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Home My WebLink About183-166From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 12-25 (PTD #1831660) Lapse on 4 year MIT-IA Date:Tuesday, October 5, 2021 3:33:48 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 2:50 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> Subject: NOT OPERABLE: Injector 12-25 (PTD #1831660) Lapse on 4 year MIT-IA Mr. Wallace, Injector 12-25 (PTD #1831660) will not be online for 4 year AOGCC MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 7, 2017 1:58 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS1 DS Ops Lead <AKOPSFS1DSOpsLead@bp.com>; AK, OPS FS1 Facility OTL <AKOPSFS1FacilityOTL@bp.com>; AK, OPS FS1 Field OTL <AK_OPSFS1FieldOTL@bp.com>; AK, OPS FS1 OSM <AKOPSFS1OSM@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Dean, James A <James.Dean@bp.com>; G GPB FS1 Drillsites <ggpbfs1drillsites@BP.com>; Oestgaard, Finn <Finn.Oestgaard@bp.com>; Stone, Christopher <Christopher.Stone@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@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>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector 12-25 (PTD #1831660) Surface Injection Line Repairs Complete - Place on Injection for Warm Up Prior to MIT-IA All, Injector 12-25 (PTD #1831660) was made not operable due to missing its AOGCC-witnessed MIT-IA resulting from ongoing repairs to the seawater injection line. Surface repairs to the injection line have been complete. The well meets operability criteria and is ready to be brought online for MIT-IA testing. The well is reclassified as Operable. Once the injection rate is stable, a witnessed MIT-IA will be scheduled. Be mindful of fluid packed annuli. Plan Forward: 1. Ops: Place well on injection 2. DHD: Perform state witnessed MIT-IA Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 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 considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 8:45 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 12-25 (PTD #1831660) Lapse on 4 year MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 2:50 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> Subject: NOT OPERABLE: Injector 12‐25 (PTD #1831660) Lapse on 4 year MIT‐IA Mr. Wallace, Injector 12‐25 (PTD #1831660) will not be online for 4 year AOGCC MIT‐IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 7, 2017 1:58 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS1 DS Ops Lead <AKOPSFS1DSOpsLead@bp.com>; AK, OPS FS1 Facility OTL <AKOPSFS1FacilityOTL@bp.com>; AK, OPS FS1 Field OTL <AK_OPSFS1FieldOTL@bp.com>; AK, OPS FS1 OSM <AKOPSFS1OSM@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Dean, James A <James.Dean@bp.com>; G GPB FS1 Drillsites <ggpbfs1drillsites@BP.com>; Oestgaard, Finn <Finn.Oestgaard@bp.com>; Stone, Christopher <Christopher.Stone@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@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>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector 12‐25 (PTD #1831660) Surface Injection Line Repairs Complete ‐ Place on Injection for Warm Up Prior to MIT‐IA 2 All, Injector 12-25 (PTD #1831660) was made not operable due to missing its AOGCC-witnessed MIT-IA resulting from ongoing repairs to the seawater injection line. Surface repairs to the injection line have been complete. The well meets operability criteria and is ready to be brought online for MIT-IA testing. The well is reclassified as Operable. Once the injection rate is stable, a witnessed MIT-IA will be scheduled. Be mindful of fluid packed annuli. Plan Forward: 1. Ops: Place well on injection 2. DHD: Perform state witnessed