Set back down with 25k, line up and retest. Took 47 strokes, (30 more than calculated), to pressure up. Held for 15 minutes, OK. Suspect CBP failure and communication to lower RBP at 3200' as indicated by strokes/volume pumped. Reconfirm depth of plug at 970'. Set 40k down and hold for 10 minutes. Line up and pressure up with 30 strokes, (13 strokes over calculated), to 2000 psi and hold for 10 minutes, OK. Pressure appears to still be communicating to lower plug. POOH and lay down tool. Will try 2nd CBP. 3/20/2007 00:00 - 01 :00 1.00 CASE N DFAL DECOMP PJSM. Bring cutter BHA up beaver slide. Clean and clear floor. 01 :00 - 02:00 1.00 CASE N DFAL DECOMP PJSM. Service and lube rig and top drive. 02:00 - 04:30 2.50 DHB N DFAL DECOMP PJSM. Pick up and make up CBP and RIH to 963'. Make up top drive. Break circulation at 126 gpm with 130 psi. Circulate until brine at 55 degrees. 04:30 - 05:00 0.50 DHB N DFAL DECOMP Set CBP at 963'. Set down 45k and verify set. Pull 1 stand back. 05:00 - 05:30 0.50 DHB N DFAL DECOMP Test CBP to 2000 psi for 15 minutes. Test OK. 05:30 - 06:00 0.50 CASE P DECOMP Blow down top drive. POOH and lay down CBP running tool. 06:00 - 07:30 1.50 CASE P DECOMP PJSM. Make up casing cutter BHA. RIH and engage knives at Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 31712007 Rig Release: 415/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/20/2007 06:00 - 07:30 1.50 CASE P DECOMP 0640' down from top of hanger. Pump at 300 psi. Slack off to verify no collar or obstructions. Install blower hose. 07:30 - 10:30 3.00 CASE P DECOMP PJSM. Bring up rotary to 30 rpm. Pump at 137 gpm with 198 psi. Torque at start of cut 1192. Increase rotary to 40. Cut casing 6.4' down from top of hanger with 240 gpm and 670 psi. Torque drop from 1600k to 1000k indicating cut. 10:30 - 11 :00 0.50 CASE P DECOMP POOH with cutter and lay down beaver slide. Clear floor. 11 :00 - 13:00 2.00 CASE P DECOMP Pick spear up beaver slide. Break down and re-dress for 13-3/8". Lay down on floor. 13:00 - 17:00 4.00 CASE P DECOMP PJSM. Remove upper bell nipple flange and install 20" flange. Back out lock down screws. Remove wellhead flange and stack bolts. Stand stack back. PJSM. Open cellar doors and remove both tubing and casing heads. Close cellar doors. Clean up and inspect 13-3/8" hanger neck. 17:00 - 18:30 1.50 FISH P DECOMP Make up spear, XO's and single of DP. Screw in and engage 13-3/8" casing. Pull and work 50k max overpull with no movement. 18:30 - 20:30 2.00 FISH P DECOMP Wrap wellhead and heat with steam. 20:30 - 00:00 3.50 FISH N DFAL DECOMP Pull and work with 100k max overpull. No movement. PJSM. Pick up and make up drilling jars and bumper sub on top of spear. Re-engage and jar/work with 100k overpull. Cool jars. Probe for cement through side bull plugs. Void to +/- 15'. Continue jarring/working with 100k over. No movement. Release spear. Break and lay down jars, bumper sub, single and spear. Fill casing with water while side bull plugs removed to verify cut. No communication between 13-3/8" x 20". Clear and clean cellar in preperation to nipple up 20" riser. 3/21/2007 00:00 - 01 :00 1.00 CASE N DFAL DECOMP PJSM. Inspect derrick and draworks after jarring. 01 :00 - 04:30 3.50 CASE N DFAL DECOMP PJSM. Bring 20" riser into cellar and NU. Rig up riser with valves and plugs. Rig up boot nipple and air up boots. Fill riser and test boots, valves and plugs for leaks. 04:30 - 07:30 3.00 CASE N DFAL DECOMP PJSM. Pick up cutter assembly. Make up XO, stabilizer and cutter. Dress tool with new knives. RIH and install blower hose. Make up top drive. Bring pump up to 150 psi, slack off and find old cut. Bring pump up to 220 gpm with 540 psi. Torque at 1.5 to 2k. Finish cut pumping at 345 gpm with 1350 psi and 4-6k torque. The 20" conductor started taking fluid verifing cut. 07:30 - 08:00 0.50 CASE P DECOMP PJSM. POOH with cutter and lay down. Blow down top drive and remove blower hose. 08:00 - 09:00 1.00 CASE P DECOMP PJSM. Nipple down 20" riser and stand back. 09:00 - 09:30 0.50 FISH P DECOMP PJSM. Make up spear assembly and RIH to no go and engage spear. Back out lock down screws. Pull 13-3/8" packoff and hanger. Back out joint and lay down. Install lifter. Remove 13-3/8" hanger from bowl. LD. 09:30 - 11 :00 1.50 CASE P DECOMP PJSM. Rig down tongs. Pick up Baker tongs and 16" wash pipe handling tools. Lay down cutter assembly. 11 :00 - 11 :30 0.50 CASE P DECOMP PJSM. Nipple up 20" riser and fill with fluid. The 20" conductor leaking in the cellar. Patch up crack in conductor. 11:30 -13:30 2.00 CASE P DECOMP Continue to pick up washpipe BHA up the beaver slide. PJSM. Run in and break down a stand of drill collars. Make up a 10' DP pup and XO to top of single drill collar. Lay down. Change elevators and rig up 16" handling equipment. Pick up 1 st joint of washpipe and make up shoe. Change out elevators. Pick up Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/5/2007 3/21/2007 11 :30 - 13:30 2.00 CASE P DECOMP and make up drill collars and drive sub. 13:30 - 18:00 4.50 CASE P DECOMP RIH and work over fish. Wash and ream down at 200 gpm with 25 rpm. All returns flowing directly into cellar box through vertical split in 20" conductor. Unable to keep up with cellar pump. Spot Vac-Truck and continue washing over to 75'. POOH and make connection. No pressure increase, torque or WOB to 90'. Possible cement from 90' to 97' with 3-4k torque at 25 rpm. WOB 2-3k. Pumping at 200 gpm with 50 psi. Pump sweep. 18:00 - 00:00 6.00 CASE P DECOMP POOH. Break and lay down drill collars. Blow down top drive. Change out elevators. Break and lay down drive sub assembly, washpipe and shoe. PJSM. Rig down Baker tongs. Clear floor of wash pipe equipment. Pick up backoff tools. PJSM. Pick up 2 drill collars from shed and run 2 stands of drill collars from derrick. PU and MU XO, blanking sub, bottom anchor and power section. Check torque on all service breaks. PU top anchor section and XO. PU single of DP. MU 1502 on pump in sub. RIH to 348'. Fill single and DC with diesel. 3/22/2007 00:00 - 02:30 2.50 FISH P DECOMP PJSM. Rig up test pump. Fill pipe with diesel. Set backoff tool top anchor at 65', bottom anchor at 91'. Pressure up and cycle elements. Start at 500 psi and cycle up increasing pressure to 5000 psi. Attempt several times. POOH to anchors and check for function. Function appears ok. Re-pin and RIH. Set top anchor at 60' and bottom anchor at 86'. Cycle several more times with no success. 02:30 - 08:30 6.00 FISH P DECOMP POOH. Break out backoff tools. Lay down tools and handling equipment. Pick up 13-318" casing cutter assembly. Change out cutter blades and circulating nozzles from 3/4" to 5/16". PJSM. PU joint of DP. Make up cutter assembly. Lay down. Pick up stand of DP and make up to cutter. 08:30 - 10:30 2.00 FISH P DECOMP RIH to 60' and open cutter. Slack off, locate collar at 72'. Slack off to 85' and verify collar clear. Pick up to 75'. Rotate at 63 rpm with torque at 1.5k. Stage pump up to 147 gpm with 1711 psi. Torque at 3-4k. Up weight 30k, down 32k. Cut 13-3/8" casing with 174 gpm at 2300 psi. Torque 4-5k at 65 rpm. Lost all torque and weight verifing cut. Shut down and blow down top drive. 10:30 - 11 :00 0.50 FISH P DECOMP PJSM. POOH and lay down cutter BHA. Clean and clear floor. Lay cutter assembly down beaver slide. Pick up spear assembly to rig floor. 11 :00 - 12:00 1.00 FISH P DECOMP PJSM. Make up spear. RIH and spear 13-3/8". Pull to rig floor. 12:00 - 16:00 4.00 CLEAN P DECOMP Pick up and rig up false bowl and handling equipment. Set fish in slips and break out single DP. Lay down spear and fish together. Clear floor. Pick up and swap out rig tongs. Pick up 16" wash pipe handling equipment and XO's. PSJM. Make up XO's, drive sub handling sub and dressoff shoe to joint of 16" washpipe. Change out handling equipment. Make up 2 singles ofDP. 16:00 - 17:00 1.00 CLEAN P DECOMP Washover and dress casing stump from 75' to 80'. Torque 2-4k at 70 rpm. WOB 1-2k. Pump at 100 gpm taking returns into cellar. 17:00 - 19:00 2.00 CLEAN P DECOMP POOH. Break down and lay down singles, dressoff shoe, drive head, XO's and washpipe. Swap out rig tongs. Clear floor of all Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 415/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/22/2007 17:00 - 19:00 2.00 CLEAN P DECOMP washpipe equipment. 19:00 - 22:00 3.00 CASE P DECOMP PJSM. Pick up 13-3/8" handling equipment, power tongs and XO's. PJSM. Rig up floor to run casing. Make up casing XO to 10' DP pup. Lay aside on floor. PJSM. Pick up casing patch and 10 casing pup and set in slips. Run 2 joints of 13-3/8" casing. Make up handling joint to 2nd joint on skate. Make up to top drive. Rotate over stump and move down to engage. Engage stump and bottom out at 78'. 22:00 - 00:00 2.00 CASE P DECOMP Attempt to test casing to 2000 psi. Try to fluid pack casing by pressuring up and bleeding. Fluid coming out of the 20" casing each time pressure is brought up. Pressure not holding. Attempt several times with no success. 3/23/2007 00:00 - 02:30 2.50 CASE P DECOMP PJSM. Continue testing on 13-3/8" casing patch. Pump 31 strokes to 2000 psi. Shut in surface equipment. Unsuccessful. Fluid leaking out 20" casing split. Fill top drive and pipe. Make up top drive. Attempt test again. Pump 27 strokes for 2000 psi. Lost 1000 psi in 2.5 minutes. Fluid still coming in cellar through 20" conductor casing. Bleed to 100 psi in 7.5 minutes. Bleed off. Break out top drive. Blow down topdrive. 02:30 - 03:30 1.00 CASE P DECOMP Clear and clean floor. 03:30 - 05:00 1.50 CASE P DECOMP PJSM. Nipple down 20" riser. Prep for WACHS cutter on 13-3/8" casing. Rig up cutting torch to drain stack. 05:00 - 07:00 2.00 CASE P DECOMP Rig service and lube. 07:00 - 12:30 5.50 WHSUR P DECOMP PJSM. Punch hole and drain 13-3/8" casing. Rig up Wach's cutter and cut casing above 20" starting head. Break and lay down cut joint and handling joint. Bolt riser to starter head. Rig up 20" Wach's cutter and cut conductor below starter head. PJSM. Remove head and riser from cellar. Center 13-3/8" casing in conductor and weld in gussets. 12:30 - 16:00 3.50 REMCM P DECOMP Spot SCH cement truck and super sucker for top job on 20" x 13-3/8" annulus. Rig up and run 70' of 1-1/4" pipe into hole. Pump 2 bbls of water and check lines. Follow with 17 bbls of 15.7 ppg Class G, Artic Set cement at 1 bpm until good cement at surface. Weigh sample to confirm 15.6 ppg. Rig down cementers. Clean up cellar and prep for cutting 13-3/8" casing. 16:00 - 23:00 7.00 WHSUR P DECOMP PJSM. Bring 13-3/8" McEvoy SOW head into cellar. Lay 13-3/8" tools down beaver slide. Spot trucks for welding new starter head. Cut 13-3/8" 10" above ground level. Ground and magnetize stump. PJSM. Install new head and tac weld. PJSM. Wrap well head in ceramic blanket and begin heating process to 500 degress as per inspector. Performing rig maintenance and cleaning. Strap and rabbit 55 joints of 9-5/8" casing. 23:00 - 00:00 1.00 WHSUR N HMAN DECOMP The heat on the 13-3/8" casing was increased beyond limits. Preheat temperature is 900 degrees and temperature was raised to 1300 degrees. Temperature probe was not on ceramics in area of high temperature. Working on alternate plans. Waiting on orders. 3/24/2007 00:00 - 05:00 5.00 WHSUR N HMAN DECOMP The heat on the 13-3/8" casing was increased beyond limits. Preheat temperature is 900 degrees and temperature was raised to 1300 degrees. Temperature probe was not on ceramics in area of high temperature. Working on alternate plans. Waiting on orders. 05:00 - 08:00 3.00 WHSUR N HMAN DECOMP Remove 13-318", McEvoy starting head. Clear and clean cellar. Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 Prep casing for FMC 13-3/8" slip on starter head. PJSM. Install FMC 13-318" slip on head and test seals to 800 psi for 10 minutes. Tested to 30% of collapse. Tested OK. 13:30 - 20:00 DECOMP PJSM. Bring new tubing spool into cellar and steam off. PJSM. Nipple up BOPE, tubing spool and secondary annulus valve. Install turnbuckles and mousehole. PJSM. Change out 20" riser nipple under rotary to drilling nipple for BOP's. Install riser. 20:00 - 21 :00 1.00 DECOMP PJSM. Make up TIW and dart valves to test joint. Make up test plug. Set test plug and fill stack to verify leaks. All good. 21 :00 - 00:00 3.00 DECOMP PJSM. Test BOPE to 3500 psi high, 250 psi low. Test annular to 2500 psi high, 250 psi low as per AOGCC. Test on valves 1,2,3 and 4,5,6 good. Test on valves 7,8,9 failed. Trouble shoot for leak. Attempt closing bottom rams against both HCR's and Dart, test failed again. Pull test plug. Grease choke valves. Trouble shoot leak again. Test not comleted at change out. Test wittnessed by Chuck Scheve with AOGCC. 3/25/2007 00:00 - 07:30 7.50 BOPSU P DECOMP PJSM. Continue testing BOPE to 250 psi low, 3500 psi high. Test annular to 250 psi low, 2500 psi high as per AOGCC. Troubleshoot and retest 7,8 and 9 successfuly. Test 12,13 and 14 failed. Re-work valves and manifold, test again, OK. Test wittnessed by Chuck Sheve with AOGCC. 07:30 - 08:30 1.00 BOPSU DECOMP PJSM. Rig down BOPE testing equipment. PJSM. Install wear ring. 08:30 - 11 :30 3.00 CASE P DECOMP PJSM. Pick up reverse basket assembly. Make up and RIH. Tagged casing patch at 75'. Set down 5k. Would not go through. POOH and lay down reverse basket BHA. 11 :30 - 14:00 2.50 CASE P DECOMP PJSM. Pick up and make up string milling assembly. 14:00 - 15:30 1.50 CASE P DECOMP PJSM. Make up top drive to milling assembly. Up weight 34, down 35k. Torque at 1k. Pumping at 250 gpm with 90 psi. Work through patch from 65' to 110'. No signs of obstruction. Break out topdrive and blow down. POOH. Lay down XO, shoe and mill. 15:30 - 16:30 1.00 CASE P DECOMP PJSM. Pick up and make up RCJB, BHA to 315'. Tagged up at 75', rotate off. Change out handling equipment. 16:30 - 17:30 1.00 CASE P DECOMP PJSM. RIH to 877'. Up and down weight 55k. Circulate at 250 gpm with 270 psi. Circulate air out of system. 17:30 - 18:30 1.00 CASE P DECOMP PJSM. Rig up and test casing to 2000 psi for 30 minutes. Test failed. Bleed down to 500 psi in 20 minutes. Pump back up to 2000 psi. Still bleeding down. Bleed off pressure. Break out top drive and PU stand. 18:30 - 19:30 1.00 CASE P DECOMP RIH to 950'. Drop ball, make up topdrive. Establish circulation at 250 gpm with 275 psi. Up weight 58k, down 60k, RT 60k. Slack off and tag top plug at 962'. Pick up and bring pump up to 446 gpm with 793 psi. RPM at 60. Slack off and wash on plug with 5K WOB. Torque at 1-2k. Shut down. 19:30 - 20:30 1.00 CASE P DECOMP PJSM. Break out topdrive and blowdown. POOH to 315'. 20:30 - 22:00 1.50 CASE P DECOMP PJSM. Rack back collars. Lay down reverse baskets and check boot baskets - no junk. Recover ball. Lay down tools. 22:00 - 23:30 1.50 CASE P DECOMP PJSM. Pick up and make up 12-1/4" bit. RIH to 307'. Change out handling equipment. 23:30 - 00:00 0.50 CASE P DECOMP PJSM. RIH to top of plug at 962'. Up weight 58k, down 60k, RT 60k.Torque off bottom 1-2k, on bottom 1-3k at 60 rpm. Tag plug and begin drilling out with 5k WOB. Printed: 4/9/2007 11 :13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 31712007 415/2007 Spud Date: 3/14/1977 End: 4/5/2007 3/26/2007 00:00 - 07:00 7.00 CLEAN P DECOMP Drill CBP's to 966'. Pump at 30 gpm to 420 gpm. WOB 5k to 25k. Torque 1.5k to 3.5k at 50 to 60 rpm. Up weight 58k, down 60k, RT 60k. Vary pump rate, rpm and WOB as needed to drill out plugs. Pump hi-vis sweeps as needed to clean hole. Circulate until hole clean. 07:00 - 09:30 2.50 CLEAN P DECOMP PJSM. RIH to 2077'. Drill up rest of CBP's to 2079'. Up weight 70k, down 80k, RT 75k. Torque 1 k off bottom, 1-2k on bottom at 70 rpm. Pump at 455 gpm with 420 psi. WOB 5-7k. Pump hi-vis sweep around. Monitor well. Rack a stand back. Blow down top drive. 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. Slip and cut 77' of drill line. 10:30 - 11 :30 1.00 CLEAN P DECOMP PJSM. POOH to 307'. 11 :30 - 13:30 2.00 CLEAN P DECOMP PJSM. POOH with drill out assembly. Lay down boot baskets and bit. 13:30 - 17:30 4.00 CLEAN P DECOMP PJSM. Pick up washpipe and break out drive sub and install mill. Make up drive sub and BHA to 341'. Change out handling equipment. 17:30 - 18:30 1.00 CLEAN P DECOMP PJSM. RIH with 11-3/4" washpipe to top of stump at 2079'. Fill pipe. 18:30 - 00:00 5.50 CLEAN P DECOMP Make up top drive. Circulate at 200 gpm with 124 psi. Up, down and RT weight 80k. Torque off bottom 1-2k, on bottom 3-5k at 60 rpm. Tagged junk at 2076'. Washed down to 2079'. Bring rate up to 497 gpm with 660 psi. Pump sweep surface to surface. Continue washing with pumps at 336 gpm with 340 psi. Work over stump and continue washing down with inner mill on 9-5/8" casing stump. Back off pump again to 84 gpm with 50 psi. Work down to no go at 2108' several times with torque at 4k-7k. No apparent obstructions. Bring pump up to 164 gpm with 130 psi and work mill in and out of stump as per Baker rep. 3/27/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Pump hi-vis sweep and circulate until clean. 01 :30 - 02:30 1.00 CLEAN P DECOMP PJSM. POOH to 43'. 02:30 - 05:30 3.00 CLEAN P DECOMP PJSM. Break out and lay down washpipe, mill and assembly. Small amount of rubber recovered in boot baskets. 05:30 - 06:00 0.50 CLEAN P DECOMP PJSM. PU 8-1/2" cleanout assembly. 06:00 - 07:00 1.00 CLEAN P DECOMP PJSM. Make up BHA #13 to 310'. 07:00 - 08:30 1.50 CLEAN P DECOMP PJSM. Run in hole from 310' to 2085',tag junk,pump and rotate to 2176',70 RPM,torque off 1k on 2k. 260 GPM @ 140 psi. 08:30 - 09:30 1.00 CLEAN P DECOMP Run in hole from 2176' to 3140' pushing junk ahead of BHA with 5-10k drag. Tag top of sand at 3140' 09:30 - 10:30 1.00 CLEAN P DECOMP Circulate Hi-Vis sweep around, pump unitl hole is clean,480 GPM @ 580 psi. 10:30 - 11 :00 0.50 CLEAN P DECOMP PJSM. POOH from 3140' to 2079'. 11 :00 - 11 :30 0.50 CLEAN P DECOMP Circulate bottoms up at 9 5/8" casing stub at 2079'. Rotate back into 9 5/8" casing stub,500 GPM @ 460 psi. Blow down top drive. 11 :30 - 12:00 0.50 CLEAN P DECOMP PJSM. POOH from 2079' to 310'. 12:00 - 15:00 3.00 CLEAN P DECOMP PJSM. Change out handling equipment and rack back drill collars. Break bit and boot baskets, baskets contained some peices of composite plug. Lay down BHA components down beaver slide,pick up new BHA from slide. 15:00 - 17:30 2.50 FISH P DECOMP PJSM. Make up back-off tool assembly to 326',change out Printed: 4/9/2007 11: 13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/27/2007 15:00 - 17:30 2.50 FISH P DECOMP handling equipment. 17:30 - 19:00 1.50 FISH P DECOMP Run in hole filling drill pipe with fresh water, from 326' to 2405'. Make up head pin and test pump line. 19:00 - 21 :30 2.50 FISH P DECOMP Pick up to 2406' and pressure up to 500 psi to set bottom anchor. Not set so increase pressure to 1000 psi then 1200 psi before anchor sets. Slack off 20k on bottom anchor and bleed off pressure. Wait 5 minutes and pressure up to 4500 psi to set top anchor. Slack off 15k on tool then set slips. Wait 10 minutes then pressure up to 2500 psi to break casing joint. Repeat until casing backed out 6 1/2 turns. Bleed down pressure and rig down test pump, and clear floor. Drop circulating sub dart and make up top drive. Shear out pump out sub at 1500 psi and pump 58 bbls brine. Break out and blow down top drive. 21 :30 - 22:30 1.00 FISH P DECOMP PJSM. POOH from 2406' to 326',change out handling equipment. 22:30 - 00:00 1.50 FISH P DECOMP PJSM. Break out and lay down back off tool,rack back collars, and clear floor. 3/28/2007 00:00 - 01 :00 1.00 FISH P DECOMP PJSM. Lay down back off tools down beaver slide. 01 :00 - 02:30 1.50 FISH P DECOMP PJSM. Make up 9 518" casing spear assembly to 52'. 02:30 - 03:00 0.50 FISH P DECOMP PJSM. Run in hole from 52' to 2079'. 03:00 - 03:30 0.50 FISH P DECOMP Spear 9 5/8" casing and back off 7 turns to left,stump pulls free. 03:30 - 04:30 1.00 FISH P DECOMP POOH with fish from 2079' to 52'. 04:30 - 05:00 0.50 FISH P DECOMP PJSM. Lay down 95/8" spear assembly and casing cut joint, 18.8'. 05:00 - 05:30 0.50 CASE P DECOMP Clear and clean floor 05:30 - 06:00 0.50 CASE P DECOMP PJSM. Pull wear ring 06:00 - 07:30 1 .50 CASE P DECOMP PJSM. Bring casing tools and long bales to floor. 07:30 - 08:30 1.00 CASE P DECOMP PJSM. Change out bales and rig up casing tools. 08:30 - 19:00 10.50 CASE P DECOMP PJSM. Run 9 5/8" 40# TC-11 casing,average torque 12,600 ftllbs. Fill casing on fly topping off every 5 joints. Galled threads on joint # 8 & 9,laid down and replaced with # 52 & 55. Galled threads on pin end #31 ,replaced with joint #53. Joints 38 & 40 required backing out and cleaning connection with emery cloth before getting proper make up. Complete running 51 joints and make up crossover pup and top drive cross over. Test casing to 2000 psi. for 5 minutes,good test. Screw into 9 5/8" casing with triple connection sub working down 11,000 ftllbs of torque. Pick up to 250k and test casing to 2000 psi for 15 minutes,good test. Break out top drive and blow down. 19:00 - 21 :00 2.00 CEMT P DECOMP PJSM. Rig up cement head, and open ES cementer with 2900 psi. Circulate soap pill surface to surface. PJSM with all crew,cementers and vac truck drivers. 21 :00 - 23:00 2.00 CEMT P DECOMP PJSM. Pump 5 bbls water and test lines to 4000 psi. Pump 33 bbls. 12 ppg mud push with 1 gallon of red dye. Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 415/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/28/2007 21 :00 - 23:00 2.00 CEMT P DECOMP Pump 145 bbls. 15.8 ppg., Class G,cement with Gas Blok. Drop ES cemeter closing plug and displace with 153 bbls 9.8 brine. Bump plug with 1500 psi and close cementer with 2000 psi. Bleed off and check plug,good. Cement in place at 22:45, 25 bbls. good cement to surface. 23:00 - 00:00 1.00 BOPSU P DECOMP Rig down cement head and clear floor. Prepare to nipple down BOP. 3/29/2007 00:00 - 01 :00 1.00 BOPSU P DECOMP PJSM. Drain 9 5/8" casing with Vac truck. Nipple down BOP. 01 :00 - 04:00 3.00 BOPSU P DECOMP PJSM. Pull 60k over sting wt to set slips. Cut 9 5/8" casing and install pack-off. 04:00 - 05:30 1.50 BOPSU SFAL DECOMP Pack-off difficult to set, inner seals rolled,pulled installed oversize seals. 05:30 - 06:00 0.50 BOPSU P DECOMP Install pack-off. 06:00 - 07:00 1.00 BOPSU P DECOMP PJSM. Nipple up BOP. 07:00 - 08:00 1.00 BOPSU P DECOMP PJSM. Test Pack off to 2500 psi for 30 minutes, good test. 08:00 - 08:30 0.50 BOPSU P DECOMP PJSM. Install riser & secure BOP in place. 08:30 - 09:00 0.50 BOPSU P DECOMP Install wear ring. 09:00 - 09:30 0.50 CLEAN P DECOMP PJSM. Pick up BHA components to drill floor. 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. Make up 81/2" clean out assembly to 312'. 10:30 - 11 :30 1.00 CLEAN P DECOMP PJSM. Run in hole from 312' to top of cement at 2057',install blower hose. 11 :30 - 12:00 0.50 CLEAN P DECOMP Drill cement from 2057' to 2085'. Up wt. 75k, down wt. 80k,rotating wt. 75k. Rotating RPM 75,torque off bottom 1k and on bottom 1-2k. 400 GPM at 390 psi. 12:00 - 13:30 1.50 CLEAN P DECOMP Drill ES cementer, pump sweep surface to surface,485 GPM@ 492 psi. Good results from sweep, metal and cememt to surface. Blow down top drive. 13:30 - 14:30 1.00 CLEAN P DECOMP PJSM. Run in hole from 2100' to 3100' and tag junk/composite plug at 3104'. Circulate at 228 GPM @ 185 psi. 14:30 - 16:00 1.50 CLEAN P DECOMP PJSM. Test 9 5/8" casing to 3500 psi,hold and chart for 30 minutes. Blow down surface equipment. 16:00 - 17:00 1.00 CLEAN P DECOMP PJSM. POOH from 3100' to BHA at 312'.Change out handling equipment. 17:00 - 18:30 1.50 CLEAN P DECOMP PJSM. Rack back collars,break out bit and junk baskets. Baskets had parts of cementer, and composite plug. Three brass sheer bolts from plug recovered.Clean and clear floor 18:30 - 19:30 1.00 CLEAN P DECOMP PJSM. Make up reverse circulating basket assembly to 320'.Change out handling equipment. 19:30 - 20:30 1.00 CLEAN P DECOMP PJSM. Run in hole to 3116',install blower hose. Make up top drive and establish circulation at 309 GPM,2537 psi 20:30 - 22:30 2.00 CLEAN P DECOMP PJSM. Wash down and tag up at 3138'. Wash down to 3151 '(length of basket). Pump sweep,surface to surface,sand and metal in returns. Break out and blow down top drive. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH from 3151' to 1067'. 3/30/2007 00:00 - 00:30 0.50 CLEAN P DECOMP PJSM. POOH from 1067' to BHA at 320'. Printed: 4/912007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/30/2007 00:30 - 02:00 1.50 CLEAN P DECOMP PJSM. Handle BHA, break out and clean reverse & boot baskets. Recovered composite plug,metal, and cement. Clean and clear floor. 02:00 - 03:00 1.00 CLEAN P DECaMP PJSM. Make up reverse circulating basket and boot baskets. Run in collars to 320',change handling equipment. 03:00 - 04:00 1.00 CLEAN P DECOMP PJSM. Run in hole from 320' to 3551', tag up. 04:00 - 05:30 1.50 CLEAN P DECOMP Break circulation and wash down from 3551' to 3578',306 GPM @ 2450 psi.Pump sweep surface to surface 05:30 - 06:30 1.00 CLEAN P DECOMP PJSM. POOH to BHA at 320' 06:30 - 07:30 1.00 CLEAN P DECOMP PJSM.Handle BHA ,break and clean reverse and boot baskets. Parts of bow springs and upper plugs recovered. 07:30 - 08:00 0.50 CLEAN P DECOMP Make up reverse and boot basket assembly to 320'. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. Run in hole from 320' to 3178'. Make up top drive and break circulation, 220 GPM @ 1508 psi. Wash sand from 3178' to 3193'. 09:00 - 10:00 1.00 CLEAN P DECaMP Increase circulating rate to 318 GPM @ 2037 psi, pump sweep surface to surface. Break out and blow down top drive. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. POOH from 3193' to BHA at 320',change out handling equipment. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM. Rack back drill collars and break and clean reverse & boot baskets. Clear floor of tools. 13:30 - 14:00 0.50 CLEAN P DECaMP PJSM. Change out handling tools and make up Halliburton retrieval tool. 14:00 - 15:00 1.00 CLEAN P DECOMP PJSM. Run in hole from 40' to 3115'. 15:00 - 15:30 0.50 CLEAN P DECOMP PJSM. Break circulation,wash from 3115' to 3193',latch into RBP at 3193'. 15:30 - 16:00 0.50 CLEAN P DECOMP Displace well to seawater, pump 40 bbl Hi-Vis sweep followed by seawater. 16:00 - 16:30 0.50 CLEAN P DECOMP Pull RPB free,set 15k down and 1/4 turn right,pull 20k over,set 15k down,turn 1/4 turn right.Pull23k over RPB released. Monitor well, blow down top drive. 16:30 - 17:30 1.00 CLEAN P DECOMP PJSM. POOH from 3193' to 40'. 17:30 - 18:00 0.50 CLEAN P DECOMP Lay down RPB and retrieval tool. 18:00 - 18:30 0.50 CLEAN P DECOMP Clean and clear rig floor. 18:30 - 19:30 1.00 CLEAN P DECOMP PJSM. Pick up 9 5/8" casing scraper assembly to 316'. 19:30 - 21 :30 2.00 CLEAN P DECOMP PJSM. Run in hole from 316' to liner top at 4383'. 21 :30 - 22:30 1.00 CLEAN P DECOMP Break circulation and pump sweep surface to surface. Approximately 30 bbls of seawater was discolored black when back to surface. 500 GPM @ 1120 psi. 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM. POOH from 4383' to 316' 3/31/2007 00:00 - 02:00 2.00 CLEAN P DECOMP PJSM. Break down BHA components and clear from floor. 02:00 - 03:30 1.50 CLEAN P DECaMP PJSM. Bring BHA components for polishing 4 1/2" stump to floor 03:30 - 05:00 1.50 CLEAN P DECOMP PJSM. Make up BHA and pick up 9 drill collars from pipe shed. 05:00 - 06:30 1.50 CLEAN P DECOMP Run in hole with 4 1/2" stump polishing assembly from 326' to 4429'. 06:30 - 12:00 5.50 CLEAN P DECOMP Run in hole, picking up drill pipe from pipe shed from 4429' to 10,903'. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM. Wash and ream from 10,903' to 10,941'. Tag tubing top @ 10,931',dress 2-3 inches of tubing top. Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/512007 3/31/2007 12:00 - 13:00 1.00 CLEAN P DECOMP up wt. 155k,down wt. 140k,rotating wt. 160k. 40 RPM,torque off bottom 5k and on bottom 6-7k. 195 GPM @ 530 psi. 13:00 - 14:30 1.50 CLEAN P DECOMP Circulate 35 bbl. Hi-Vis sweep around surface to surface,circulate till clean. 410 GPM 2275 psi. Monitor well. 14:30 - 18:30 4.00 CLEAN P DECOMP PJSM. POOH from 10,941' to 325'. 18:30 - 20:00 1.50 CLEAN P DECOMP PJSM. Rack back collars, and lay down wash pipe. Tubing cut off(22.83') tubing pup joint (9.87') and K anchor (.85')pulled out of hole. Top of packer in hole 10,964'. 20:00 - 21 :00 1.00 CLEAN P DECOMP PJSM. Clear floor of baker tools. 21 :00 - 21 :30 0.50 CLEAN P DECOMP PJSM. Pull wear ring. 21 :30 - 22:00 0.50 CLEAN P DECOMP PJSM. Rig up to test BOPE,fill choke and BOP. 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM. Test BOPE and related valves to 250 psi low and 3500 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Lou Grimaldi,test witnessed by BP rep Blair Neufeld (WSL) and Nabors drilling rep John Castle. 4/1/2007 00:00 - 08:00 8.00 CLEAN P DECOMP PJSM. Test BOPE and related valves to 250 psi low and 3500 psi high.Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Lou Grimaldi,test witnessed by BP rep Blair Neufeld (WSL) and Nabors drilling rep John Castle. Pull test plug,clear floor. Problems testing series #2 and #3 of the choke manifold due to improper greasing of the packing. Greased properly then tested OK. Changed bad fitting on pressure sensor oil line for chart (mechanical failure). 08:00 - 09:30 1.50 PULL P DECOMP Make up burn shoe BHA to mill over production packer, run in hole to 312',change out handling equipment. 09:30 - 13:30 4.00 PULL P DECOMP PJSM. Run in hole from 312' to 10,952' 13:30 - 14:30 1.00 PULL P DECOMP PJSM. Cut and slip drilling line. 14:30 - 15:00 0.50 PULL P DECOMP Service top drive. 15:00 - 20:30 5.50 PULL P DECOMP Mill packer at 10,963'. Up wt. 200k,down wt. 135k,rotating wt. 160k. 250 GPM at 830 psi,75 RPM with 7k torque off bottom and 11-12k on bottom. Hole started taking fluid,pumped 500 GPM with no returns. 20:30 - 21 :00 0.50 PULL P DECOMP Push packer and tailpipe down hole to 11,143'. Blow down top drive,remove blower hose. 21 :00 - 00:00 3.00 PULL P DECOMP PJSM. POOH from 11,143' to 4323',filling hole with double pipe displacement, no returns. Total losses 781 bbls. seawater 4/2/2007 00:00 - 01 :30 1.50 PULL P DECOMP POOH from 4323' to BHA at 312'. Filling hole with double displacement. 01 :30 - 02:00 0.50 PULL P DECOMP Break out boot baskets and packer mill. Boot baskets had 2-3 gallons of metal in them. 02:00 - 02:30 0.50 PULL P DECOMP Make up spear and run in drill collars from derrick. 02:30 - 05:30 3.00 PULL P DECOMP Run in hole with packer spear. 05:30 - 06:00 0.50 PULL P DECOMP Circulate at 4 BPM, 125 psi. Enter fish with spear pressure increases to 300 psi. Shut down pump and run spear down to Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 4/5/2007 Rig Number: Spud Date: 3/14/1977 End: 4/5/2007 4/2/2007 05:30 - 06:00 0.50 PULL P DECOMP 11,146' ,set down 30k. Pick up with 10k overpull,dragging at times to 60k. 06:00 - 11 :00 5.00 PULL P DECOMP POOH from 11,148' to 312',filling hole with 120 BPH. 11 :00 - 12:00 1.00 PULL P DECOMP Rack back drill collars and break out spear and tailpipe. Clear Floor. 12:00 - 12:30 0.50 CLEAN P DECOMP PJSM. Clean floor and pick up tools to drill floor. 12:30 - 13:30 1.00 CLEAN P DECOMP PJSM. Make up 7 5/8" casing scraper BHA to 310'. 13:30 - 17:00 3.50 CLEAN P DECOMP Run in hole from 310' to 11,167'. 17:00 - 17:30 0.50 CLEAN P DECOMP Wash down from 11,167' to 11,189'. 17:30 - 00:00 6.50 CLEAN P DECOMP POOH from 11,189' to 3106' ,laying down drill pipe,filling hole with 120 BPH. 4/3/2007 00:00 - 02:30 2.50 CLEAN P DECOMP POOH from 3106' to 310' laying down drill pipe,filling hole with 120 BPH seawater. 02:30 - 03:30 1.00 CLEAN P DECOMP Lay down collars and BHA components. Clear floor of tools. 03:30 - 04:30 1.00 RUNCO RUNCMP Pull wear ring,install long bales. 04:30 - 06:30 2.00 RUNCO RUNCMP Rig up to run 4 1/2 x 5 1/2" completion. Rig up tongs and compensator. 06:30 - 07:30 1.00 RUNCMP Pre-Job safety meeting with all personnel. Make up packer and tailpipe assembly. 07:30 - 17:30 10.00 RUNCMP Make up and run 4 1/2", 12.6#,13Cr80,Vam Top completion. Optimum torque = 4440 ftllbs. Continue filling hole at 120 BHP. 17:30 - 18:30 1.00 RUNCMP PJSM. Change out handling equipment to 5 1/2" and make up 4 1/2" to 5 1/2" crossover. 18:30 - 22:30 4.00 RUNCMP Make up and run 5 1/2",17#, 13Cr-80,Vam Top tubing. Optimum torque 6580 ftllbs. Continue filling hole at 120 BPH. 22:30 - 23:30 1.00 RUNCO RUNCMP PJSM. Change out power tongs. 23:30 - 00:00 0.50 RUNCO RUNCMP Make up and run 5 1/2",17#, 13Cr-80,Vam Top tubing to 9315' Optimum torque 6580 ftllbs. Continue filling hole at 120 BPH. 4/4/2007 00:00 - 03:00 RUNCMP Make up and run 5 1/2",17#,13Cr-80,Vam Top tubing to 11,023' Up wt. 175k,down wt. 118k Optimum torque 6580 ftllbs. Continue filling hole at 120 BPH. Rig down compensator,change out elevators. 03:00 - 04:00 1.00 RUNCMP Make up landing joint and land hanger in tubing spool. Run in lock down screws. 04:00 - 06:00 RUNCMP Rig to and pump 250 bbls inhibited seawater followed by 116 bbls. clean seawater down annulus at 3 BPM @50 psi. Drop ball and rod after inhibited seawater is in the hole. 06:00 - 09:00 RUNCMP Test tubing to 3500 psi hold for 30 minutes and chart. Bleed tubing to 1500 psi and test annulus to 3500 psi, hold for 30 minutes and chart. Bleed off annulus then tubing, pressure up annulus and shear DCR valve at 2000 psi and confirm circulation. 09:00 - 10:00 1.00 BOPSU RUNCMP Dry rod TWC and test from below to 1000 psi. good test. Blow down surface lines. 10:00 - 11 :00 1.00 BOPSU RUNCMP Change out long bales. 11 :00 - 12:30 1.50 BOPSU RUNCMP Nipple down BOP, noticed TWC leaking out through mud cross during nipple down. 12:30 - 14:30 2.00 BOPSU SFAL RUNCMP Nipple up BOP and re-test TWC from below to 1200 psi to Printed: 4/9/2007 11:13:02 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-11 09-11 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2007 Rig Release: 415/2007 Rig Number: Spud Date: 3/14/1977 End: 4/5/2007 re-seat poppet, good test. Nipple down BOP. PJSM. Nipple up tree and adaptor. Minor fluid leakage noted past TWC. 18:00 - 00:00 6.00 WHSUR N SFAL RUNCMP PJSM. Attempt to test tree to 5000 psi from above,leaking. Pull TWC and re-seat,attempt to test from above to 5000 psi.,leaking. Pull TWC and install new TWC,attempt to test from above to 5000 psi.,leaking. Test to 1000 psi from below, starts leaking then holds for good test. Attempt to test from above to 5000 psi., leaking. Pull TWC and rebuild. 4/5/2007 00:00 - 01 :00 1.00 WHSUR N SFAL RUNCMP Rebuild TWC and dry rod same. Fill tree. 01 :00 - 03:30 2.50 WHSUR N SFAL RUNCMP Test tree to 5000 psi,no good. Several attempts made. Test TWC from below to 1000 psi,good test. Test TWC from above to 5000 pSi,no good. Rig down test hose. 03:30 - 04:30 1.00 WHSUR P RUNCMP Pull TWC with DSM lubricator, rig down DSM. 04:30 - 06:30 2.00 WHSUR P RUNCMP PJSM. Rig up circulating lines to Little Red Hot Oil Services to pump freeze protect. Pressure test lines to 3500 psi. and reverse circulate in freeze protect at 150 BPM at 700 psi. 06:30 - 07:30 1.00 WHSUR P RUNCMP U-Tube annulus to tubing. 07:30 - 08:00 0.50 WHSUR P RUNCMP Verify well dead,suck back circulating line to hot oil truck. Rig down circulating lines and move truck. 08:00 - 11 :00 3.00 WHSUR N SFAL RUNCMP Spot and rig up slickline unit. Make up XX plug and running tool. 11 :00 - 12:00 1.00 WHSUR N SFAL RUNCMP Run in hole with XX plug to XN nipple at 2203' and set. 12:00 - 12:30 0.50 WHSUR N SFAL RUNCMP Rig down slick line unit. 12:30 - 13:00 0.50 WHSUR P RUNCMP PJSM. Rig up to test tree. 13:00 - 15:00 2.00 WHSUR P RUNCMP Test tree and tubing to 2203' to 5000 psi. 300 psi loss over 30 minutes. Test to 3500 psi, 100 psi loss over 30 minutes. 15:00 - 15:30 0.50 WHSUR P RUNCMP Clear floor of slick line lubricator and BOPE tools. 15:30 - 16:30 1.00 WHSUR P RUNCMP PJSM. Rig up hot oil truck to test XX plug from below. Test XX plug to 1200 psi from below,good test. 16:30 - 17:00 0.50 WHSUR P RUNCMP Rig down annulus circulating lines to hot oil truck. 17:00 - 18:00 1.00 WHSUR P RUNCMP PJSM. Clean up cellar and secure well. Rig release 18:00 04/05/2007. Printed: 4/9/2007 11:13:02 AM f Schlumberger fR'" E"C'" E'··ß'ß\/I''''''''' "._-,," ,~ "- A" j~i~ M~ >\,. ~"'I \", ,r ".,_.-1 J '\.; .:'~ 04/16/07 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503·2838 ATTN: Beth APR 2 0 Z007 NO 4214 Oil ~~ Gas COilS. GQmm!~ Ançh~ Company: State of Alaska Alaska Oil & Gas Cons IComm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# Loa Description Date BL Color D DS 04-01 11637323 SCMT 03/13/07 1 2-34/P-14 11638622 USIT 03/20/07 1 N-22B , 11594483 SCMT 03/06/07 1 N-22B N/A USIT (CORROSION) 02/13/07 1 N-22B N/A USIT (CEMENT BOND) 02/13/07 1 P2-S0B 11626472 SCMT 03/17/07 1 09-11 . 11638619 USIT (CEMENT EVALUATION) 03/16/07 1 09-11 . 11638619 USIT (CORROSION) 03/16/07 1 09-11 . 11638621 CEMENT BOND LOG 03/19/07 1 L2-32 11221617 RST 10/13/06 1 1 A-24 11221856 RST 03/23/06 1 1 {'1- & -C·~'5¿1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 SCANNED APR 2 5 2007 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Field: Prudhoe Bay C . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: ? bp . . o BP Exploration IAlaskallnc, 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 19071561-5111 April 13, 2007 Via Hand Delivery Mr. John Norman Chairman , IGJ!"'ta.NNED APR 1 7 Z007 ALASKA OIL AND G~NSERVATION COMMISSION 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 \'lCo -'C)~~ RE: Alaska Oil & Gas Conservation Commission ("AOGCC") letter dated April 3. 2007 Dear Commissioner Norman, BP Exploration (Alaska) Inc. ("BPXA") is in receipt of your letter of April 3, 2007 regarding blowout prevention equipment ("BOPE") on Nabors Alaska Inc. ("Nabors") Rig 2ES (the "Rig"), in which you requested an explanation of how the event happened, confirmation that all other BPXA-operated rigs in Alaska comply with BOPE requirements, and that the rig be made available for Commission inspection to verify installation of proper kill line equipment. The incident arose as a result of damage to the original kill line when the Rig was moved to Prudhoe Bay Unit Well 09-11. When the Nabors tool pusher observed the damaged kill line, he ordered a new kill line, and a temporary replacement kill line was installed using pressure rated chicksan pipe and hammer union connections. The Nabors toolpusher did not inform BPXA representatives, or the AOGCC, of the temporary kill line. The BOPE was pressure tested on March 15, and the opportunity to witness this test was waived by the AOGCC. Subsequently, when BPXA company personnel observed the temporary kill line, because the initial BOPE pressure test had been completed, he erroneously assumed that the AOGCC had been notified of the issue. On March 24, 2007, when witnessing the BOPE test, an AOGCC Inspector observed the temporary kill line. The AOGCC inspector noted the use of the temporary kill line in his BOPE Test Report. By April 1 ,2007, the new kill line had been received, installed, and the BOPE had been successfully tested (See BPXA Daily Operations Report #22, attached). BPXA has confirmed that all rigs in its operations comply with AOGCC BOPE requirements. There is no confusion regarding the AOGCC well control equipment requirements. Nevertheless, this incident has identified a gap in our operating procedures related to management of change and communications between onsite personnel and the AOGCC. I want to assure you that we consider this issue quite seriously, and we have taken actions to prevention future occurrences. Actions in response to this issue include: Mr. John K. Norman,lirman AOGCC April 13, 2007 Page 2 . · BPXA review of kill line compliance necessary to make the confirmatory statement above; · Nabors' memorandum emphasizing the requirement to comply with AOGCC regulations and to communicate with AOGCC field inspectors when temporary equipment changes are anticipated (See attached); · review of this incident with all Well Site Leaders ("WSLs") on shift at the time of the incident; · scheduled discussions with off-duty WSLs to ensure that all WSLs are aware of the issues raised by this incident; · a communication to all ADW personnel emphasizing the importance of following AOGCC regulations; and · review of management of change process to improve its robustness and quality. We also wish to note that at all times when the temporary kill line was in place, the well was secured with a pressure tested barrier and with kill weight fluid in the hole. The new kill line was installed and pressure tested before the barrier in place was broken to commence the next phase of operations. The Rig is, and will remain, available for Commission inspection to verify the installation of proper kill line equipment. We regret that this incident occurred, and we hope that this letter satisfies your requests. Sincerely, Gary Christman BPXA Wells Director CC ADW Management Team H. Engel S. Stash fIþ . . Nabors AJaska Drilling, Inc. A/ways /ookingfor better ways to provide safe, environmentally sound. (~ost-efficient service to our customers. MEMORANDUM TO: All Nabors Alaska Toolpushersffourpushers FROM: RE: DATE: Dan Hebert, Nabors Deming Superintendent :?):::H- State OJ] and Gas Conservation Commission Regulations April 2, 2007 Recently, a Slate regulation was violated on Nabors Rig 2~ES when they replaced the KìJ1 line hose after damage to the hose body was identified by the rig crew. With no approved replacement on location, the damaged hose was replaced with one utilizing a welded 1502 hose connection. AOGCC policy requires aU Kill and Choke lines to be assembled without the use of hammer unions. This temporary solution cJearly does not meet the AOGCC policy requirements and should not have been installed without prior approved dispensation by the State's field inspector. Do not install hammer unions in any part of the choke or kill lines. Only after contacting your superintendent, a Nabors engineer and then receiving an approved opemtor and agency dispensation will this even be considered. Operator: BP EXPLORATION Well: 09-11 Field: PRUDHOE BAY Depth MD: Est. TVD: Progress: Auth Depth: Hole Size: DOUDFSfTarget: 18.40/18.90/ Geologist: Engineer: Supervisor: (It) (It) (It) (ft) Joshua Sudderth Decker/Neufeld cUrrent'status: 24hr Summary: 24hr Forecast: Comments: BP EXPLORATION Daily Operations Report Rig: NABORS 2ES Event: WORKOVER Well Type: DEVELOPMENT Current Well Status Casing Size: 13.375 (in) Costs in: USD Casing (MD): 49.5 (ft) Daily Mud: 2,422 Next casing Size: 9.625 (in) Cum. Mud: 80,856 Next Casing (MD): 2,099.0 (ft) Daily Well: 72,832 Next Casing (TVD):2,098.7 (ft) Cum. Well: 2,155,725 Page 1 of 3 Report: 22 Date: 3/31/2007 Rig Accept: 3/13/2007 Rig Release: Spud Date: 3/14/1977 WX Date: Elev Ref: MEAN SEA LEVEL Program: Weather: KB Elev: (ft) Tot. Personnel: 31 Cost Ahead: 0 USD, Days Ahead: 0.00 . T.el11P ! Wind ! ~.mp~~. 2~~cif3g, YesiíñgSOPE'S Clean out to 41/2" stump. Pull K anchor out of hole. Test BOP. Complete BOP test.MiII up and retrieve packer. No accidents, no spills, no incidents. Rig repair time daily - 0.0 hrs. Rig repair time cum - 27.0 hrs. Days Since Last DAFWC~. ~7~8 lasfGsgTesfPress.: 2,boo (psi) Last BOP Press. Test: 3/25/2007 Next BOP Press. Test: 4/1/2007 N().~t()l'gards: TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: (It) (ppg) (psi) (psi) (ppg) (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Bha No: 22 Depth In: ~~~ "TYl'f3: C~~,t\N_2UT. ..,gept~ Out: Component I Component Detail " 'i3If Scraper Boot Basket Boot Basket Bit Sub Bumper Sub Jar Pump Out Sub Collar XO Bha No: 23 Depth In: Bha Type: DRESSING DOWNB@ bJ5 But: cOmpOnenC!COmponent DetaT rshoe ¡ Washpipe extension HSE & Well Control All Free Days: 9 Last Envir. ïñdi:lf3nt:2/25/200'7 Last Abandonment Drill: 3/31/2007 Last Spill Drill: 3/31/2007 Regulatory Agency Insp: N Pump' --- --'STowPumpRates (Gire) Stroke Rate Pre~s,~reO Last Trip Drill (D1): Last Safety Meeting: 3/27/2007 3/31/2007 Non-compliance Issued: N - rsiOwPumpRates'(Ghokè), .. - 'SiowPumpRates -(Kill) ! Stroke Rate F-'ress,lJre() Stroke Rate PresslJ~eº ._.~.. . o erational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Rotating Weight: Pick Up Wt.: Slack Off WI.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 10,945.0 10,945.0 , JIšT Length (ft) -0.86 4.23 4.60 3.75 2.84 8.70 11.55 1.92 275.51 2.31 --~._~--_._-_..- Length (ft) T98' 4.46 BHA Bha Weight: Wt Below Jars: CLÌiíilërígth:' OIfTö (ftl.._i ji~L _ Ji~Lc 0.86: 8.500: 1.500 ¡ 5.09 8.000: 2.250 t 9.69 7.000 2.250: 13.44 7.000 2.250; 16.28 6.375 2.250 i 24.98 6.250 3.125 ¡ 36.53 6.250 2.250' 38.45 6.125 2.125 313.96 6.375 2.875' 316.27 6.250 2.500, Bha Weight: Wt Below Jars: Cum Length:" ... 5ïY- -'10" Blade OD Bend Angle, " Connection (ft) . (in) ! (in) (in) n I Size(in) TYPf3.. -r.9sT6.7S0'.LS'ÕÕ: I -iÜ32S'u . n fss 6.44 5.750! 5.000 j i 6.625 TSS Ann. Vel. Riser: (ft/min) Ann. Vel. DC: (ft/min) Ann. Vel. DP: (ft/min) (hr) Pump Status - Drilling and Riser 'PÚmp!Typei Elf. TStrokes'Ün-erSiie1circ. Rate I () 0, () 0 -¡P/è ----"--- pis Printed: 4/2/2007 6:45; 1 0 AM . Operator: BP EXPLORATION Well: 09-11 Field: PRUDHOE BAY BP EXPLORATION Daily Operations Report Rig: NABORS 2ES Event: WORKOVER Well Type: DEVELOPMENT BHA Bha Weight: Wt Below Jars: Length ·'CumTii"ngtf¡r-· OO-~~ìD SladeÖD:SencfA¡'gle! (ft) (ft). (in) . (in) (in)n. . - Koör- .. 11.44' 5~5·öi 5.000' 3.32 14.76 5.687! 2.250 1.70 16.46 4.750 1.500 4.51 20.97 5.000 1.500 4.46 25.43 4.750 1.500 3.32 28.75 5.375 1.250 1.92 30.67 4.625 1.500 7.86 38.53 4.750 2.000 11.07 49.60 4.750 2.000 9 273.65 323.25 4.750 2.250 2.45 325.70 5.250 2.500: Drillin Fluid (lb/100ft2) Ca: (lb/100ft2) K+: (cc/30min) CaCI2: (OF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) ! Pf/Mf: Bha No: 23 Depth In: Bha Type: DRESSING DOWN~ Ðut: Componenf-¡Componenti5eli:1¡ï-- m. ....-- SUB Type: Time/Loc: Depth: Temp: Density: Funnel Vise.: ECD: PV: YP: pH: From-To Op. Depth ÖO:ÕÖ~Ö2:ÓO 10,945 02:00-03:30 . 10,945 Ö3:30~05:ÖÒ 10,945 Ò5:ÖO~06:3Ò 10,945 06:3-0~12:ÒO 10,945 12:00~13:60 10,945 ¡Was'hprpeextens·iõn . W.O. Boot basket I ¡XO Boot Basket Boot Basket Casing scraper Bit Sub Bumper Sub Jar Collar iXO SEA WATER 21 :OO/PIT 11,595. (ft) (OF) 8.50 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) 'Hrs Phase Task (hr) 2.ö6 ·OEc6M CLEAN 10,945.0 10,964.0 -'Jt5· 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity Bt-iAHDL P 1.50 DECoM CLEAN' èHAt-iDL 1.5Ö'ÖEC6M CLEAN· BHPULD 1:56 ·DECOMCIEAN! 5.50ÖEC6McLËÄN' .00 -DE COM CLEAN RIH RIR WAsH 13:ÖÖ~14:3b 1.50 DECOM CLEAN i CIR 10,945 14:3Ö~ Ü3:3Öt4:ÖOmÖECOMCLEAN pÖR- 10,945 18:30-20:06 :1.50 ¡DECOM CLEAN'-èHAHoL 10,945 2ò:06~21 :06' 1.6ó1ÖECOM CLËAN; 10,945 21 :oö~2-i :30 ¡ mÒ.50 'DECOM CLEAN, put 10,945 21 :30-22:00 ! 0.50 'DECOM CLEAN. 10,945 Page 2 of 3 Report: 22 Date: 3/31/2007 Connection Size (in) 6:625 6.625 P/B 2,100 (mg/L) (mg/L) (%) (%) 25,000 (mg/L) (%) (ppb) (ppb) / (mUmL) ES: Solids: Oil: Water: Oil/Water: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) (%) (bbl) (bbl) (bbl) (bbl) rations Summa NPT Operation PJSM. Break down BHA components and clear from floor. 'PjsM.SnngBRA components forpoJìshing 41/2" stump-to floor 'pJsM, Make up èHAandpìck up 9 drillc<:>lIars from pipe shed. - RÙn În hae íNÌlh4Ü2"stÙmp polishing assembly from 326'10 4429'. .. Run in hole, picking ÙpcJrili pìpefrompipeshed froin 4429' to 10,903'. , pjSM. Wash ancJrsam from 10;903'1010,94 f'. Taglubing top @ 10,931',dress 2-3 inches of tubing top. up wt. 155k,down wt. 140k,rotating wt. 160k. ¡ 40 RPM,torque off bottom 5k and on bottom 6-7k. j~~_~F'./I,1_~n~3_0J).s!:~n_n ........._....n._ ..... ....n....... , Circulate 35 bbl. Hi-Vis sweep around surface to surface,circulate till clean. :410 G PM 2275 psi. Monitor well. i PJSM.poÖR from 16;941' 10325'. . . ¡-p J8M .-Ffac·kback- collars, and iay downwa5hpipe:Tubing cut 'off(22.83') tubing pup joint (9.87') and K anchor (.85')pulled out of · hole. Top of packer in hole 10,964'. .... TpJSM.Cleartloororbaker ¡oois. . PjsM.Puìf wear ring: ~pjSM.R¡g uplO lestBOPE;fiiïëhoke andèop. Printed, 4/2/2007 6145,10 AM .. Operator: BP EXPLORATION Well: 09-11 Field: PRUDHOE BAY BP EXPLORATION Daily Operations Report Rig: NABORS 2ES Event: WORKOVER Well Type: DEVELOPMENT erations Summa NPT Page 3 of 3 Report: 22 Date: 3/31/2007 From-To ¡ Hrs Phase Task Op. Depth r. (hr) '.. . .. .'. ... ... .' -22:00~ÖO:OO'2.oëf iDECÖM CLÈÄN! 10,945 . , Activity Operation From-To Hrs ¡ Phase Task ¡ Op. Depth (hr) 'I ; ! ÖO:OO:08:0Ö r~8.Öo~þEcðMcIEÄNi 10,945 Activity TPJSM.TestBOPE and reiated-va¡ves to 250ps' 'Òwand 35ÖÖ-pSl high.Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Lou Grimaldi,test witnessed by BP rep Blair Neufeld (WSl) and Nabors drilling rep John Castle. 06:00 U date NPT Operation TSTPRS Item Units ~GAC "pJSM:test BOPEandreiàfedvaÎvesto2S0ps,íowana-350Ó pSI I high.Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Lou Grimaldi,test witnessed by BP rep Blair Neufeld (WSl) and Nabors drilling rep John Castle. Pull test plug,clear floor. Problems testing series #2 and #3 of the choke manifold due to improper greasing of the packing. Greased properly then tested OK. Changed bad fitting on pressure sensor oil line for chart (mechanical failure). Materials I Consum Usage ! On Hand 1922]- -7482 Personnel ! Hours Company No. Hours Company :f2.06 NABORS . U . , '2'12:ÖO NAsORS .. ..-. ' 12.00 NABORS 3 12.00 M-I DRilLING FLUIDS 12.00 SPERRY-SUN 0 12.00 SPERRY-SUN 12.00 BAKER 1 12.00 Cumulative Phase Breakdown Change of Scope Prod % Totäl NPf%TotâT WÖW % Total lJ~age 10n Hand biESEL COlTlpany : Hours n12~ÖO 12.00 12.00 SP DOYON BP SPERRY-SUN Phase PRÈ DECOMP fot ÃI§, Prod %Totall 44.50 58.6%1 400.00 92.2% ! 444.50 8'Y.2% ¡ Planned NPf~%Tc>t¡:II¡ WoW % Total SL5Ö·41.4% Window Top: (ft) Mud Sys Ftg: (ft) CTOD: CTID: CT length: 0.0%' 0.00 Total Total Cost Hours. USD nrò6T329,886.89 434.00 ¡ 1,825,837.8 510.ÖO ¡ 2;155,724.7 34.00 7.8%· 34.-ö6- 6.7%: 0.0% lSRV 1: (cp) lSRV 3: (cp) Drill Solids: (%) Window Desc: Remarks PJSM held prior to all Ops. Derrick inspection. Check Crown savers. Check & set flow and PVT alarms. O.A. 0 psi. I.A.Opsi. New shaker screens used on 09-11 Non Permanent Employees None New Permanent Employees Matt Stewart· Floor Hand - Transfer - Not new to position· started 3/16/07 Adam Marang - Roustabout - New to position started 03-28-07 Printed: 4/2/2007 6:45: 1 0 AM . . i i FRANK H. MURKOWSKI, GOVERNOR AJ,ASIiA OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 3, 2007 CERTIFIED MAIL - RETURN RECEIPT REQUESTED 7005 1160 0001 5753 9004 Mr. Gary Christman Wells Director - ADW BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,AJe 99519-6612 \1fø- of6l. - Subject: Improper BOP Equipment - Nabors 2ES s~ APR 0 5 2007 Dear Mr. Christman: On March 24, 2007 an Alaska Oil and Gas Conservation Commission ("Commission") Inspector witnessed testing of blowout prevention equipment ("BOPE") on Nabors Rig 2ES. At the time of inspection, Nabors 2ES was performing a tubing workover of Prudhoe Bay Unit Well 09-11 (PTD 1760840) under sundry approval 307-043. The Commission Inspector found the kill line rigged up with chicksan pipe and hammer union connections. A copy of the inspection report is attached. The facts reported by our inspector appear to indicate a failure to install proper BOPE, which would be a violation of State regulations. Within 14 days of receipt of this letter, you are requested to provide the Commission with an explanation of how this event happened and confirmation that all other BPXA-operated rigs in Alaska are compliant with BOPE requirements. You are reminded of the requirements of 20 AAC 25.285(e) ("Secondary Well Control For Tubing W orkover Operations: Blowout Prevention Equipment Requirements"): (e) Kill and choke lines must (1) be constructed of rigid steel pipe, fire-resistant rotary hose, or other conduit that has been approved by the commission as capable of withstanding the temperature and pressure of an ignited uncontrolled release; (2) be as straight as practical,' (3) if constructed of rigid steel pipe, use targeted turns where the bend radius is less than 20 times the inside diameter of the pipe; Mr. Gary Christman April 3, 2007 Page 2 of2 . . (4) be secured to prevent excessive whip or vibration; (5) be sized to prevent excessive erosion or fluid friction; and (6) be assembled without hammer unions or internally clamped swivel joints, unless the commission determines that those joints do not compromise the maintenance of well control. The Commission Inspector was surprised to learn that no one on the rig could point to a Commission approval when asked about the alternate kill line configuration. As a longstanding operator with extensive drilling and workover experience in the State of Alaska, BPXA should have no confusion about the well control equipment requirements and the need for approval before deviating from Commission requirements. The Commission Inspector allowed operations to continue on PBU 09-11 pending the installation of an appropriate kill line. The rig crew was advised that repairs should be completed before initiating work on any other well using Nabors 2ES. The rig should be made available for Commission inspection to verify installation of proper kill line equipment. Such inspection should be coordinated with a Commission Inspector at least 24 hours in advance of inspection. The Commission reserves the right to pursue enforcement action in connection with the apparent violation as provided by 20 AAC 25.535. Should you have any questions regarding this correspondence, please contact Mr. James Regg at (907) 793-1236. Attachment cc: AOGCC Inspectors (via email) ~f(> - STATE OF ALASKA OIL AND GAS CONSERV A nON COMMISSION BOPE Test Report Contractor/Rig No.: Nabors 2ES Operator: BP EXPLORAT[ON (ALASKA) [NC Type Operation: WRKOV Type Test: WKL Y MISe. INSPECTIONS: P/F p p NA P P P P NA Location Gen.: Housekeeping: PTD On Location Order Posted Well Sign Dr!. Rig Hazard Sec. Misc FLOOR SAFTY VALVES: Quantity P/F Upper KeIlY___L___L Lower Kelly ~~_~ Ball Type 2 P Inside BOP 1 P FSV Misc NA Test Results Number of Failures: 3 PTD#: 1760840 DATE: 3/25i2007 Reviewed By: P.I. Suprv Comm Inspector Chuck Scheve Rig Rep: Ronnie Dalton Insp Source Inspector Test Pressure: 250/3500 250/2500 Annular: Valves: 250/3500 Inspection No: Related Insp No: bopCS070327160013 Rams: -~---'^- -_.~-~-,-^_._~--~~ TEST DATA MUD SYSTEM: Visual Alarm P p P P -~-- P P P P P P NA NA Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector MS Misc BOP STACK: Quantity Size Annular Preventer 1 13 5/8 Pipe Rams 1 3.5 x 6 Lower Pipe Rams 1 2 718 X 5 Blind Rams 1 Blind Choke Ln. Valves 1 3 1/8 HCR Valves 2 3 1/8 Kill Line Valves 1 3 1/8 Check Valve 0 none BOPS Misc 1 2" P/F P P P P P P NA CHOKE MANIFOLD: Quantity P/F No. Valves 18 FP Manual Chokes 1 P Hydraulic Chokes 1 P CH Misc 1 F Remarks: Casing pressure gauge on choke pannel not working. Kill line rigged up with chicksan and hammer unions, new hose on order and will be installed prior to next well. Choke valves 7 and 12 failed initial test serviced and retested good. Operator Rep: Bill Decker ACCUMULATOR SYSTEM: Time/Pressure System Pressure 3000 Pressure After Closure 1400 200 PSI Attained 29 Full Pressure Attained 119 Blind Switch Covers: all Nitgn. Bottles (avg): 6~2200 ACC Misc P/F P P P P P P P NA F Ke: Update on U~-ll K WU \;~/ ~ Josh, et aI, Thanks for the information. Unfortunately, you never really know what is broke on a well until you open it up. It appears that you are attempting to contain fluids to the wellbore and are actively managing any fluids that might seep to the cellar. You all are more knowledgeable as to the ability to safely and regulatorily manage the situation. Best wishes on the washover operation. Call or message with any questions. Tom Maunder, PE AOGCC Sudderth, Josh wrote, On 3/21/2007 2:21 PM: &CANNED MAR 2 1 2007 Tom, Greg and I felt we should send you this update: We are currently in the process of washing over 13 3/8" casing below the starting head. The casing head and tubing spool have been removed and we had to cut out the 13 3/8" hanger joint. Our plan is to wash over the 13 3/8" casing to the point that we can back off a joint, run new 13 3/8" casing, install a new wellhead and perform a top job on the conductor by 13 3/8" annulus. As discussed before, the conductor by 13 3/8" annulus will be abandoned as the new wellhead will start on the 13 3/8" casing. After we made our cut in the 13 3/8" casing below the wellhead, we discovered that the conductor pipe had split along the pipe seam. The split goes below ground level so we were unable to weld it. Prior to cutting the 13 3/8" casing, we opened the conductor x 13 3/8" annulus and found a void from the well head to about 15' below the wellhead. On the original drilling reports, cement was circulated to surface, but this likely shrank and left free water standing in the closed annulus. We believe this water froze and caused the conductor to split. In order to continue our operations, we have packed the split with barite as we have no choice but to wash over the 13 3/8" casing to get to a connection that we can back out and tie back into. We are making every effort to prevent fluid seepage and are sucking up any fluid that may seep out of the split. Just wanted to make you aware of these operations. If you have any questions or comments, please contact Greg Hobbs at 980-1439. Thanks Tom, Josh Sudderth Operations Drilling Engineer BP Exploration Alaska Office: 907-564-4342 Cell: 907-632-3807 1 of 1 3/21/20073:33 PM Re: 09-11 rotary work over sundry - additionalrmation . Josh, The activities have indeed become more complex. I will include your message in the well file. Good luck with the operations. Tom Maunder, PE AOGCC l ì1 (g -a<¿ç~ You all know the well situation much better than I. SCANNED FEB 2 6 2007 Sudderth, Josh wrote, On 2/22/20074:08 PM: Tom, We have already received the approved Sundry for the 09-11 rotary workover. In this sundry, step 12 says: 12. Perform well head repair/replacement. NOTE: Current well head is welded onto the 20" conductor. The new well head configuration will have a new well head on the 133/8" casing. The 20" x 13 3/8" annulus was fully cemented during the original drilling operations and will be topped off after the well head is installed As we have fine tuned the procedure, the complexity of this operation has become more apparent. Below are the steps as we see them happening during the well head change out. OPTION 1 (13 3/8" Backoff) 1. PU 133/8" casing cutter. RIH and cut the casing 2 ft below the first collar (-6 ft below the starting head flange. The casing hanger pup is 3.4' long) The 13 3/8" casing was landed on a hanger in the 20" starting head. 2. NO the BOPE and the well head to the starting head. 3. Attempt to determine the top of cement in the 13 3/8" x 20" annulus. Probe through the flutes if possible. When this well was originally drilled, the 13 3/8" casing was cemented with 5650 sx , 14.6 ppg Arctic Set and good cement returns were reported at the surface (shaker). 