MIT-IA Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 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 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 considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 10,2017 TO: Jim Regg P.I.Supervisor I f 10I 47 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 12-25 FROM: Chuck Scheve PRUDHOE BAY UNIT 12-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jj(2--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 12-25 API Well Number 50-029-21042-00-00 Inspector Name: Chuck Scheve Permit Number: 183-166-0 Inspection Date: 10/7/2017 ,✓ Insp Num: mitCS171007155611 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 12-25 Type Inj W TVD 8447 Tubing i 592 ' 593 594 " 594 PTD 1831660 Type Test SPT Test psi 2112 IA 0 2500 " 2475 " 2467 BBL Pumped: 5.9 ''BBL Returned: 5 OA 281 562 ' 561 558 ' Interval ; 4YRTST P/F P V Notes: SCANHEO w: a S Tuesday,October 10,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 7, 2017 1:58 PM To: Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS FS1 DS Ops Lead;AK,OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Dean, James A;G GPB FS1 Drillsites; Oestgaard, Finn; Stone, Christopher;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 J Subject: OPERABLE: Injector 12-25 (PTD#1831660) Surface Injection Line Repairs Complete - Place on Injection for Warm Up Prior to MIT-IA All, Injector 12-25 (PTD #1831660) was made not operable due to missing its AOGCC-witnessed MIT-IA resulting from ongoing repairs to the seawater injection line. Surface repairs to the injection line have been complete. The well meets operability criteria and is ready to be brought online for MIT-IA testing. The well is reclassified as Operable. Once the injection rate is stable, a witnessed MIT-IA will be scheduled. Be mindful of fluid packed annuli. Plan Forward: 1. Ops: Place well on injection 2. DHD: Perform state witnessed MIT-IA Please reply if in conflict with proposed plan. SCANNED SIT / 2201,7 Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • p7-D 183 - Loepp, 83 -Loepp, Victoria T (DOA) From: Carlisle, Samantha J (DOA) Sent: Wednesday,April 06, 2016 9:40 AM To: Davies, Stephen F (DOA); Loepp,Victoria T (DOA) Subject: FW: 12-25 (PTD# 183-166)corrected As-Built Attachments: FRB16 DS12 01-00 WELL CONDUCTOR 25.pdf Follow Up Flag: Follow up Flag Status: Flagged Want me to print this or will one of you do that? SCANNED APR 2 ® 2016 From: Lastufka, Joseph N ['rfl o:Joseph.Lastufka@bp.com] Sent: Wednesday, April 06, 2016 9:32 AM To: Carlisle, Samantha J (DOA) Subject: 12-25 (PTD# 183-166) corrected As-Built Samantha, Please let me know if you have any questions. Thank you! Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 RAIIV BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage,AK 1 °7 a0 �1. ta- 0 v I o a ill SLB > ._ I o� CH2M -. qf--i � z a F� ��, �� d �'S BC>/ I SEC . 7 th C� a ti� "' TM8 PROJECT J DS12 _ Fao �,!,j� o ao _� ��,� Pei: o. I 29■ O' 13■ I —e' .1 28. ao [p .`,NSB Qf e I o� 12■ ■2 27■ ff11 a6or +p i b�� 32 I G° ) �. IA $2 r SEC �C 11 ■ ■3 26■ A SEC A 20 w 37■ 19 1= as £�`d� 10■ .4 425 ' ` / .2o I ,/,,,,\Q3 ,Rt- fl y .:, ■34 9■ ■5 VICINITY MAP •19 I N N.T.S. 14■ ■6 .18 22• 117 ■17 35 30 �, ,,QF,"i,''� �, 23. 8 ''�' -\ -° °°°°AC41/45, ■16 31 ■ I .,5 24• 0 =*o 491h /\ °°°it/ 40 •36 ° ° O. — r r SEC 181__SEC 17 j4 SEC 19 SEC 20 Timothy F. Barnhart ,, �� 10200 °°e,/, or 1 ( I '�` °°° GRAPHIC SCALE glittnu 0 200 400 800 FEET ) SURVEYOR'S CERTIFICATE 1 inch = 400 it I HEREBY CERTIFY THAT I AM • PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT NOTES: THIS AS—BUILT REPRESENTS A SURVEY LEGEND: MADE BY ME OR UNDER MY DIRECT 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. SUPERVISION AND THAT ALL 2. BASIS OF LOCATION IS D.S. 12 MONUMENTS 12—A & 12B. + AS—BUILT CONDUCTOR DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 11, 2016. 