4. Spear the 13 3/8" hanger or screw into the LH ACME thread in the top of the casing hanger. Jar if necessary. (Possible use of casing jacks instead of jarring??) 5. NU riser onto 21 X" 2K starting head (riser to be manufactured for this purpose) 6. RIH and wash over 60' of 13 3/8" casing. Two full joints exist below the landing joint. POOH 7. PU spear or Baker Back-off tool. RIH and back off top joint. LD recovered joint. (IF BACK OFF FAILS, MOVE TO OPTION 2 BELOW) 8. RU 133/8" casing equipment. PU new 133/8" 68# BTC casing. RIH and screw into connection. 9. Pull test connection to 150K-lbs. 10. RU Cement head and pressure test 13 3/8" casing to 2000 psi. 11. Drain the riser to minimize fluid loss. Lift riser to allow access to 13 3/8" casing. 12. Cut 13 3/8" casing with Wachs cutter and LD 13 3/8" landing joint. 13. Remove the riser 14. RU 20" Wachs cutter. Cut 20" conductor just below the old starting head. Remove old starting head. 15. Install McEvoy 2-Step well head as per the welding instructions provided in this procedure lof2 2/23/20077:23 AM Re: 09-11 rotary work over sundry - additional information . . and under the guidance of the welding engineer. 16. Grout the 20" x 13 3/8" annulus 17. NU BOPE and test to 250/3500 psi for next phase OPTION 2 (13 3/8" Casing Patch - Back off is unsuccessful) 1. PU 133/8" casing cutter. RIH and cut 5' below the next collar. POOH 2. PU 13 3/8" casing spear. Recover stub. 3. RIH and dress off stub as per Baker fishir'fg rep. 4. RU 13 3/8" casing equipment. PU new 13 3/8" 68# BTC casing and 13 3/8" casing patch (Baker). RIH and tie back the 133/8" casing with the casing patch. . Casing Patch is rated to -20 deg F 5. RU Cement head and pressure test 13 3/8" casing to 2000 psi. 6. Drain and Lift riser to allow access to 13 3/8" casing. 7. Cut 133/8" casing with Wachs cutter and LD 13 3/8" landing joint. 8. Remove the riser 9. RU 20" Wachs cutter and cut conductor just below the old starting head. Remove old starting head. 10. Install McEvoy 2-Step well head as per the welding instructions provided in this procedure and under the guidance of the welding engineer. 11. Grout the 20" x 13 3/8" annulus 12. NU BOPE and test to 250/3500 psi for next phase During this well head change out, we plan to line the cellar with herculite or some form of containment. It is anticipated that up to a barrel of fluid (sea water/brine) could end up in the cellar when we cut the spool off. We will use a vac truck to remove the fluid as it occurs. Our intent is to minimize fluids draining into the cellar as much as possible. Also, in step 10 of the approved sundry, we will be running a composite bridge plug instead of an RTTS. Josh Sudderth Operations Drilling Engineer BP Exploration Alaska Office: 907-564-4342 Cell: 907-632-3807 20f2 2/23/20077:23 AM . ~V~VŒ (ID[F ~~~~æ~ . AIIA~1iA. OIL AND GAS CONSERVATION COHltlISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,AK,99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-11 Sundry Number: 307-043 \1 k l) <bY- 5CANNED FES 0 1 2007 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ day of January, 2007 Enc!. . STATE OF ALASKA c:fltl/. ALA~ Oil AND GAS CONSERVATION COMM.ON APPLICATION FOR SUNDRY APPROVAL ~~ ,~-~# ,í-¿;::¡p../}? ~/~ù 20 MC 25.280 RJ=rr=f\¡:::n 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension - o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o R~t'è r £¡,eri<i~ ~ell o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waive'Al 9 Btr1!; .8S . Gas Cons. Commission 2. Operator Name: 4. Current Well Class: 5. Pernflli1't8QJØgt.lumber BP Exploration (Alaska) Inc. 181 Development o Exploratory 176-084 ( 3. Address: o Stratigraphic o Service 6. API Number: ./ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20236-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-11 / Spacing Exception Required? DYes 181 No 9. Property Designation: I 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028345 54 j Prudhoe Bay Field / Prudhoe Bay Pool r 12.i'/ ,', "'<.. ... ,<.f. . ·ii/· . ..i'V?i"<.·i<V' 't'.""·· .. ... .. <'·'i..'.·.·.. < ...... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12347 / 9130 12262 9090 None 12212' - 12342' Casino Lenoth ize MD TVD Burst CollaDse Structural Conductor 73' 20" 73' 73' 1530 520 Surface 2702' 13-3/8" 2702' 2702' 5380 2670 Intermediate Prodllction 11595' 9-518" 11595' 8751' 6870 4760 Liner 1060' 7" 11282' - 12342' 8576' - 9127' 8160 7020 Scab Liner 1049' 4-1/2" 11208' - 12257' 8531' - 9089' 8430 7500 ~UJ..'" c::.'!.d \'¡'4-t;T (.,.\~c¡( '1"(~<\ 4'-\ü J- ~\ ()()F) . ~ ~~ Hi.. ~- Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11779' - 12185' 8852' - 9056' 7" x 5-112" x 4-112",29# x 17# x 12.6# 13CR-80 11042' Packers and SSSVType: 5-1/2" Camco TRDP SSSV I Packers and SSSV MD (ft): 2209' 13. Attachments: 14. Well Class after proposed work: D Description Summary of Proposal o BOP Sketch o Exploratory 181 Development o Service 181 Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina Operations: February 5, 2007 181 Oil o Gas D Plugged o Abandoned 17. Verbal Approval: Date: o WAG OGINJ DWINJ o WDSPL Commission Representative: 18. I hereby certify that the foreir9 is true and correct to the best of my knowledge. Contact Joshua Sudderth, 564-4342 Printed Name Greg),fqbbß 1/ Title Senior Drilling Engineer ßY~ ~ 564:~ '-\ \<i \ Date ft"t.01' Prepared By Name/Number: Signature Phone Sondra Stewman, 564-4750 VI '() Commission Use Onlv , I Sundry Number: .3D7 - 04 3 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~PTest o Mechanical Integrity Test o Location Clearance Other: %--oa\,~\ ~\~\~~~ ~?~~ Subsequent Form Required: \..\G,-\ APPROVED BY /- ßO ,11'- Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 .V L./ Submit In Duplicate RBDMS BFl ~ì 2007 0 RIG 1 N A L . . Obp G~AJlArAr To: AOGCC Date: January 23, 2007 From: Joshua L Sudderth- BPXA GPB Rotary Drilling Subject: 09-11 Application for Sundry Approval- Rig Work Over to Return to Production Approval is requested for the proposed work over of the 09-11 well. Well 09-11 is an Ivishak producer that is currently shut-in due to IA x OA communication. Scope of work: Cut and pull the existing tubing string above the current packer, cut and pull 9-5/8" above the 13 3/8" shoe, RTTS will then be set in the 13 3/8" casing for isolation to perform well head replacement work. After the well head is replaced/repaired, new 9 5/8" premium thread casing will be run and the 9 5/8" x 13 3/8" annulus cemented to surface. New 5 W' x 4 112" chrome tubing will be run in a stacker packer configuration. Estimated Work Over Date: 2/05/07 Joshua L. Sudderth GPB Rotary Drilling Engineer Ph: 564-4342 / Cell: 632-3807 CC: Well file Terrie Hubble / Sondra Stewman Proposed Procedure Current Status: y SI '7 \'('..,-Q "J 0 '5" y IA x OA communication BHP - 3180 psi @ 8,800 ft TVD ~ '\.a E~~ ~¥\\f~o MASP - 2300 psi = (3180 psi - (0.1 psi/ft * 8800ft)) Pre-Ria Operations: 1. WIRELINE: Drift tubing for bridge plug and tubing cut 2. WIRELINE: Run and set Composite Bridge Plug at -11,030' MD. 3. OTHER: Test bridge plug to 3500 psi 4. WIRELINE: Chemical cut the tubing in the middle of the full length tubing joint at -10,945' MD. 5. OTHER: Circulate well with sea water and FP to 2200' MD. 6. OTHER: CMIT TxlA to 3500 psi. MIT OA to 2000 psi. . . Page 2 of 3 7. OTHER: Bleed casing and annulus pressures to zero. Freeze protect to -2,200' MD with diesel. 8. OTHER: Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT -IC and PPPOT-T 9. OTHER: Set a BPV. Remove well house and flow line. Level the pad as necessary. RiQ Operations: 1. MIRU - Pull BPV. RU and circulate out FP. Confirm well dead. CMIT TxlA. MIT OA. 2. Install TWC in tubing hanger and test. 3. ND tree. NU BOPE and test to 250 psi low and 3500 psi high. Pull TWC 4. Pull 7" x 5 %" x 4 W' production tubing from cut at -10,945' MD. 5. RIH with dress off shoe and 9 5/8" casing scraper. Dress off tubing stub if required. Circ well clean. POOH ~ -+oÇl c;,Ç- ,\5h;\\ c::.~'t> \\~r-M?)v'{ 'h.o 6. Run USIT from 4387' in cement and corrosion modes. Note condition of casing and cement tops. 7. Set RBP 1000 ft below TOC. Pressure test to 2000 psi. 8. Cut and pull 9 5/8" casing in second full joint above TOC. **Annulus arctic packed! Circ out annulus. 9. Test 13 3/8" and 9 5/8" casing to 1000 psi for 30 minutes. 10. PU 133/8" RTTS. RIH to -1000 ft MD. Set RTTS and test above to 1000 psi. 11. Open well and monitor well for WH repair. ND BOPE. 12. Perform well head repair/replacement. NOTE: Current well head is welded onto the 20" conductor. The new well head configuration will have a new well head on the 13 3/8" casing. The 20" x 13 3/8" annulus was fully cemented during the original drilling operations and will be topped off after the well head is installed. 13. NU BOPE and test 250 psi low and 3500 psi high. 14. RIH and retrieve RTTS 15. Run 9 5/8" premium thread tieback casing and screw in sub with 1 centralizer on every joint above ES cementer. 16. RU and cement 9 5/8" x 13 3/8" annulus from tie back to surface. 17. ND BOPs, set slips and packoff. NU and test BOPs 250 psi low and 3500 psi high. 18. Drill out baffle plate and shoe track. 19. Pressure test casing to 3500 psi for 30 min. POOH. 20. RIH and pull 95/8" RBP. 21. PU bladed junk mill and enough 2 7/8" PAC pipe to RIH, drill out the 4 W' composite plug and push it to the bottom of the liner. 22. RU and run 5 %" x 4 W' premium thread tubing. 23. Set the packer. Increase the pressure and test the tubing 3500 psi for 30 mins. Bleed tubing to 1500 psi and test the IA to 3500 psi for 30 mins. 24. Bleed both T and IA to zero. Pressure up IA to shear DCK valve. (run in top GLM). Confirm circulation both ways. 25. Install TWC. Test above and below to 1000 psi 10 mins charted. 26. ND BOPE. NU adapter flange and tree. Test to 5000 psi. 27. Pull TWC. Freeze protect T and IA to 2200' MDfTVD. 09-29 RWO Application for Sundry . 28. Install SPY. Test to 1000 psi. Secure tree and cellar. Post-RiQ Work: 1. Install well house and flowlines. 2. Retrieve ball and rod (slick line) 09-29 RWO Application for Sundry . Page 3 of3 - :rREE = McEVOY WELLHEAD = FMC GEN 1 ACTUATOR = OTIS KB. ELEV = 54' BF. ELEV = KOP= 3057' Max Angle = ŒJ Datum MD = 11783' DatumTVD- 8800' SS ŒJ 13-3/8" CSG, 72#, MN-80, ID= 12.3471 2702' Minimum ID = 3.725" @ 11029' 4-1/2" OTIS NIPPLE I 8-1/4" X 7-1/2" BKR TIE-BACK SLEEVE I I BKR FLEX-LOCK HANGER I I 7-5/8" CSG, 29#, L-80, ID = 6.875" I 7-5/8" SCAB LNR, 29#, L-80, w/BROWNTYÆ'PA' LOCATER& SEALS 7" LNR, 29#, MN-80, .0565 bpf, ID = 6.182" 14-1/2" SCAB LNR, 12.6#, L-80, .013 bpf, ID = 3.958" I 9-5/8" CSG, 47#, N-80, ID = 8.681" I 09-11 I I -~ . -. ~ U . 2296' 2418' µ I SAF~TE: I I 2147' -f 7" X 5-1/2" XO I I 2209' - CAMCO 5-1/2" TRDP SSSV NIP, ID = 4.550" I 2989' H 5-1/2" X 4-1/2" XO I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 3555 3538 78 KBMGM DOME BK 08/23/94 2 6347 5500 55 KBMGM DOME BK 08/25/94 3 7758 6295 57 KBMGM D ES 08/09/95 4 8658 6810 53 KBMGM D BK 07/01/94 5 9418 7284 50 KBMGM D BK 08/09/95 6 10170 7792 46 KBMGM D BK 07/01/94 7 10852 8283 43 KBMGM D BK 08/26/94 I 10918' H 4-1/2"OTISXNIP,ID-3.813" I I 10978' H 7-5/8" X 4-1/2" BAKER SABL-3 I I 11012' H 4-1/2" OTIS X NIP, ID = 3.813" I : 11029' H 4-1/2" OTIS XN NIP, ID = 3.725" I I 11042' H 4-1/2" TUBING TAIL WLEG 1 I 11017' H ELMDTTLOGGED01/06/95 I / 8 ~ ~ 11194' H 8-1/4" X 7-1/2" TIE-BACK SLEEVE I ~ _ ì 11207' 1-1 9-5/8" x 7" BROWN MODEL H LNR- TOP PKR I ...... ~ 11208' H 7" X 4-1/2" XO, MILLED OUT I 4387' ~ 4395' l :8 4402' f- I · ~ ..... '-' I · I · · 11200' I x~ 11282' I Jl'i 11208' I 11595' ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/20/77 ANGLEAT TOP ÆRF: 57@ 11781' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I OPN/SQZ DA TE See Page 2 for Perforation Data I 4-1/2" SCAB LNR. 12.6#, MN-80, ID = 3.958" I 12257' I I PBTD I I 7" LNR, 29#, MN-80, .0565 bpf, ID = 6.182" I DATE 05/01/77 06/28/94 OS/24/01 09/07/02 09/28/02 03/22/03 REV BY COMMENTS ORIGINAL COM PLETION LAST RWO RN/TP CORRECTIONS A TD/TLH DRAWING CORRECTION BIII1/TP WANER SAFElY NOTE JMP/KK WANER DATE CORRECTION 12212' 12342' I DATE 09/29/05 10/26/06 10/31/06 -.. ~ ~ -, III.. I' I 12212' -fCIBP- 03/02/011 I 12172' - PKR ELEMENTLOGGED 10/06/92 1 I 12342' -f RUBBER ELEMENTS FROM IBP LOGGED 07/10/94 I REV BY COMMENTS EZL/TLH WANER SFTY NOTE DELETED DCR/PAG SCHEMA TIC CORRECTIONS PJP/PAG SCHEMA TIC CORRECTIONS PRUDHOE BA Y UNIT WELL: 09-11 ÆRMIT No: ~ 760840 API No: 50-029-20236-00 SEC 1, T10N, R15E UM, 1463N, 50E OF SWCR BP Exploration (Alaska) PERFORA TION SUMMARY REF LOG: BHCS ON 04/20/77 ANGLE AT TOP PERF: 57 @ 11781' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SQZ DATE 11779 - 11782 S 01/27/90 11782 -11786 0 07/13/92 11786 - 11789 S 01/27/90 11804-11809 0 07/13/92 11809-11839 S 01/27/90 11880 -11885 S 01/27/90 11910 -11916 0 07/13/92 11916 - 11920 S 01/27/90 11928 - 11936 0 07/03/92 11936 -11961 S 01/27/90 11984-11996 0 07/13/92 11996 - 12028 S 01/27/90 12043 - 12060 0 03/25/90 12085 - 12094 0 03/25/90 12094 -12112 0 02/18/95 12117-12121 0 03/25/90 12153 - 12159 0 03/25/90 12175 - 12185 0 03/25/90 ;rREE= WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 3- 3/8" 3-3/8" 3- 3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" DATE 05/01/77 06/28/94 OS/24/01 09/07/02 09/28/02 03/22/03 41/2 2 1 41/2 33/8 4-1/2" 1 33/8 4 4 4 McEVOY FMC GEN 1 OTIS 54' . 3057' 11783' 8800' SS 2 REV BY COMMENTS ORIGINAL COM PLETION LAST RWO RNlTP CORRECTIONS A TDITLH DRAWING CORRECTION BrvvTP WAIVER SAFETY NOTE JMP/KK WAIVER DATE CORRECTION DATE 09/29/05 10/26/06 10/31/06 09-11 PERFS -.. -.. -.. REV BY COMMENTS EZLlTLH WAIVERSFTY NOTE DELETED DCR/PAG SCHEMA TIC CORRECTIONS PJP/PAG SCHEMA TIC CORRECTIONS . PRUDHOE BA Y UNIT WELL: 09-11 PERMIT No: ~ 760840 API No: 50-029-20236-00 SEC 1, T10N, R15E UM, 1463N, 50E OF SWCR BP Exploration (Alaska) - " SCAB LNR, 29#, L-80, OWN TYÆ 'PA' LOCA TER & SEALS 7" LNR, 29#, MN-80, .0565 bpf, ID" 6.182" 4-1/2" SCAB LNR, 126#, L-80. .013 bpf, ID " 3.958" See Page 2 for Parforation Data PRUDHOE UNIT WELL: 09-11 ÆRMIT API No: 50-029-20236-00 SEC 1, T10N, R15E UM, Sf> ÆRFORA TION SUMMARY REF LOG: SHCS ON 04/20/77 ANGLE AT TOPÆRF: 57 @ 11781' Note: Refer to Production 08 for historical perf data SPF INTERV A L DATE 11779 - 11782 S 01/27/90 3-3/8" 2 11782 . 11786 0 07/13/92 11786 11789 S 01/27/90 3-3/8" 11804 - 11809 0 07/13/92 11809 11839 S 01/27/90 41/2 11880 - 11885 S 01/27/90 3-3/8" 2 11910 11916 0 07113/92 11916 -11920 S 01/27/90 3-3/8" 1 11928 - 11936 0 07/03/92 41/2 11936 - 11961 S 01/27/90 3-3/8" 33/8 11984 - '1 1996 0 07/13/92 11996 12028 S 01/27/90 3-3/8" 4-1/2" 12043 - 12060 0 03/25/90 3-3/8" 1 12085 12094 0 03/25/90 3-3/8" 33/8 12094 - 12112 0 02/18/95 3-3/8" 4 12117 12121 0 03/25/90 3-3/8" 4 12153 - 12159 0 03/25/90 3-3/8" 4 12175 - 12185 0 03/25/90 PRUDHOE SA Y UNrr WELL: 09-11 ÆRMrr No: 760840 API No: SEe 1, T10N, BP FW: 09-11 Cancel Waiver ') Subject: FW: 09-11 Cancel Waiver From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 26 lun 2005 16:34:02 -0800 TO;: "Rossberg,R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Harris, Marvin L (CONOCO)" <h~rrn11@BP .com>, j im _regg@admin.state.ak.us, winton _ aubert@admin.state.ak.us, "GPB, FS21COTU Area Mgr" <GPBFS2TL@BP.com>~ "GPB, Wells Opt Eng" <GPBW ellsOptEng@BP . com> , "OPB, Optimîzation 'Engr" <GPBOptirnìzati~nEngr@BP..co:m>, "GPE, FS2 DS Ops Lead" <GPBFS2DSOpsLead@BP.com>, "Carlson, BrianH" <Brian.Carlson@BP . com> , Cç:" "Dube, Anna T" <Anna.Dube@BP.com>, "NSU, ADW Well Integrity.Engineer" <NSUADWWellIntegrityEngineer@BP .com>, "Holt, Ryan P (VECO)'~<Ryan.Holt@BP.com>,' , "Mielke, Robert L.""<robert.mielke@BP.com>,"Hughes,Andr6i1 (\tECO)" ~hughå4@BP.com>: " " " ) P7ï) "it- t 7~ - 084 Hello all. Well 09-11 failed recent waiver compliance testing, the MITOA failed. The well has been 81 and classified as a Trouble well. We're working with the Anchorage PE to evaluate remediation options. Please call if you have any questions. Joe 1-907 -659-51 02 SCANNED JUL 222005 From: Holt, Ryan P (VECO) Sent: Sunday, June 26, 2005 1 :09 PM To: NSU, ADW Well Integrity Engineer Subject: 09-11 Cancel Waiver 17/0 - o'KLf Hello all, Well 09-11 has been classified as a trouble well and the waiver has been canceled. 09-11 recently failed waiver compliance testing and new waivers are not being issued at this time for artificially lifted wells with IAxOA communication. Please contact Joe Anders or Donald Reeves at x5102 with any questions. Thanks, R}'anHolt Well Integrity Tech. Pager 4236-786 Office 659-5524 .1 -ù I( ~~"\plclz~;~ 1 of 1 5Ruf1 Î (r?)oç frocU\_c~,,~ (to ~l ) ~) W"~\'- (\)~l) ¡\4\¡l,~ ù,¡ , 6t:>Q - '63(,.ç o o4ß2- ~:4 q3 7 tv'a." Ut')ç I . ,J ' I ¥ \ lGÛÇ' 7ò9:L\ S"kozM 273 , 37 I I ¡\/Iw c~ â,D'Ç' <-D"l ( '1 1Z?ß3 '30 c¡ g:r:J I f 7/13/20059:56 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 54 feet 3. Address Exploratory 7. Unit or Property name :~:~ P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number ~ '.~ 0.3 3816' FNL, 5229' FEL, Sec. 1, T1 ON, R15E, UM (asp's 718428, 5942932) 09-11 At top of productive intewal 9. Permit number / approval number 3973' FNL, 3946' FEL, Sec. 6, T10N, R15E, UM (asp's 693326.5, 5942090) 176-084 At effective depth 10. APl number 50-029-20236 At total depth 11. Field / Pool 4100' FNL, 3534' FEL, Sec. 6, T10N, R16E, UM Nsp's 725160, 5942847) Prudhoe Bay Oil Pool 12. Present well ~ndition summa~ Total depth: measured 12347 feet Plugs (measured) Tagged PBTD (4/0~2000) ~ 11956' MD. true vertical 9130 feet CIBP (1/29/2000) ~ 11977' MD. Effective depth: measured 11956 feet Junk(measured) ORIGINAL true vertical 8946 feet Casing Length Size Cement~ Measured Depth True vertical Depth Conductor 80' 20" 500 Sx 80' 80' Surfa~ 2648' 13-3/8" 5650 sx AS 2702' 2702' Production 1 1541' 9-5/8" 10oo Sx Cla~ G & 300 Sx AS 1 1595' 8751' Scab Casing 6798' 7-5/8" ~3 sx C~a~ G 4402' - 11200' 4306' - 8526' Liner 1060' 7" 4So Sx C~a~ G 12342' 9126' S~b Liner 1049' 4-1/2" 82 Sx Class G 11208' - 12257' 8531' - 9088' Perforation depth: measured 11782'- 11786'; 118~'- 11814'; 11910'- 11916'; 11928' - 11936'; (Isolated below CIBP are 119~'- 11996'; 12~3'- 12060'; 12094' - 12112'; 12117'- 12121'; 12153'- 12159'; 12175'- 12185'). true vertical 88~' - 8856'; 8866' - 8871'; 8922' - 8925'; 8931' - 8936'; (Isolated below CIBP are 8960' - 8966'; 8989' - 8998'; 9014' - 9022'; 9024' - 9026'; 9~1' - 90~'; 9051' - 9056'). Tubing (size, grade, and measured depth) 7", 29~, 13CR-80 Tbg ~ 2189' MD; 5-1/2", 17~, 13CR-80 Tbg ~ 2989' MD; 4-1/2", 12.6~, 13CR-80 Tbg ~ 10919' MD; 4-1/2", 12.6~, 13CR-80 Tbg ~ 11~2' MD. Packers & SSSV (~pe & measured depth) 7" BROWN ~PE H PACKER - MILLED OUT ~ 11207' MD; 7-5/8" X 4-1/2" BAKER SABL-3 PACKER ~ 10978' MD. 5-1/2" CAMCO TRDP SSSV ~ 2209' MD. 13. Stimulation or cement squeeze summa~ Inte~als treated (measured) (see a~ached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pm~um Prior to well operation ~9 4056 9~8 - 305 Subsequent to operation 275 2555 8662 - 279 15. Affachments 16. Status of well classification as: Copies of Logs and Suweys run ~ Daily Report of Well Operations ~ Oil ~X Gas ~ Suspended __ Sewi~ 17. I hereby certi~ that the foregoing is true and ~rrect to the best of my knowledge. Signed ~~ ~ Title: Dispo~l/Reg Compliance Engineer Date Mike Bill Prepped by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-11 DESCRIPTION OF WORK COMPLETED CAST IRON BRIDGE PLUG FOR WATER SHUTOFF Date Event Summary 1/29/2000: 3/10/2000: 3/11/2000: 4/02/2000: RIH & set CIBP @ 11977' MD for WSO. RIH & dumped 4 gallons of 100 mesh sand ontop of (31BP. RIH & dumped 4 gallons of sand & 8 gallons of Cement. RIH & tagged BTM @ 11956' MD. Placed well BOL & obtained production data. Page 1 STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC /IISSION REPORT SUNDRY WELL OPF_.rlATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCQ Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1463' FSL, 50' FWL, Sec. 1, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-11 At top of productive interval 1306' FSL, 1086' FWL, Sec. 6, T10N, R15E, UM At effective depth 1210' FSL, 1493' FWL, Sec. 6, T10N, R15E, UM At total depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R15E, UM 12. Present well condition summary Total depth: RECEIVED MAR 1 3995 ~.il & (las Cons, Commlssl0n -'-~.~. [/t, llch0ra - ~ feet 9. Permit number/approval number 76-84 10. APl number 50 - 029-20236 11. Field/Pool Prudhoe Bay Oil Pool measured true vertical 12347 feet 9070 feet Plugs(measured) Fill @ 12119' MD (2/18/95) Effective depth: measured true vertical 12119 feet 9025 feet Junk(measured) Casing Length Conductor 80' Sudace 2702' Production 11595' Scab Casing 6813' Line r 1060' Scab Liner 1063' Perforation depth: Size Cemented Measured depth True vertical depth 20" 500 Sx Cement (approx) 80' 80' 13-3/8" 5650 Sx AS 2702' 2702' 9-5/8" 1000 Sx CI 'G' & 300 Sx AS 11595' 8750' 7-5/8" 643 Sx CI 'G' 4402-11200' 4306-8526' 7" 450 Sx CI 'G' 11282-12342' 8575-9126' 4-1/2" 82 Sx CI 'G' 11208-12257' 8531-9088' measured 11782-11786'; 11804-11814'; 11910-1 1916'; 11928-11936'; 11984-11996'; 12043-12060'; 12094-12112'; 12117-12121 '; 12153-12159'; 12175-12185' true vertical 8854-8857'; 8867-8872'; 8923-8926'; 8931-8935'; 8960-8966'; 8990-8998'; 9015-9022'; 9024-9026'; 9041-9044'; 9051-9056' Tubing (size, grade, and measured depth) 7", 29#, 13CR-80, Tbg @ 2189' MD; 5-1/2", 17#, 13CR-80, Tbg @ 2989' MD; 4-1/2", 12.6#, 13CR-80, Tbg@ 11042' MD Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 10978' MD; 7" Camco TRDP SSSV @ 2209' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ionorlnjection Data OiI-Bbl Gas-M~ Water-Bbl Casing Pressure 837 2769 6211 1070// 3533 8238 - Tubing Pressure 298 311 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,/f/~ '?Ti. Form 10-404 Rev 06/15/88 cc: KZ. JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 9-11 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/1 8/95: MIRU & PT equipment. Reperforated: 11984 - 11996' MD (Z2) 12096 - 12110' MD (Z1B) Added perforations: 12094 - 12096' MD (Z1B) 12110 - 12112' MD (Z1B) RIH w/perforating guns & shot 30' of perforations as follows: 4 spf 6 spf Ref. Log: BHCS 4/20/77. 6 spf 6 spf Ref. Log' BHCS 4/20/77. Used a 3-3/8" carriers & shot perfs at 60 degree phasing at balanced pressures. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED 1 199 ,~pi~ & Gas Cons. Commission .......... Anchora GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: 3/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Weil Job # Log Description Date BL Floppy RF Sepia Mylar Disk '15 ~ "73 i D.S. 1-2~x',~ LEAK DETECTION 021 995 1 1 ID.S. 4-1-"2-~ TUBG PUNCHER RECORD 021 895 1 1 ~D.S. '~?~_~, RESERVOIR SATURATION 022195 '1 1 D.S.4.4~19~ CNT-G 022195 1 1 D.S. PERF RECORD 021795 I 1 D.S. 4'~3~-J PERF RECORD 021995 1 1 D.S, 4-48''''--J ~.. PERFRECORD 021395 1 1 D.S. 6-3X~ PRODUCTION LOG 0221 95 I 1 D.S. 7-4A'"',~ PERF RECORD 021 595 I 1 D.S. 9-2%~,,~ ( INFLATABLE BRIDGE PLUG 021 795 1 1 D.S. 9-11 ~ PERF RECORD 021 895 I 1 D.S. 9-45 ~ PERF RECORD 022095 1 1 D.S. 13-20~ INFLATABLE BRIDGE PLUG 021795 1 1 D.S. 11-4A'~ PROD PROFILE 022095 1 1 D,S. 15-11% _~ ~ PROD PROFILE 022095 I 1 D.S. 18-1,,1~,, ¥ iDUALBURSTTDT-P 021895 I 1 D.S. 11-0~4)t~ 95058 DUAL BURST TDT-P 021195 1 D.S.-1--t-e~'- q 5 95057 DUAL BURST TDT-P 020595 I Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED ~F~'E: ~ !995 Alaska 011 & Gas Cons. Commission Thank you. Anchorage GeoQuest 500 W.,nternationa, Airport I~a~!VED Anchorage, AK 99518-1199 ,. ,~_ ~.. ATTN: Sherrie NO. 9228 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay 2/3/95 Floppy Well Job # Log Description Date BL RR Sepia RF Sepia Mylar Disk · ,J.S. 5':11 94409.' DUAL BURSTTDT-P "120294 1 ,,, D.S. 1-22A DSI 01 1395 I 1 D.S. 3-3 ' pROD pROFILE 01 05 95 1....... 1 , ..... D.S, 3-8 PROD LOG 01 0695 I I ,, D.S. 3-11 INJEC PROFILE 01 0595 I 1 D,S, 3-14 PERFRECORD 010895 ...... I ..... 1 D.S. 3-22 PROD PROFILE 01 0895 I 1 ,, D.S. 3-25A PROD PROFILE 01 0995 I 1 . , D.So 3-24 PROD PROFILE 01 0795 I 1 D.S. 3-31 PROD PROFILE 01 I 1 95 I 1 ,,, D.S. 4-41 LEAK DETECTION 011095 I 1 D.S. 6-23 PROD PROFILE 01 11 95 I 1 D.S. 7-13A PROD LOG 010695 I 1 D.S. 9-11 PROD PROFILE & JEWERLY LOG 01 0 695 I 1 ........ .r'J.S. 9-42 PROD PROFILE 011 095 I 1 J,S. 11-23A DUAL BURST TDT-P 012195 I 1 ......... D.S. 11-23A CNTG 01 2095 I 1 D.S. 13-3 REPEATA PATCH SE'I-RNG RECORD 01 05 95 I 1 D.S. 13-33 INFLAT BRIDGE PLUG RECORD 01 05 95 1 1 ., D.S. 15-30 LEAK DETECTION 01 0995 I 1 D.S. 16-6 PRCD PROFILE 01 0895 I 1 ~D.S. 16-15 PROD LOG 010795 I I SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other . 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1463'NSL, 50'EWL, SEC. 1, TION, R15E At top of productive interval 1306'NSL, 1086'EWL, SEC. 6, TION, R15E At effective depth 1210' NSL, 1493' EWL, SEC. 6, TION, R15E At total depth 1191'NSL, 1956'EWL, SEC. 6, TION, R15E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 54' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-11 9. Permit number/approval number 76-84/Conservation order #258 10. APl number 50- 029-20236 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well Condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured feet feet feet feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth RECEIVED AUG 1 0 1994 Aiaska 0il & Gas Cons, Commission Anchoraje true vertical Tubing (size, grade, and measured depth) 7", 13CR80 tubing to 2149' MD; 5-1/2", 13CR80 to 2990' MD; 4-1/2", 13CR80 to 11042' MD Packers and SSSV (type and measured depth) 7-5/8" "SABL-3" packer @ 10978' MD; 5-1/2" Camco TRDP SSSV @ 2209' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re.~resentative Daily Average Production or Injection Data OiI-Bbl Qas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as' Copies of Logs and Surveys run I Daily Report of Well Operations x Oil x Gas Suspended 17. I hereby certify that the foregoing i.s t[ue and correct to the best of my knowledge. Signed Title Drillin¢] En~Tineer Supervisor Form 10-404 Rev 06/15/88 ' Service SUBMIT IN DUPLICATE ~P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-11 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 06/23/94 09:00 SPUD: RELEASE: 07/01/94 02:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 06/24/94 ( 1) TD:12347 PB:12259 06/25/94 ( 2) TD:12347 PB:12259 06/26/94 (3) TD:12347 PB:12259 NU BOPE MW: 8.5 Seawater MOVE RIG F/DS 3-02 T/DS 9-11. LD HERCULITE/MATS. SPOT RIG OVER WELL. SPOT & BERM SLOP TANKS. RU F/W/O. CHANGE POSITION OF THE WING VALVE ON CASG HD. ACCEPT RIG @21:00 HRS ON 6/23/94. TAKE ON SEAWATER, PREPARE X-MAS TREE. RU LUBRI. PULL BPV. RD LUBRI. CIRC OUT FRZ PROTECT F/TBG ANNUL. CIRC T/BALANCE WELL. SET TEST PLUG IN TBG HNGR. ND X-MAS TREE/ADPTR. NU BOP STACK. CHANGE TOP RAMS T/4.5" X 7" VARIABLE RAMS. POOH LD 4.5" TBG MW: 8.5 Seawater TEST TOP RAMS/BLIND/SHEAR RAMS/CHK MNFLD/LINES/VALVES, FLOOR BOPE T/250/5000. HYDRIL T/250/2500. WINESS WAIVED BY JOHN SPALDING AOGDD. RU LUBRI & PULL 2-WAY CHC VALVE. SEALED BELL NIPPLE. RU CELLAR PLUS CATCH TANK/DRAIN LINES T/TANK. NU LNDG JT. BOLDS. PULL TBG HNGR T/FLOOR. COMP. STRING SHOUT BE SOWN T.CHEM CUT @10960. RU SURF. LINES CIRC HOLE CLEAN. CLOSE HYDRIL. CIRC THRU OPEN CHK T/CLEAN UP WELL. WELL IS STATIC. POOH LD COMP STRING. RIH W/OS PU DP MW: 8.5 Seawater COMP. POOH W/REMAINDER OF 4.5" COMP STRING. RECOVER ALL COMONENTS DOWN T/CHEM CUT @ 10960. FISH LEFT IN HOLE: CUT OFF SECTION OF 4.5" TBG. PUP JT, PCKR ASSY, TAIL PIPE ASSY. 4 SS BANDSD. 9-5/8" PACKOFF TESTED T/3500. LD TBG PULLING EQUIP. CO TOP PIPE RAMS T/3.5 X 6. COMP BOP TEST 250/2500. J. SPAULDING W/AOGCC WAIVED WITNESS. PU 6-3/8" OVERSHOTW/GRAPPLE. MU BHA PU 3.5 DP T/TOP OF 7-5/8" LINER @ 4382. WORKED FISHING STRING-NO LUCK. POOH T/INSPEC'N. MARKS SHOWED RESTRICTION ON OD. PU 6-3/4 TAPERED MILL. MU BHA RIH T/TOL. DRESSED OFF TOL. POOH W/MILL-WEAR NOTED ON TAPER. MU OS. RIH T/TOL WORKED INTO LINER OK. CON'T RIH W/OS. RECEIVED AUG 1 0 1994 Aiaska Oil & Gas Cons. Commission Anchorajc WELL · DS 9-11 OPERATION: RIG : DOYON 16 PAGE: 2 06/27/94 ( 4) TD:12347 PB:12259 06/28/94 (5) TD:12347 PB:12259 06/29/94 ( 6) TD:12347 PB:12259 06/30/94 ( 7) TD:12347 PB:12259 MILLING UP PKR MW: 8.5 Seawater COMP RIH W/OS, PU 3.5" DP T/TOF @10978. MU KELLY W/O OS OVER FISH & ENGAGE. POOH W/OS. RELEASE OS F/FISH LD. RECVR'D CUT OFF JT 4.5" TBG/PUP JT/LOCTR SEAL ASSY. SLICK STICK. LD OS. PU PBR RETRIEVE TOOL. MU BHA RIH T/TOL @4382 SLIP & CUT DL. CON'T RIH W/RET TOOL. T/TOF @11001. MU KELLY. WORK INTO PBR. ENGAGE PBR RETRVNG TOOL. RELEASE K ANCHOR. POOH W/RETRVNG TOOL. PU PCKR MILL ASSY, MU BHA RIH T/TOP OF PCKR @ 11021. MU KELLY/WORK PRT INTO PCKR & MILL 11021 T/11023. PUMP HI VIS SWEEP. CLEAN TOP OF SAND PLUG MW: 8.5 Seawater COMP MILL UP PKR T/11024. PKR FELL. CBU. GAS NOTED ON BU. MAX H2S 2PPM. MONITORED WELL/STATIC. CHASED PKR ASSY T/BTTM @11192 POOH W/PRT MILL ASSY. RELEASE PRT. LD.PRT, MILL, FISH, PKR & TAIL PIPE ASSY. FULL RECOVERY + 25 LBS OF METAL F/BOOT BSKTS. PU 6.75" BIT 7-5/8" CASG SCRAPER. MU BHA RIH T/TOP OF FILL PUMPED HI VIS SWEEP/CBU POOH W/BIT & SCRAPER. LD ASSY. PU REV. CIRC JET BSKT. RIH T/TOP OF SAND PLUG @ 11192. MU KELLY DROP BALL & CLEAN TOP OF SAND PLUG. DSPLC HOLE W/SEAWATER MW: 8.5 Seawater WORK REV. CIRC JET BSKT ON TOP OF SAND PLUG @11192. COULDN'T ROTATE-HIGH TRQ. POOH W/REV. CIRC JET BSKT RECOVERED 2 PIECES OF PKR SLIP. LD ASSY. PU 5.75 CRIPPLED BURN SHOLE. MU ROLLIN DOG OVER SHOT/BHA & RIH T/TOL @4382. SLIP & CUT LINE. RIH T/TOP OF SAND PLUG @ 11192. PU CLOSED ANNUL. REV CIRC WHILE WORKED ASSY DOWN F/11192 T/l1200. REVERSE STRING CLEAN. RECOVER 30 LBS METAL PIECES & SAND. POOH W/ OS ASSY, PKR SLIP PIECES, SS BAND MAT'L & RUBBER. LD ASSY. PU TEST PKR MU BHA & RIH T/11164. SET PKR @ 11164. TEST CASG T/3500/30 MIN. UNSEAT PKR & DISPLACE HOLE W/INHIBITED SEAWATER. RUN COMP STRING MW: 8.5 Seawater CIRC HOLE T/CLEAN INHIBITED SEAWATER. TOOH LD DP & BHA. PULL WEAR BUSHING & RU & RUN COMP STRING. RECEIVED AUG 1 0 1994 Aiaska Oil & Gas Cons. Commission Anchomj,~ WELL : DS 9-11 OPERATION: RIG : DOYON 16 PAGE: 3 07/01/94 ( 8) TD:12347 PB:12259 RELEASE RIG MW: 8.5 Seawater INSTALL SSSV/CONTROL LINES. TEST T/5000. OK. RUN 4.5/5.5 & 7" COMP. STRING. INSTALL TBG HNGR. ATTACH 1/4" CL. TEST T/5000. DROP BALL/INSTALL BPV. PU LNDG JT. CHCK. INSTALL 2-WAY CHCK. ND BOPE. NU ADPTR FLNG & TREE. TEST CL/TREE & ADPTR FLNG T/5000. RU & PRESS TBG T/4000/30 MIN. SET PKR. PRESS TBG T/1500 ANNUL T/3500/30 MIN. RELEASE PRESS. PRESS ANNUL T/3000. SHEAR RP. PUMP 5900 GL DIESEL T/ANNUL & U-TUBE T/TBG. SET BPV. SECURE WELL. CLEAN LOCATION. RELEASE RIG @ 02:00 HRS ON 07/01/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED AUG 1 0 1994 Ai~ska Oil & Gas Cons. Commission Anchor~jo ARCO Alaska, Inc. Date: Subject: Fro m/Locatio n: Telephone: To/Location: P.O. Box 100360, chorage, AK June 21, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94048 99S10.~ ~, Number, (M-D-Y) =,/ ,: * ! 5-14A I 7-09-93 ]./ CDN ! 1,2"&5" SCH 9-11 i 6-11-94 ! /-~ Collar i 1,5" Atlas / /il-35 { 5-19-94 i'" Borehole Prof i 1, 2"&5" Atlas ,/" -'11-35 i 5-19-94 !./[~,ual Ind, GR/SP ! 1,2" & 5" Atlas ~ ~ .-11-35 i 5-19-94 1 × SSTVD ! 1,2" & 5" Atlas '%1 .-1'1-35 I 5-19-94 i/'Z-Densiiocj,CN { 1, 2" & 5" Atlas -'15-36 i 6-05-94 i '~. DLL, GR/SP { 1,2"& 5" I Atlas ? /15-36 i 6-05-94 iJBorehole Prof i 1, 5" Atlas ' 1/15-36 i 6-05-94 [... Z.-Densiiocj,CN i 1,2" & 5" Atlas t J15-36 i 6-05-94 i/Comp 4-arm dipio i 1, 5" Atlas '~. i~15-36 i 6-05-94 I/'B.H. C Acous, GR i 1,2"&5" Atlas ~1/15-36 I 6-05-94 I / SSTVD ! 1, 2" &5" Atlas * The .correct APl. # for $-14A is 50-029-20253-01 Number of Records: John E. DoGroy . Distribution- Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska-'-' Mobil D & M PB Well Files Please acknow%e~ng and returning a copy of transmittal. By: Date: ARCO AlasKa, inc. Is a Subsldla,'y of Al]antlcRIchtleldCompany ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, . aorage, AK Transmittal #: 94023 Subject: ARCO C~ From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well !Log Date Number (M-D-Y) 1-24A l 12-24-92 PWDW 101-24-94 ,~'"3-1 i 1-30-94 i 3-20AI 2-2-94 j 3-21 ! 2-4-94 i ! 3-27 ~ 2-3-94 3-32 ~ 1-25-94 4-5 ~ 1-26-94 4-32 ~ 2-2-94 2-6-94 2-6-94 5-35 f 2-7o94 9-9 I 2-7-94 1-26-94 Tool Type I Run, I, Scale 9-11 1-24-94 9-13 1-29-94 9-2O 1-24-94 9-34 1-25-94 11- 2-3-94 16ST1 11-17 2-5-94 12-16A 2-2-94 2-3-94 4-2B 2-4-94 14-31 2-4-94 15-9A 2-6-94 15-22 2-6-94 PFC/GR I 1, 5" Static press/Temp Perf Record 511 5" CompI Record CompI Record Contractor Atlas Sch Sch CNL 1, 5" Sch Perf Record 1, 5" Sch Sch Prod Profile Bridge Plug ~v.. Cutter Compi Record USiT/Oement PDC & Leak Detec Leak Detec Leak Detec ! 5I1 1~ 5II 1, 1"&5" 1, 5" 1 511 Sch Sch Sch Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 2" Sch 1, 2"&5" Sch 1, 1 "&5" Sch ?.~.- 1 5" Sch 1, 5" Sch 1, 5" Sch I 5" Sch 1, 5" Sch ~[~: 1, 1"&5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch Mi Inj Profile Bridge Plug&z, Leak Detec Perf Record USlT/Cement Perf Record Prod Profile Perf Record Perf Record 16-7 6-16-92 Collar 16-22 2-3-94 Gas lift st 16-29A ~ 1-31-94 Prod Log 1, 5" Sch 1, 5" Atlas 1, 1" Sch 1, 1 "&5" Sch * DS# 1-24ST the correct well name is 1-24A ** DS# 11-16ST1 the correct APl# is 50-029-21581-00 Number of Records:32 John E. DeGrey ARCO Alaska, Inc. I$ a 8ub~idlary of AllanllcRIchfl~ldCOal~ny ARCO ,,~l~sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-1-93 REFERENCE: ARCO CASED HOLE FINALS ~-33 10-16-93 '~ 5_.5_~X_2-10 10-22-93 -~_:_t~2-17 10-16-93 2-25 10-15-93 3-9 1~1~3 ~1~ 1~~3 ~~~ 1.12~3 1~~3 .~/~2~ 1~93 x~2~ 1~1~93 ~~~ ~93 ~~ 1~21~3 ~13 1~1~93 ~~~19 1~1~93 ~ 1~21~3 ~~7 ~~93 7~13 1~~3 ~?~19~ 1~7-93 ~ 1~17~3 ~~2-1~ 1.1~3 1~1~3 12-1~ 1~1~93 ~~~ 1~1~93 . 1~1~3 Prod Profile/~, Peri Record B~ o-~¢i¢1 q Rnn Dual Burst TDTP ~o~ ~?~ R~n Prod Profile ~, Gas Lift 1 ¢¢~ ~z=-rnej ~cc~ Run MI Inj Proflle/e~q Prod Profile/~a~ffe~/~r~ Run Leak Detect/~,0 Collar Log i ~-~ ~ ~0 -~9{0 Run UilT(¢¢~t~t+ ~o~ Color Run Leak Detect ~ m~r ~ l Perf Record i Peff Record ~q 0 ~q~©o Run IBP Set.= t~¢~-k-ma.~ ~a~-, ?~'~ Run CNL h~oo --,'3~5o ~ l~n Peff Record ~tSo ~¢/~o Run Leak Detect.,%e,~ Baker IBP I~D IBP Set I%ZoO - Inj Profile 5a ~ t'r~e 1 ¢&~e~- Run USIT/'c~'rost~m ~ Color l~m PeffRecord It~ ~1~7 Run </PerfRecord ~0- 1005o Run ~o~,~ XpeffRecord ~o-ioo5o Rmn Collar (/~c~x ~ Run CCL (Packer) /~2x~-- ~5 l~m Leak Detect/s~m l ~n¢)~ Run IBP Set I'b iff I~-t ~ l~m Completion ~i00-~o Run ~ Detecttse~o Please sign and return the ~ttached copy as receipt of data. RECEIVED BY ~ Have A Nice Day! Sonya Wallace AT(~1529 APPROVED Trans# 93144 # tm~'rKAL ~ #~N #BPX # STATE OF ALASKA 1, ~' Sch 1, ~'~O~Tz~ ~h 1, ~'~' 0-11~0 ~h 1, 1, ~' Atlas 1, ~' ~h 1, ~' ~h 1, ~' ~h 1, ~' ~h 1, 1"~' 0-~osE ~h 1, ~' ~h 1, ~' ~h ~h ~h ~h Aths Atlas ~h ~h ~h ~h 1, 5" 1, 5' 1, 5' 1o 5' 1, l"&5" 1, 5" 1, 5" 1, r' .xo-2 w$ * The correct APl# for 9-7 is 50029-20223-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~'~D~FINALS 4-24 ~- ~01 ~10-10-93 . 2/6-4`/ 9-30-93 -~%~ ~-4~ 10-1-93 6-12A ~- ~ ~9-29-93 I/9 ~ ~0 6-13 10-1-93 7-5 7~-~ 10-6-93 -28 10-9-93 -2S 10-9-93 9-11 9/~ ~ /10-4-93 9-13 /10-3-93 9-20 -;7-~ ~ ~ 10-7-93 ~10-1-93 12-22 B0/~0 /9-28-93 /13-2o ~o-2-93 ~.~ ca <-13-20 / 10-10-93 14-3 lx~ ?~.~ ~ ~-25-93 14-3 ~ ~-28-93 ~Z~ 14-32 ~10-2-93 15-22 ~~ ~9-30-93 ~ ~ ~016-17 ~ 10-8-93 16-22 ~ ~10-10-93 ~-l~ 17-15 ~ 10-8-93 *** 17-16 ~1-~ 40-3-93 17-21~L~ ~10-4-93 Perf Record Run P~r~fJlla~rd Run USIT [¢~- ~~"' "-' ~Color Run Perf Record I~1~-~/~7 Run Perf Record ~ ~co - ~ ~ R~ Completion R~ Pe~ Record R~ lnj ~offie J~~/~l~ R~ ~ak ~tect ]5~x~]~]~/~ R~ Perf Record ~ 1 ~v~ - ~ 1 ~ ~% R~ Perf Depth Control/~,! Completion Leak Detect ~Prod Proffie/~a /Completion ~ Prod Profile ~Dual Burst TDTP Leak Leak Detect/~al~ Inj Profile Dual Burst TDTP Patch ~tting InJ Profile C~TG/GR/CC~ Prod Proffie/ Completion Completion Inj ~oduction Please sign and return th~ attache.d copy/, r~ceipt of data. RECEIVED BY ~~ Have A Nice Day! $onya Wallace ATO-1529 * *mm # CENTRAL FILES # CHEVRON # BPX # STATE OF AIASKA The correct API# for 1-22 is 50-029-20848-00. The correct API# for 11-16ST is 50-029-21581-00. The correct API# for 17-16 is 50-029-22286-00. STATE OF ALASKA ALASKA ·AND GAS CONSERVATION CC ..... fISSION REPORT SUNDRY WELL OPEHATIONS 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 1463' FSL, 50' FWL, Sec. 1, T10N, R15E, UM. At top of productive interval 1306' FSL, 1086' FWL, Sec. 6, T10N, R15E, UM. At effective depth 1210' FSL, 1493' FWL, Sec. 6, T10N, R15E, UM. At total depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R15E, UM. 12. Present well condition summary Total depth: measured true vertical 12347 feet 9070 feet 5. Type of Well DevempmentX Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-11 ~' 9. Permit number/approval number 76-84 10. APl number 50 - 029-20236 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill @ 12191' MD (10/7/92) feet Effective depth: measured 12191 feet true vertical 9057 feet Junk(measured) SST Tool: stuck @ 12171' MD. Casing Length Conductor 80' Surface 2702' Production 11595' Scab Casing 6813' Liner 1060' Scab Liner 1063' Perforation depth: Size Cemented Measured depth True vertical depth 20" 500 Sx Cement (approx) 80' 80' 13 3/8" 5650 Sx AS 2702' 2702' 9 5/8" 1000 Sx Cl 'G' & 300 Sx AS 11595' 8750' 7 5/8" 643 Sx CI 'G' 4402 - 11200' 4306 - 8526' 7" 450 Sx CI 'G' 11282 - 12342' 8575 - 9126' 4 1/2" 82 Sx CI 'G' 11208 - 12257' 8531 - 9088' measured 11782 - 11786'; 11804- 11814'; 11910- 11916'; 11928- 11936'; 11984 - 11996'; 12043 - 12060'; 12096- 12110'; 12117- 12121'; 12153- 12159'; 12175 - 12185' true vertical 8854 - 8857'; 8867 - 8872'; 8923 - 8926'; 8931 - 8935'; 8960 - 8966'; 8990 - 8998'; 9016 - 9021 '; 9024 - 9026'; 9041 - 9044'; 9051 - 9056' Tubing (size, grade, and measured depth) 7", 29#, L-80, 7 x 4 1/2" X-Over @ 2890' MD; 4 1/2", 12.64t, L-80, PCT @ 11145' MD. Packers and SSSV (type and measured depth) Baker '4H' Packer @ 11037' MD; 7" Camco BaI-O .S~V~(t)~.206' MD. 13. Stimulation or cement squeeze summa~ ~ ~ ~ ~ - Intewals treated(measured) see A~ached Treatment de~ription including volumes used and final pressure 14. Representative Daily Averaoe Produ~ion or Ini~ion Data m~' ....... OiI-Bbl Gas-M~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1535 3522 3~4 - 332 Subsequent to operation 1734 ~-' 4364 ~- 5686 348 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ~.. 16. Status of well classification as: Oil X..~. Gasm Suspended..--. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'~ F'~/ '~' ~'"~ ~""~ ~' ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 LW cc: SW, JWP. SUBMIT IN DUPLICATE 9-11 DESCRIPTION OF WORK COMPLETED SELECTIVE ACID STIMULATION USING SST TOOL 10/2/92: RIH & tagged bottom at 12152' MD. 10/3/92: RIH w/CT & performed a fill cleanout from 12152' to 12202' MD. Rigged down. 10/7/92 - 1018192: MIRU & PT equipment. RIH & tagged bottom at 12191' MD. Loaded wellbore w/Dead Crude, then RIH w/CT mounted SST Tool & inflated sealing elements to straddle at 12153 - 12156' MD, to selectively stimulate the perforation interval at: 12153 - 12159' MD (ZIB) Ref. Log: BHCS 4/20/77. Pumped 11 bbls 7.5% HCI w/10% Xylene @ 0.8 bpm, followed by 11 bbls 6% HCI - 1.5% HF, followed by 25 bbls 1% NH4Cl Water & 11 bbls Meth Water for acid displacement, followed by Shutdown. Resumed pumping 54 bbls 1% NH4Cl Water, followed by 14 bbls 50% Diesel/50% Xylene @ 0.9 bpm, followed by 38 bbls 1% NH4Cl Water displacement, followed by Shutdown. Attempted to deflate SST packers, but failed at several attempts to release tool. Made failed attempts to jar SST free, then resumed pumping 51 bbls 7.5% HCl w/10% Xylene @ 0.4 bpm, followed by 53 bbls 6% HCI - 1.5% HF, followed by 350 bbls 1% NH4Cl, followed by 70 bbls 50% Diesel/50% Xylene, followed by Shutdown. Attempted several more times to free SST tool with no success, then lost all pump rate down CT. Pumped 350 bbls Dead Crude down CT annulus & flowed well back to surface in attempt to free SST. Disconnected & POOH w/plugged CT, leaving stuck SST in the well. Rigged down. 10/11/92 & 10/22/92: Made failed SST Tool fishing attempts. Made a final tag on top of SST tool at 12171' MD. Returned the well to production w/gaslift & obtained a valid production test. ARCO .a*~_-s~rs, Inc. P.O.Box 100360 Anchorage, Alaska ~510 DATE: 9-18-92 REFERENCE: 7-31-92 lnJ Profile Run 1, 5" Cnmco 7-31-92 lnJ Profile Run 1, 5" C~mco 8-1-93 Prod Profile Run 1, ~' C~mco 8-2-92 Prod Profile ]am 1, 5" C.~mco 741-92 ~ Run L 1~ Cnmco 8-4-~ lnJ Profile Run 1, ~' C~mco 8-,14)2 Prod Profile Run 1, ~' Camco 7-30-92 Prod Profile Run 1, I~' Camco 7-31-92 (IR Run 1, 5" C.~mco 8-3-92 Prod Profile Run 1, 5" C.~mco Please sign and return tl~.e attach~l copy u receipt of dat~ RECEIVEDB~~ .... , Sonya Wallace 0 5 1992 APPROVED ATO-1529 OCT Trans# 9220-~'~g/--- Alaska 0il & Gas Cons. Commission Anchorago # CE1TI'~ ~ # CItEVRON D&M # EXTENSION EXPLORATION # EXXON ]~L~J~V,A'I'HON # MOBIL # PBIL~ PB W~3.~'. FILES R&D # BPX # STATE OF ALASKA 'I~ * The correct well name is 16-29A not 16-298T. STATE OF ALASKA ALASKA~'--"_ AND GAS CONSERVATION C(-' VllSSION 0 ~ I G INA I, REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate. Plugging Perforate X 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 1463' FSL, 50' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1306' FSL, 1086' FWL, Sec. 6, T10N, R15E, UM At effective depth 1210' FSL, 1493' FWL, Sec. 6, T10N, R15E, UM At total depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-11 9. Permit number/approval number 76-84 10. APl number 50 - 029-20236 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12347 feet Plugs(measured) 9070 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2702' Intermediate 11595' Liner 1060' Liner 6813' Liner 1063' Perforation depth: 12262 feet 9031 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 500 sx cmt (approx.) 80' 80' 13-3/8" 5650 sx AS 2702' 2702' 9-5/8" 1000 sx CL 'G' & 300 sx AS 11595' 8750' 7" 450 sx CL 'G' 11282-12342' 8575-9126' 7-5/8" tieback 643 SX CL 'G' 4402-11200' 4306-8526' 4-1/2" 82 sx CL 'G' 11208-12257' 8531-9088' measured 1 1782-11786';11804-11814';11910-11916';11928-1 1936';11984-1 1996';12043-12060'; 12096-121 10';12117-12121 ';12153-12159';12175-12185' true vertical 8854-8857';8867-8872';8923-8926';8931-8935';8960-8966';8990-8998';9016-9021 '; 9024-9026';9041-9044';9051-9056' Tubing (size, grade, and measured depth) 7",29#,L-80,7" x 4-1/2" x-over @ 2890' MD; 4-1/2",12.6#,L-80, PCT @ 11145' Packers and SSSV (type and measured depth) Baker '4H' pkr @ 11037' M D,Camco 'BaI-O' SS~Vi~(,,?2~61' ~I/E F~ 13. Stimulation or cement squeeze summary Intervals treated(measured) S E P - ~ 1~992 Treatment description including volumes used and final pressure Alaska 0il & 6as Cons, 60mmiSSi01~ ~nchora_oa 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 980 × 3528 3474 - 330 Subsequent to operation 1600 ¢~' 4000 3733 - 345 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~. ~ Title FS-2 Regional Operations Engineer Form 10-404 Rev 06/15/88 SUBMI'F~N~)UPLICATE~ ALY REPORT OF WELL OPER~ ,ONS DS 9-11 Perforating Operations: ARCO Alaska, Inc. perforated DS 9-11 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 7/13/92. The intervals perforated were the following: 11782'-11786'; 11804'-11814'; 11910'- 11916'; 11928-11936' and 11984'-11996' MD (Reference Log: SWS-BHCS dated 4/20/77). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 7/13/92. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, okay. S.I. well, RIH and perforated 11984'-11996' MD at 1 SPF, Logged up and perforated 11910'-11916' MD at 2 SPF, POOH, and confirmed all shots fired. RIH and perforated 11782'-11786' MD at 2 SPF, POOH, and confirmed all shots fired. RIH and perforated 11928'-11936' MD at 1 SPF, Logged up and perforated 11804'-11814' MD at 1 SPF, POOH, and confirmed all shots fired. (ref: SWS-BHCS of 4/20/77). Rigged down and secured well. RDC: 8/13/92 RECEIVED Alaska Oil & Oas Cons. Commission Anchorage ARCO .~l~sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 S° ~>~ 7-12-92 CCL/Perf Run 1, 1-13 ?~ 7-18-92 CCL/Perf Run 1, 2-31 7-6-92 Prod/Press/Spin/Temp/Trap Run 1, 3-10 ~-~-/ 7-6-92 CCL/Perf Run 1, 3-35 7-13-92 C~L/Perf Run 1, 9-11 ?~..~o~/ 7-13-92 CCL/Perf Run 1, 11-7 3/-/~ 7-11-92 CCL/Tubing Cutter Run 1, t 11-16ST 5-30-92 MAI Acoustic Filtered Waveforms Run 2, 11-16ST 5-30-92 BHC MAI Comp Slowness Curves Run2, 15-9 7-13-92 Collar/Perf Run 1, 17-3 7-12-92 CCL/Perf Run 1, NGI-11 7-19-92 CCL/Tubing Cutter Run 1, Please sign and return the attached copy as receipt of data. RECEIVED BY .~~e~~~_~___ Have A Nice Day! Sonya W~ll~_ce ATO-1529 ~' Atlas 5" Atlas 5" Sch 5" Atlas ~' Atlas 5" Atlas 5" Atlas 5" Atlas 5" Atlas 1~' & 5" Atlas 5" Atlas 5" Atlas ~' Atlas 5" Atlas 5" Atlas # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO R£CEIVED AUG 1 0 199?- Alaska Oil & Gas cons. Commission A~chorage TO: THRU: FROM: ,',, .~ ":,.~Lonnie C. Smith .. " Commissioner .. · . . ~., · ?, , .; .. ·. . .. '.. ~' i!:~-Doug Amos..._ - _ ., ~ ',: "Petroleum ' InsPector : · ,,..., .:', DATE: .' FILE NO: TELEPHONE NO: sUBJECT: July 1, 1990 JT.DA. 726 Safety Valve Tests AAI PBU Drillsites Prudhoe Oil Pool , Tuesday June 19~ '1990: I traveled this date from Anchorage to AAI's PBU to stand by for the Safety valve retests on the following drillsites: 2-5,9,11-13,15,17 and Lisburne L1. ~ednesday. june 20'thru 'Monday June 25, 1990: The testing commenced each morning at 7:00 a.m. and was concluded each evening at 7:00 p.m. I shut in.the following wells because of a second failure on equipment that failed on the initial test: DS9-4, 11 and 33, DS 13-21, DS17-4 and 7. Ail wells shut in with the exception of well 17-4 were repaired and retested by me on 6/23 and 6/25/90. I checked on well 17-4 before leaving PBU on 6/25/90 and wireline work to replace the SSSV was still in progress. An AOGCC safety ~alve test report for all drillsites retested is attached along with a report for the retests of the shut-in wells. The following is a list of the equipment retested and the resulting failures: '"~ .~ Pilots Tested - 18 . Pilots Failed - 0 SSV's Tested - 22 SSV's Failed - 3 SSSV's Tested , 38 SSSV's Failed - 7 In summary, I witnessed the safety valve retests at AAI PBU Drillsites 2-5,9,11-13,15,17 and Lisburne L1. .. · . ~ "' '~ - ' .~' .',. '- ' At t a chment . .' ~ · · . '~ , , : .., .., ~ :-, ~ ..... : .-,:. _. ~. t . . ~ '...,'~?~: .~.' ... "' ' '"'. ' . i-..'"?'- --.- ':'.-~,~' ' - " ., .. ~. .( .:~:'~..,..,. -,.~ - , ' .. .- .. , . ~' ~ ,, '- , · ~ ~' . "~ : ~, ...- ~ 'x; '~: .,-j..~ ''- ... ~ ; :. ': .:~ ' . ' · .. , -. 02-~IA (mC. m9) ;:':-'"" : :.. .- ~ ~gMOI.PM3 . . REP~E~TATIVE: ~.-i~e. F~'~¢~ '' I I ss~~ I ss~ s~s~= I sss I~1 I(~o~)1 T~e"l T~e I ~-I r~ ~I~S~ ~l.r~l~S~l~l I I . I ......... I.. I ".""' I,,':', "'i,I' :,~,1%1_1 I I...~: i~:---.",- ;I.:~,..,',, , I, ! I I I I ' I ~1 I '1 I' I I~1 I I ..-;1':- .I .... I I. ,:ILl .... . , .,_, I I I I I I I~-'~'' ,--iI- I~, I I I .I -I I ;I I I · I I '1~-~ .I '1 . ...~1 .... I I I '1 ~1 ..... I i. I I, I I I I I I I I I REHARKS: I I I .o I , I I I . I', I~! .... I'_1 I I I II I '-I I'," ~l 't ~ 'Il , I ...... I~1 .... I I I I I I I , ,I ...... I~l I_l I I t I II I I I' I II I I~l ......... I, I_l I I I I II I..,l~l~l ,, I_l I I I I II I I I I II I . I 'l~l I_l I I I I II I, I~l I,,,l_l I I I III I I~l~l I_l I I I I II I I ,l~l I_l I I I INSPECTOR ARCO AI..A3'KA, INC., P.O. BOX i00;S60 AiHCHORAGF_', ALAS'KA 995i DATE' 6/20/90 RFF--E~F;.:IENCI:-:' AF;,:CO CASED HOLE FINAL~',S' i;, "" ":' 5- 2 :-3 - ':.:;"3P R 0 :() LJ C T I ri N F' F;.'. 0 I-':' I' L E-- ;~' L.I R V E.::. Y R U N i '::.'" ~ :;.~. '..' ..... .~ ....-' o._,.-.,,. ,.. 6_'~..~,:.;,;.':-~. ,. , ,, TEHPERATURE LOC- Rl..ii".J.. 'i ,':"..,. 9-.4 6-3-90 TEHF:'EF.:ATURE L. OG R U i'.! 'C-.' c,- , ,, , -.., ,.':) - L3.-':-') 0,. 'f'E MPERA'F U RE S IJ I;.'. v IE Y RI_Ii-,!. ':,-'-'-6 di,-.7';-c;'''''~ TEHPERATURE £~'LIK'VE..:Y Ri. IN i '::" ; .,... . i . . 9-9 6-4-90 TEi'iPERA'i'LIRE I..CI(.~ I:::lJi',! t , o_.~., , i6 --- .4 - ":',':',, ,, 'I'EHF'ERATURE LOG. ..... F:..'I liq i , ~.." 9-i,..,° 6.,.a-~;';:',, , .., TEi'iF'ERATtJRE SI..IF,:VEY RUN.. i '..:,'- "' ,':'~ 6 .-4 9(::, i'Ei"-i!::'ERATURE L. Ci[¢ RIJN i ~" .,..-,~ .,..., o_o4 6-4-90 '¥1.EHPERA'¥1 iF.'.E ;~URVE"f RUN z ;~.. "'*' .. . o_..':. ,:.'... ~..., /;-a-on.; , ... TFHPERATIIF;.:[:' LOG RUN t, ":'";. i2-4A 5--:3(E)--90 LEAK DETECTION. RUN. i , '~'., i 5-7 _"~ -- :q ¢ -- c;' O,. . , TEHF'/£'F']:NNI_:-ER. G/'L. ,?:,'IJRVEY.. RUN i , ..,.':~'" C: ,'::~ ri C 0 C. A ."'-i C 0 C A i"i C 0 C': A H (3 (:) C ~':':i r'i [::: C A/'i C 0 C A r-i C: 0 C]A i"i C (.'.'1 C A ~:,i C 0 :3 A i',I C (] ;; F-', r,i C 0 C A H C El PLEA,?E SIGN AND RE'i'URN T14E A'FTACHED COF'Y A,? RFJCEZF'F OF; DATA. REC R I!"' r:.. E ]1 V :.._r:' T':, ,.f-': y' ,," ~ JUN ~ 2 1990 ~E ,.~ NICE DAY! :.'..:: A L L. Y H 0 F F:' F C K E F.: Alaska. Oil & 6as Cons. 60remission A T 0- '~ '.:;'2 9 Ancl~omge A F' F'R 0 V E ......... '1'RAN$:~ o,.:~o,~ z, · : DISTRIBUTION · ,,-'"' CENTRAl_.. . F'ILEZ ~,- C H E V R C] N D & M .:JJ:EXTEN,_9ION EXPLOR'ATION :~ EXXON MARATHON $ MOBIL · ,- F'H I 1.. L. I F'$ l::'B WE";L.L. F'I LES' R & D · ,,-'"' B P X '"' ~;TA'i-E OF ALA.?KA 'ir TEXACO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION · REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging __ Re-Perforate X Alter casing X Repair well Pull tubing X Other ,~ Workover 2. Name of Operator ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1463' FSI, 50' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1306' FSL, 1086' FWL, Sec. 6, T10N, R16E, UM At effective depth 1210' FSL, 1493' FWL, Sec. 6, T10N, R16E, UM At total depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R16E, UM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Se~ice 6. Datum elevation (DF or KB) 72' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-11 9. Permit number/approval number 76-84/9-1024 10. APl number §0-029-20236 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 12347' 9070' feet feet Plugs (measured) None Effective depth: measured 1 2262' true vertical 9031' feet feet Junk (measured) None Casing Length Conductor 8 0' Surface 2672' Intermediate 1 1 568' Production Liner 1060' Liner 6813' Liner 1063 Perforation depth: measured true vertical Size 20" 13-3/8" 9-5/8" # 7-5/8"tieback 4-1/2" 12043'-12060', 12175'-12185' 8930'-8938', 8992'-8997' Cemented 500 sx cmt (approx.) 5650 sx AS cmt 1000 sx Class G & 300 sx AS cmt 450 sx Class G 643 sx Class G 82 sx Class G 12096'- 12110', Measureddepth 87' 2702' 11595' 11282'-12342' 4387'-11200' 11194'-12257' 12117'-12121', True vertical depth 87' 2702' 8691 ' 8518'-9068' 4288'-8470' 8466'-9029' 12153'-12159', 8955'-8962', 8965'-8966', 8982'-8985', Tubing (size, grade, and measured depth) 7" / 4-1/2", L-80, tbg w/ tail @ 11145' Packers and SSSV (type and measured depth) Camco 'BaI-O' sssv @ 2206', Baker '4H' pkr @ 11037' 13. Stimulation or cement squeeze summary RECEIVE ,'; See Well History for further details Intervals treated (measured) Perfs f/11780'-12185' Treatment description including volumes used and final pressure 240 bbls 12% HCI & 165 sx Class G ARC cmt Gas Cons. CommissiOn 14. N/A Prior to well operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Subsequent to operation Attachments *Workover Well Histories & Copies of Logs and Surveys run __ Addendum Daily Report of Well Operations X* 16. Status of well classification as: Water Injector.._ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Re~ 05/17/89 Title Drilling Analyst Date SUBMIT IN DUPLICATE feet ADDENDUM WELL WORK LOG Well # 9-1 1 Date: 3/25/90 & 3/26/90 Work performed: RUN GR LOG. RE-PERFORATE WELL Cost: ~ AFE: AS3170 Time Summary 1000 1900 2100 2330 MIRU, PT rams & lub to 3000 psi, RIH w/CCL & GR. Tag PBTD @ 12626'. Log up. RIH w/ 3-3/8 x 20' switched (60/120° phasing, 4 spf). Log up, tie-in. Park CCL. Shoot gun #lA f/12175-12185', shoot gun #lB f/12153-12159'. All shots fired RIH w/ 3-3/8 x 20' (60/120° phasing, 4 spf). Log up, tie-in. Park CCL. 3/26/90 0052 0300 O420 0605 0730 1000 Shoot gun #2 f/ 12117-12121. All shots fired RIH w/ 3-3/8 x 20' (60/120° phasing, 1 spf). Log up, tie-in. Park CCL. Shoot gun #3 f/ 12096-12110. All shots fired RIH w/ 3-3/8 x 20' (0° phasing, 1/4 spf). Catch flag, tie-in. Shoot gun #4 f/ 12043-12060. All shots fired. Perforated: 12043-12060 w/ 1/4 spf 12096-12110w/ 1 spf 12117-12121 w/ 4 spf 12153-12159 w/ 4 spf 12175-12185 w/ 4 spf 0° phasing 60/120° phasing 60/120° phasing 60/120° phasing 60/120° phasing SUPERINTENDENT ARC,., Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday afte~ a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO ALASKA INC. PBU JCounty. parish or borough Leaseorun~ORTH SLOPE Title ADL: 28345 WORKOVER IState AK DS 9-11 lWell no. Auth. or W.O. nO.As3170 API: 50-029-20236 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. JDate Complete record for each ~yreported POOL 102 12/24/89 J ARCO W I 21.0000 IHour Prior status if a W.O, 0400 HRS 12/24/89 ( 1) RU TO KILL WELL MW: 0.0 TD: 0 RD AND MOVE TO DS 9-11. ACCEPT RIG @ 0400 HRS, 12/24/89. PB:12262 FIN FILLING PITS W/ SEAWATER AND RU. TREE TO KILL WELL. SUPV:RO DAILY:S45,760 CUM:$45,760 ETD:S45,760 EFC:$1,282,500 12/25/89 ( 2) ND TREE MW: 0.0 FSW TD: 0 REPAIR LEAKS AND PUMP THROUGH LINES. PULL BPV. TEST LINES PB:12262 TO 2500 PSI. KILL WELL. MONITOR WELL. SITP 0 PSI. FILL SUPV:RO HOLE EVERY 15 MIN. TAKING 100 BPH. SET BPV. ND FMC TREE. DAILY:S47,728 CUM:$93,488 ETD:S93,488 EFC:$1,282,500 12/26/89 ( 3) LD 7" TUBING MW: 0.0 FSW TD: 0 FINISH ND FMC TREE. BU BOP'S. CHANGE RAMS, TEST BOP'S AND PB:12262 CHOKE MANIFOLD TO 5000 PSI. TEST HYDRIL TO 3000 PSI. PULL SUPV:RO BPV. FILL HOLE. MONITOR WELL. RU AND TEST 9-5/8" X 13-5/8" ANNULUS TO 2000 PSI F/30 MIN. OK. MU TRI STATE SPEAR(7") AND STAB INTO HANGER. RU CAMCO SPOOLING UNIT. POOH LD 7" TBG. DAILY:S31,922 CUM:$125,410 ETD:S125,410 EFC:$1,282,500 12/27/89 ( ¢) PU 3~1/2" OS.RIH W/OS MW: 0.0 FSW TD: 0 WORK ON POWER TONGS AND LD 7" TBG. CHANGE TONGS AND PB:12262 ELVATORS. LD 5-1/2" TBG. BREAK DOWN 7" SPEAR. LOAD PIPE SUPV:RO SHED W/ DC'S AND 3-1/2" DP. MU BHA. PU 3-1/2" DP AND RIH. RECOVERED 88 JTS 7" TBG. RECOVERED 23 JTS 5-1/2" TBG. RECOVERED 26 CLAMPS AND 4 SS BANDS. RECOVERED 1-7" SSSV AND 1-GLM. DAILY:S36,398 CUM:$161,808 ETD:S161,808 EFC:$1,282,500 12/28/89 ( 5) RELEASE AND LD OS MW: 0.0 FSW TD: 0 PU 3-1/2 DP AND RIH W/OVERSHOT(OS).TAG FISH @ 4820'. PULLED PB:12262 28,000# OVER STRING WT. 5-1/2 PARTED. POOH W/10,000# GAIN. SUPV:JC LD OS AND 15 JTS 5-1/2" TBG. MU BHA AND RIH. TAG FISH @ 5410'. PARTED FISH W/23,000# OVER STRINGWT. POOH W/6000# GAIN. CIRC OIL OUT OF DP. POOH. REPAIR BREAKOUT TONG HYDRAULIC CYLINDER. POOH LD OVERSHOT. ** DAILY AND CUMULATIVE COST BETWEEN THIS REPORT AND REPORT FROM RIG WILL DIFFER BY 168,000. ADDED 20K F/ICE RD AND 148K FOR STDBY ON THIS REPORT. RIG WILL ADJUST TOMORROW. DAILY:S200,197 CUM:$362,005 ETD:S362,005 EFC:$1,282,500 12/29/89 ( 6) RIH W/ 4-3/4" SPEAR MW: 0.0 FSW TD: 0 LD 5 JTS 5-1/2" TBG. PU SPEAR, 6 3-1/8" DC'S AND REST OF PB:12262 BHA. RIH. WORK INTO FISH 40'. PUMP 75 BBL HEC PILL. PULL SUPV:JC 30K ON FIST. FISH PARTED W/SK WEIGHT GAIN. POOH. LD 5 JTS /l~v ~n,~ 5-1/2" ~o~ ur, ~u~ o~T~ o~r~ LI~E RIH The above is correct ....... ' Signature %'~. ___~.._._ ........... ~ate RIC FOR::~: ......... ~_,! CCST FOR RIC :TANDDY ~%~k~ ICEROAD TOD Y. DAILY COST ~pR~;~;; REPORT WILL DIFFER FROM For form preparat, .... d distribution. Ofiiiing see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR38-459-1 -D INumber all daily well history forms consecutively Page no. as they are prepared for each well. ~ ARC,.. Jil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a dr stem tests sequent a y Attach descr ption of al cores Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report off c a or representat ve test on "Final" form. 1 Submit "Interim" sheets when filled out bul not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and fo ow ng se ting of oil slrin§ until completion. District ARCO ALAS[4_A INC. lC .... Y°rPar'~)RTH SLOPE IS .... AK I I Lease or UnitDS 9-11 Complet ...... d for ei~'O~aY ~)i,~12~ drilling ..... k .... in prog .... Field Date and depth as of 8:00 a.m. PBU 12/30/89 TD: 0 PB:12262 SUPV:JC 12/31/89 TD: 0 PB:12262 SUPV:JC 01/01/90 TD: 0 PB:12262 SUPV:JC 01/02/90 ( TD: 0 PB:12262 SUPV:JC 01/03/90 ( TD: 0 PB:12262 SUPV:JC 10) 11) RIG REPORT (MADE ADJUSTMENT YESTERDAY) BUT TOTALS ARE SAME. SHOULD TRACK FROM HERE ON OUT. DAILY:S33,984 CUM:$395,989 ETD:S395,989 EFC:$1,282,500 RIH W/FTA ~6 MW: 0.0 FSW SPEAR 3-1/2" TBG @ 5804' MD. PULLED INTO W/ 28000# PULL. POOH. LD 5 JTS 5-1/2" TBG. RIH W/ FTA #5. SPEAR FISH @ 6001' MD. PULLED IN TWO W/30000# PULL. POOH. LD 1GLM & 4 JTS 5-1/2" TBG. RIH W/ FTA #6. DAILY:S31,893 CUM:$427,882 ETD:S427,882 EFC:$1,282,500 RIH W/ FTA #8 MW: 0.0 FSW SPEAR 5-1/2" TBG @ 6189' MD. PULLED IN TWO 2/ 15000# PULL. POOH. LD 6 JTS TBG. RIH W/ FTA ~ 7. REPAIR DERRICK HEATER. RIH W/ SPEAR. WORK ON DERRICK LIGHTS. W/SPEAR. SPEAR 5-1/2" TBG @ 6426' MD. PULLED FISH IN TWO WITH 22000# PULL. POOH. LD 7 JTS 5-1/2" TBG. CUT DRLG LINE. RIH W/ FTA #8. DAILY:S35,171 CUM:$463,053 ETD:S463,053 EFC:$1,282,500 RIH W/OS SPEAR COMBINATION MW: 0.0 FSW RIH W/ FTA ~8. WORK THROUGH TIGHT SPOT F/ 6688' MD TO 6703' MD. WORK SPEAR 10' INTO 5-1/2" FISH. POOH. REPAIR DERRICK LIGHTS. POOH W/ NO FISH. MU 8-1/2" OVERSHOT (OS) W/ 5-1/2" SPEAR. RIH. WORK THROUGH TIGHT SPOTS F/6688' MD TO 6703' MD. WORK SPEAR 6' OVER FISH TO 6709'. POOH W/ NO FISH. MU OVERSHOT/SPEAR AND RIH. DAILY:S33,065 CUM:$496,118 ETD:S496,118 EFC:$1,282,500 POOH W/ FISH MW: 0.0 FSW RIH. TAG FISH AT 6703' MD. POOH W/ 8000# GAIN. LD 1JT 5-1/2" TBG. CHANGE RAMS. TEST BOPE. MU OVERSHOT/SPEAR. RIH. SLIP DRLG LINE. RIH. TAG FISH @ 6733'MD. POOH W/ 6000# GAIN. NO FISH. CHECK AND CLEAN OVERSHOT AND SPEAR. RIH W/ OVERSHOT AND SPEAR. TAG TOF @ 6733. PU KELLY AND WORK LEFT HAND TORQUE. PULLED 15000# OVER AND PULLED FREE. POOH W/ 8-10K GAIN. DAILY:S32,477 CUM:$528,595 ETD:S528,595 EFC:$1,282,500 POOH W/ FTA #15 MW: 0.0 FSW POOH AND LD 3 JTS 5-1/2" TBG. RIH W/ BHA #14. SLIP DRLG LINE. TAG AND SPEAR FISH @ 6851'. POOH. LD 3 JTS 5-1/2" TBG. RIH W/FTA ~15. TAG AND SPEAR FISH @ 6970' MD. POOH. DAILY:S32,327 CUM:$560,922 ETD:S560,922 EFC:$1,282,500 lWell no. The above is correct . . For form preparation and distribution see Procedures Manuel Section 10. Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well IPage no ARC,. ,Jil and Gas Company {~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially, Attach description of all cores. Work performed by Producing Section will be reported on "Interim'* sheets unlil final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out bu~ not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District County or Parish ISlate ARCO ALASKA INC.Lease NORTH SLOPE I Field or Unit PBU DS 9-11 AK Date and depth as of 8:00 a.m. 01/04/90 TD: 0 pB:12262 SUPV:RO 01/05/90 TD: 0 PB:12262 SUPV:RO 01/06/90 TD: 0 PB:12262 SUPV:RO 01/07/90 TD: 0 PB:12262 SUPV:RO 01/08/90 TD: 0 PB:12262 SUPV:RO Complete record for each day while driHing or workover in progress POOL 102 .2) .3) [4) LS) L6) POOH W/FISH MW: 0.0 FSW POOH W/FISH. BREAKDOWN SPEAR AND LD 17 JTS 5-1/2" TBG. TOTAL LENGTH 672.25'. MU SPEAR AND BHA AND RIH. CUT AND SLIP DRILLING LINE. RIH. TAG TOP OF FISH AT 7642'. PULL TUBING IN TWO. POOH W/FISH. BREAKDOWN SPEAR AND LD 4 JTS 5-1/2" TBG. TOTAL LENGTH 157.45'. RIH W/SPEAR. TAG TOP OF FISH AT 7799'. PULL TBG IN TWO. POOH W/FISH. DAILY:S32,300 CUH:$593,222 ETD:SO EFC:$1,875,722 POOH W/FISH MW: 0.0 FSW POOH W/FISH. RELEASE SPEAR AND LD 3 JTS 5-1/2" TBG. TOTAL LENGTH 118.13'. REPLACE HYDRAULIC GASKET. RIH W/SPEAR. TAG @ 7917'MD. POOH W/FISH. LD SPEAR AND 2 JTS 5-1/2" TBG, 2 PUP JTS, AND 1GLM. TOTAL LENGTH 108.00'. RIH W/SPEAR. TAG @ 8021. POOH W/FISH. DAILY:S33,570 CUM:$626,792 ETD:S626,792 EFC:$1,282,500 CHANGING OUT GRAPPLE MW: 0.0 FSW FINISH POOH W/FISH. LAY DOWN 1JT 5-1/2" TBG. TOTAL LENGTH 39.51. MU BHA AND RIH. SLIP DRILL LINE 24'. RIH. ?U 5 JTS DRILLPIPE AND TAG FISH AT 8064' MD. POOH W/FISH. CUT FISH OFF SPEAR. LAY DOWN 1JT 5-1/2" TBG. TOTAL LENGTH 35.30 (ACTUAL 39.32). MU BHA AND RIH. TAG AT 8104' HD. POOH W/FISH.LD 1JT 5-1/2" TBG. TOTAL LENGTH 39.45. CHANGE OUT GRAPPLE TO 4.805. DAILY:S33,129 CUM:$659,921 ETD:S659,921 EFC:$1,282,500 RIH W/SPEAR/4.9" GRAPPLE MW: 0.0 FSW FINISH MU SPEAR AND RIH. CUT 72' DRLG LINE. SLIP 24' DRLG LINE. RIH AND TAG FISH AT 8143' MD. POOH W/FISH. LD 6 JTS 5-1/2" TBG. TOTAL LENGTH 237.58'. MU SPEAR AND RIH. PU 6 JTS 3-1/2" DP. TAG FISH AT 8381' MD. POOH. NO RECOVERY. MU SPEAR W/4.9" GRAPPLE AND RIH. SLIP 24' DRLG LINE. RIH W/ SPEAR. DAILY:S32,363 CUM:$692,284 ETD:S692,284 EFC:$1,282,500 POOH W/FISH MW: 0.0 FSW FINISH RIH W/SPEAR. TAG FISH @ 8381'MD. POOH W/FISH. UNSPEAR F/FISH. LD 11JTS 5-1/2" TBG. TOTAL LENGTH 455.64'. MU SPEAR AND RIH. PU 15 JTS 3-1/2" DP. TAG @ 8816' MD. POOH W/ FISH SLOWLY. UNSPEAR F/FISH. LD 6 JTS 5-1/2" TBG. TOTAL LENGTH 238.45. MU SPEAR AND RIH. SLIP 24' DRLG LINE. RIH. TAG AT 9054' MD. POOH SLOWLY W/FISH. DAILY:S32,208 CUM:$724,492 ETD:S724,492 EFC:$1,282,500 JWell no. The above is correct For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 AR3B-459-2-B Number all dally well hislory forms conseculively as they are prepared for each well IPago no ARC~, ,Jil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" shoals unld final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil slrin§ un comp etlon. District ~C .... y or Parish iS .... ARCO ALASKA INC. I NORTH SLOPE I AK Field Lease or Unit PBU DS 9-11 Date and depth Complete record for each day w~lile drilling or workover in progress as of 8:00 a.m. POOL 1C2 17) IWell no 01/09/90 TD: 0 PB:12262 SUPV:RO 01/10/90 ( TD: 0 PB:12262 SUPV:RO 01/11/90 ( TD: 0 PB:12262 SUPV:JC 01/12/90 ( TD: 0 PB:12262 SUPV:JC 01/13/90 ( TD: 0 PB:12262 SUPV:JC 01/14/90 ( TD: 0 PB:12262 SUPV:JC 18) 19) 20) 21) 22) The above is correct Si~ at u.(e~-.. ~ For form ~epar~ion and distribution see Proced,.h'es Manual Section 10, Drilling, Pages 86 and 87 RIH W/SPEAR MW: 0.0 FSW FINISH POOH W/FISH. UNSPEAR F/FISH. LAY DOWN 1JT 5-1/2" TBG. TOTAL LENGTH 39.50'. MU SPEAR AND RIH. CUT AND SLIP DRILL LINE. RIH. TAG FISH AT 9094' MD. POOH W/FISH. LD 20 JTS 5-1/2" TBG AND 1GLM. TOTAL LENGTH 453.05. HU SPEAR AND RIH. REPAIR AIR SUPPLY AND SPINNING CHAIN. W/SPEAR. DAILY:S32,031 CUM:$756,523 ETD:S756,523 EFC:$1,282,500 RIH W/4.9" SPEAR MW: 0.0 FSW FINISH RIH W/SPEAR. PU 22 JTS 3-1/2" DP. TAG FISH @ 9947' MD. POOH W/FISH. UNSPEAR F/FISH. RU POWER TONGS TO LAY DOWN 5-1/2" TBG. LD 1 JT 5-1/2" TBG. TOTAL LENGTH 44.6. LOST REST OF FISH. CHANGE OUT GRAPPLE TO 4.9". SLIP DRLG LINE. RIH W/SPEAR. TAG FISH @ 9992' MD. POOH W/FISH. UNSPEAR F/FISH. LD 12 JTS 5-1/2" TBG. TOTAL LENGTH 555.65. RIH W/SPEAR. DAILY:S32,040 CUM:$788,563 ETD:S788,563 EFC:$1,282,500 RIH W/SPEAR MW: 0,0 FSW RIH W/SPEAR. TAG FISH @ 10547'MD. POOH. LD 10 JTS 5-1/2" TUBING AND 1GLM. MU BHA. SLIP DRLG LINE. RIH. TAG FISH @ ll,010'MD. POOH.LD 3 JTS 5-1/2" TBG, 1 - 10' PUP AND GLM. MU BHA AND RIH. DAILY:S31,932 CUM:$820,495 ETD:S820,495 EFC:$1,282,500 ATT STING PKR W/PRT MW: 0.0 FSW CUT AND SLIP DRLG LINE. RIE W/SPEAR. TAG UP AT 11,163. JAR SEAL ASSEMBLY OUT OF PKR. POOH. LD 1-10' PUP, 1JT 5-1/2" TBG, 1-6' PUP AND SEAL ASSEMBLY. LD SPEAR. HU PRT MILL AND RIH. SLIP DRLG LINE. RIH AND TAG PKR AT 11223'MD. SPOT 70 BBL HEC PILL. ATTEMPT TO STING INTO PKR W/PRT. ACTING AS THOUGH SOMETHING LAYING OVER PACKER. DAILY:S32,326 CUM:$852,821 ETD:S852,821 EFC:$1,282,500 MU 5-34" JUNK MILL ON 4-3/4"DC MW: 0.0 FSW POOH W/PRT, MU 8-1/2" METAL MUNCHER MILL. SERVICE RIG. RIH W/8-1/2" MILL. SLIP DRLG LINE, RIH W/MILL. PU KELLY AND 16' PUP. MILL ON JUNK ON TOP OF PKR. NO TORQUE, NOT MAKING ANY HOLE. POOH. LD MILL AND CLEAN BOOT BASKETS. MU 5-3/4" HILL AND BOOT BASKETS ON 1 - 4-3/4" DC. DAILY:S74,786 CUM:$927,607 ETD:S927,607 EFC:$1,282,500 CIRCULATE BOTTOMS UP MW: 0.0 FSW RIH W/5-3/4" MILL. SLIP AND CUT DRLG LINE. RIH W/ 5-3/4" MILL. MILL ON JUNK ON TOP OF PKR AND CLEAN OUT PKR B©RE TO 11,244'. POOH. MU 8-1/2" MILL. TIH. SLIP DRLG LINE. RIH W./8--1./2" MTT=L- M~TTT_ PK? ~!,?78 - 11,229 PACKER RELFAq~'q Pfl~ PA("~'~ TC~ 11 ~AQ'MF~ CIRCULATE Bf] ]bat~ ' ITitle DAILY: $46t801 CUM:$974,4~8 ETD:S974, 408 EFC:$1, 282,500 AR3B-459-2-B Number all dally well hislory forms consecutively Page no as they are prepared for each well ARC,. Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, shew formation name in describing work performed· Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when lilled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until complelion. District ARCO ALASKA INC. ICounty or Par~RTH SLOPE lState AK Field PBU tLease or UnitDS 9-11 lWell no. Date and depth as of 8:00 a.m. 01/15/90 ( TD: 0 PB:12262 SUPV:JC 01/16/90 ( TD: 0 PB:12262 SUPV:JC 01/17/90 ( TD: 0 PB:12262 SUPV:JC 01/18/90 ( TD: 0 PB:12262 SUPV:GLC 01/19/90 ( TD: 0 PB:12262 SUPV:JER 01/20/90 ( TD: 0 PB:12262 SUPV:JER Complete record for e[:~l~ay [v~)il~ drilling or workover in progress 23) 24) 25) 26) 27) 28) SLIP DRLG LINE MW: 0.0 FSW CIRC GAS AND OIL OUT OF HOLE. POOH. LD 8-1/2" MILL. MU SPEAR AND RIH. SLIP DRLG LINE. RIH. PU PKR AND TAILPIPE. POOH. LD PACKER AND TP. MU ROTARY SHOE/JUNK BASKET AND RIH. SLIP DRLG LINE. DAILY:S34,026 CUM:$1,008,434 ETD:S1,008,434 EFC:$1,282,500 POOH W/ 6" MILL MW: 0.0 FSW FINISH SLIP DRILLING LINE AND SERVICE RIG. RIH W/ROTARY SHOE/POOR BOY JUNK BASKET. WASH FILL F/12,085' MD TO 12,128' MD. POOH. MU 6" JUNK MILL AND RIH. WASH AND REAM F/12,128 TO 12,256. POOH. DAILY:S31,364 CUM:$1,039,798 ETD:S1,039,798 EFC:$1,282,500 POOH W/SCRAPERS MW: 0.0 FSW POOH W/6" MILL. MU 7" SCRAPER AND SPACE OUT FOR 9-5/8" SCRAPER. RIH 30 STDS DP. STRING UP NEW DRILLING LINE. RIH W/7" AND 9-5/8'° SCRAPERS TO 12,256'MD. 7" SCRAPER HANGING UP THROUGH PERFORATED AREAS. ll,780'MD TO 12,180'MD. WORK PIPE, CIRCULATE. SHORT TRIP TO TOL. SCRAPER DRAGGING OUT. RIH WITHOUT ANY DRAG. CIRCULATE 70 BBL HEC SWEEP A~OUND. POOH W/SCRAPERS. DAILY:S69,018 CUM:$1,108,816 ETD:S1,108,816 EFC:$1,282,500 RUNNING KINLEY CALIPER LOG FrW: 0.0 FSW FINISH POOH W/SCRAPER AND HILL. LD SAME. RU WESTERN ATLAS. LOGGED 9-5/8" F/11,280 TO SURFACE W/VERTILOG. 7" F/11,980' - 11,280' W/VERTILOG. RIH W/KINLEY CALIPER IN 9-5/8". DAILY:S31,444 CUM:$1,140,260 ETD:S1,140,260 EFC:$1,282,500 RIH W/7" RTTS MW: 0.0 FSW FINISH RUNNING WESTERN ATLAS VERTILOG AND KINLEY CALIPER IN 9-5/8" AND 7". RD WA. RIH W/9-5/8" RTTS AND FO CLOSING FINGERS. RIH BELOW FO'S TO 2506' MD. SET RTTS AND PRESS TST 9-5/8" ABOVE PKR TO 2500 PSI. RELEASE PRESS, POOH, LD RTTS AND FO FINGERS. MU 7" RTTS AND RIH. DAILY:S79,500 CUM:$1,219,760 ETD:S1,219,760 EFC:$1,282,500 RIH W/7" EZSV MW: 0.0 FSW RIH W/7" RTTS TO 11,310' MD. SET RTTS AND PRESS TST 9-5/8" X 7" CASING ABOVE 11,310' TO 2500 PSI. TEST GOOD. RELEASE PRESS, POOH W/RTTS. MU 7" EZSV ON 900' 2-7/8" TUBING AND RIH. DAILY:S32,181 CUM:$1,251,941 ETD:S1,251,941 EFC:$1,282,500 The above is correct,, :igft 'r~~~~n see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supt. AR3B-459-2-B INumber all daily well history Iorms consocutive[y as they are prepared tor each well. Page no ARC.. Oil and Gas Company Daily Well History--Interim Instructiolls: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final complet on Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and fol owing setting o oil str ng until complet on. District Field Date and depth as of 8:00 a.m. County or Parish ARCO ALASKA INC. Leaseor UnitDsNORTH9_11SLOPE Complet ...... d for ~¢3(~i~)~ay ~v(~i~>e drilling ..... k .... in prog .... 01/21/90 ( TD: 0 PB:12262 SUPV:JER 01/22/90 ( TD: 0 PB:12262 SUPV:JER 01/23/90 ( TD: 0 PB:12262 SUPV:JER 01/24/90 ( TD: 0 PB:12262 SUPV:JER 01/25/90 ( TD: 0 PB:12262 SUPV:HMP 29) 30) 31) 32) 33) The above is correct -. For form p~eparat~on and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IState AK Well no. TESTING CASING MW: 0.0 FSW RIH W/7" EZSV. SET EZSV @ 11,745' MD. ATTEMPT TO ESTABLISH INJECTION RATE ABOVE EZSV. PRESS 9-5/8" X 7" TO 2400 PSI, LOST 150 PSI IN 5 MIN. BLEED OFF PRESS. EST INJ RATE BELOW EZSV OF 6 BPM @ 2200 PSI. RU BJ. PUMP ACID TREATMENT OF 240 BBLS 12% HCL FOLLOWED BY 50 BBLS(165 SX) CLASS G(ARC) CMT. DISPL FINAL 10 BBLS CMT @ 1/3 - i BPM. FINAL DISPL PRESS = 2500 PSI @ 1/3 BPM. STING OUT OF EZSV AND SPOT 1 BBL CMT ON TOP OF EZSV. POOH, LD 2-7/8" TUBING. MU 9-5/8" RTTS AND RIH TO 370'. PRES~ TST 9-5/8" CASING. DAILY:S86,537 CUM:$1,338,478 ETD:S1,338,478 EFC:$1,282,500 PULL 9-5/8" PACKOFF MW: 0.0 FSW PRESS 9-5/8" X 7" ABOVE EZSV @ 11,745' TO 2500 PSI. LOST 500 PSI IN 10 MIN. REL PRESS, POOH, LD RTTS. MU 7" RETR BP AND RIH. SET BP @ 11,310' MD. SPOT 15' SAND ON TOP OF BP. POOH. TEST 9-5/8" X 7" ABOVE BP TO 2500 PSI F/30 MIN. GOOD TEST, BLEED OFF PRESS. MU RETR TOOL F/FMC 9-5/8" PACKOFF AND ENGAGE PACKOFF. BOLDS AND PULL PACKOFF. DAILY:S36,945 CUM:$1,375,423 ETD:S1,375,423 EFC:$1,282,500 POOH W/BACKOFF TOOL MW: 0.0 FSW PULL 9-5/8" PACKOFF. RIH W/DP TO 200'. DISPL TOP 200' OF HOLE W/DIESEL. POOH. MU CSG CUTTER ON DP AND RIH. CUT 9-5/8" CSG @ 96' MD. POOH. SPEAR 9-5/8' CSG BELOW HNGR AND POOH. LD 2 JTS 9-5/8" CSG. MU 13-3/8" CSG SCRPR AND RIH. TAG TOP OF CUT JT @ 97' MD. POOH. MU TRI-STATE BACKOFF TOOL AND RIH. SET TOOL AND BREAK CONNECTION @ 145' MD W/50000 FT-LBS. BACK OUT CONNECTION 3-1/4 TURNS. RELEASE TOOL, POOH. DAILY:S32,476 CUM:$1,407,899 ETD:S1,407,899 EFC:$1,282,500 NU BOPS MW: 0.0 FSW LD BACKOFF TOOL. RIH W/SPEAR. SPEAR 9-548" AND FINISH BACKING OUT. POOH, LD CUT JT AND FULL JT. PU 3 JTS 9-5/8" 47# L-80 MOD BTC CSG AND RIH. SCREW INTO BOX AT 145' MD. PRESSURE TEST 9-5/8" TO 2500 PSI F/30 MIN. PU BOPS, SET EMERGENCY SLIPS ON 9-5/8" W/275,000 LBS. CUT 9-5/8" CASING AND INSTALL PACKOFF. NU TBGHD AND BOPS. DAILY:S49,774 CUM:$1,457,673 ETD:S1,457,673 EFC:$1,282,500 POOH W/BRIDGE PLUG MW: 0.0 FSW NU BOPS. TEST 9-5/8" PACKOFF TO 3800 PSI F/30 MIN. PRESS TST 9-5/8" CASING TO 2500 PSI F/30 MIN. MU RETR TOOL F/BRIDGE PLUG AND RIH. TAG SAND ON TOP OF BP @ 11294' MD. REV CIRC SAND OFF OF BP. LATCH BP AND POOH 1 STD. CBU. POOH W/BP. ITitle Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively as they are prepared or each well, Page no ARC._ ,.)il and Gas Company Daily Well History--Interim Instructions: This form s used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work performed. Number a dr stem eats sequent a y Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less lrequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of od string until complelion. District Field PBU Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. NORTH SLOPE Lease or Unit DS 9-11 Complete record for each day while drilling or workover in progress POOL 102 01/26/90 ( TD: 0 PB:12262 SUPV:HMP 01/27/90 ( TD: 0 PB:12262 SUPV:HMP 01/28/90 ( TD: 0 PB:12262 SUPV:HMP 01/29/90 ( TD: 0 PB:12262 SUPV:HMP 01/30/90 ( TD: 0 PB:12262 SUPV:HMP 34) 35) 38) ISlate DRILLING CEMENT MW: 0.0 FSW POOH W/BRIDGE PLUG. MU 6" BIT AND RIH. TAG CMT ON TOP OF EZSV @ 11698' MD. DRILL CEMENT TO EZSV @ 11,770' MD. DRILL EZSV AND CEMENT TO 11,941' MD. DAILY:S68,313 CUM:$1,562,226 ETD:S1,562,226 EFC:$1,282,500 POOH MW: 0.0 FSW DRILL CMT TO 12157' MD. WASH TO 12,259' MD. REV CIRC HOLE CLEAN. TEST SQZ TO 2200 PSI. PRESS BLED TO 700 PSI IN 30 MIN. BLEED OFF PRESS, CIRC BTMS UP. NO FLUID LOSS. POOH. DAILY:S46,367 CUM:$1,608,593 ETD:S1,608,593 EFC:$1,282,500 REVERSE CIRC CMT MW: 0.0 FSW POOH. MU AND RIH W/ll00', 4-1/2" BTC LINER. RIH W/LINER ON 3-1/2" DP. CMT LINER W/SHOE @ 12,257' MD, 7" TIEBACK SLEEVE @ 11,194' MD. SET HNGR AND TYPE 'H' LINER TOP PKR. REL SETTING TOOL, REV CIRC CMT OUT OF DP. DAILY:S32,537 CUM:$1,641,130 ETD:S1,641,130 EFC:$1,282,500 LD DP MW: 0.0 FSW REV CIRC 4 BBLS CMT OUT OF DP. POOH, LD DP. MU 9-5/8" RETR BRIDGE PLUG AND RIH. SET BP @ 4530'. TEST 9-5/8" ABOVE BP TO 2500 PSI. POOH, LD DP. DAILY:S112,081 CUM:$1,753,211 ETD:S1,753,211 EFC:$1,282,500 CLEANING PITS MW: 0.0 FSW POOH, LD DP. DISPLACE TOP 2000' OF WELL W/DIESEL. POOH, LD DP. ND BOPS. INSTALL TUBING HANGER W/BPV AND TEST HANGER SEAL TO 5000 PSI. CLEAN PITS. DAILY:S40,029 CUM:$1,793,240 ETD:S1,793,240 EFC:$1,282,500 AK IWell no. Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. [Page no. AR~,J Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Raport" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space is available. t Accounting cost center code District ARCO ALASKA INC. County or Pa~RTH SLOPE Slate AK Field PBU ILease or UnitADL 28345 DS 9-11 Well no. I Auth. or W.O. no. AS3170 ITitle WORKOVER I API: 50-029-20236 Operator ARCO Spudded or W.O. ~EPT Date and depth as of 8:00 a.m. 01/31/90 ( TD: 0 PB:12262 SUPV:HMP A.R.Co. W. L21 .0000 Date 12/24/89 Complet ...... d ~ch ].d~5 reported Iotal number of wells (active or inactive) on thisj Dst center prior to plugging and bandonment of this well our 0400 HRs[Prlor status if a W.O. RIG RELEASED MW: 0.0 FSW CLEAN PITS. RELEASE RIG @ 1200 HRS 1/30/90. CLEAN RIG AND PREP F/MOVE. SCOPE DOWN DERRICK. DAILY:S25,194 CUM:$1,818,434 ETD:S1,818,434 EFC:$1,282,500 Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ~ffective date corrected The above is collect su t. For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. I Dlvi~Jon of AtlantlcfllchfleldCompany ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the °'lltlflal Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. County. parish or b~H SLOPE Istate Field PRTJ-DHOE BAY Lease or Unit ADL: 28345 T t e WO[:~OVER Auth. or W.O. ho. AS3170 AK API: 50-029-20236 Operator ARCO IARCO w.I 21 . 0 0 0 0 Spudded °r W'O' ~t-~e~PT . IDate 02/27/90 IH°ur 1800 HRS JPri°r status if a w*O' Date and depth as of 8:00 a.m. 02/28/90 ( TD: 0 PB:12257 SUPV:LP 03/01/90 ( TD: 0 PB:12257 SUPV:RWO 03/02/90 ( TD: 0 PB:12257 SUPV:RWO 03/03/90 ( TD: 0 PB:12257 SUPV:RWO 03/04/90 ( TD: 0 PB:12257 SUPV:RWO 03/05/90 ( TD: 0 PB:12257 SUPV:RWO Complete record 40) The above is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 41) 42) 44) 45) NU BOPE MW: 8.5 FSW PICKED UP NABORS RIG 2ES TO FINISH DS 9-11 WORKOVER. CONTINUED WITH SOME RIG MODIFICATIONS. MOVED ONTO DS9-11. PAD NOT LEVEL. TOOK AWHILE TO SPOT AND LEVEL RIG. ACCEPTED RIG @ 1800 HRS 2/27/90. TAKE ON SEAWATER, PU KELLY, LAY HERCULITE IN CELLAR AREA. CHECK WELL FOR PRESSURE. OK. BEGIN ND TREE. DAILY:S20,297 CUM:$1,838,731 ETD:S1,838,731 EFC:$1,282,500 CIRC @ 4512 MW: 8.5 FSW ND TREE AND NU STACK. PULL HANGER. RUN TEST PLUG. TEST BOPE. MU BAKER RETRIEVING TOOL FOR MODEL "G" BRIDGE PLUG AND RIH W/3-1/2" DP TO 2367'MD. DISPLACE DIESEL CAP W/8.6 PPG FSW. CONT RIH AND TAG BP @ 4512'MD. LATCH UP TO BP. CHECK FOR PRESSURE AND FLOW. OK. RELEASE BP. CIRC BOTTOMS UP @ 4512'MD. DAILY:S23,530 CUM:$1,862,261 ETD:S1,862,261 EFC:$1,282,500 BREAKDOWN MILL & SCRAPER MW: 8.5 Few FINISH CBU @ 4512'MD. NO GAS. NO OIL. NO LOSS. POOH W/BAKER RBP. BREAKDOWN RBP RETRIEVING TOOL. MU POLISHING MILL & 9-5/8" CASING SCRAPER AND RIH. TAG TOP OF LINER AND POLISH OFF SAME. PU 182K. SO 180K. CIRC HOLE VOLUME AND TREAT SEAWATER W/EP MUD LUBE. POOH W/MILL & SCRAPER. DAILY:S22,774 CUM:$1,885,035 ETD:S1,885,035 EFC:$1,282,500 RIH W/7-5/8 CASING MW: 8.5 Few 'CHANGE OUT TOP RAMS TO 7-5/8. TEST 9-5/8 CSG, 4-1/2 LINER, LINER LAP TO 2500 PSI F/30 MIN. OK. PU BROWN TYPE PA TIEBACK SEAL ASSF.~4BLY W/3 SETS SEALS 2 JTS 7-5/8 CSG. PUT ON RIGHT ANS LEFT HAND TURBOLATORS IN MIDDLE OF FIRST 25 JTS. PUT TURBOLATORS ON EVERY OTHER JT FOR NEXT 100 JTS. DAILY:S26,925 CUM:$1,911,960 ETD:S1,911,960 EFC:$1,282,500 RIH TO TOL MW: 8.5 FSW RIH W/7-5/8" TIEBACK. CEMENT W/ 643 SX CLASS G, AND SET TIEBACK. F/ 4387'-11200'. RELEASE F/TIEBACK. POOH. CHANGE BHA. RIH AND TAG TOL @ 4387'MD. NO CMT. DAILY:S278,546 CUM:$2,190,506 ETD:S2,190,506 EFC:$1,282,500 CBU MW: 8.5 FSW TAG TOL @ 4387'MD. RU & R~VERSE CIRC AT 4386'MD. NO CMT. POOH. CHANGE BH~.. RIH ~3~ TAG CMT @ 11053'MD. DRILL PLUG AND HARD CMT FORM l1053'MD TO llll8'MD PRESSURE TEST 7-5/8 TO 3000 PSI F/30 MIN. DRILL LANDING COLLAR AND HARD CMT TO ll198'MD. TAG XO. REVERSE CIRE. PLUG OFF BIT. RELEASE PRESSURE. CIRC DOWN DRILLPIPE. PUMP 50 BBL HEC SWEEP. CBU. PU 200K. SQ ~K, DAILY:$24,~O~ CUM:S2~214.815 ~TD~S2:214:R15 EFC:SI~2R2~50~ AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well, Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number alt drill stem tests sequential y Attach descr pt on of all cores Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit nlerim" sheets when filled out but not less frequen ly than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ARCO ALASKA INC. State AK Field PRUDHOE BAY County or Parish NORTH SLOPE Lease or Unit DS 9-11 well no. Date and dept~ as of 8:00 a.m. 03/06/90 TD: 0 PB:12257 SUPV:RWO 03/07/90 TD: 0 PB:12257 SUPV:RWO 03/08/90 TD: 0 PB:12257 SUPV:LP 03/09/90 TD: 0 PB:12221 SUPV:LP 03/10/90 TD: 0 PB:12212 SUPV:LP Complet ...... d f ..... h[~dri~i~ ..... k ....in prog .... 46) 47) 48) 49) 50) LD BHA MW: 8.5 FSW TEST 7-5/8" X 9-5/8" CASING TO 3000 PSI F/30 MIN. POOH LD BHA. PU BHA & RIH. TAG TOC @ ll,198'MD. DRILL CMT F/11,198' TO 11209'. HARD CMT. PUMP HEC PILL POOH. LD 4-3/4" BHA AND PU 3-1/8" BHA. DAILY:S26,681 CUM:$2,241,496 ETD:S2,241,496 EFC:$1,282,500 DISP W/INHIBITED FSW MW: 8.5 FSW PU 3-1/8" BHA W/2-7/8" DP. RIH AND TAG CMT @ 11210' MD. DRILL CMT FROM 11210' MD TO 12211' MD. 11210' MD - 11306' MD CMT STRINGERS. 11306' MD - 12132' MD WASHING. 12132'MD - 12211' MD HARD CMT. AT 12211' MD TORQUEING UP WOULD NOT DRILL OFF. LANDING COLLAR. DAILY:S25,015 CUM:$2,266,511 ETD:S2,266,511 EFC:$1,282,500 LDDP MW: 8.5 FSW CIRC HOLE W/INHIBITED FSW. POOH. TIGHT THRU LINER LAP. PU KELLY AND WORK THRU LINER LAP. STAND BACK KELLY. RIH SLOW LOOKING FOR DRAG. PU KELLY AND CBU. LDDP. DAILY:S22,899 CUM:$2,289,410 ETD:S2,289,410 EFC:$1,282,500 RIH W/4-1/2" TUBING MW: 8.5 FSW LD 2-7/8" DP AND BHA. RU WESTERN ATLAS AND WLIH W/6.6" GR/JB TO ll,180'MD. WLOH. HAD 2, 1/2" PIECES OF SLIP DIES ON TOP OF JUNK BASKET. CHANGE OVER TO 3.625" GR/JB AND WLIH TO 12,185. RECOVERED RUBBER AND CAST ALUMINUM PIECES BUT NO SLIP DIES. RD WESTERN ATLAS. RU AND RUN 4-1/2", 12.6#, L-80 TUBING WITH 7-5/8" PACKER AND GLM'S. DAILY:S284,619 CUM:$2,574,029 ETD:S2,574,029 EFC:$1,282,500 ND BOPE MW: 8.5 FSW/DIESL RIH W/4-1/2" TBG. RU 7" TBG TOOLS. RIH W/7" TBG. PU AND MU SSSV. TEST ALL CNTL LINES TO 5000 PSI. OK. CONT RIH. LAND TBG. SET PACKER. TEST TBG. OK. SHEAR PBR AT 175K. TEST ANNULUS TO 3000 PSI. OK. ATTEMPT TO BLOW OUT SHEAR OUT SUB. NO GO. BLEED PRESSURE. SET BPV (2 WAY CHECK). ND BOPE. (CAMCO 'BAL-O' SSSV @ 2206', BAKER '4H' PKR @ 11037' & TT @ 11145') DAILY:S25,485 CUM:$2,599,514 ETD:S2,599,514 EFC:$1,282,500 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling AR3B-459-2-B Number all daily well history forms consecutively Page no. as lhey are prepared for each well. ARCO (jII and Gas Company Daily Well History-Final Report Instructiolls: Prepare and submit the "Final R~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report compietloll end representative test date in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District IAccounting cost cantor code State AK ARCO ALASKA INC. I County or Parish NORTH SLOPE Lease or Unit ADL: 28345 Title WORKOVER PRUDHOE BAY Auth. or W.O. no. AS3170 Operator ARCO Spudded or W.O. bequn ACCEPT Date and depth as of 8:00 a.m. 03/11/90 TD: 0 PB:12212 SUPV:LP API: 50-029-20236 JA.R.Co. W.I. Date Complete record for each day re~qrted NABORS 2ES 21.0000 02/27/90 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 1800 ERS IPH°r atatu~ if a W,O. I (51) RIG RELEASED CONT ND BOPE. NU TREE. PSI. OK. INSTALL BPV. DAILY:S81,014 MW: 8.5 FSW/DIESL TEST ALL FLANGES AND VALVES TO 5000 RELEASE RIG 1300 HRS 3/10/90. ~ CUM:$2,680,528 ETD:SO EFC:$3,882,014 Old TD Released rig INew TD I PB Depth Date I Kind of rig Classifications (oit, gas, etc.) Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Wel'l no. Date Reservoir Producing Interval Oil or gasTest time Production Oi'l on test Gas per day · Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date ' corrected The abov, i~ ~t3rr~r ' ~ Sig Da Title UIIIIIII~ ~,~MI~. For form preparation and distribution, ~,/ / ' see Procedures Manuel, Section 10, I Drilling, Pages 88 and 87. AR3B-459-3-C 'Number all daily well history forms consecutively I Page no. as hey are prepared for each well. I i Dlvllion of AtlantlcRlchltaldCompany ARCO ALA£'KA, IN(;. P.O. BOX t00S60 ANCHORAGE, ALASKA 995t DATE' 4-4-90 REFERENCE' ARCO CASED HOLE FINAL~ 2-5 3-30-90 2-~8. ~ 3-o4-90_ 2--28 3-24-90 7-27 3-26-90 7-'34 3-~4-°0~ · 9-ti 3-25-90 9-i4 ~-2J--90 9-~4 ~-2~-90 F'RODUCTION LOGGING CBT CET PERF RECORD F'ERF RECORD PERF RECORD & DEF"¥H CONTROL PERF RECORD TBG PUNCHER RUN RUN Ir:UN RUN RUN RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF" DATA. RECEIVED BY ____/~-~_~__~_. HAVE A NICE DAY!~ SALLY HOFFECKER DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO ANCHOF;,'AC;-E: ALASKA DATE' 2-i-90 I-?.E.F!EF:ENCE' AR'CO CAS'ED HOLE · .~-"),"~, t -2n-c.'n ,'-'-n, ..~ PERr' "- .~ ........ L.,,_. L ~-~ R,,' .... . . 4-i ~';..., i -i '~' -- '::' ,::,..,. ,. _ iN. .._.~ E C; ]-'r ."".' ~,~.,. ,.,, ,: ,,' ':.:' ~' :[ N N E R,.,. t;,' I. t N_ . '"-:i::F: I 6 o,':', i'Ei"~P RUi'-! '~ '- '-" i '- '-'" ':; - 9 n it 0 L L A i;: 1:;: ! i N 6 - 2 i - 2 G - 9 G ViE R T ]: L 0 G F;,' LJ i'.i ","-n i - ,i o-.'.;,;.-'~ itFIN~:'~ ~::'1' :[' ~"i~'-J RL::COF'..'D F,'UN I ~..,,,- .... . -.,.. .... ~ ~.. ~....- 2 .. .. .. -' , .' ,, ; ,,..- ~ ~ "' '"-' '::~ - 'i '~ '~ - '~ '? - ':;',':, v E ~',..' 7' .~. L.. 0 G ( ':., 5': / 8" ) F;.'. U N 9- t i 'i - i '7-- 9,3 V L:: R'i' i i_ 0 G ;' 7" ) R U N i i - 6 i C, - '? - 89 F:' E R F F;.'. E C 0 R D R LI i"'-~ .'? i2-i 8 i,:')-7-89 COI_LAR TO ZET AVA F'A'i-CH RUN 'i '.2;-26 i -t ,;E.~- ?,:':) F:' .i: ]-£/,S'F' i NNI.:'_'R RUN 'i 5--''~''''' .~ -' ,",~:', ~'-.r'i RI IN t -4-.'Z'i t -i 4-9,:'::, F'ERF F;,'.EC'ORD R ..IN t 6-2 '! -27-9,:3 C. OLLAR/F'ERF RIJN F'LEA£F SIGN AND RETURN THE A'I"¥ACHF. JD COPY AS' RECEIF'T OF' DATA, I-,,l:.Ul:. I V ED BY HAVIE A NICE DA"'(! SALLY HOF'FECKER ATO-! FEB - 91990 'Anchorag~ APF'ROVED .._~:_ _ ]'RANb':~ 9,.'-], ,."~, b 2 I)I~, RtBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL F'H ILI_IF'Z PB WELL FILEZ R'& D BPX STATE OF ALA£1<A TEXACO I::' :1 _;. H F..' Z HRS (::; 'Y' L. A. ,'".'.: S C H. A'FL..A:i: A"!'i..A F. H t...S' H.'L.S I--t R :_7 HRZ ';"' ,.~ .., H A i'i, AZ AI_,~,~ K ARC(] ..... P., O, BOX t ANCHORAGE, ALASKA 995i DATE' t 2-5-89 REFERENCE:' ARCO CA~ED HOLE FINALS · ,.°-"> =~' ~...,' I t-27-89 COLLAR/F'ERF RUN 4-5 9-2t-89 PERF RECORD RUN 4-5 t ~-".2~-89 PERF RECORD RUN 9-t t t i-26-89 NOISE RUN t~- ~ i6 c,_~, ..t-8~, PERF RECORD RUN t4-28 tt-26-89 TUBING CU1-'I"ER' RUN ~ 5-~ ~ ! -29-89 COLLAR/F'FRF RUN i 8-2 t (:;,-25-89 GAMM~ DSN RUN F'I..EASF' SIGN AND~ETURN//~HE ATTACHED COF'Y A.S' RECEIPT OF DATA. HAVE A NICE DISTRIBUTION CENTRAL FILE.? -,-'"' PHIl_LIPS CHEVRON F'B WELL FI:LE~ D & M R & D EXTENSION EXPLORATION ~: ' BF'X EXXON '" ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL A'i-LrqS HLS I-ILS fILS' A f'LAL.;' A 'f'L A,S' FILS * THE CORRECTED AF'I~ FOR 2-25 IS 5~-~29-2~766, ARCO ALASKA, INC. -- P.O, BOX i00360 ANCHORAGE, ALASKA '995i~ DATE' tt-27-89 17EFERENCE' ARCO CASED HOLE F'rNAL£' ~"1-54 t¢-t4-89 PRODUCTION PROFILE m-2¢ t ¢-25-89 GAMMA DIN ~ 27 8-26-89 PERF RECORD ~'5-i t t-9-89 COLLAR/PERF/PACKER ~ 5-27 t i-4-89 CBT · ¢.' 6-3 t t-2-89 FM TEMP ~4-i4 ti-3-89 F'ROI)UCTION PROFILE ~"-TA t ¢-25-89 F'RODUC't'ION PROFILE '""7-i 7 t ¢-25-89 PRODUCTION F'ROFILE ~'"'",;-2¢ t t-6-89 PRODUCTION PROFILE /?-27 tt-4-89 INJECTION PROFILE //'7-28 t 1-3-89 PITS .¢"7-29 t i 4-89 F'IT3 /7-30 t t ~' ..¢-89 F'IT2' ..7-SS it-5-89 INJECTION PROF]:LE/TEidF' ¢ 9-9 t¢-27-89 PRODUCTION PROFILE ~- 9-.tt t0-28-89 LEAK DETECTION 9-28 t ¢-3¢-89 TEMF'/GR . 9-38 ii-5-89 F'ERF RECORD · ,~- it-5 9-2-89 PERF RECORD ,¢-'it-5 t¢-27-89 PRODUCTION t-ROFILE/I_EAK · *.~i'2-t t i ¢-28-89 LEAK DETECTION ,.,.-.-.,-89 CCL/TEMP ~I2-33 t¢-26-89 INJECTION F'ROFILE ~,~t 4-4 t t -6-89 COLLAR/F'ERF ~-t5-t3 tt-7-89 TUBING CUTTER 4 5-i ,.S i ¢-:28-89 TEMF' . .~. ~..-..')n i I -4-89 CNL ~/'t 7-4 9-8-89 F'ERF RECORD DEl' R U N RUN RUN RUb! RUN RUN RUN I;:lJ N R U N RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN F'LEA;~E &*IGN AND RETUiRN THE ATTACHED COPY A&~ RECEIF'T HAVE A NICE - SALLY HOFFECKER A TO- i 529 OF NOV 7 01989 Alaska 0il & Gas CoDs. Anchorage APPROVED /~__ TRAN$~ ¢94~6 DATA CAMCO H L ,? I-tL2! A i'LA2' ;TCH CAMCO CAMCO C A H C 0 CAMC'.O C A M C 0 C A ~-i C H I;.'. ;~ H R £' HR.? CAMCO CAMCO CAMCO CAMCO ~'CH CAMCO CAMCO CAMCO (]AMC(] A "I'L.A S' ATLA 33 C A M C 0 HL3' DISTRIBUTION $ CENTRAL FILES $ PHILLIPS $ CHEVRON F'B WELL F'ILE3 D & M R & D ~- EXTEN3'ION EXF'LORATION ~-"' BF'X $ EXXON ~- $'FATE OF ALASKA MARATHON -.-"'TEXACO .'- MOBIL * TI-lIE COR'RECI'ED AF'I$ FOR tt-5 I~' 50-029-20670. .......... ,-.,-.,--,,-,,-,----,-r_-r, A,'.'r.,. u-n~, ~"~ ~ 'r" sG c, o9-"'~6,60t . -- . % ~ .~ ,._ ..;_. STATE OF ALASKA ALA,.