3. BASIS OF ELEVATION IS BPXA MLLW DATUM. ■ EXISTING CONDUCTOR 4. GEODETIC POSITIONS ARE NAD27. 5. DRILL SITE 12 AVERAGE SCALE FACTOR IS: 0.9999445. 6. DATE OF SURVEY: MARCH 11, 2016. 7. REFERENCE FIELD BOOK: NS16-13 PGS. 01-04. LOCATED WITHIN PROTRACTED SEC. 17, T. 10 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC BASE FLANGE SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS Y= 5,931,186.33 N= -1434.52 7012'58.121" 70.2161447' 852' FSL 25 X= 697,736.04 E= -374.98 148'24'17.701" 148.4049169' 43.15' 5,142' FEL DRAWN: JACOBS DAECKED: *bp DRAPER M 0 b DATE 03/12/16 bellDRAWING: FR816 12 01 EOA DRILL SITE 12 SHEET: JOB NO: AlELL 25 SCALE: AS-BUILT CONDUCTOR LOCATION 1'=400' 1 OF 1 00,03/12/18 ISSUED FOR INFORMATION NO. DATE REVISION BY CHK I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 1 f DATE: Friday, January 25, 2013 TO: Jim Regg 1 el/'C,' 1 ( t P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-25 FROM: Jeff Jones PRUDHOE BAY UNIT 12-25 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name PRUDHOE BAY UNIT 12-25 API Well Number 50-029-21042-00-00 Inspector Name: Jeff Jones Permit Number: 183-166-0 Inspection Date: 11/10/2012 Insp Num: mitJJ121114150338 Re! Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min , I Well 12-25 1 Type Inj w TVD j 8447 • IA j 645 1 2295 1 2269 - 1 2263 - PTD 1831660 , Type TestjsPT jTest psil 2112 - OA 302 - 485 • 486 - I 486 1 I Interval 1 Four Year Cycle , Jp/F Pass -I Tubing I 211 - 212 1 211 1 211 Notes: I well inspected; no exceptions noted. - SCANNED APR 1 1 ZO13 Friday, January 25, 2013 Page 1 of I 1 n!m rna Schfwaberger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Gambol) Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job A Log Description Date BL Color CD K -11 AY1M -00033 SBHP SURVEY 1'fj' IV? 09/12/09 1 1 L4 -30 AWL8 -00031 PRODUCTION PROFILE 01 tr-ic 08/06/09 1 1 P2 -31 AP30 -00045 LDL /let —o3� 141 07/11/09 1 1 01 -29 B6JE -00009 PRODUCTION PROFILE (1 g79 5 08/11/09 1 1 J -22A 869K -00013 PRODUCTION PROFILE 0 i 08/30/09 1 1 W-44 B14B -00071 INJECTION PROFILE 1 Me l 1 t' 09/06/09 1 1 12 -25 B581-00010 INJECTION PROFILE�jj 9 08/22/09 1 1 L5 -33 AYKP -00051 SBHP SURVEY 4 ---F5-.{ 2, 09/01/09 1 1 P2-48 B69K -00015 SBHP SURVEY 1 t�� f j le-g- 09/01/09 1 1 2 -28 B69K -00016 INJECTION PROFIL V V a 1 /87� 09/19/09 1 1 0 -02A AP3Q -00054 -MEM R 1- 07/24/09 1 t 1 N -10A AXBD -00040 MEM PROD PROFILE E .-Al P1 44 08/25/09 1 1 W -24 AWJI -00044 MEM INJECTION PROFILE 1) f(- (y�0 '11./p8/15/09 1 1 V -03 t B2NJ -00021 MEM PROD PROFILE ,40.-a-- (x 09/03/09 1 1 H -14B B2WY -00026 MEM PROD PROFILE a19._1t 08/27/09 1 1 P1-01 AY1M -00031 INJECTION PROFILE 1 h- Q 9 08/20/09 1 1 P1 -05 B581-00009 PRODUCTION PROFILE 1 (53.-4- 08/20/09 1 1 NK -10 B2WY -00023 MEM INJECTION PROFILE 7� 1 b 08/22/09 1 1 13-27A B2NJ -00019 MEMORY SCMT 1 O' i T O 08113(09 1 1 18-028 B2WY -00021 MEMORY SCMT a(', 7 0 1 08/19/09 1 1 NK -38A AYKP -00049 USIT 1 08/17/09 1 1 06 -09 SWL8 -0 0028 USIT 1 07/30/09 I 1 13.03A 09AKA0150 OH MWD/LWD; a jj y 1 07/06/09 2 1 C -188 B2NJ-00017 RST -00017 MCNL 3/L 1 7�L 08/09/09 1 1 1-35/0-25 B69K-00011 t 08/26/09 1 1 04 -35A t AXED -00025 MCNL 7 ._-_0 111 05/13/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: AP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambol) Street, Suite 400 900 E. Benson Blvd. r y �j {P� Anchorage, AK 99503 -2838 `t l j 1 ,1 L- V t...) • 1 V I E 1 ®/I ®R A l®1 D U 10 / I T®~ Jim Regg --~ P.I. Supervisor ~~Q~~ (~~~~%~~_ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, December 1 s, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 12-2s PRUDHOE BAY LNIT 12-2s Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~:~ Comm Well Name• PRUDHOE BAY UNIT 12-25 Insp Num• mitJCr081210203130 Rel Insp Num: API Well Number: 50-029-21042-00-00 Permit Number: 183-166-0 Inspector Name: John Crisp Inspection Date• 12/6/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tz-zs ,Type Inj. j w i TVD s3a6 IA~6o ~ zsoo za6o i zaso P T ~ 1a3166o ',TypeTest sPT ;Test psi ! __ 2os6.s OA ~ o i zo I zo ~ zo ~ ~ ~ Interval INITAL p~F, P ~ Tubing ! 600 ~ 600 600 ~ 600 Notes' 4.8 bbl's pumped for test. No problems witnessed. _. iviorday, December 15, 2005 Page I of 1 STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP RT OF SUNDRY WELL OPE~TIONS 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 183-168 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21042-00-00 7. KB Elevation (ft): 73 0 ~ 9. Well Name and Number: PBU 12-25i 8. Property Designation: 10. Field /Pool(s): - ADL 028331 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11390 ~ feet true vertical 9210 ~ feet Plugs (measured) None Effective depth: measured 11339 feet Junk (measured) See Diagram true vertical 9172 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 180' 20" 180' 180' 1490 470 Surface 2591' 13-3/8" 2591' 2591' 4930 2670 Intermediate Production 10783' 9-5/8" 10783' 8745' 6870 4760 Liner 908' 7" 10489' - 11385' 8514' - 9206' 8160 7020 Perforation Depth MD (ft): 10790' - 11173' Perforation Depth TVD (ft): 8751' -9048' 5-1/2" x 4-1/2", 17# x 12.6# L-80 10532' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-112" Baker S-3 Packer, 9-5/8" x 5-1/2" Baker 0277, 10405' " " x 4-1 /2 FB-1 Permanent Packer and a 7 Baker FB-1 Permanent 10850 Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: • ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: , ® Well Schematic Diagram ^ Oil ^ Gas, ®WAG ^ GINJ ^ WINJ ^ 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 Mackie Derrick, 564-5891 308-287 Printed Nam Sondra Stewman Title Drilling Technologist Prepared By Name/Number: nature Phone 564-5743 Date -~ ~" Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~ Submit Original Only ' TREE = GIW 6" WELLHEAD= FMC ACTUATOR= AXELSON KB ELEV.- _ .73 ___ __ BF. ELEV = _KOP = _ 3000. Max Angle = 50 @ 6400' Datum MD = 10947' Datum TV D = 8800' SS • S~TES: None 12-25 221$` (-{ 5-1 i2" X NIPPLE, ID = 4.56„ 13-3/8" CSG, 72#, L-80, ID = 12.347" 2591' 5-1;'2",17#, L-80;TCII Tbg .0232 bpf; ID= 4,892" 10355' Minimum ID = 3.81" @ 10534' 10247' S-1t2° x NIPS E, ID=4.5s" 4-1 /2" Otis X Nipple 10277' 'J-5/$"x5-112" BAKER S-3 PKR, 4.767" ID 10343' S-1,'"2" X NIPPLE, iD = 4.56" ~9-518" x 5-112" Unique Overshot ~ 10355' Top of 5-112" Tbg Cut Joinf 10359' 5-112",17#, L-80, Tbg .0232 bpf, ID= 4,892" 10402' Baker Seal Asserr~ly w 1 NoGo Collar on top 10403' TOP OF 7" LNR I-I 10477' 4-1/2" TBG; 12.6#, L-80, .0152 bpf, ID = 3.958" I 10531' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10783' 10394' -~ 5-112" OTIS X NIP, ID = 4.56" 10405' 9-518" X 5-112" BAKER FB-1 PERM PKR 1{3408' Baker 15ft Seal Bore w 1 Mill Out Ext. 'ltid~ 5-1/2" x 4-1/2" XO 1(3521' -14-112" OTIS X NIP, ID = 3.81" 10532' 4-112" WLEG 10518' ELMD TT LOGGED 02/14/92 10850° I~ 7"Baker FB-1 Pkr set w J Eline PERFORATION SUMMARY REF LOG: BHCS ON 01/26/84 A NGLE AT TOP PERF: 39 @ 10790' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-118" 4 10790 - 10820 O 06/15/89 3-3/8" 4 10922 - 10960 O 12/07/84 3-3/8" 4 10970 - 10998 O 12/07/84 3-3/8" 4 11012 - 11028 O 12/07/84 3-3/8" 4 11031 - 11038 O 08/08/87 3-3/8" 4 11038 - 11086 O 12/07!84 3-3/8" 4 11100 - 11120 O 12/07/84 3-3/8" 4 11120 - 11142 O 08/08/87 3-3/8" 