~,,A OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate _ Other X WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1463' FSL, 5O' FWL, Sec. 1, T10N, R15E, UM At top of productive interval ~ 1306' FSL, 1086' FWL, Sec. 6, T10N, R16E, UM At effective depth 1210' FSL, 1493' FWL, Sec. 6, T10N, R16E, UM At total depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R16E, UM 6. Datum elevation (DF or KB) RKB 54' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number 9-11 9. Permit number 76-84 10. APl number 50-Q29-20236 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 12347' feet Plugs (measured) 9 0 7 0' feet None Effective depth: measured true vertical 12262' feet Junk (measured) 9 0 31 ' feet None Casing Length Size Conductor 8 0' 2 0" Surface 2672' 1 3-3/8" Cemented Measured depth True vertical depth 500 sx cmt (approx.) 87' 87' 5650 sx AS cmt 2702' 2702' Intermediate 11 568' 9-5/8" Production Liner 1 060' 7" Perforation depth' measured See Attached true vertical See Attached Tubing (size, grade, and measured depth 7"/5-1/2", L-80, Packers and SSSV (type and measured depth) 1000 sx Class G & 300 sx AS cmt 450 sx Class G 13. Attachments tbg w/tail @ 11360' 11595' 8691' Camco 'BaI-O' SSSV @ 2220', & Baker 'SB-3' pkr @ 11232' Description summary of proposal X Detailed operation program _ BOP sketch 14. Estimated date for commencing operation December 10, 1989 16. If proposal was verbally approved Name of approver Date approved 15. 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. Signed (~~ ~:~~j Title Drilling Analyst ~J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integriiy Test_ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form ORIGINAL SIGNED BY I~ONN1E C. SMITH require IApproval No. SUBMIT IN TRIPLICATE ITEM 11 - PERFORATION DEPTHS: APPLICATION FOR SUNDRY APPROVALS 9-11 (CONT'D) 11780'-11790' 11810'-11840' 11880'-11885' 11910'-11920' 11933'-11961' 11994'-12028' 12043'-12060' 12096'-12110' 12117'-12121' 12153'-12159' 12175'-12185' TVg 8793'-8799' 8810'-8826' 8847'-8850' 8863'-8867' 8875-8889' 8905-8922' 8930-8938' 8955-8963' 8965-8967' 8982-8985' 8992-8981' PBU DS 9-11 WORKOVER PROCEDURE SUMMARY OBJECTIVE: Fish parted tbg and clean out to PBTD / Cmt sqz preforations / Cut, pull and replace 9-5/8" csg to 2250' / Recomplete well w/ 7" x 5-1/2" tbg / Reperforate and return well to production. PROCEDURE: 1. MIRU Pool #102. Pull BPV. Bullhead kill well with 8.5 ppg seawater. Set BPV. ND tree. NU and test BOPE to 5000 psi. Pull BPV. Spear and LD 4800' of 7" and 5-1/2" tbg. (Tbg parted @ 4795') Fish and LD the balance of the 5-1/2" tbg. Mill over and retrieve 9-5/8" Baker SB-3 pkr @ 11232' MD. Fish Baker 4-1/2" shear-out sub insert. (insert is on fill at 12063' MD) Clean out well to 12262' PBTD. Cement sqz perforations. (Balance plug / braden head sqz) RU EL unit. Set 9-5/8" CIBP at 11250' MD. Run CBL to locate arctic-pack cmt top. Cut ad pull 9-5/8". (Remove 1st full jt of free pipe, above TOC) Run 9-5/8" 47# ABM BTC csg to tie production csg back to surface. Pressure test 9-5/8" csg to 3000 psi. RIH and drill out 9-5/8" ClBP. Pressure test the production casing against the 7" cmt plug. Drill out cmt to 12030'. Pressure test Zone 2 sqz perfs to 1500 psi. (Re-sqz if , , . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. necessary) Drill out cmt and clean out to 12262' PBTD. Recomplete well with 7" x 5-1/2" tbg and GLMs. Set BPV. Release and move rig. Turn well over to Production dept. for reperforating. Anticipated Bottomhole Pressure: Workover Fluid -. Seawater Drilling Engineer 3750 psi 13-5/8" 5000 PSI BOP STACK I I ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 3 1.13-3/8" CASING HEAD 2.9-5/8" CASING HEAD 3.5000 PSI TUBING HEAD 4. 13-5/8" - 5000 PSI BLIND RAMS 5.13-5/8" - 5000 PSI PIPE RAMS 6.13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WiTH CHARGING PUMP OFF, 4. RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DAM 8/4/89 REVISION OF11/21/86 BOP SCH (FOR:AUDI 4,NORDIC 1, NAB 2ES) Mo L ARCO ALASKA, INC~ F'~O. BOX i00S60 ANCHORAGE, ALASKA 995 ~ 0 DATE · 5-~ 0--89 REFERENCE' ARCO PRES -4 4-24-89 -9 4--3-89 - ~ 6 .Z~-29-89 ~-26 "-: '-'9 oo 2-~ 2 4-2~-89 5-~ i 4-~-89 5- ~ 6 4-5-89 6-~6 S-~ J '-89 9- ~ ~ ~-22-89 2-2 4-2 ~ -89 ~ ~ 0 4--2J -89 2-~ S S-J 6-89 2-28 S-~ 7-89 2-29 S--~ 6-89 ~ 29 4--2~-89 S-8 4-22-89 ~ S--2SA 4-2S-89 S-26 4-~6-89 ~-~S 4-26-89 ~5-9 ~-i~J -89 8-20 4-S-89 PLEASE SiGN AND RETUR SURE DATA BHF .... STATIC GRADIENT BHF .... STATIC GRADIENT BHP--S'¥AI'IC GRAQIENT BHF'--$TATIC GRADIENT BHF .... STATIC GRADIENT BHF'--$TATIC GRADIENT BHF'--$TATIC GRADIENT BHF .... STATIC GRADIEN[ BHP--FLOWI BHP--STATI BHP--FLOWI BHP--FLOWI BHP--FLOWI 8HP--STATI BHF,--STAi~'I BHP--FLOWI BHP--FLOWI BHP.--FLOWI BHP--FLOWI BHP--STATI BHP--£TAI'I NG GRADIENT C GRADIENT NG GRADIENT NG GRADIENT NG GRADIENT C GRADIENT C GRADIENT NG GRADIENT NG GRADIENT NG GRADIENT NG GRADIENT C GRADIENT C GRADIENT C A M C 0 OT IS CAMCO CAMCO CAM(][} CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO N THE ATTACHED COPY AS RECEIPT OF DA'FA~ RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER AT0-i529 APPROV .H_D g__ TRANS~ 89~-00 DISTRIBUTION CENTRAL F~LE~ ~ ~ PHILLIPS' CHEVRON PB WELL FILES D & M ~. ~ R & D EXTENSION EXPLORATION $ BPX EXXON ~ ~ STATE OF ALASKA MARATHON $ TEXACO f'i i-':. L: i,J ~ L ~'q 3, fi, ~ ~ .L I'~ L, ,. F:',.O. BOX iOn~,,._6~' ~- Mix!I~I-tuI-',I.,t~E, ALASKA 99_ DATE ' 4-26-89 REFERENCE - ARCO CASED HOLE FINALS i -5 4-7-89 t .--i 0 4-7-89 i -t 2 4/.:5-6/89 t - t 7 4-8-89 q' "i "':" 3~- ''~ .... 5-i i 4-i-89 6-S 4-i -89 7-22 S-SI -89 9-i i 3-2S--89 t I-8 4-5-89 i 2-t 8 4-i 0-89 i 4-:52 I D-'6 4-9--b9 t 8-20 4-5-89 PRODUCTION F'R'OF l L_E: F'RODUCTION PROFILE/PITS F'F.:ODUCTION PROFILE: PRODUCTION PROFILE TEMF:'/GANMA RA'Y' GAMMA RAY/FEMP SURVEY GAMMA RAY/TEMP SURVEY GAMMA RAY/TEMP SURVEY F:'RODUCTION FFt3FILE INJECTION F'ROF i:LE PITS GAMMA RAY/I"EMP SURVEY LEAK DETECTION GAMMA RAY/TEMP SURVEY RtJN t 5" RUN t, 5" RLJN,..."> ~:" RUN RUN i D" RUN i , ':~"~'" RUN i 2" &5" RUN i , ,-_;'~" &~-.,." F;.'. I_ JN RUN F,'UN i D" F,' tJ N R LJ N RUN F't..[.:.A,S'E SIGN ANI) REI'LJRN THE ATTACHED COF'Y AS RECEIF'i' OF' DA'¥A: SALLY HC'IF:'FEC~~~' .,..~,,, n" o" -" " . . ' AF'F'ROVED ._ ATO-i .529 ~ AlasKa u~l.~, uas uons. uommmslorl TF:ANS~ 89 tW'6 Anchorage C A M C 0 CAMCO CAMCO CAMCO C.'. A M C 13 C A M C 0 C A M C 0 ~l,~lJ CAMCO CA¢iCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ¢ PHILLIPS CHEVRON PB WELL FILES D&M R&D EXTENSION EXPLORATION ~ BPS EXXON ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL "r" -5 - * THE CORRECI' AF']:~ F dR t . IS 50 .0 9-20076 ARCO ALASKA, INC F'. O. BOX J ANCHORAGE, ALASKA DATE' 3-27-89 REFERENCE' ARCO CASED HOLE FINALS 2-7 3-~-89-. 3'- J J 3-3-89 5-JO 3-J 7-89 5-J '? 3-4-89 9-~ J 3-5-89 J J-~ J J-J "7-89 ii-i3 3-6-89 ii-i6 3-i4-89 i2-29 3-i6-89 F'WDWi-i 3-J-89 F'WDW3-i 3-4-89 PITS INJECTION PROFILE PITS PRODUCTION PROFILE TEMF' SURVEY TEMF' SURVEY PRODUCTION PROFILE TEMP PITS TEMP SURVEY STATIC TEMP SURVEY RUN i, 5' RUN i, 5' RUN i, RUN i, 5' RUN i, RUN t, 2'&5' RUN i, 5' RUN i, RUNS i-6, 5' RUN t, 2' RUN i, 2' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 APF'ROVED DISTRIBUTION CAMCO CAMCO OTIS CAMCO CAMCO OTIS CAMCO OTIS OTIS CAMCO CAMCO CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D SAF'C STATE OF ALASKA TEXACO ** THE CORRECTED API$ FOR THIS LOG IS 50-Q29-2Q26J. ARCO ALASKA, INC. F'.O. BOX t~368 ANCHORAGE, ALA£KA 995 ~ ~ DATE' 3-29-89 REFERENCE: 4-2 4-t9 5;-t7 6-8 9-3 9-tt tt-t tt-tt t2-t5 t2-23 t 4-28 t8-t '7 PWDWt PLEASE $IG ARCO PRE£$URE DATA 2-tG-89 BHP--FLOWING GRADIENT CAMCO t-3t-89 BHP--$TATIC GRADIENT CAMCO 2-t6-87 BHF'--$TATIC GRADIENT CAMCO 2-5-89 BHP--STATIC GRADIENT CAMCO t-t5-89 BHP--STATIC GRADIENT OTIS t-3~-89 BHP--$TATIC GRADIENT CAMCO 3-5-89 BHF'--FLOWING GRADIEN'r CAMCO t2-2~-88 BHP--STATIC GRADIENT OTIS 3-t7-89 BHP--$TATIC GRADIENT OTIS 3-t4-89 BHP--STATIC GRADIENT OTIS 2-t~-89 BHP--STATIC GRADIENT CAMCO 2-t5-89 BHP--STATIC GRADIENT CAMCO 2-5-89 BHP--STATIC GRADIENT CAMCO 3-t~-89 BHP--PRESSURE BUILD-UP OTIS 2-t3-89 BHF'--FLOWING GRADIENT CAMCO 3-J-89 BHP--$TATIC GRADIENT CAMCO N AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE SALLY HOFFECKER AT0-t529 TRANS ~8~t~ APPROVED _~___ ~ AI~s',,.'~ Oil & Gas Cons. Commissior~ Ar]chorage DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES '"' D & M -,-'"' R & D EXTEN£ION EXPLORATION ~ ~'AF'C ~ EXXON ,~ STATE OF ALASKA MARATHON ~ TEXACO ,~ MOBIL ARP, R P.FI. DF)× t ANP, Hr)RARE: Al .A.gK A 99.~ ~ f) DATE: REFERFN£E- AR£O PRES~IIRF DATA ,').-7 .')-6-88 :t-...~ · 't-,2._.G 4- i 5-OR ~-22 4- ~ - ,.:"!. 4 4-t .'~- RR ~-2R 4- t A-RR 9-.7 · -..~.4-R, 9-9 4-t A-RR · :.~f~-.9-,.~? 4 - i 7- .R. - ,.-_ .~. 4-t 6-RR i 7-t t -P7-gg ~HP-$TATTR ~RADTENT ~HP-STATT£ RRADTENT RHP-~TATTR CRADTENT ~HP-~TATTC CRADTFNT ~HP-STATT£ 6RADTFNT RHP-~TATTK CRADTFNT BHF'-FI.flgl'NR ~RADIENT ~HP-FI DWTN~ ~RADTFNT RHP-STATT£ ~RADTFNT BHP-~TATT£ ~RADTFNT ~HF'-STATT£ 6R~DTFNT ~HF'-Fi. AWTN~ CRADTENT PI.EASE .~IGN AND RFTIIRN .,T,,~E ATT,/CCHF.,.~,~,,~F'Y ¢~.~' RECF,TP_..c,,P.,~..."I'~F DATA. ~ /~as~ 0g & Gas Sons. Commissio~ ATO- t 5,:..9 TRAN,? . ~88~ .R. g APPROVED__ DTSTRT~IITION CFNTRAI.. FII...E~ · PHTLI...TP~ CHEVRON F'R WEI..I... EXTENSION EXF't. ORATION ~ ~AF'C EX¥ON ~'~"~Y~TE~'O'F ,'~T~ A OTI~ RTT~ nTT~ ~TT~ RTT~ ARCO A~a,?ka, Inc. P~O. Box ~(')(~S6() A n c h o r a g e, A L a .'..~' ~-,' a I) A" F:'ebruary.') ....O, t9P,? R E F' Ii': R E N C E:A R C 0 P r e ~ .'.~' u. r e D a '[' a 9 .... Jt t .... 6---.87 F:'Lowing C;radient 9 -.--2 7 ~."~ - .., ':~' -..-B, 7 F:' / o w i n g (:.; r a (:1 i e n t C a m c o I::'l. ea.'.~e _~:,'ig'n and return the attached copy a£' receipt of data, Central. F'i Le~: Chevron PB WeLL Fi I.e.~ ~: D & M ..~' R & I) ~ Sohio Exten.'..~:ion Expi. oration :l~ E:xxc:,r~ ~ State of' A Las'l<a N a r a t h o n :~: T e x a c o .11, ARCO Ala~'ka, Inc I::' ~ 0 ~ Box Ant:borage, Alaska 99.5'1 DATE' February t 9, t987 REI-. EI.~ENCE · ARCO Ca.'.;ed Ho l e F' ina L 3-..-6 2-t-87 Inj~ Profile Run ~, 5" 3-7 ~°-~."~-.,.~v, Inj. F'rofi ~e' Run t, 5" :3.-..8 2-.2-8'7 F'rod, F:'rofi Le Run t, 5" ~S--t2 t.-St-87 Inj. F'rofi Le Run i, ~:5-t3 2-tt .... 87 In.j, I::'rofi Le Run 3- 26 2- 2- 8'7 P r o d ~ P r o f i I. e R u n ~?--5 t/2¢..-S¢/87 Prod, F:'rofi Le Run t ~9-.5 2-4-87 'l'emp~ Log Leak betectiona Run t, - 5 9-..7 2-4 87 GR/FLowmeter Run ~9-- t t t .-"~ 5" ~6-87 Sp i nner/GR Run ~9-t3 '2-5-~7 GR/F Iowme~er I:::~n 9-26 2-6-87 GR/F Iowmeter Run ~9-..27 2/6-7/87 F:'rod. Profi Le Run ~t8-t2 2-t5.-87 GR/Tul~ing Col. lar I..og Run 1, & !5" fll E 0 m c o fl1E 0 Ill C 0 file 0 m c: o m c o m c o m c o m c o fllC)C PI. ease sign and return the attached COPY as' receipt of data, Received By HAVE:' A NICE DAY! Rosanne Peek ATO .... i 529 TRANS' Ap p r ovecl FEB 23 1987 Alaska Oil & Gas Cons. Commission Anchorage D I $'f' R I B U T I (] N · "'.,,. C e n T. r a [ F:' i t e ~. Chevron D & M '~..-E x '~ e n .'.; i o ri IF x p I. o r a ~ i o ri · ~r'"' E X X 0 n · .- Hob i L ,,. F:'h i I. I. i p .'3' PB WeLl. Fi Les' R & D .,.'r~,~- oh io tate}o ?'ALaska -'" T e x @ ¢.. (:.1 ~lr '~'-~ STATE OF ALASKA ALASK,,~ OIL AND GAS CONSERVATION Cu,VIMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well Classification of Service Well REVISED OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ¢ ARCO A1 aska, I nc. 76-84 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20236 4. Location of well at surface 9. Unit or Lease Name 1463' FSL, 50' FWL, Sec. 1, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1306' FSL, 1086' FWL, Sec. 6, T10N, R16E, UM DS 9-11 (13-6-10-16) 11. Field and Pool At Total Depth 1191' FSL, 1566' FWL, Sec. 6, T10N, R16E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 54' RKB 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 3/14/77 4/20/77 5/01/77'I N/A feet MSLI 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°st 12347'MD - 9070'TVD 12262'MD - 9031 'TVD YES~ NO [] 2220 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/SP, BHCS/GR, FDC/CNL/GR, GR/CNL/CCL, Multishot 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20~ 9~,.O# H-4U Surf 73' 30" Approx 500 sx circ to su~!f 13-3/8" 72.0# MN-80 Surf 2702' 17½" 5650 sx Arctic set 9-5/8" 47.0# N-80 & Surf 11595' 12½" 1000 sx Class G & 300 sx AS cmt S0095 7" 29.0# N-80 11282' 12342' 8½" 450 sx Class G cmt 24. Perforations open t0Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) *11780' - 11790'MD 12043' - 12060'MD 7"/5½" 11360' 11232' *11810' - 11840'MD 12096' - 12110'MD 11880' - 11885'MD 12117' - 12121'MD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 11910' - 11920'MD 12153' - 12159'MD DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 11933' - 11961'MD 12175' - 12185'MD N/A 11994' - 12028'MD 8856' - 9055'TVD * New perfs w/4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May, 1977 Flowing CHOKE SIZE GAS-OIL RATIO Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL 5/01/8Zt 4 0 TEST PERIOD I~ ,;qR 3531 0 ~11 / 9~1 ~~ ~ OIL GRAVITY-APl (cor'r~ Flow Tubing Casing Pressure CALCULATED ..~ OIL-BBL GAS-MCF WATER-BBL Press- 2336 100 24IHOUR RATE"I~ %588 7!186 0 27° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev. 7-1-80 *Note: Well was worked over 6/15/86_ D~C1/129E CONTINUED ON REVERSE SI Submit in duplicat~ 29. ]. · 30.- ,. GEOLOGIC MARKERS '~-ORMATION TESTS . · . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 11781 ' 8853' 0/W Contact 1 2200 ' 9063' Base Sadl erochit 12200' 9063' N/A - . ,.. · . . . 31. LIST OF ATTACHMENTS None . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~//~ Associate Engineer Signed (/'~/~ ~ 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none"° Form 10-407 STATE OF ALASKA ...... ~ ALAS~ OIL AND GAS CONSERVATION U,:¢,VIMISSlON WELL COMPLETION OR RECOMPLETION 'REPORT AND LO 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED[] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 76-84 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20236 4. Location of well at surface 9. Unit or Lease Name 1463' FSL, 50' FWL, Sec. 1, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1306' FSL, 1086' FWL, Sec. 6, T10N, R16E, UM DS 9-11 (13-6-10-16) At Total Depth 11. Field and Pool 1191' FSL, 1566' FWL, Sec. 6, T10N, R16E, UM Prudhoe Bay Field 5.54Elevation, RKB in feet (indicate KB, DF, etc.)16.ADLLease28345Designationand Serial No. Prudhoe Bay 0i 1 Pool I 12~/l~ate Spudded4/77 13. Date T.D. Reached 4/20/77 14. Date Comp., Susp. or Aband. 5101/77* 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns N/A feet MSL 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 12347'MD - 9070'TVD 12262'MD - 9301 'TVD YES)~ NO []I 2220 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/SP, BHCS/GR, FDC/CNL/GR, GR/CNL/CCL ,,, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20;; 94.0# H-~,U Surf 73' 30" Approx 500 sx circ to surf 13-3/8" 72.0# MN-80 Surf 2702' 17½" 5650 sx Arctic set 9-5/8" 47.0# N-80 & Surf 11595' 12½" 1000 sx Class G & 300 sx AS cmt S0095 7" 29.0# N-80 11282' 12342' 8½" 450 sx Class G cmt 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) *11780' - 11790'MD 12043' - 12060'MD 7"/5½" 11360' 11232' *11810' - 11840'MD 12096' - 12110'MD 11880' - 11885'MD 12'117' - 12121'MD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 11910' - 11920'MD 12153' - 12159'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11933' - 11961'MD 12175' - 12185'MD N/A 11994' - 12028'MD 8856' - 9055'TVD * New perfs w/4 spf 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) May, 1977I F1 owing DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/01/8/4 4,0 TEST PERIOD I1~ 59R ~;'~1 0 6~./2/~· 5905 Flow Tubing Casing Pressure CALCULATED I1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press- 2336 100 24-HOUR RATE 3588 71186 0 27° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None E 'EIvrr. D OCT 2 o 1986 AlaSka 011 & Gas Cons, commissior, Submit in duplicate/ Form 10-407 *Note: Well was worked over 6/15/86. WC1/129 Rev. 7-1-80 CONTINUED ON REVERSE SIDE '-: : ':' 30. / 29. GEOLOGIC MARKE ,:S "-' '~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 11781 ' 8853' 0/W Contact 12200 ' 9063 ' Base Sadl erochit 12200' 9063' N/A : 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~,~L,~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, 'Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 / TELEPHONE (907) 279-1433 September 29, 1986 Telecopy No. (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 213.2 Re.. Waivers to Rule 6 and Rule 11 of Conservation Order 154. Mr.'D. F. Scheve ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Scheve: By letter dated September 24, 1986, waivers to Rule 6 and Rule 11 of Conservation Order 165, as amended by Conservation Order 213, were requested for DS 9-11. Prudhoe Bay Unit DS 9-11 has been shut-in since May, 1986~ and conversion to water injection is pending. Since the well is shut-in, a transient pressure survey is not prudent. A static pressure survey will yield an accurate measurement of reservoir pressure. Therefore, substitution of a static survey for the transient survey required in Rule 6(b) of Conservation Order 165 is hereby approved. In addition to being shut-in, the well is only completed in the Lower Romeo. Since all flow would necessarily come only from the Lower Romeo, a spinner survey is not needed to determine this. Therefore, the Commission approves your request to waive the production profile required by Rule ll(a) of Conservation Order 165. Sincerely, C ommis s loner jo/3.AA213.2 STATE OF ALASKA .... ALASK.. OIL AND GAS CONSERVATION COMN..,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging L~ Perforate [] Pull tubing Alter Casing [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 An~horaqe, AK 99510 4. Location of well at surface 1463'FSL, 50'FWL, Sec.1, T10N, R15E, UM At top of productive interval 1306' FSL, 1086'FWL, See.G, T10N, R16E, UM At effective depth 1210'FSL, 1493'FWL, Sec.6, TION, R16E, UM At total depth 1191'FSL, 1566'FWL, Sec.G, T10N, R16E, UM 5. Datum elevation (DF or KB) RKB 54 ' 6. Unit or Property name Pr,,~lh~ n~_y Ilnit 7. Well number 9-11 8. Approval number Permit #76-84 9. APl number 50-- 029-20236 10. Pool Prudhoe Bay 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical 1 2347 feet 9070 feet Effective depth: measured 1 2262 feet true vertical feet 9031 Casing Length Size Conductor 80' 20" Surface 2672' 13-3/8" Production 11568' 9-5/8" Li net I 060 ' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 500 sx cmt(approx) 73'MD 5650 sx AS cmt 2702'MD 1000 sx Class G & 11595'MD 300 sx AS cmt 450 sx Class C 11282'-12342'MD ~ue Verticaldepth 73'TVD 2702'TVD 8691'TVD 8518 ' -9068 'TVC 'Perforation depth: measured (see attachment) true vertical Tubing (size, grade and measured depth) 7"/5-1/2", L-80, tbg w/tail ~ 11 ,360' Packers and SSSV (type and measured depth) SB-3 pkr ~ 11,232' & BAL-O SSSV @ 2220' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associate Engineer Date Form 10-404 Rev. 12-1-85 (DAM) SW0/071 Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS Drill Site 9-11 (cont'd) Perforations: 11 ,780 11 ,810 11 ,880 11 ,910 11 ,933 11 , 994 1 2,043 12,096 12,117 12,153 12,175 ' - 11 ,790 'MD ' - 11 ,840 'MD - 11 ,885 'MD - 11 ,920 'MD - 11 ,961 'MD - 12,028'MD - 12,060'MD - 12,110'MD - 12,121 'MD ' - 12,159'MD ' - 12,185'MD 8856' - 9055'TVD SWO/O71a:tw ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspend'ed for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ~hease or Unit I Prudhoe Bay Auth. or W.O. no. ITitte AFE 903086 Capital/903078 Exp~nse Accounting cost center code State Alaska North Slope Borough ADL #28345 Well no. 9-11W/O Recompletion WWS #1 API 50-029-20236 Operator ARCO Alaska, Inc, A.R.Co. W.I. 21,66% Spudded or W.O. begun Date Workover 6/4/86 Date and depth Complete record for each day reported as of 8:00 a.m. I otal number of wells (active or inactive) on this ost center prior to plugging and ] bandonment of this well our I Prior status if a W.O. 1430 Hrs. 7" @ 12,342' 12,262' PBTD, RR 9.1 ppg NaC1 Brine w/diesel cap TIH, set RTTs @ 2800', tst csg; FO's open, POH. TIH, closing fingers, close FO's, set pkr. Tst csg to 2000 psi. TIH, set RTTs @ 11,240', tst csg to 2000 psi, POH, LD DP. RIH w/gage ring/JB, POH, RD DA. RIH w/tailpipe assy, SB-3 pkr & 5½" x 7" compl equip. Lnd tbg. Pmp 90 bbls diesel dn ann, set pkr. Tst tbg to 2500 psi & ann to 2000 psi. ND BOPE, NU & tst tree to 5000 psi. RR @ 2000 hrs, 6/15/86. 6/14/86 thru 6/15/86 (NOTE: Rn 88 its, 7", 26#, L-80 LTC 8RD tbg, 177 its, 5½", 67#, L-80 AB Mod tbg & 3 its, 4~"2, 12.6#, L-80 BTC tbg w/Bal-O-Nipple @ 2220', SB-3 pkr @ 11,232', TT @ 11,360') Old TD New TD 12,262~ I~eleased rig Date 2000 Hrs. Classifications (oil, gas, etc.) Oil PB Depth K nd of r g 6/15/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production !Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Well History- Initial Report- Daily Instructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on _the form giving inclusive dates only. District ICounty, parish or borough Alaska I North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL #28345 Auth, or W,O. no, ITM AFE 903086 Capital/903078 ExpOse Recompletion WWS #1 API 50-029-20236 IState Alaska IWell no, 9-11 w/o I ARCO W.I. Operator ARCO Alaska, Inc. Spudded or W.O. begUnworkover I°ate 6/4/86 IH°''r1430 Hrs. IPr'°rstat"sif"w'°' 21.66% Date and depth as of 8:00 a.m. 6/5/86 6/06/86 6/07/86 thru 6/09/86 6/10/86 6/11/86 6/12/86 6/13/86 Complete record for each day reported 7" @ 12,34~~ 12,262' PBTD, Kill well 9.2 ppg NaC1 Brine Accept rig @ 1430 hfs, 6/4/86. RU DA, make 2 art's to perf tbg w/o success, RD DA. Bullhead 25 bbls Bridgesal pill dn tbg. Sqz pill into perfs. 7" @ ~2,34~1~ 12,262' PBTD, Tst BOPE 9.4 ppg NaC1 Brine Sqz pill & displ w/9.2 ppg brine; well dead. RU DA, att to perf tbg w/o success. RIH w/cutter & cut tbg @ 10,328', POOH, RD DA. Displ well w/9.4 ppg brine. ND tree, NU & tst BOPE. 7" @ 12,34~ 12,262' PBTD, Mill on pkr 9.4 ppg NaC1 Brine, RIH RIH w/3½" DP, fsh PBR & K-Anchor, POOH, LD fsh. PU mill, RIH, tag pkr @ 10,445', mill on pkr. 7" @ 12,34~'~ 12,262' PBTD, POOH w/pkr 9.4 ppg NaC1 Brine Mill on pkr, trip f/new mill, circ, POOH. 7" @ 12,34~' 12,262' PBTD, RIH, PU DP 9.4 ppg NaC1 Brine !:~,~,.:,~.:~ (~'~ ::~i ~:: POOH w/pkr & tailpipe, circ out gas. Cont POOH & LD'fsh. PU 6" bit, RIH, PU DP. 7" @ 12,34~' 12,262' PBTD, Displ'g well w/brine 9.2 ppg NaC1 Brine RIH to top of fill, CO fill f/12,025'-12,262'. Pmp hi-vis pill, displ well w/cln brine. 7" @ 12,34~' 12,262' PBTD, TIH w/pkr to tst csg 9.1 ppg NaC1 Brine Filter brine, POH w/bit. Tst 9-5/8" pack-off to 3800 psi; fluid loss increasing. TIH w/OEDP to 11,200', pmp 40 bbl Bridgesal pill & sqz into perfs, TOH. TIH w/9-5/8" RTTS to tst csg. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 6/20/86 ITM Drilling Supervisor Post Office Box 360 Anchorage, A! a 99510 Telephone 90? ~/7 563';' December 11, 1985 Reference: ARCO Cased Hole Finals DS 9-2 11-20-85 Prod Prof/Fluid ID~Spinner Run i 5" Camco DS 9-5 11-20-85 Spinner/Fluid ID Run i 5" Camco DS 9-6 11-20-85 Spinner/Fluid Id Run 1 5" Camco DS 9-11 11-21-85 Spinner/Fluid Id/GR Run 2 5" Camco DS 9-13 12-21-85 Prod Prof/Fluid Id~Spinner Run 2 5" Camco Please sign and return the attached cop. y as receipt of data. Kelly McFarland ATO-2429F Trans # 509 DISTRIBUTION Chevron Bxp2oration Services Extension Bxpiorati on ~ara~hon Mobil ARCO Alaska, Inc. Post Office Bo..00360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 26, 1985 Reference' ARCO Directional Surveys 9-11 -MWD Directional Survey 8-16-85 Teleco 9-30 MWD Directional Survey 9-5-85 Teleco 9-31 MWD Directional Survey 8-13-85 Teleco 9-34 MWD Directional Survey 6-3-85 Teleco Pam Lambert ATO 1429C Please sign as receipt of data. Received by Trans 334 Chevron Phi l i ips D & M PB Well File~ Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon T~xa co Mobil ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 1985 Mr. C. V. Chatterton Commissioner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 3-5, 9-11, 9-13, 11-5, 11-6, 12-3, and 12-5 Dear Mr. Chatterton' Enclosed are Sundry Notices for the subject wells. We propose to workover the above wells installing new gas lift equipment and tubing. This work is scheduled beginning May, 1985. If you have any questions, please call me at 263-4610. Sincerely, //~ Ar~ Drilling Engineer TLF/ELC/tw SN/L01] Enclosures AR(~C) AIn~kn Inc i~ n f~lth~i~tinrv n! STATE OF ALASKA ~- ALASKA L~,L AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1463' FSL, 50' FWL, Sec.1, TION, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 54' 6. Lease Designation and Serial No. ADL 28345 7. Permit No. 76-8~ 8. APl Number 50- 029-20236 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-11 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 12. 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 Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a workover on 9-11 in June, 1985, to install gas lift mandrels. The workover will be executed in the following manner: 1. Install blanking plug in packer tailpipe assembly. 2. Circulate well to brine workover fluid. 3. MIRU workover rig. 4. ND tree. NU BOP stack and test. 5. Pull 5-1/2" completion assembly. 6. Run 7" x 5-1/2" tapered tubing string with gas lift mandrels. 7. ND BOP stack. NU tree and test. 8. Displace we, ll to crude oil, leaving diesel cap on annulus. 9. Pull blanking plug and install SSSV. 10. Secure well and release rig. A subsequent sundry will be submitted following the completion of this workover detailing the new completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The s~elo~or Commission use g~f'~itions of Approval, if any: Ar~-~ -~--~ ..... Date r)ri 1 1 inn Fnn~ n~r By Order of the Commission Date Approved by COMMISSIONER Form 10-403 (ELC) SN/020 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate r-~ F;; [.-; [) (:'~ I..::'~ ::; k a, :[ n cc, F:' ,. (3 ,. E.: ,:::, ::.:: i ,3, (~ ~ 6 (.) ¢-', 'n c: I'; ,:::,'r' a g e.',, r-~ 1..a .s- k a Ch evFo'n Hob i L :(.".'- 8: H; H:':::,t::,i I. E' ,!!-< Exp [,L-,~-a± i ¢.',n ~er'v i ,::e:--: F'hi t. 1. i p::.:.: E x t e n s' i o n E: x p I. o',- a !' i o n F:'-r' :..':. ,::I h ,:::: ~.:, .f.-:-: .:'~ '.: J.,.J ,::.:: I. L i:: i E x x o n F;.: ,!:.< Get t y 3'oh i o J"J .:."i 'i ' .::'i : ?'im::) 'i"i ~ ~ ~, ~ 8 0 '~' ~ [ <] .~ J< ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 26, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-1 DS 9-3 DS 9-8 DS 9-11 DS 9-13 Ds 9-19 Permit No. 75-76 Permit No. 76-35 Permit No. 76-70 Permit No. 76-84 Permit No. 77-8 Permit No. 77-40 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/kg Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 1)W4-3 File Pi(DS 3)W4-3 File Pi(DS 8)W4-3 File Pi(DS 11)W4-3 File Pi(DS 13)W4-3 File Pi(DS 19)W4-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany - - STATE OF ALASKA ALASF' )IL AND GAS CONSERVATION( ,¢IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 7. Permit Number 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360~ Anchorage, Alaska 99510 4. Location of well at surface 1463'N & 50'E of SW cr, Sec 1, T10N, R15E, UM At Top Producing Interval 1306'N & 1086'E of SW cr, Sec 6, TLON, R16E, UM At Total Depth ll91'N & 1566'E of SW cr, Sec 6, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28345 12. Date Spudded 113. Date T.D. Reached 3/14/77 i 4/20/77 17. Total DePth (MD+TVD) 18. Plug Back Depth(MD+TVD) 12347'MD- 9070'TVD 12262'MD- 9301'TVD 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, FDC/CNL/GR, CR/CNL/CCL 76-84 8. APl Number 50-029-20236 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-11 (1 ~-6-_!0-!6) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pooh 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 5/1/77 I N/A feet MSLI 1 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost YESX[] NO ~ 2254 feet MD I 19OO~+ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94f~ H40 Surf. 73' 13-3/8" 72~AButt MN80 Surf. 2702' 9-5/8" 47~AButt N80 & Surf. 11595' 7II 29~ S0095 11282' 12342' 24. Perforations open to Production (MD+TVD of Top and Bottom and 30" 17~." 12k" Aonrox 500 sx n~rn rn s 5650 sx Arct~cset cmt 1000 sx Class O 8½" 450 SX Class G cmt 25. TUBING RECORD interval, size and number) *11780 - l1790'MD(lO') *11810 - 11840'MD(30') 11880 - 11885'MD(5') 11910 - l1920'MD(10') 11933 - 11961'MD(28') 11994 - 12028'MD(34') *New perfs w/4spf 12043 - 12060'MD(27') 12096 - 12110'MD(14') 12117 - 12121'MD(4') 12153 - 12159'MD(5') 12175 - 12185'MD(10') 8856 - 9055' TVD 27. SIZE DEPTH SET (MD) PACKER SET (MD) ]0529' ]0393' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED PRODUCTION TEST Date First Production Hay 1977 Date of Test 5/1/84 Flow Tubing Press. 