4 11152 - 11173 O 08/08/87 PBTD 11339' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11385' TD 11390' h~ ?? -FISH: IBP STIFFNER RING {11105/08} 11111' SLM SL TOOLSTRING w /-20' OF WIRE TOTAL LENGTH = 29' (07/29/06) 11140' 4-1/2" TBG TAIL W/PXN PLUG AND HYDRAULIC GS ON BOTTOM - 4-1/2" OTIS XN NIP W/XN PLUG BODY, ID = 0.1" - 4-1/2" TBG TAIL DATE REV BY COMMENTS DATE REV BY COMMENTS 01/31/84 ORIGINAL COMPLETION 02/11/92 LAST WORKOVER 11/03/08 D16 RWO 11/03/08 MJA 1992 RWO DEPTH CORR 11/08/08 KJB/SV PULL IBP (11/05/08) PRUDHOE BAY UNfT WELL: 12-25 PERM~f No: 183-1660 API No: 50-029-21042-00 SEC 17, T1 ON, R15E, 4994' EEL, 102' FNL BP F~cploration (Alaska) BP EXPLORATION Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 12-25 12-25 WORKOVER Start: 10/23/2008 DOYON DRILLING INC. Rig Release: 11/3/2008 DOYON 16 Rig Number: Date I From - To I Hours Task ~, Code j NPT 'j .Phase Page 1 of 7 ~ Spud Date: 1 /12/1984 End: 11 /3/2008 Description of Operations 10/23/2008 15:00 - 00:00 9.00 MOB P PRE Moving Rig from Pt Macintyre to Drill site 12. 10/24/2008 00:00 - 06:00 6.00 MOB P PRE Continue moving rig to Drill Site 12. Present location at 06`.00 hrs, Rig has just entered the Pad. 06:00 - 12:00 6.00 MOB N WAIT PRE Wait on Pad prep work. Remove rear boosters. Install BOP stack and remove rams. Perform miscellaneous maintenance and house keeping projects. 12:00 - 00:00 12.00 MOB N WAIT PRE Continue to wait on Pad prep work. Install rings and seals in fast line sheave. Remove double gate rams and install single gate rams to BOP stack. Continue with miscellaneous maintenance and house keeping projects. 10/25/2008 00:00 - 12:00 12.00 MOB N WAIT PRE Continue waiting on Pad prep work. Stand Derrick. Paint stairwells. Replace geronimo line. Perform Derrick inspetion. Install blind/shear rams. Weather strip drilling line chute. 12:00 - 00:00 12.00 MOB N WAIT PRE Continue building up pad for Rig. Service pipe shed and cellar door sheaves. Continue with miscellaneous maintenance projects. Continue with general house keeping and painting projects. 10/26/2008 00:00 - 18:00 18.00 MOB N WAIT PRE Pad Prep continues. Continue to maintain Rig. Received 3 1/2" x 6" VB Pipe Rams and installed them in the lower ram body. Continue with general house keepiing and painting. Weld new bolts on dram works guard. Re-route bridge crane hydraulic houses. The Roads and Pads crew left the pad -0430-hours with their work unfinished and didn't return until 1000-hours. Normal day crew found the pad to be in worse shape than they had left it. Resume leveling the pad and building more gradual approach in preparation for laying rig mats. 1600-hours, called AOGCC with an update for the planned initial BOP test; 1605-hours, Jeff Jones returned the call and waived State's right to witness the BOP tests. 18:00 - 20:00 2.00 RIGU P PRE Pad prep is finally done! Lay Hericulite and set matting boards. ', Build up ramp to pad. Accept rig at 18:00 hrs. ', 20:00 - 23:00 3.00 RIGU P PRE Spot Rig at 12-25i well slot. Shim up Rig. ' 23:00 - 00:00 1.00 RIGU P PRE Install double annulus valve. Secure cellar. Spot Slop tank. 10/27/2008 00:00 - 01:30 1.50 RIGU P PRE Finish nipple up dual IA and OA valves. OAP = 0 psi. IAP 150 psi. Bleed IAP to 0 psi. Take on 120 deg F. Sea Water to Rig Pits. 01:30 - 02:30 1.00 WHSUR P DECOMP Rig up line to IA. Pressure test line at 250/3500 psi. Good test. Pressure test BPV from below at 1000 psi x 10 minutes. Good test. Record on chart. Bleed IA to 0 psi and monitor open line to slop tank. 02:30 - 09:30 7.00 WHSUR P DECOMP PJSM with All. Continue to monitor IA. Bleed control lines and hanger void. Nipple down Tree and Adaptor Flange. Check hanger threads and install blanking plug on top of back pressure valve. R/U BOP test equipment. 09:30 - 17:00 7.50 BOPSU P DECOMP Test BOPE to 250-psi low, 3,500-psi higLi. Test Hydril with the 4" test joint and all other tests with 4" and 5-1/2" test joints where needed. At 1500-hours, confer with ADW engineer and learn that BOPE must be tested to 4000-psi due to injector ressure re uirements. Re-test VBRs with 4" and 5-1/2" test joints, test the Blin s, test the Choke/Kill Manual Valves and both HCRs. 17:00 - 17:30 0.50 BOPSU P DECOMP Rig down test equipment. Blow down lines. 17:30 - 18:00 0.50 WHSUR P DECOMP Pull blanking plug. Printed: 11/25/2008 11:01:23 AM • • BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Spud Date: 1/12/1984 Event Name: WORKOVER Start: 10/23/2008 End: 11/3/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/3/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~! Hours Task ~ Code NPT Phase Description of Operations 10/27/2008 18:00 - 20:00 2.00 WHSUR P DECOMP Install Dutch Riser. Vent IA to slop tank. Pick-up Lubricator and test to 500 psi. Good test. Pull BPV. Lay down same. 20:00 - 21:00 1.00 WHSUR P DECOMP Plck-up landing oint and screw into tubing hanger. BOLDS. Pull tubing hanger to floor with no problems. Have one control line still attached. Machined pin end on tubing hanger parted. Can see top of tubing collar and arted control line #2 just below su ace. 21:00 - 00:00 3.00 FISH P DECOMP Discuss est way to overshot tubing with control line in the way. Bring tools to floor and make up 8 1/8" Overshot with 6" grapple. 10/28/2008 00:00 - 01:00 1.00 FISH P DECOMP P~ant~vershot in parted tubing at 5 feet below GL. Working tubing up to 250K in an attempt to pull seal asembly from packer bore. Work up to 300 K. Attempt to circulate well through tubing punch holes at 10,396 - 10,398'. Unable to circulate through hole due to fluid by-passing across vershot ack off. Pack off unab a to seal due to con igura ion o e op of the fish. 01:00 - 03:00 2.00 FISH P DECOMP Release Overshot. Had a small amount of gas work to surface. Shut in we I with y n I. Made proper no i ica ion . Estimate SI pressure - psi. Bleed gas to s op tan u I out of hole with Overshot and lay down same. Monitor well. 03:00 - 03:30 0.50 FISH P DECOMP Make up Bowen Itco Spear/Pack-off Assembly with a 4.805" Grapple. 03:30 - 04:00 0.50 FISH P DECOMP Plant Spear in top of tubing at 5 feet below GL. Work to pull tubing free at 300K. Work to pull tubing free at 325K. Work to pull tubing free at 350K (80% plusTop Drive). One control line broke. Recovered the "wad". Control line out of the way of the BOP Stack. 04:00 - 07:30 3.50 FISH P DECOMP Circulate well at 3.8 bpm/50 psi. Gassy diesel returns. Increase rate to 5.0 bpm psi. eturns continue to be gas cut diesel with some sea water. Pump a 20 bbls Hi-Vis sweep. Continue to circulate and condition. Increase rate to 6.0 bpm/530 psi. Gas breakout at surface; S/I Hydril and R/U to circulate through the gas buster. Pump sweep around and monitor well. 07:30 - 09:30 2.00 FISH P DECOMP Monitor well for 30-minutes. Still getting some gas bubbles, decide to circulate through the Pits. Calculate fluid hauled to location versus fluid on board versus fluid circulated versus fluid disposed and there is no fluid lost. Circulate bottoms up 8-1/2-BPM, 520-psi for 455-Bbls. Monitor well and well is dead. 09:30 - 12:30 3.00 FISH P DECOMP Disen a e s ear and POH. Break off spear and L/D. P/U Overshot for 5-1/2" tubing and M/U to XO and two 5-1/2" TCII pup joints. RIH and engage stub, P/U to 20K-Ibs above string weight in seawater plus blocks. 12:30 - 14:00 1.50 EVAL P DECOMP PJSM with SWS/Rig Crew/WSL. Bring SWS tools to rig floor. 