2336 Hours Tested 4.0 Casing Pressure 100 Method of Operation (Flowing, gas lift, etc.) PRODUCTION FOR OIL-BBL TEST PERIOD ~ 598 OIL-BBL 3588 CALCULATED 24-HOUR RATE GAS-MCF 3531 GAS-MCF 21186 WATER-BBL 0 WATER-BBL 0 I CHOKE SIZE IGAS'OIL RATIO I 5905 §b/24 OIL GRAVITY-AP 27° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. (corr) RECEIVED JUN 2 81 84 Alaska Oil 8, Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 11781 12200 TRUE VERT. DEPTH 8853 9063 9063 30. FORMATION TESTS 12200 Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~~~~/]'~~/--~"'~/~ Title Regional Engineer 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, In¢ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 22, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 DS 9-3 DS 9-8 DS 9-11 DS 9-13 DS 9-19 Permit No. 75-76 Permit No. 76-35 Permit No. 76-70 Permit No. 76-84 Permit No. 77-8 Permit No. 77-40 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File Pi(DS 9-1)W1-3 File Pi(DS 9-3)W1-3 File Pi(DS 9-8)W1-3 File Pi(DS 9-11)W1-3 File Pi(DS 9-13)W1-3 File Pi(DS 9-19)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA - ALASKA L AND GAS CONSERVATION CL ,MISSION SUNDRY NOTICES AND RERORT$ ON WELLS DRILLING WELL[] COMPLETED WE L L:)ID[ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 1463'N & 50'E of SW cr Sec. 1, T10N, R15E, UM (Producing Interval) 1306'N & 1086'E of SW cr Sec. 6, T10N, R16E, UM (Total Depth) l191'N & 1566'E of SW cr Sec. 6, T10N, R16E, UM 5. Elevation in feet (indicate 1<8, DF, etc.) t 6. Lease Designation and Serial No. 54' RKB I ADL 28345 12. 7. Permit No. 76-84 8. APl Number 50- 029-20236 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-11 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-t70). Began perforating operation 5/7/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot intervals 11780 - 11790' and 11810 - 11820' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 11820 - 11840' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSV, secured well, RD. Ref: BHCS 4/20/77 Title Regional Engineer RECEIVED ,JUN 2 81984 Alaska 0il & Gas Cons. C0mmissi01 Anchorage 14. I hereby certify that tjl,e foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Prudhoe Bay c'ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File Pi(DS as above)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AllanflcRIchfleldCompany STATE OF ALASKA ~ ALASK, JlL AND GAS CONSERVATION ( ¢IMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-84 Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20236 OTHER [] 4. Location of Well 1463'N & 50'E of SW cr Sec. 1, T10N, R15E, UN 1306'N & 1086'E of SW cr Sec. 6, T10N, R16E, UM 1191'N & 1566'E of SW cr Sec. 6, T10N, R!6E,_ UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28345 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-11 1 1. 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: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (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 add perforations on DS 9-11 for selected intervals within the Sadlerochit Sand from 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: 11780-11790' MD 11810-11840' MD Ref: BHCS 4/20/77 Su]~!equept Work Bej2orted 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, ~ ~_~_~~ Title Regiorlal EFIcjirteer The space below for Commission use Date Conditions of APproval, if any: Approved by. BY H~RRf ~. [~t[I COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~"~ 360 Anchorage, ~ .~ska '99510 Telephone 907 277 5637 January 28, 1983 Reference: Arco Pressure Data D.S. 1-4 11-18-82 Pressure Build-up Otis 11-18-82 Pressure Build-up Survey Report D.S. 9-11 1-2-83 1-2-83 D.S. 11-3 Pressure Build-up GO Pressure Build-up Survey Report 12-16-82 Pressure Build-up Camco 12-16-82 'Pressure Build-up Survey Report D.S. 15-1 12-10-82 Static Bottom Hole Pressure Survey 12-10-82 Static Pressure Survey Data D.S. 15-2 12-9-82 Static Bottom Hole Pressure Survey 12-10-82 Static Pressure Survey Data D.S. 16-12 2-10-82 Static Survey Otis DA DA Pleasesign and retUrn the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. $ 089 DISTRIBUTIO~.~ -~ ~.~,_ ..... .~, ~., DRILLING GET~ '¢~ 0i/ SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON DALLAS' North Alaska District Enginee'~9~. T RAN SM I T TA L From' J. A. Rochon/R. A. Logue 'l'ransmitted herewith ,are the follo,,:ing for the subject well' F/J.),~/L,. ,{9~/~ Run No. Scale Xerox Sepia BL Line . Acid or Fracture TreatTnent Log . -. BHP Buildup ~' Flow Profile Survey Borehole Geometry Log Carbon Oxy/sen Log Casing Collar Log Cement Bond Log Compensated Neutron Log - Cased Hole · '. Core Analysis - Interval Core No.. ----.Core Description (~4C) - Interval Core Description (Cony.) - Cgre No. Directional Survey- Gyro - Singl~ Siibt ~ Multishot · -!;~/ Engineering Production Log 'Fluid Analysis Fluid Density Gamma Ray Location Plat Monthly Well Test Data ' Mud Log Perforat.~g Record State-Reservoir Pressure Report ~' Surveillance Reports Temperature Log Transient Pressure Surveys TFD Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log ~ Porosity Log ~ece:ipt AcknOwledged By: /]~~:~:.~/ ~/~? Z-~/' ~ ..... t.>l.ease Return Receipt To' Ms. R. A. Logue Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 ,f:'~,; ~'J ntLeH ~ ch li etd r,.;o rn party North American Producing u~Wslon Alaska Regi .... Post Office t- ,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ; .... "'~' ~ January 13,1978 Reference: Dear Gentleman: The ~llowing material is being submitted he,with. Please acknowledge receipt by signing a copy of this letter a~d returning it to this office. D.S. 9-1 D.S. 9-2 D.S. 9-3 D.S. 9 5 D.S. 9-6 D.So 9-7 D.S. 9-8 D.S. 9-9 .~,~.. D.S. 9-1~ .... , D.S. 9-12 Initial Transient Pressure Survey Nov. 14/77 Nov.27/77 Nov. 24/77 Nov.21/77 Nov.18/77 Dec.18/77 Dec.6/77 Dsc. 10/77 Dec.17/77 Dec.21/77 Initial Static Gradient Pressure Survey D.S. 9-13 Nov. 20/77 · D.S. 9-14 Nov.18/77 D.S. 9-16 Nov.21/77 · Donovan Jackson _ ~/ \ ' North Alaska Dist~:~Engineering To' North Alaska District Engineering TRANSMITTAL From' J.A. Rochon/~D~, R. Jackson Date: q-27~-77 Well Name' ri,S, 0-11 Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Ganma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log' Compensated Neutron-Formation Density .... Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density. Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mudlog - Interval Sample Log (A.R. C0.)"Interval Synergetic Log TVD-DIL TVD-PorosityLog fluid density collar log Bottomh~le pressure Survey 9~2-7~ Receipt Acknowledged For: CAMCO ~ ea ! ea Please return receipt to' Atlantic Richfield Company . North Alaska Engineering ~ianager P. O. Box 360 Anchorage, Alaska 99510 #592 ~AflanticRichfieldCompany North Ame~n Producing Division North Alas )istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 7, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 9-11 (13-6-i0-i6) Permit No. 76-84 Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report along with the Well Completion Report detailing the work done on the above-mentioned well. Very truly yours, F. M. Brown District Drilling Engineer /jw Enclosures /o-17-77 F o.m P - 7 SUBMIT IN Db.-L,CATE* STATE OF ALASKA '~s~ ,q~ l'[lc[ l(ins Oll OIL AND GAS CONSERVATION COMMITTEE ~ i i WELL (OMPLETIO~ OR RE(OMPLETION REPORT ASD LOG J J ~ Other WELL~) WELL ~ DRY b. TYP~ OF COMPLE~ON: W EI, I, OVER ~ EN BACK nESV~. Other ~ ~. NAME OF OPERATOR gt]ant~c R~chf~e]d Company 3. ADDRESS OFOPERATOR P. 0. Box 360, ~nchoca~e, ~]aska _ 4, LOC)~rmN OF W~LL (Re~ort ~ocaNon ctear~ and in accordance with an~ State requ~r,menta)* ~t ~u~ace 1463'~ $ 50'[ of S~ cr Sec 1, 110~, R]5[, ~ It top pro0. tnterval reported below 1306'~ & 1086'[ of S~ cr Sec 6, 110~, R16[, ~g Sec 6, ~t total dep~ 1191'~ & 1566'[ of S~ cr Sec 6, 110~, R16[, ~ ~. ~r~o. 76-84 . 3/14/77 4/20/77 5/1/77 .... 54'R~B ~OW~Y* ROTARY TOOLS CABI,E TOOl8 12347'~D,~ 9070'1V~ 12262'~D,9301'Y~D/~ S~n~le ~. P~ODUCING [~RVAL(8), O~ ~I8 CO~P~TIO~TO*P, BOSOM, NA~ (MD AND ~)~ ,23. WAS D[i~ECTIONAL Top Sadlerochit ll,781'MD, 8794'TVD , Bottom Sadlerochit 12,200'MD, 9003'TVD ~ Yes 6. LF. ASE DESIGNATION AND SERLkL biO. ADL 28345 7. iF INDIA.N, ALLO'I'TP2E Oll, TRIBE NA_SLEI 8. UNIT,FARAVI Obl L ~I~t.~E NAME Prudhoe Bay Unit 9. ~VF~LL NO. DS 9-11 (13-6-10-16) 10. FIELD A2qD POOL, OI~ WILDC&T )rudhoe Bay 'Fi:~ld-Prudhoe ,,. s~.c.. ~.. ~., ~., (~o~,~,o~i ~o~ Bay OJBd IgC'i'IV E) Pool 12,175'-12,185' 12,153'-12,159' 12,117'-12,121' 12,096'-12,110' 1_2,043'-12~06Q' ~0. 24. TS~PIg ELF-CT~IIC AND OTHEI% LOGS RUN DIL/SP, BHCS/GR, FDC/CNL/GR, GR/CNL/CCL 25. CASING RECORD (Report all strings set in we_Il) ~s~,c, ~z~20,,13_3/8 wz~, ~,z,. ~ 'o~,D~ J ~ sz~ (~: ~ ~o~z ~z~ J72~_Butt94~ JJ MN- 80 IH-40 J 2702'73' 30"17_1/2.15650. ! Approx, sxC~:'~'~ =~o,~500 Arcti csetSX Circ cmt.t° su 9-5/8" 72~-Butt J ,-80&J 11,59~'... 12-] /4"~1000 sx Class G c~t. 26. ' " LINE~ ~CO~ ' '" ' ' ' 7" .... .[11'282'~ . .[ 12,342' [... , ,. 450 5-]/2" 10,529' 10,393'. 28 PERFORATIONS OP~ TO PRODUC~ON (interval size and nurnbe~) 29. 'ACID, Si:OW, FiD~i;'L Gq{E, C~.iLNT SQULDfZ>J, ETC. ,~.52'008'-12,028' fill,~ o~.~.~'~v.~,~, "1gl,994'- 2,008' to NA .~ ~11,941'-11 ,~' 11,885.' d. 1~-11,941' 4 shots ~11~910'-1]~920' per ft. . . .. P~ODUCTION ~ -, . ' , . DATE Fi~ST PI~ODUCTION [ P~ODUCTION MEI[{OD (Flowii~g, g'.a3 lift, parnping--size and type of pump, :' JXSI;:LI., :;'I'ATUS t[,roducing or l 9/19/77 I Producinq DATE OF TEST. .9/2_6.Z77 FLO%', TLTEtNG 1090 3]. DISPOSITION OF j Flowinq __3 ~5 1 78/64 CASE'G PRESSURE ICALCUI_AkTED 0 'GAS (Sold, used ~or fuel, vented, etc.) oIL--BBL. G-ZkS--;.\.ICF. V.,%5. TEIl--I~IT, L. J GAS-Olh IIA.TiO 1146 I 745 I 0 j 650 Reinjected 82. LIST OF ATTACHMENTS OIL--BBL. CrAS--~elCF. W/kTER~IgBL. J OILGRAVITY-A_PI (COLOR,) 7859 15106 J 0 I . JTEST WI'I'NESSII;D HY ,- 33. I hereby~ that the~in~;~d~attached information is complete and correct as determilled frolll all-available Feb )FtS SIGNEI~~., ~~e~ TITLE DistrictDrilling Engineer r,,,T~.; 10/6/77 *(See Jnstructions and Spaces [or AdditionaJ Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachmer~ts. Items 20, ~,nd 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~c. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervol reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the acJ~clitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FO~.MATION T~S'I'S 1NCLUI)IN(; IN'I'EI~VAL TESTED,' t>H.ESSURE DATA AND'~,COVERIES OF OIL, GAS. 35. GEOLOGIC M ARK~2I~ WATER AND MUD NAM'~ MEAS. · .16. COlliE DATA. Aq~I'ACI{ nRIEF DI~CHIi~.rIqoNS Or ~ITIIOLOGY. POROSITY, F[iAf'TUIIE~. Ap~{ AN~ I~C~'ED SIIOWS OF OIL, G~S Oil ,, , Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to cleepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. ~vIELLL~--'~ GAS D OTHERWELL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At SUrface 1463'N & 50' E of SCl cr Sec 1, T1 ON, 13. 14. 99510 R15E, UM ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20236 6. LEASE DESIGNATION AND SERIAL NO. ADL 28345 7. IF INDIAN, ALLOTTEE OR TRIBE NAME · 8. UNIT, FARM OR LEASE NAME Prudhoe Bay [Init 9. WELL NO. DS 9-11 (13-6-10-16) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 6, T1ON, R16E, UM 12. PERMIT NO. 76-84 ~ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letells, and give pertinent dates, Including estimated date of starting any proposed work. Began perf ope.rations 9/1/77. Tstd tree, csg, & wireline BOP's. Pulled dummy valve. Perf'd intervals: 12,175' - 12,185', 12,153' - 12,159', 12,117' - 12,121', 12,096' - 12,110', 12,043' - 12,060', 12,008' - 12,028", 11,994' - 12,008', 11,94'1' - 11,961", 11,933' - 11,941.', 11,910' - 11,920', ll~ 1~1,885' with 4 shots per foot. Ran Amerada press bombs. Flowed well'. Ra~ & set ~a,1 valve. Tstd balance and control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept 9/6/77. 16. I hereby certify that the foregoing is true and correct Dist. Drilling Engineer TITLE ' DATE October 7, 1977 (This space for State office usa) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' T IT LE DATE See Instructions On Reverse Side 02~01B STATE of ALA. SKA DEP~~f C~F ~AEURAL RESGJRCES Division of Oil smd Cas C~Dnserv~tion TO: ~ FROM: O. K. Gi[lb~e~, Jr. Director Hoyle H. l~milton Chief PetroletE~ Eng~ PetroletEn Inspector DATE : SUBJECT: 12, 1977 Surface (kntroll~l Subsurface Safety Valve and~ce Safety V(31ve Tests Arco's D~~~ 9-12 ~?nday, sepf~ 4, 1977 - i departed, my hc~e at 4:00 ._~;~ for a 4:30 st~wup and 5: 30 '?M dele v~ Wi~ F~ 919 f~ ~ ~y, ~iv~ ~e via F~ at 8:00 E4. I ~i~ at ~i~ Si~ 95 at 8:30 ~e K~y C~ff, ~ill~ f~~, ~~ ~ ~ ~ ~ ~1~ m ~ 5-16. I ~ at~ ~ ~~ ~ ~y ~ ~~ 3~ ~t ~e f~t ~ ~1~ d~ ~ ~ f~ ~~ ~ ~~ F~~ a~ Kirk ~ite contacted ~ shortly after arrival at Drill Site #5 and a~vised. SSSV's ~u-~ ,~V's on 9-11 and .9-12 %~dld be tese~l the follc~4nq~ day. ~te~. 5, 197! - Minos ~bemt pict~d me up at 9:30 _~. oa~d ~sts ~ ~ ~ ~ ~~ at 10:00 ~I ~, ~ ~1~ ~ wi~ 3500 ~i ~ ~ ~~ol 1~. ~e %~11%~s fl~. f~ ~ n~u~s ~ t~ shut ~. ~ut ~ ~~ ~es~ ~s 1250 ~ig. ~es~e ~e ~ ~ ~t at 22~', ~ ~ bl~ ~ 1000 ~ ~ ~~. f~ f~~m~. ~~ ~ ~ bl~ ~ 700 ~ig ~1~~ f~ fif~~~. ~ ~ ~ ~L~ ~e ~ ~~s~~ ~ 1250 psig ~ ~ clX. ~~ ~~of ~ ~Vw~ bl~ ~ z~ ~ ~~ f~ fi~ ~~s. ~s~ ~e ~1~ at 11:45 ~{. A field ~~~ ~~ ~ p~~ ~i~h ~ orig~ giv~ ~ M~os He2~, a ~~1~ ~ ~ ~' " ~ a ~ at~~ ~ ~s r~. .~_sdaY_,~.Sep_~ 6, 1977 - yinos l~3~t and I arrived at DS 9-12, ~ ~-~-9~':05 ~ ~und shu~c in tubing pressure v~ 1300 psi9. was ~hen closed. Pressure ~ ~%e F~qSV, set at 2204', ~ then bl~] to 1050 psig and monitored for five ~nu~ues. Pressure was then bled, to 700 psig and monitored for five. ndr~ates. The S,~_c&.cV ~s then reopened shut in tubing pressure returned 5o 1300 ~psig. ~ was then clo.~d, ar~] pressure downstream bled to 150 psiq and ~t~itored for five minutes. T~sts %~are ccncluded at 9:50 ~I ~mt a field inspection repGrt co~ple~ with ~he original given to N/nos Hebez~, a copy mailed, to Bob I-~ines, a cc~y attac~hed to this report. I departed Arco's Pm~ihoe strip at 4:20 ~,~ via .9~ daarter, arrivJn.7 in Anchorage at 5:50 P~ and at n~ bo~e at 6:30 P~. ~ ~~: I v,~tnessed~ successful E~SV and SCSV tests cn Arco's DS 9-11 Attach~_~nt '::~. :...:,.'- ,~:-~ pe~a~or-~'~:~'~'''_: :~~ :~ :'~?>'::~'~ .................. ' ?~'~:::'"..'"'"'. :Re~'prese~ted. ' "'~:~_ b:' ~':y .~- ~~~~' ...:'-.- Name. &..N~mber .' -"':. ''~.." ' , "~ ~.' '-- ~,~" .... ..~' ..... '"'~ -~ '-' -~'?~: .Sa.~i:sfactory'..'>~Typ~::;~nspect~on .... Sat~ sfactory .'TyDe,'Inspection . ' '' Yes: .No' 'Ite~'(.:):~:~6C'ation,General ' Yes No Item (~'BOPE Tests . ' ( )' ( ) 1. Well:-~Sign ( ) ( ) 15. "Casing set ~ ( ) ( ) 2. General'Ho~sekeeping ( ) ( ) 16. Tes~ fluid-( )wt,)mud ( ) oil. ( ) ( ) 3. Reserve.Pit,( )open( )filled ( ) ( ) 17. Master. Hyd. Control Sys.- psig ( ) () 4..Rig.- ( ) ( ) 18. N2 btls. , , , psig (~Safety Valve Tests ( ) ( ) 19. Remote Control~-- (~ ( ) 5. Surf~Ee-N.O'. Wells~ (.) ( ) 20. Drilling spool-~"outlets (~ ( ) 6.. SubSurface-No. Wells ~ ( ) ( ) 21. Kill Li.ne-( ) Check valve ( ) Well Test Data ( ) ( ) 22. Choke Flowline ( ) HCR valve '( ). ( ) 7. Well Nos. , , , ( ) ( ) 23. Choke Manifold No. valvs fl~s ( ) ( ) 8. Hrs. obser ~: , , ( ) ( ) 24. Chokes-( )Remote( )P~s.(~dj. ( ) ( ) 9. BS&W ,--,--,-- ( ) ( ) 25. Test .Plu~-( )We~lhd( )csg( )none (). ( ) 10. Gr. Bbls. , , , ( ) ( ) 26. Annular Preventer, psi~ ( )Final' A~andonment -- ( ) ( ) 27. Blind Rams, psi~ ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams .psiq ( )' ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock ~psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve ~si~ ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valves-( )BV ( )Dart Total inspection observation time/~hrs/d~s Total number leaks and/or equip, failures Remarks cc-'~~ ~/~~ Notify in days or when ready 'Inspected by ~7~~ate CONFIDENTIAL DISTRIBUTED TO: STATE OF ALASKA D~VISION OF OIL & CAS North Alaska District Engineering T RAN S M I T TAL To' From' J. A. Roch0n/D. R. Jackson Date: May .26,. 1977 . . Well Name' D.S. #9-11 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log 1 ',. BHC Sonic/Caliper - Gamma Ray Log 2" & '"S" BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/%~L Compensated Fo~ation Density Log ,. Compensated Neutron-Formation Density _ 5" Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (COny.) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction'Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat b~crolaterolog b~crolog b~dlog -_Interval Sample Log (A.R.C~.) - Interval Synergetic Log TVD-DIL TVD-Porosity Log Casing Collar ~og '5" .2." & 5" Xerox Sepia BL Line ea. / ea. ea. t ea. ea. I ea. ! ea. . [ ea. . I ea. Receipt Acknowledged For: Date' Please return receipt to' Nr~l~ Alaska Engineering ~X~nager P. O. Box 360 Anchorage, Alaska 99510 #405 AtlanticRichfieldCompany North Arneric '~'~"roducirtg Division North Alask ~,rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 6, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 9-11 (13-6-10-16) Permit No. Dear Sir: Enclosed please find a Completion Report along with the Drilling History and Multi-Shot Directional Survey for the above mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure · SUBMIT IN D, STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ~TE * her ~1 l.uct iotl~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF %~ELL: b. TYPE OF COMPLETION: x~w ~ WOnK [---~ V,' E L I, OVER 5. API NU-NLI~I[ICAL CODE 50-029-20236 6. LEASE DF-~IGNAT/ON AND SERIAL NO. ADL 28345 WELL WELL ~ DRY Other DEEP- ~L~ PI. UG [~ DIFF. [--~ E N BACK RESVR. Other __ 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360 Anchoraqe, Alaska 99510 4. LOC^rlON OF WELL (Report location clearly and in accordance with amy State requirements)* At surface 1463'N & 50'E of SW cr Sec. 1, TION,R15E,UM At top prod. interval reported below 1306'N & 1086'E of SW cr Sec. 6, TION,R16E, UM At total depth llDI'N & 1566'E of SW cr Sec. 6, TION, R16E, UM 13. DA. TE SPUDDED ~14: DATE T.D. I~F-~CHF. D 3/14/77I 4/20/77 7. iF INDiA-N, ALLOTTEE (9ft TI<IBE NAi~LI~ 8. UNIT,FAILM O1~ LEASE NAME Prudhoe Bay 9. WELL NO. ('~Ds 9- i'~')(13-6-10-16 ) ~0. F~ -JaD-,~l~4~OOh, OR WILDC&T Prudhoe Bay - Sad]erochi 11. SEC., T., ti., M., (BOTTOM HOLE OLk~ EC~I'IV E) Sec. 6,TION,R16E, UM 12. PEI:LMIT NO. 76 - 84 15. DAT~ COMP SUSP OR ABAND. 5/1/77 ('54' .I~KB ~S. TOTAL DEPTH, MD & TVD~t9. PLUG, ~BACK MD & TVD~20. IF 1WcrLTI:PLF, COIVZPL., I 21. 12,347JqD,9070'TVD112,26 'MD,9031'TVD/blng,e~°w~' I ~"T"~kiTI"~ 22, PRODUCING LN-T~ERVAL(S), OF THIS CO~ViPLJgTION--TO,P, BOTTOM, NAME (MD AND ~-D)' Top Sadlerochit ·11,781 'MD, 8794'TVD Bottom Sadlerochit ~12,200'MD, 9003'TVD t~T, GR, ETC)*ll7. ELEV. CAS1NGtlEAD I INTER~.'AI,S I)RII, I,ED BY CABI,E TOOI,~ 23. ~,VAS DIRECTIONAL SLJIlVEY MADE Yes 24. TYPE ELECTRIC AND OTHE~ LOGS RUN DIL/SP, BHCS/GR, FDC/C_NL/GR,GR/CNL/CCL 25. CASING RECORD (Report all strings set in well) c~s~4c; size! l'b/ft2t~-~'" ~ GaXD"~ '1 DEPT>t SET (~D) [H°L~' sIzE20"13_3/8,, 72t:'Butt94~ [ MN--80IH--40[ 2702 ' .73' ~ 17~1130",' ADoroxlsfifO. ' ~x'CE:'~LN2'iNG I~ECOI~ Arcti c~t500 sx cirCcmttn ~l~ ,'~?..I,)UNT PULLEDrf 9-5/8" 47~-But{ N-aO&I l l:Sq~ ~" l!000 sx Class G cmt [ lsoo-951 m 1-"1 , I 26. LINE~ ~CO~ [ 27. TU~iNG ,,. 7" [ 11,282'~o ~ 12.342',_ [ 450 . I ~" ...... 28. PERFORATIONS OP~ TO P DUC O~ (illtcrval, size and nurnber) 29. ACID, S'i:OT, FiiA. U'I Gl{E, C~.IENF SQUZZ;?Z~J, ETC. DEPT~i 1N'i'~VAL (MD} ] AMVUN i' ,'~]?~) xyl,'p,~.t~wl~ USED 30. PRODUCTION D~C~.EFIRSTP~.`~D~CTI~N~P~DUCT~NME~[~D(~w~i~U:a~pping-sid~ype~fpump'-~ .... ..... [ V, 1,H~t, i~'['AT US,, P,'oducing or __ N/A DATE OF T~ST, [~OLrRS 7_EST~ ' [CIiOZ{E SIZE '[PROD'N FOR OI~BDL. G.AS--21CIc. %:ATER--I]DL. [ GAS-OII, It.VI'lO 31. msrosm'xos or ~*s (8o1~, used IJr luet, renteR, 'etc.) i ITEST WITNESSED BY Drilling History, ~ultishot Directional Survey .... 23. I hereby certify that the foregoing and attached information is complete and correct as determined frvm all-available records 8I¢NE[ 29} N TITLB District Orilling_~n~inem. r mm m m *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate whic'h elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, production from more than one ~nterval zone (multiple completion), so state in item 20, and in ite,~ ?2 show the prcJc, ci~0 .interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this .form, adequately identified, for each additior~al interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced~ (See instruction for items 20 and 22 above). 34. SUMMAIiY OF' IvOI;[MA'I'ION TEST.'6 IN('/,UI)IN(; INTI~.IIVAI_, TESTED'. PHE,~SUHE DATA ~ '}[ECOVEItlES OF Olio. GAS. 35, G I~X)I.,OG I C MARK~ WATER AND MUD ~ , , ~tl. C~I'IE DATA, A'I'I'ACI[ AN[~ DET'EC'TE1) $11(IWS OIg OIL, GAS OI1 IVA'T'E'I{. ,, ,,, ,, , ....... -,, DRILLING HISTORY D.S. 9-11 (13-6-10-16) API 50-029-20236, ADL 28345, Permit No. 76-84 Spudded well @ 1300 hrs on 3/14/77. Drld to 2750'. Ran 13-3/8" 72# MN-80 Butt csg w/shoe @ 2'702', FC @ 2622'. Cmtd w/5650 sx Arcticset cmt w/0.7% D13R. Good 14.6 ppg slur returns. NU & press tstd BOP. Drld FC, firm cmt & FS. Press tstd form to 11.6 ppg equiv mud wt. Directionally drld 12¼" hole to 5267'. Rmd 5109'-5210'. Side tracked hole. Rmd 5192'-5210' unable to work into turbine run. Drld 5210'-5250'.. Turbo drld to 539~'. Rmd 5345'-5399'. Drld to 5443'. Rmd 5372'-5443'~. Drld directionally to 11,600'. Drpd multishot. Unable to pull wear bsg. Set 13'3/8" BP @ 1,000' ND BOP. Inst new spools. Tstd BOP & retrieved BP. Removed wear bsg. ~an 282 jts 9-5/8" csg 47# w/shoe @ 11,595', FC @ 11,473', upper FO @ 2296', lwr FO @ 2418'. Cmtd w/lO00 sx Class G cmt w/0.75% D65 & 0.2% D13. Slur wt 15.9 ppg. Set 9-5/8" csg pkoff & tstd to 5000 psi. OK. Opn lwr FO,.~.~.~2EIQ~.Sx ^rcticset cmt thru lwr FO. Flwd FO & tstd 3000 psi OK. Opn uppe~ FO. wSha~'~'L5/8" X 13-3/8', anul w/400 bbls wtr. Arctic Packed w/brk thru @ 155 bbls w/O% contam. Clsd upper FO, tstd 3000 psi OK. Drld 3 ' ' 8½" hole to 12, 47 . Drpd multlshot. Ran DIL, BHCS/GR,FDC/CNL/GR from 12,347'-11,595'~ Cond hole. Ran 7" 29# N-80 butt csg set @ 12,342' Cmtd w/450 sx Class b cmt w/0.75% D55 & 0.2% D13 & 0.2% D46, slur wt 16 ~pg. Displ w/235 bbls 10.9 mud. Drld cmt to top of lnr @ 11,282'. CO lnr to 12,171'. Tst csg 3000 psi OK. RIH w/DST tools w/77 stand wtr cushion. Opn tool w/slight blow after ½ hr no blow. Rev out mud w/lO0 bbls fresh wtr followed by 10.6 ppg CaC1e wtr. Ran junk bskt w/gauge ring to 11,282' Ran GR/CNL/CCL logs from ~0,000'-12, 262'. Ran 5½" tbg w/shear sub @ 1~,529', Baker pkr @ 10,393', PBR @ 10,349, RQY nipple @ 2254'. ND BOP. Inst & tstd tree to 5000 psi OK. Pulled dummy valve. Ran CCL/dummy gun. Ran dummy valve. Released ri9 @ 2400 hrs on 5/1/77. ~~ i .Eastman ~ i Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Richfield COMPANY D. S. 9-11 WELL NAME Prudhoe LOCATION JOB NUMBER A477 S0341 TYPE OF SURVEY Multi-shot SURVEY BY Shyam Talwar OFFICE Alaska DATE 3-4-77 REPORT MAY 3, 1977 ~TLANTIc RICHFIELD CO, ~7 ...... ? DRILL SITE 9-il a-~G'NET"iC MUL TT~O'T'-~-O-R-~'~-Y-'~ DECL IN~'"fi ON 3 i DEGREE~ EAST : O"~P OT E D-- F 0-~ E-~'~-A-~-W~ I-P-S'TO C K I'N- C' ;--B~'-'F~"-~ ~'~D-S-E'~A~-D~~C-F~E S R-E~O-FD--O-F-'-SfJRgE Y A LU--C~CI/JCT~T'FO-gf-P-E-~FO-R~-£ D-"B ?'-T'-B'"-~-'T[~T~O N-iC~ COM PU ~'E~' S-;--"D~-['P Y-9"~-'~'T-i"~'~ ......... -.SUB DR I F T DEPTH ANGLE DEPTH SEA DIREC DOGLEG TOTAL COORDINATES CLOSURES SEVERITY DISTANCE SECTI ANGLE DEG/IOOFT DISTAr, 0o000 0,092 0.187 925,91 929,65 935,75 2750 i 0 2749,77 2695,77 S 9,OOW 1394.01 N 729,26 E 1573,24 N 27 36 57 E 0.022 .... ~7§'~ ....... ~---~ "~"9-~7'~ ...... ~'~"7~ ~-~-6-O-E ...... i~9'~'Ji'~-~ ......--~6,08 E i-~2186 N 27 39 25 E 3,363 2888 6 35 2887,44 ze'3-~.~ N78.00E 1394~-~-- ...... ~7,36 g 1577,26 N 27 52 18 E 4.399 .__~.8~ .....9_.~ .... g~.~.~_7._..._~ 26.'77 ...... N 8..!., ~ ........ ~.~ ~ 6 · 73 .... N ......... ~.5.0 ,_~_..~.~.1.5.8.5.~.~.? N_..2.8~._~_ ....... 0 E_L ......... ~ 63 307B ~ 30 ~07~,87 3017187 NS~,O0~ 1898,82 N 767,50 3169 13 30 3163164 3109,64 Nse.ooE 1400,06 N 787,81 E 1606,49 N 29 21 58 E 2,135 929,72 930,40 937,76 951,11 968,25 988,51 3262 1~ 45 3253.82 3199,82 N90,OOE 1~00,46 N 810.50 E 3356 15 0 33~4167 3290167 S86,00E 1399161N 834,61E 3450 15 45 3435131 3381131 S84eOOE. 1397144 N 859144 E 1618,08 N 30 3 35 E 1629157 N 30 48 29 E 1640,57 N 31 35 30 E 1,351 1011,00 0,390 0,813 1034,72 1058.94 3544 17 35 3525.36 3471,36 58110'0E 1393,92 N 886,17 E 1651,76 N 32 26 44 E .... ~'~'~'-'-1-9-'-~-5 3613,59 3'5-59-'.59' 579.00E 1388.82 N 915.10 E 1663.20 N 33 22 52 E 3730 19 35 3701,30 3647,30 S80,OOE 1383.19 N 945,51 E- 16751~7 N 34 21 19 E ~823 19 20 3788198 37~-~198 N88,5OE 1380-'89 N 976.36 E 1691,20 N 35 15 ~4 E .... 39'19 22 15 3876e85--}82-2-~85 N~6-~6-OE 138"k-"~'-%- 1009.69 E 1711e95 N 36 8 31 E~ 1,979 1,800 0.385 1.383 3,119 2,963 1084 i 1141,90 1172,07 1205,26 12~2,38 4103 27 45 4045,36 3991.36 N90,OOE 1385185 N 1088,18 E ...... ,-_o_-9 E,fO s' o 4290 32 10 4207,49 4153,49 587,00E 1383,77 N 1181,23 E 4384 34 45 4285,90 4231,90 586,00E ~1380,61 N 1232,95 E 4477'--3~ 0-' 4-~--6-i-,--~-6 -4-30~'-"~-6--'5~'5-~-5-0E---1-3-7-6,57 N 1287.30 E 45-7-1 4-6---2-0 4~3~,6~ ~-s-Sb-,-6W-"S'8'S-;-50E f3-~-l-,-gg-N 1345,8~ E 1762,02 N 38 8 21 E 1789169 N 39 16 23--E' 1819e38 N 40 29 5 E --1851,ol N 41 45~:-59 E-- 1921,87 N ~,4 26 57 E 3.039 2.167 2.644 2,766 2.427 3.553 1283,37 i 3 z-7-'5'3'- 1375,06 i 2 1478,85 i 5 3 6 4664 43 30 4503,83- 4449,83 584100E 1366,28 N 1407,70 E 1961,72 N 45 51 20 E 3.483 1596,36 RECORD OF &URVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER __TRUCE M_EA_,S_,__D__EI_.F_T VE___R_T_!_CA L DEPTH ANGLE DEPTH SUB DRIFT SEA- DIREC D M DEG, TOTAL COORDINATSS DO..~LL..E_G .......... ¢ C 0 ._S,.U_.__R._~___S SEVERITY .SE.C_T. ION. D I STANCE.__ ......... ..A_N G.L..E ..... .D_E_G_~.i_O_QF_T_ ............ D I_STANC.[ D M S --44757 44.6 20 4569,67 /+ 5.15..76_? SS__4.3_5__O_E !..3_5_9_,_'/_0 N 1~!3_,_0..4 E 20044,65 N 447 1_7 2_8_E 3_.,_0_67 ........ 3,.63'9.~9.7_i 4485]. 449 440 44632,56 44578,56. __S84_,_0_05 ]...aE_217..O_N__l_5._~_2_,_5_4..E... 2_0.5.1~.6...4. N_GS_44.5___5_5 j_,_5_5..6 .......... 1_72" ~.44_ ............ .... __5 0 3 7 5 5 3 0__44 7.4 5.,_9.._5 4_6_~.!_,_9_5___$._8._3_,._.5_._0_E 1~_._3._.6_._,._~_4, _N__L68_8 · 9 6 E ~_1_.5__3_,_6_9 N 5 1 3 8 B 3 E 8._,_~_9_.~ ....... 18_69._,_9_7_ 5130 57 z~5~ 44797,,1_1 4743,.lJ. ...... ~_8_4.._,_0_Q.~ 1_~_2~_,_8_8 _N 1_~_6._6_,_1_6_~ . 2_~_0_9_e_6_6. N_5_3 ....... 3 44__4_E 2..,_44~_0 .... 1_9_~,.~_,_0.~_ 5182 58 445__~82.~_,.~_7__~__7_7_0_,7t7 S_8_5_.,_5_O.E .!~_2._3_,_8~_N L8_l_Q._,_k9 E 22_9_Z_,_62_N_5~_~9__~,_5_E Z_,_8_5_4 ~9_ 8 ..7... ,. 9_6_. _ 5 2 7 6 5 7 .... 0___~.87~_,.46 4_8_Z_0_,76 $8_9_, 00E 1_D_2.0,02__N ....... ~88..9_.,..6_9 E.___2.3_QE_,_08 ...... N .... 55 ...... 3 .... 5.1 ~ : .... ~_,2.1~ ............. 2.0.65.,99. 5_3_6_9._5_4_.1.5 . 4_9.2_6_,_96 44872_,._9_6 ....... _N.8.5_~_5_QE 1_3..2.2_,_3 6__~t__1_96_6. ,_37_.5 ....... 2.3.69,.66 N.....D6 .... 4...446 E ................ 4,.8.90 ............. 21~2,.16 __5~ 6 2 ~ 5 30___~9._SQ.:__~_?____~9_2A,_~_? N__8.~_:.O_O__L_l..~_2_9_,..32___N__Z_O_.~_2__,_l.2 __5 55 4 5 6 0 5_0.3 2..,.27 __5647 55 20 5084,69 5030,6_9.. __57 41 5 5 3 0 513~_:_0.~_..__5_9~4_,._..07 58344 56 0 5190,38 5136,38 __5928 5_5 /+5 . 5_2__~_3_,_1_2___5189,12__ 6020 55 0 5295,39 52441,39 6113 55 0 5348,73 5294,73 6206 55 ].0 5401,96 5347,96 6299 54 445 6_393 55 64487 55 0 5553,3~ 5509,36 6 5 8-1__~5 o 6_6_7J+ 5_5__15 E 4_._9__~_8....,__2~ N._8_5, OOE !_3 ~_.6_161 N 2117,81 E .N..8_5,005 1_%~_%,_~_0__~ 2_1~_~_,_%Z_5 ._ N_e_6._,_O._9.E !3_4_9_,37__~___Z_Z 7 ~.. 447 E N86.00E 1354.74 N 2348,16 E N 8.6_,_5_0 E 1~_5_ 9_,_8.2_..N.. N 8_6,00 E 1.3.6~.,78 N 2_.5D_1_,_3_5 E__ NS_6__,_O_O.E___!3_7_O..,.09 N 2573_,_34. E N86,50E 1375,08 N 2653,444 E N87,005 1379,39 N 2729,446 5 N8 6,_5_QE. 1.3_ 83__,_7_ .5_._ N__ 2_8_0_6_,_2_2__5 __N89aOOE ]._3_8_6_,~_8 N.. 2~_8..._3_.~_~.5 E 5_6_1_7_,_2_8 .5563,28 N. 8_7_,_QQE 5_6_7_0_,_45. 5_616_,_4_5 N 8_7_,_5_0L13_9 3_,_ Z2_N S_O3_6_,31___E 2436.,~..N__5.6 .... 56__.16_~ ..... L,_7_3A .... 2504,33 N 57 44 34 5 2710,93 N 60 1 ~+ E 2__7_8_0_,_9. 5__N_ 6_0 2_84.9,~_5_N_61 22 ~6 5 __2 9 !_8_,_8_8__N_._6.2 0 19 E 2988,58 N 62 36 20 E 305_8_,.22_N__63__ 1_1 21 E__ .~_1_28_,_8_4._ N_._ 6 D___. 4_5___ __7___5___ ~_1_9_9_,_3__3_._.N_.6_~_1_8 .4.5 5 ~_2_6_9,_99_N_..64_._ 5 1 1..7_._~ 33__4.0_,_6.6_ N__65 .... 21 _ _]._. l_. E __ ~_,_9_2._~ _22.9_~_,_0.3_ O_,_7_LO , 2 3_.7_0_,_6_7_ 0 · 7 ~_2__ 2.~ ~_7_:_8_7_. . .0_*_5_38 O_,_~t..5_O 2 602J_0.3_ 0_,._8_9_3 0_,_0_0 O__ 0,44 0 6 28 2_9_,_~_8_ 0,577 2_9_0.. _O_,~AE_ 29_8 ..... Z._*_k7_9 1.._7.4.3 ........... 3.13_44 0_,~52 __ 3.21 67_6_8_53_k5 5_7_2_44_,_03 68 6 2_5_5 0__5_7_7_7_ 6956 55 440 5831,24 704 9 56_.3_0 71_4_1 5 7 0 5_9_333_5_._8 72.33 56 20 5984,13 7326 57 0 33.13_,_/+_7_E___3_4_k2.,32_ N_ 65_5.0_3.1 3_1._9.0_,_5_2_E 3_4_8.4_ ,&_ k. N_ 66__18__36__E 0_,26 6 3_2_6_7_,_7_9 L3_5_5_5_,_9_4_N___66__46__~_ Z__E 1_,301 _3~,_0,88 · 3_3_~_4_,_9_6 E 3_6_2_7_,.5_0 N_.6_7 L44__l_Z_E 0_,_892____3.5_17,3 7_ · ~?_2J._,_8_9 E 3_6_9_ 8_,_8 2_N_6_7_.__4._ 1_ 1_7 __34498,76 E 3770,04 N_6_8 7 54 5 0,71~_ 3_66_9,_5_44. 5_6_7_0_,.03. 5_7_23_,_7_8 5777,2_4 5879,58 N.8_7_ ,_ 5_ 0.E~.9_6_ ,_4_9J N8_7.,__5.05 .