14:00 - 16:00 2.00 EVAL P DECOMP Make up CCL tool string. RIH to 10,435' and tag top of sluggets. Log X-Nipple at 10,412' elmd. Flag line at 10, 300'. Had trouble seeing flush joint collars. POOH. 16:00 - 17:00 1.00 EVAL P DECOMP Rig down tools. Leave E-line Unit spotted on location. 17:00 - 19:00 2.00 EVAL P DECOMP Wait on SWS to change out pressure control equipment in their shop so we can rig up for jet cutting operations. 19:00 - 19:30 0.50 EVAL P DECOMP PJSM with new SWS Crew/Rig Crew/WSL. Printed: 11/25/2008 11:01:23 AM BP EXPLORATION Page 3 of 7 ~ Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To I :Hours Task Code NPT 10/28/2008 19:30 - 22:30 3.00 EVAL P 22:30 - 00:00 I 1.501 EVAL I P 10/29/2008 100:00 - 01:15 I 1.251 EVAL I P 01:15 - 02:45 I 1.50 I EVAL I P 02:45 - 03:15 ~ 0.50 ~ FISH ~ P 03:15 - 05:15 ~ 2.00 FISH 05:15 - 06:00 I 0.751 PULL I P 06:00 - 16:00 10.00 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 22:00 5.00 BOPSU P 22:00 - 23:30 1.501 CLEAN ~ P 23:30 - 00:00 ~ 0.50 ~ CLEAN ~ P 10/30/2008 00:00 - 09:30 9.50 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 11:00 1.00 ~ CLEAN ~ P Spud Date: 1 /12/1984 Start: 10/23/2008 End: 11 /3/2008 Rig Release: 11/3/2008 Rig Number: Phase ', Description of Operations DECOMP Bring pressure control equipment to rig floor and rig up. Rig up sheaves. Make up tool string. Arm Jet Cutter. DECOMP Run in with 4.15" Jet Cutter. Log tie-in pass. Log Jet cutter in place with cutter at 10,376' (Odometere at 10,364') DECOMP ire Jet utter. Good surface indications. Tubing cut at 10,376'. PO H. DECOMP Lay down tool string. Jet cutter fired. Rig down a-line equipment off to the side. Plck-up on tubing string to make sure free. String weight = 184K. Clear floor of a-line equipment. Monitor well dead. DECOMP Lay down 5 1/2" space-out pup joints. Pull Overshot to floor and release same. Lay down space-out pup joint fish and 2 more space-out pup joints. Pull up 1 joint. No control line with tubing, yet. Run joint #1 back in hole. Suck out stack. See no control line in stack. DECOMP Rig up to circulate well. Circulate well at 10.0 bpm/1030 psi. Total volume pumped = 710 bbls. Returns =clean Sea Water. No gas. Well static. Rig down circulating equipment. Blow down lines. DECOMP Rig up Spooling Unit. Lay down Joint #1. Un-tangle control line birdnest. Continue to single down 5 1/2" Tubing and spool both control lines. DECOMP Pull and L/D 5-1/2", 17#, L-80 Tbg from well. Control line bunching up in places and broken but able to recover most of it from well. Recovered 54 SS Bands of the 60 SS Bands that were listed as being in hole. Total Pipe Pulled and L/D = 257 joints and Cut Joint. First 115 Joints were BTC Connection, Remaining Joints IJ4S Connection. Very mild internal corrosion /pitting seen in Tbg, external body and connections seemed to be in good shape. Cut Joint = 6.30 ft. DECOMP Clean and Clear Rig Floor. L/D Tbg Handling Equipment. DECOMP Rig up test equipment. Test Annular at 250/3500 psi with 4" test joint. Change out klll Ilne HCR valve. Test choke HCR valve and kill line HCR valve at 250/4,000 psi. Good tests. Record on chart. Rig down test equipmnet. Pull test Plug. Install wear bushing. DECOMP Make-uo BHA #1 as follows 8 1/2" x 5 1/2" Dress Off Shoe. 4 ea Washpipe Ext, 7" x 4.750" Inner Dress Off Mill, Boot Basket, XO, Boot Basket, 9 5/8" Casing Scraper, Bit Sub, Bumper Jar, XO, 6 ea Drill Collars, XO. DECOMP Start RIH with BHA #1. Single in with 4" Drill Plpe from pipe shed. DECOMP Continue RIH with BHA #1 and 4" Drill Pipe from pipe shed. DECOMP Take Initial Parameters at 10350'. P/U Wt = 200,000; S/O Wt = 150,000; Rot Wt = 170,000 with 40 rpm's and 5,000 ft-Ibs free torque. Pump Rate = 4.0 bpm at 370 