__N_8_9_, OOE 1 44 0 2.,_22_N_ .N 8_9_.,_QQE N~Om 005 14404,24 N 5930.13 N90.005 1404.24 N 6035.23 5981,23 N89.50E 14404,57 N 9576,46 E 3842,39 N 68 33 31 E 0,80~ 37~6,442 RECORD OF SURVEY TR-OE DOG LEG DRIFT TOTAL COORDINATES C L 0 .5 U R E ,5 SEVERi~TY SECTIgN_ MEAS. DRIFT VERTICAL SU@ DISTANCE ANGLE DEG/i'OOFT DISTANCE D N DEG. D M $ 7420 57 1.5 6086,25 603-2-'25 NgoeooE ].~04,92 N 3655,/+1 E 3916,10 N 68 58 34 E _0_,_~+_6.3. .. .... ' _ 7606 58 5 6185,27 6131,27 589,50E 1404,58 N 3812,86 E 4063,3/+ N 69 4.6 3.8 ..... E ........ 0,_3..9_9__398_Q.,_]._5_ 7700 58 0 6235,02 6181,02 ........ $9_0_,_0_0_E .l_.~_O_.~!.i23_N__3.89Z,_6.1._E.... 9.1_3~._,._1_5 N70 9 48__5 ....... 0,_39.4 40583_9_5_ 7-9'9~;-5-ff-'-~-~--6~-~-'5-',--3-5 ....... 623'1.35 SgO.OOE 1~04.Z~ N 3972.00 E ~+212.92'N 70 - 788_7 .... 5_.7._~0__6.3.3.5_,_6_.0_ ..... 628_1_,60 .... _5_8......9__,._5_9E_. ~_~__0~_,_8__9 N ....... 4.0..5_0_,_26 E 4286,66 N 70 52 58 ..... 7980 .57 ....... 0 ...... 6.._38.6_.__._0.2 ..... 6332.. 02 ..... N 89.,_0_0E.____1_4._0..4_.,_23_~ ........ ~__12.8....~0__E.. ........ ?_~_6.0.....68 8074 56 35 6437,50 6383,50 N89,00E 1405,60 N 4207._tO_.~__E .... 816.7 5_6.__0_ 6_4..89~_.1.0 ...... 6435,1.0 ......N.8_9~_5_0E 140~_:__6.._1__N___~..28~__,?0 ..... .8 2 6_0._5_ _5_.__0 _65__4_1_?_78 6487.,.78 .......Ng.0_._,__O__OE____l..~_O_6..~_-9_~_N ~_3.61__,_.02+ 835/+ 55 5 6595,64 6541,6/+ N89,50E 1407,28 N 41+38,08 --8~97.___5_.~ .2_ _ .0. __ 6_ . 6_/+_ 9 3_ ~ _6 . 6.-ii595,36___N89_,~..O.L!_._~_O_8?_z_8__N 4_5_!_3_:__9_9 .8._5_~..0__5_3_~5.__6_7.0 3.-'._9_6 ..6 61+9 · 9 6 ...... N 8 9.._50E_____Z...~ O?...Z.6_N z+_5_8.9._._Z 6_E 4435,61+ N 71 3~_~.~_E 4509,~9 N 7.3,__~_9. 27 E 4582,38 N 72 7 9 E 4655,86 N 72 24 23 E 1+72_8_,__5_7 N 72 4.800,77 N 7__2 5.5__~5 E 4 __o · z+ 3.6 _0._,.73_~, 4_~..~6_,.6.8_ __k,13_.~ 1+ 0_,.88_], ~.6_7_3_ 8632 52 5._0. .... 6_7__5_8_Lg_5___670~,.95.__N89...,_5_OE . 8_?.2.6__5_2___3_0_ 6_8...1.5._,_9_5 .... 676]..,.95 ....... N89.:.O_.O_E__.l__4-Z_O..,_88_N ....... ~_7.3_7_,_76 E____?__9_4_3_,37 N 73 21+ 59 E__ 8820 52 45 6873,01 6819.01 N89,50E 1411,86 N 481_2_,.~5 E 5015,28 N 73 38 58 E 8913 52 40 6929,35 687.5....35 N89,50E 14123_5_1 N 4886,44 E 5086,50. N 73 _5._~__ 37 E __._900.6__52.._.!_5__.__6~_8_6_,_.0_.2___69~2,02 ...... N89,.5_O~_~_l_~.._l...%,.15__N ..... 4_96_0_.,18_E 5157,55 N 74 5 51 E 9099 5 2 0 ..... ~.0.~_3_,.1._2 69 a 9 · 12 N 89,5_OE .... .1. 4__13 .,_7_ 9 N 5._033.,. 58__E ....... ~._2_2_8 :_36_N__7._~___l._8___~._l__E .... 9192.52 0 7!00.,..37 70~+6.37 NS. 9,.50E ...... .1_z+1~+,~3 ..... N .... 5_.1.06_,.86 E__5299..,~2 N 71+ 31 8 E 0 · 49_3 z+_89_5_.,..5! .0_.._~29 ~9_6.9_~_5_7_ 0_,_0_8_6 5_0_~._2_ o.1+52__5 L~_' ~2_ ...... 0_._2__6.9 ... 5!88_.._5.0_ __o · o o o__..5_2.6_~_:_o.~_ 937.9_5_0__~_5 7_2_1_7_,_.3._7 ..... 7_].63_,3? .... N8.9,.OOE_.___l~_16,66 N 5252 · 72 E 9473 50 0 7277,31 7223.31 N88,50E 1418,24 N 5325,11 E 9567 ~9 55 7337,78 T~"8'~-'-~/8--N-B'~"-OOE 1419,81 N 5~97,06 E 9~61 49 10 739-8-'-7;/---7'3'~+~-;-77 ..... N88'-5-O'E 1421.37 N 5468,58 E 9-755 ~+9 0 7460,33 7406.33 N89,50E 1422,61 N 5539.60 E 9848 ~8 20 7521,75 7467,75 Ngo,ooE lz~22,91 N 5609,4~ E .... z_ .... N _O...O0 E _.]...0.03~.._~7 10 76/+6,80 7.592:80 .... 58_9.,0.0..E___1.?.2_2..,.32N 571+7,11 E 5369,63 N 71+ 43 0 E 0.950 51+ 4_0___,_~_1__N_7. _ .~_5__4_. 2_3_ E ..... 0_..51+7 5510.73 N 75 5 11 E 0.857 5333,24 5405,60 5~77,~1 5580,69 N 75 15 39 E 5650.28 N 75 25 48 E 5719,35 N 75 35 50 E 0,632 5787,09 N 75 45 58 E 0.771 5854. !.~_N.___7_~_55_57 E 0 · 631+__ 5920.50 N 76 5 58 E 0.320 55~8,79 0.864 56~0~_~ 5759,23 58_2~._' 61. __0 · 851 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER ~_E6S, DR ! FT VER.T. ZCAL ............. S.._U.B ....DR ! FT DEPTH ANGLE DEPTH SEA DIREC TOTAL C O0_B_D__I_ N A__TE $ __ D M DE6, ..1_O3.11_75_20 ......78:38,90 ..... 7'7_8~_.9.0 ....... $88_.0OE 14..].._5,.94._N__59._.4._6~_5_~_E ..... 6]..12,78__N._76 36__2~_E 0..,3_70. ........ 6091, }__ _1_0_~_0_5_~+_4_5_0 ....... 790_5,2Z ..... 78~!_.,~2_7 $8_8~.0_0.E _!_4_.]..3_.~62_N__6.Q!3,06 E__ .6!!6_, 9 9, N_._76_.~+_6_13~_E ........... 0_,..53._2 ....... 6156,92 .... 10499 z~__L5 .... 7972..:_26 79.!.8_,_2..6 $.8_8.00E 1_4_1.1_,..~2__N~ 6_03_8~_9._6_E'____6..~_O_e.6.4_N__76_5_.5_~.6_E... 0_._6.2._8 . 6221,73__ _1_9.5.9_3_.z~_/~ 0 .8..0.39 · 74 ....... ,.70_N_77 ......5_2.0_E- .0:_518 ......... 628.5 !0_6.87 4_3__30. 810.7.,_64 ..... 80_53_,_6~___S.8.5_,0_QE__.14.03,..93_N__.62_O_9_:_l_8__E _ 63_65.,~92_N_77__lS_3.3_E 1_,._1_.~0_ ............ 63/+9 · 10782 42_..2_0 ..... 8_]'_7..~.,..20____8!_2...~_,_2~0_._~ 84, OOE !..39..~_,..7..~_N ' 6..2!3_..5.7_E____6~_2.7_,. 39_N_77_Zb_2_~_~___l....~-1.]' ..... 6~.12.11 _]._0.8!5_~.2.. 0 8.2.46_,.13 ....... 81.9.2_,_13 S_83..,_O..9.E ..... 1390,66 .... N 6_33_5_,_6_0__E 67.8_6_..._4.3_N__77 .... 37._1.1._E__ ~ 0_,_6_Q5 ........ 667.2, _1_0_9_~_0_8_& _0 ....8.3.15._.6.1 .... 826.L,_6~___S82~_.5.QE__!~82,__4-8_N 6399,87 E .654.7,~9_N__77 4.8 37 11063 46 2_0__:__838,1.,,..1.7 8327,17__S_8.1,50E 137~,30 N 6465,18 E 6609,/+3 N 78 0 27 11156 50 15 8~.~3__?_03 8~_8_.~.,_9.3..S.8Q_,._OO_E____13_6...Z.15__N 6533,70 E__6674,,18 N._78 .... 13__2_5 _1_!2_5.I__5__~__....08_50_1.34 8447 .,,_.3._4.___S7._8_?_0.QE. ...... 13~._7_:84t_N 6_6_07_,.27 E._____6_T_.4.3_._3.6_N_78 28_1.2_E 1134,5 57 10 8_5..5..4;._.._66~ 8_5_0_.0_,~._6. S....7_8_;_0_0E .... 133..1_,_~2_N 6_6_8_.3..._!3._E .... 6_SJ,_~_.,.52_N_7.8__~.~__~_9_E_ 3_]._4.._38__57___0 86P.5.,OO__8_55_l_,_OO__S78_,_9..O_E. 1~],.5,_~9_N__6759,.50 E. 6886,31 N _1_1500 56 ~0 863_8._.92 11530.56 30 8655,44 11600 56 30 8694.07 _1_!_7_3_4 5.6___~_0__.8_768.._03 ... 11827 57 30 8818.68 6_8_!.0_,_2_1__E.___6_934.,02 N_79 ..... 9_23 E' 8601,4/+ S77,00E 1298,95 N 6834.,64. E. 6956,,98 N 79 14 20 E 864.0,O_7.___~_7_7_,Qg_E 12_8_5_,_8_2 N 6891,5], E 7QI_O_._.~4._N 79 25 52 E__ 8__7_!_~_._0.3 577,50E 1261,16 N 7000,50 E 7113,19 N 79 4.7__!5 E__ 8764..68 S77.50E 1_2~._28 N 7076.65__E. 7_!_85_,.20 N 80 1 39 2,12. t 6_53.~_,71 2._,.5_7_8 6 4.,311 .......... 6663.,98 ~ .1.81__ 3_,_3_7_.2 0_._1.8.3 · 0_._7_75 6928 · 75 __!_._Z3 0 6 9_5. 2._, 9_ ~ 0.009 7006:3~ 0_._3_1_.1 .... 71 ]' O, l_._ ]',075 7183.,_]' 7_, 8868,..85___8_81_~__._8.5____$77_._o~E ..... 1226.4.7 N 7155,33 E 7259,68_N._80_1.6_24. E _ 89.16,..05___8862_,Q..5_ ST. 7_-OOE.. 120.8,__4.5__N_ 7_233_,_~.0__E 73.33,66_N_80_3Q_5.5_E ...... _1,_311 ....... 7258,3 0 1._,.61_3 ...... 733 2,8 0 ._ _1.220_.1 6.2__~5 ... 90_03._._.7 2..__8.9_.{+_9_.,_72__S 76,50 E___llT_O.._50__N___7.39Z,_98__E _1_22.32 63_ Q_ 9QL7_,.85... 8.963_,_85. S76..5.0E 1_16_~__,06_N 7A19_._81_E _1_2_.Z6_3_63.. 0__ 9_Q3_1.._93 89_7_7__,_9_3.___SY.6,_OOE_ 1_15_7_,_5_0__~_ 7/+_~6_,_6~_E _1_22_8.~_63 0 90~+ 1, z+6 8987.~6 S_7_SxO. qE 1 !52_,8_1_N. 7 ~_6_~_,_7..5_E.~ 123~7 63 0 9070,06 9016.06 $75,00E 1138.28 N 75].8,97 7AO 8., 9Z_N_80 _~+5_3.Z__ E 7_~85 · 07___N__8 I___0_~i_E~ 7.5..:LO...5.6_N_81__5 ..... i__E 753_6_,06_N_81 __ 9__SZ_E_ 7_5_5_3_~__2_4 N__8!_l 3_1..5_E 760~.65 N 8_], 2.3__19 E 0--5.38 7 ~+8 ~_, 89 .0...8.06_____75_10 ..~+ 6_._. 1 ._~,_3_'!______153. 6 ~00~ z+_._2_~3 . ' 7_553,21 ..... O_._ODO 7_60 _~_~_6 BOTTOM HOLE CLOSURE 760~.65 FEET AT N 81 23 29 E DEPTH AND OTHER _D_A_T_A_._F_QR_E_V_E_R_Y_ E_._V__EN 1.0.0 FEET OF SU_B ,5E2~ TRUE M E A S-LIR-E-~ VE-R-T]-C~-[---50"B M D' T 9D V E r T I (1A L DE PTM 'DIEP-T-H S'EA--D-1:'-F'F~ER1YNCE-- ' CO-RR-EUT-I-ON T-O-TA~-OR-D-/N-A-T-t~,5 154 154. 100 0 0 1410,15 N 723.11 E 254 254. ,!O'O 0 0 1410.41 N 7z3.30 E 354 354 · 300 0 0 1-4~' i-0-'-~-i--1~------7-2- ~,-5- 9--E 454. 400 0 0 1411.34 N 723.97 E 5'54 554.--500--'0 0 1411.99 N 72z+.45 654 654. 600 0 0 1412.78 N 725.02 754 7-'5~+-" .......... 700 0 0 1413.69 N 725.68 ....................... 954 1054 85"4 854. 80'0 0 O' 1414.71 N 726.46 E 95'~+-' .................. 900 0 0 1415.47 N 727.52 E 1 o 5,+-, ........ iooo o o 1415.82 N 728.77 E 115%. i'100--0 (~' 1415,73 N 730,07 E 1254 125-F' ....... i200 ............. 0 0 1415.19 N 731.26 E --1354 1354. i300 0 0 1414.28 N 732.18 E 1~54 0 1554 1~-5'~, ..... 1'5oo o 1654 f6--5~-~ .... 160'0 .......... 0 1754 - 1854 1954 2054 2054. '~-000 --0 2~4 2'15~, ............. 2100 ................ 0 ............ 2254 2254. 2-200 0 1454. 140'0-- 0 1413.10 N 732.74 5 0 1411,80 N 732.86 E O-- --14-1-0-'-52 N 732.59' E 175~+. i'7'00 0 0 1409,21 N 732,28 g 18 5"~'-' ............. 18 O0 0 0 ~"4"07"'"8'I6--~ .... 7'3i'"9'6 E 195~+. 1900 0 0 1406.47 N 731.65 E 0 1405.04 N 731 · 34 E 0 ' 1-4-6-3.57 N 73-i-;-0-3--E 0 1402.06 N 730.72 E 2354 2354. 2300 0 ............. 2~+ 2~5~, ..... 2~O'o o 2554 2554. 2500 0 2'654 2654. 2600 0 2754 ' 2-7'5~-. 2-700 --0 2854 2854. 28-00 0 2'9'5-5 29-52~. ---2-9'0'0-- 1 3057 3'05/+-', ...... 3000 2 3-1-59 3154. --31 O0 5 3262 3254. 3200 8 33'6-6 33'5~-; .....33 '00 11 3-4-6-9 3-45-~. 34'00 15 '3'57~' 3-5-54 .--35'00~- .20 0 1400,52 N 730,42 E 0 1398,93 N 730,12 ~ 0 1397.31 N 729.83 E 1395.64 N 729.54 E 1393.93 N 729.26 E 1393.68 N 733.96 E 1396.00 N 746.19 E 1398.47 N f6-3-J~'~ a 1400.46 N 810.50 1399.43 N--~3-7-,-iI E 1396.87 N ~39Z.43 N 8g5.24 E ._ MEASURED_._D.[~_T_H__A_N.D__O..Z_H_E_.R__~.A_T_A .... F'OR EVERY .... .E_. V_E_N___~_O 0. FEET OF SUB, SEA D~_~ i ,,, · TRUE MEASURED VERT I CAL DEP_TJ'J D EP_TJ:::t~S EA_D I. EE g RE.N~E_ ...... ~O.t~LR EC,_LLO N .... , T_0.iALCOORB_~ A.T_ E .s .................... 3786 3.Z5._~.. .......... 37Q0 ........... 32 7 3892 3854, 3800 38 6 4001 3954, 3900 47 9 1382.04 N 1000,40 E 1384.57 N 1043.11 E 4113 4054, 4000 58 11 4227 4154e 4100 73 15 4345 4254. 4200 91 18 1385.85 N 1092,74 E 138.5.10 N 1_!_4_8,47 E 1382,05 N 12_!_1._~Q_8 E 4_5_97 4454, 4400 4734 4554, 4500 180 4885 4654. 4600 230 5051 Z+754, 4700 297 5238 4854. 4800 384 5415 4954, 4900 461 5592 5054. 5000 538 5769 5154. 5100 615 Z2 5O 67 87 77 77 ._ 77 __1376.80 N 12_8!_,9.0__E 1361.14 .N...__i 456,57__E 1349.89 N 1568,4_8_E 1334.9/+ N 1700,44 E 1320.66 N 1857,74 E 1325.79 N ...... 2_0_Q3.70 E 13 3 9.3_5_~N .... 2_~_~_9:,_14 E 1350,98 N 2294.5~ E 5947 6122 6_2.9_6 ............... 6~7.0 6645 6820 __525.~., ........... 5200 ......... 6.9.3 ............................ 78 5354_. ........ 5300 .......... Z6.8 ........................... 75 54~.~_. .....5~.0.0 842 74 55_5_~.,_ 55_00 .......... %~6 74 5654. , 5600 991 75 5754. 5700 1066 75 1360 ._9_2 N___2_~_~_, 46' E 1370.60 N 258/.+,70 E 13 7 9.5 9 N 1386,3_9_._N 2869,22 E 1392 ._2_1 N ~k2_,_.51 E 1398,73 N 3156'.11 E 6996 7360 ~5~.6_ 7.735_ 7921 8281 8623 8788 ............... 8953 5.8_5_~.. .... 580o .... .1_.!_42 595~.. ..... 5..9 o.0 .... 1_22 ~, 6 o 54._,.__6_Q0._o 13 o 6 6_~5A* 61 O0 13__9_2 62 54_,__6.200__1_481 63}.4_, 6300 .~.5_67 6A5.~., ....... 6 ~ O0 ....... !.6 ~ 9 675~_. ..... 6_70.0 .... !86_9 6854, 6800 193~ 69 5'~-' ....6900 .....~ 999 7'0-54-. 7000 .... 20'62 76 82 82 8.6. 89 86 8.2 78 74 68 65 6-5 14_02_.80 N 3300.89 E L~_o_~. 98 N ,3_6_0_~_'_9_~ E L~_O~_.._8_~__N ,,33_6_L._9/+__E __.1_~).~_,.2 3_N__3_ 9_22_,25_ E __ , i~_Q_~._,DJ_J~ .... __l 4.06_,_Og_jN AZ3_L,.21_ E 1406,98 N 4378,24 E 1408,39 N 4520,45 E 1410e42 N 1411.74 N 141~.06 N 4655,83 E 4786,99 E 4918.20 E 5046.98 E 63 1414.03 N MEASURED DEPTH AND OTHER.DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. ME'A-,~O'R'~'D' V E-R'T' ICA'L---~50B .... ND;=T'VD V'I~-~-¥ I CAL DEP-T~I · i~ DEP"TR'--$"EA-'D-':[FFER"ENCE------CORRECTI'ON 9'278 7-i-'5-z+'. 71 O0 21 '24 959 2 735 ~. 9'74-5 7 45 4'; ..... o ~ ~ 3 8-05-~ ~-0~'5'0' 8-~'5-~-';--8Y00--2-5'9-6 i-08'8'5 8254. 8'~'00 1415.61 N 5174--'-2(~ E 113~+z+ ...... 11527 1170-8 11893 12093 12311 8400 2719 50 8600 2873 8-3 8700 2954 81 895~ 8900 31.39 ].00 9'6'5 ~. 9 o0'0 3 z 5 7 ~ 18 1231.69 N 7131.15 E 11/+6.59 N 7487,99 E INTERPOLATED .VALUES FOR EVEN ' ................ TRUE MEASURED, VERTICAL SUB DEPTH ' DEPTH SEA TOTAL COORDINATES 7000 8 000 9000 10ooo__ 11000 'I~12000 ........................ ALL _DEPTHS..~SH_OWN : ARE TVD - --~ ; i HORIZONTAL- VIEW ~ - SCALE --I"= IOC~3' . ATLANTIC RICHFIELD-CoMPANY DRILL SITE 9-11 ......... i RADIUS OF-CURVATURE .... ! ..... iMAGNETiC MU,LTISHOT .... i]-]],~_-i. ~VERTICALT'-SECTION .. t -' 'i SCALE i l".=~'lO00' . i-i~i *i.-._! _~. 400 ~ATLANTIC RICHFIELD COMPANY ........... ..... :- ....................................... DRILL.- SITE .... 9-11 ............ ; ...... ' -- ~ :RADIUS OF-CURVATURE ....... i ......... 8OO ;MAGNETIC MULTISHOT SURVEy~'' - - - 2000 2400. - ~ 2800 ..... ~ -- - : .... { ......... · ! 360 ' - ' - - { - - * ~ ............ ~ ........ , .... ........ ........................ ~ ............ _._j.~ ~.?_~ ...... ~ ............... ,___.-~.. ~ ~._'A LL..DEPTHS_. SHOWN~..~_~; I · i ~ ~ ~ ~ ; I - ' - ~ * -' j ' ~- ~ ...... ~ .... ~ ............ ' *i ............ ; ...... ~- ' TVD =- 9070, AtlantjcRichfieldCompany .... North Ame-~Lc -~roducing Division North Ala[ ~ ..,trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 10, 1977 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' D.S. 9-11 (13-6-10-16) Permit No. 76-84 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure Form !9-403 ..... Submit "Intentions" in Triplicate REV. 1-10-73 '~ & "Subsequent Reports" in Duplicate ~'~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drlll or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) Im I-1 WELL 1-6.1 WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company.. . 3, ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4, LOCATION OF WELL At surface 1463'N & 50'E of SW cr Sec. 1, T10N, R15E, UM 13, ELEVATIONS (Show whether DF, RT, GR, etc.) 54' Gravel Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20236 6. LEASE DESIGNATION AND SERIAL NO. ADL - 28345 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay ;9. WELL NO. Drill Site 9-11 (13-6-10-16) 10. FIELD AND POOL, OR WILDCAT ?rudhoe Bay Oil Field, Prudhoe Oil Pool. }i: S'EC.,T., R.,M.,(BO'I'TO~ HOLEOBJECTIVE) Sec, 6, T10N, R16E, UM '~2. PERMIT NO. 76-84 3ort, or Other Data NOTICE OF INTENTION TO: TEST' WATER 5HUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) p ~ y, ~cpl ~,~ ~.~ -~.-,~ ~.~ ~- SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING ORACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All .perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The down hole safety valve will be installed and tested upon conclusion of job. Estimated start date' 6/22/77 16. I hereby certify that the foregoing is true and correct ..:. / -; ,.: /: .. ~. /- ~ -, ~ SIGNED ' ~ _ .~,_ ¢c -, TITLE District Drilling Engineer DATE (This. space for State office use) ,--~..OVED ~¥ /~. ,-('/, -:C'ON~',T,ONS OF APPROVAL, TITLE Pr trn. !~,~m Fn .n. ! n~r See Instructions'On Reverse Side DATE 5-16-77 AtlanticRichfieldCompany North Amer;-~ 'roducing Division North Aiask .,,~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 14, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 9-11 (13-6-10-16) Permit No. 76-84 Dear Si r' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure l'~rra No. P--4 REV. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS WELl, WELL OTHER 2.NAME OF OPERATOR Atlantic Richfield Company 31A. DbRESS OF' O~:I,ATOR P. O. Box 360, Anchorage, Alaska 4.LOCATION OF WELL 99510 SUBMIT IN DUPLICATE !5. AP1 NUAIER1CAL CODE 50-029-20236 6 LEASE DESIGIqATION AND SERIAL NO. AD[ 28345 7. IF INDIAN[, ALOTTEE OR TR1BE NAME 8. LTNIT,FARAI OR LEASE NAME Prudhoe Bay 9 WELL NO DS 9-11 (13-6-10-16) 10. FIELD A_ND POOL. OH WILDCA. T At surface' 1,463' N & 50' E of SW cr Sec. At Proposed Prod Zone- 1,320' 1, TION, R15E, UM N & 1,320' E of SW cr Sec. 6, TION, R16E, UM Prudhoe Bay-Sadlerochit Pool 1I. SEC., T., R., M.. (BOT'TOM HOLE OB, FECTFVE) Sec. 6, TION, R16E, UM 12. PEP-MIT NO. 76 - 84 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~%'GES IN HOLE SIZE, CASING AND CE~[ENTING JOBS INCLUDING DEPTH SET AND VOLLrlVIES USED. PERFORATIONS. TESTS A_ND tAESULTS, FISHING JOB~. JLrNK L~q HOLE AND SIDE-TRACKED HOLE AND A.NY OTH~,I% SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spudded Well 1300 hrs March 14, 1977. Drilled to 2750'. Ran 13-3/8" 72#/ft MN-80 Buttress casing w/shoe @ 2,701', float collar at 2,622'. Cemented casing w/5,650 sacks of Arcticset cement w/ .7% D13R. Good 14.6 ppg slurry returns. Nippled down 20" BOP. Nippled up and pressure tstd 13-3/8" BOPE. Drilled float collar and float shoe. Press tstd formation to 11.6 ppg equivalent mud weight. Drilled to 2800'. PU Turbo-Drill and drilled to 2,975'. Picked up BHA and drilled to 3,742'. Picked up Turbo-Drill and drilled to 4,091'. Picked up drilling BHA. Drilled to 5,145'. Picked up Turbo-Drill and drilled to 5,267'. Reamed from 5,109' to 5,210' Side tracked hole. Unable to get back in old hole. Picked up TurbO-Drill. Drilled to 5399. Picked up drilling BHA and drilled to 8,630' as of March 31, 1977. S~GW~D ::mDistrict Drilling Enginee~A~ , STATE of ALAS~ DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation To: [-- Hoyle H. Hamil ton/~ Di rector/T//v ~ Thru: Lon~.ie C. Smith Chief Petroleum Engineer FROM: Harold R. ~iawkins Petroleum Inspector DATE : March 22, 1977 SUBJECT: Witness BOP Test, DS 9-11 Sec. l, TllN, R15E, U.M. Permit No. 76-84, ARCO, Prudhoe Bay F'r~day, J~.arch 18, 1977 - I left BP base ca~ to witness a BOP test for Arco On DS'9-~ll-. .... JOhn Fr~nkline, operator for Arco, picked me up at l:O0 PM. The crew on DS 9-11 was nippling up the BOP's. Saturday, March 19, 1977 - BOP, testin¢~, started The annular preventer was ~-~sted t6' 30'0~ p~i'and'held OK. Next~' the upper pipe rams were closed, but did not test. The two wing valves and check valve on the kill line leaked and had to be repaired. The lower pipe rams were tested and held 5000 psi OK. Meanwhile the two low torque Haliburton wing valves on the kill line are being worked on and also the check valve. Tests were stopped until repairs had been done. Tests were resumed at 6:30 PM. The upper pipe rams and i~side kill and inside choke were tested to 5000 psi OK. Then the outside kill and outside choke valve were tested to 5000 psi OK. The test stem was pulled and the blind rams were closed. The blind rams, check valve and four low torque wing valves were being tested at one time to 5000 psi - all i~ the cellar. The check valve did not hold, plus the door leaked on the gate of the blind rams. Also three of the iow torque Haliburton wing valves blew their grease Plugs. Tests were stopped again until repairs were done. Testing resumed at 9:30 PM. Blind rams and five low tor.~ue wing valves away from the stack in the cellar tested to 5000 psi OK, but the check valve on the kill line would not test. They are out of parts for the check valve for repairs. The manifold on the floor is to be tested next. Six love, torque Haliburton wing valves on the manifold were tested to 5000 psi and held OK. There is a ball valve and dart valve on the floor OK. ~~ ~arch 2~, 1977 - Upper and lov~er kelly were tested to 5000 psi and l~-~--].O~.--~}'~e m~ud pi-i~-~as Open, but well bermed. Also there was a steel fuel tank OK. The location in general was clean. The Swaco superchoke and the manually operated choke actuated freely. There was 2750 psi on the master gauge on the accumulator and all control valves actuated BOP's OK. There are four nitrogen backup bottles hooked up to the control lines ,~.~ith 2250 psi each. The well sign is up with all data OK. John Franklin~, operator for Arco, said he would call our office as soon as the check valve S 9-11 2- March 22, 1977 ias repaired. The field trlp report was given to John Franklin. One copy s to be sent to Bob HiMs, superintendent for Arco. Tests were concluded t 2:45 A~i. ~: There were nine failures on the BOP testing. All but one :.as repaired ' the check valve on the kill line. All the other tests ~ere atisfactory. Test took 21 hours. ttachment 'ohn Franklin called - check valve repaired and tested. .~.!satisfac~6,~.~.:~.~???~yje'.~IBspec! 0n~..'~.~:~?:;~.. -'.?~sa~is.-~a~ct0~-~,~?~-~e Inspect?n'- ,<~.y~s:..'..~NO.]-:?~I-t~=~:~ :~:LoCatio~ /Gene¥~a~l~]-: ]:': :?~ ~::.Y?.s ":~ NO:~'.~Item'~J- BOPE Tests . ~'(,'-) ()'~.-8.'.Hrs. obser ..' , , , }~. ( ) 24 .Chokes-(~)Remote( )Pms.(~dJ.>~': .... ~ '.. - ( ) (). 9' BS&W __,=-'~ ,~, -- ( ) 25'] Test Plug-(~He!lhd( )csg( )none ( )' ( ) 10, Gr. Bbls. , ": ~) ( ) 26. Annular Preventer,~sig (=.~) Final Abandonment -- (~) ( ) 27. Blind Rams~opsig ( ) ( ) ' 11. P&A Marker ' (~) ( ) 28. Pipe Rams~ psig_ ' ( ) ( ) 12. Water well-( )capped( )plugaed (~) ~ ) ~. Kelly & Kelly-cock~ p~ig -" ( ) ( ) 13. Clean=up ~, ~) . ) . Lower Kelly valve~ ~ ~~~)~* ¢~~e~~~) ~dn ~~~ ~~~~1 {~ ~~~~Safety Fl °°r val ve~ By (~art s n ea~s and/or enuip, failures ,~ ~t'~ ~ .~ /~z~ --J~. /~' ~x~ '~/~' z-W~/r ~ ~ cc' /:~]? ,./?/'/~'}z~;Notify in _~days or when ready ~, Inspected by/~,~i~z','x/~' .Date~/~/?~ Conservation November 4, 1976 Re: Prudhoe Bay DS 9-11 (13-6-10-16) Atlantic Richfield Company State Permit No. 76-84 C. R. Kn~ates District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 6, Township tON, Range 16E, U.~4. Well samples, core chips and a mud log are not required. A directional survey is not required. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative Code}. Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- merit of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prc~ulgated thereunder (Title 18, Alaska Adm. inistrattve Code, Chapter 70) and by the Federal Water Pollution Control Act. as amended. Prior to c~ncing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in sc'h~duling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. ~)e would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled, C. R. Kno~les -2- November 4, 1976 ]~n the event of suspension or abandonment please give thts offlce adequate advance nottflcatton so that we may have a wttness present. Very truly yours, flo~le ~I. l~am~tton ChaJrman Alaska 0~1 and Gas ConServation CommerCe Enclosure CC: Oepartment of Ftsh and Game, Habitat Sectlon w/o encl. Oepa~nt of Environmental Conservation w/o encl. Oepartment of Labor, Supervisor, Labor Law Comp11 ance 0tvtston w/o eric1. AtlanticRichfieldCornpany North Amerir'"'~'~roducing Division North AIask ~,trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 29, 1976 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 9-11 Dear Mr. Hamilton: Enclosed herewith is our Application for Permit to Drill DS 9-11, a $100.00 filing fee, and the required survey plat. Very truly yours, ¢. R. Knowles Distr~ct Drilling [n§~neer /j~ Inclosures AilantjCRichfieidCompany North .Amo;-i,~' ~''' North A~sk~, ~[rJct Pos~ Office ~;ox 360 Teh~ph,g~e 9()7 277 5637 October 28, 1976 Mr. P. R. Judd BP Alaska, Inc. P. O. Box 4-1379 Anchorage, AK 99509 Subject: Drill Site 9-11 (13-6-10-16) Prudhoe Bay Field Dear Mr. Judd: We propose to drill the subject well from a surface location of 50'E & 1463'N of SW cr, Sec 1, T10N, R15E, UM to a 8800' subsea target of 1320'N and 1320'E of SW cr, Sec 6, T10N, R16E, UM. At TD the well is projected to be 3967'S, 3650'W of SW cr of BP Lease ADL 29343. Atlantic Richfield will drill and operate the well. Attached is a copy of State Form 10-401, Application for Permit to Drill. Under Paragraph 22 050, Title II, Part 3, of the Alaska Administrative Code, you are classified as an affected operator as far as the proposed well is concerned. Before the State of Alaska Oil and Gas Conservation committee can approve our application for a permit to drill this well, a letter of non-objection from BP is required. We would be grateful if you would give this matter your earliest attention and if you are in agreement, sign the enclosed letter and transmit it to the Alaska Division of Oil and Gas at your earliest convenience. Very truly yours, C. R. Knowles District Drilling Engineer /cs Enclosures cc: State of Alaska, Division of Oil and Gas Form 10-401 REV. 1-1-71 SUBMIT IN TRI (Other instruct, revers.e side) STATE OF ALASKA . . OIL AND GAS CONSEFIVATION C0;.MMITTEE [ PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [] DEEPEN [--] b. TYPE OF WELL WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company P. O. Box 360,..Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1463'N & 50'E of SW cr Sec 1, T10N, R15E, ~UM At proposed prod. zone 1320'N & 1320'E of SW er Sec 6, TiON, R16E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TO~ OR POST OFFICE* Approx±mately 6-1/2 m±les northeast of I)eadhorse,. Alaska 14. BOND INFORMATION: SINGLE F--1 MULTIPLE ZONE :CO ZONE API No. 50-029-20236 6. I,EASE DESIGNATION AND SERIAL NO, ADL 28345 7.IF INDIAN, ALLOTTEE OR TRI BE NAblE 8.UNIT FARM OR LEASE NAblE Prudhoe Bay 9. WELL NO. DS 9-11 (13-6-10-16) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11.SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 6, T10N, R16E 12. Wy~EStatewide. Surety and/or No. Federal Insurance Co. 8011-38-40 Amount $100~000 15. DISTANCE FRONt PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, it' any) 1313 ' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2666' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 21' Pad Elevation (Gravel) 16. No. OF ACRES IN LEASE 2560 . 19. PROPOSED DEPTH 9304' TVD, 12717'MD 17. NO.ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rot ary 22. APPROX. DATE WORK WILL START December 31, 1976 23. PROPOSED CASING AND CEMENTING PROGRAM SIZEOFHOLE SIZEOFCASI~G ~IGHTPERF~T GRADE SETTINGDE~tl ~antityofcement ,. 20" 94# H,40 100'+. Circ to surf approx 500. SX 17-1/2" 13-3/8" 72# N-80 2700'~ Circ to surf approx 5500 sx 12-1/4" 9-5/8" 47# N-80 11766'~ . 2500'~ cmt column on 1st stg & S00-95 300' cmt on 2nd g~ 125+ 8-1/2" 7" 29# N-80 12483' 1200' thru lao 300 sx + Atlantic Richfield Company proposes to directionally drill this well to 9304 '+MD, 12717'+TVD to produce the Sadlerochit Zone. Logs will be run across selected intervals. A 20-3/4" 2000 psi Hydril will be used on the 20" conductor.. A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. The well will not be perforated at this time. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. ~ ~O~ SPACE DESC~BE PROPOSED PROGRAM: If propo~ is to deepen ~ve data o~ present productive zone and proposed new productive zone. If pro~ml is to drill or deepen dkection~y, ~ve pertinent data on subs~hce locations and measured and true verti~ depths. Give blowout preventer progam. ax SIGNED,24' I hereby certify t~the~~~Foregoi[lg is True anC~Correct DA~ /D- ~ ~ -- 7 ~ TITLE D]st:'Drlg: Engineer (This space for State office use) SAMPLES AND CORE CroPS REQUIRED [] ~s {X] NO ] DIRECTIONAL suRVEy REQUIRED 0q YES [] NO CONDITIONS OF APPROVAL, IF ANY: PERMITNO, 76-84 MUD LOG YES [~ NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20236 APPROVAL DATE TITLE Chairman *See Instruction On Reverse Side November 4, 1976 DATE November 4, !976. · - -- ~ilISECTION / CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE .BY ME OR UNDER MY SUPEP,,VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. SEPT. 29~ 1976 .~ · ~',y DATE OF SURVEY FOR WELLS 10 DATE OF SURVEY SURVEYOR /' ;UILT WELL No, 7 LAT. 70°14'52.613" LONG. 148° 14' I0 146" WELL No. 8 LAT. 70°14'51.460'' LONG. 148o14'09.433'' WELL No.9 LAT 70° 14 LONG. 148° 14 Y 5 943 399.24 X 718 315.12 Y 5 943 282.76 X 718 343.04 50.304" Y 5943 165.96 08.723" X 7 18 370.86 WELL ',~; lO I AT. -0° 14-' 43. 145" LONG. i48©t41 '.;7.987" "NELL r~o. II lAT. 7C"',4' 4Z992" LONG !48'-' 14' 0?.270 943 !348.88 ,', .~ 39.). 55 Y 5942 932.43 718 427.64 EXISTING WELL OR CONDUCTOR PIPE ADD WELLS REVISION J CKD 1 ARCO No. HVL No. 35-DS9-76 .1 ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No.9 WELLS No. 7,8 & 9 LOCATED IN PROTRACTED SECTION 2, T. IO N.~ R.15E~ U. M. PREPARED BY HEWITT V. LOUNSBURY 8 ASSOC. 723 W. 6th AVE., ANCHORAGE, ALASKA DATE 18 JUNE 76 SCALE 1": 2,,.00' CHKD BY GD FIELD BK b908£ LEAF CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks .1.Is the permit fee attached ...................... 2.- Is well to be located in a defined pool 3. Is a registered survey plat attached 4. Is well located proper distance from property line .......... -/~J~ 5. Is well located proper distance from other wells .......... ~-~_ 6. Is sufficient undedicated acreage available in this pool ....... ~ 7. Is we'll to be deviated ........................ ~ 8. Is operator the only affected party .................. ~..~, 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ................. ~ 11. Is a conservation order needed .................... 12. Is administrative approval needed .................. 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface ..... 15. Will cement tie in surface and intermediate or ~roduction strings 16. Will cement cover all known productive'horizons .......... 17. Will surface casing protect fresh water zones ............ 18. Will all casing give adequate safety in collapse, tension & burst . . 19. Does BOPE have sufficient pressure rating . .'. ~'L ......... Additional Requirements' Approva 1 Recommended' Geol O,Qy Engi neeri nq' JAL LCSx~ JCM ~i~ Revised 1/15/75