psi. Continue to Slack Off and Tag Up at 10358 ft. DECOMP Work Dress Off Assembly over top of Tbg Stub at 10358 ft. Rotate and Work Over first 1 to 1.5 ft of Tbg Stub and the shut down rotation and slide down another 19 ft. Pick Up and Bring Rotating again, Dress Off Top of Tbg Stub with Inner Mill, milling at 2-5,000 WOB ant 7-12,000 ft-Ibs torque. Able to work down and swallow full 22 ft with Dress Off Assembly. Printed: 11/25/2008 11:01:1:1 Ann • BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Spud Date: 1/12/1984 Event Name: WORKOVER Start: 10/23/2008 End: 11/3/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/3/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hotars 'Task ', Code NPT Phase Description of Operations 10/30/2008 10:00 - 11:00 1.00 CLEAN P DECOMP P/U off top of Tbg Stub and Attempt to Slide over, Unable to get over W/O Rotation. Dress Off Top of Stub again and then slide down to inner mill and dress off inside of Tbg again. P/U off top of Tbg Stub and able to slide over with No Rotation. Rotate down to and tag inner mill on Tbg Stub. Full Swallow down to 10381 ft. P/U and Repeat Tap again. Able to slide over Tbg Stub with 11:00 - 12:30 1.50 CLEAN P DECOMP Pump 20 bbl High Visc Sweep. Circulate Sweep Out of Hole at 12.5 bpm and 2650 psi. Very small amount of material seen at shakers from circulation. 12:30 - 16:00 3.50 CLEAN P DECOMP Monitor Well after Circulating. Pump Dry Job, B/O and Blow Down Top Drive. POOH and Stand Back DP 16:00 - 18:00 2.00 CLEAN P DECOMP Monitor Well Prior to POOH with BHA. Stand Back Drill Collars. B/O and UD Csg Scraper, Boot Basket, Bumper Sub, and Dress Off Assembly. Recovered -1 gallons worth of small metal shavings /pieces and scale in boot baskets. No wear indications on inner dress off mill with tattle tail. Looked as if untouched. The bottom 8-1/2" x 5-1/2" mill showed 8" OD wear pattern . Unsure from what wear pattern is from, should have -33 ft of Tbg Stub Looking Up. Call Town and Consult on Situation. 18:00 - 22:30 4.50 EVAL P DECOMP Pick-up Halco 9 5/8" RBP. Trip in with 4" Drill Pipe to _10,298' 22:30 - 23:30 1.00 EVAL P DECOMP Stop to cut and s ip ri ing ine. Inspect op nve. ' 23:30 - 00:00 0.50 EVAL P DECOMP PUW = 196K. SOW = 150K. Set Halco RBP with center element at 10,319' md. 10/31/2008 00:00 - 02:45 2.75 EVAL P DECOMP Rig up test equipment. Pressure test casing at 4,000 psi x 30 minutes. Good test. Bleed off pressure. Pull two stands. Pick up Halco 9 5/8" RTTS storm packer. Set storm packer just under surface. Rig up test equipment. Pressure test on top of storm acker at psi x 0 minutes. Good test. Record both tests on chart. ig own test equipment. Blow down lines. 02:45 - 04:30 1.75 WHSUR P DECOMP Suck out stack. Pull wear bushing. Had problems backing out one lock down pin. Pull 9 5/8" pack-off. 04:30 - 06:00 1.50 WHSUR P DECOMP Nipple down BOP stack. 06:00 - 08:30 2.50 WHSUR P DECOMP Grind down stuck lockdown screw nose. Unable to move lock down screw in or out. Set new madrel pack off packoff and N/U New FMC Tbg Spool. Install VR Plug in spool body on the front side of well and install blind flange on top of it. Install Secondary Annulus Valve on Spool. 08:30 - 09:00 0.50 WHSUR P DECOMP Pressure Test Mandrel Packoff to 5000 psi for 30 mins w/ FMC. 09:00 - 10:30 1.50 WHSUR P DECOMP N/U BOP's 10:30 - 11:00 0.50 WHSUR P DECOMP Set FMC Test Plu .Pressure Test BOP Bod and Breaks to 250 psi low and 4000 psi High for 5 mins each, charted test. 11:00 - 11:30 0.50 WHSUR P DECOMP Pull Test Plug and Set Wear Ring. 11:30 - 12:45 1.25 CLEAN P DECOMP M/U HES Retrieval Tool and RIH to the RTTS Strom Packer at 38 ft. Engage RTTS and Check Pressures. Unseat RTTS. Monitor Hole, and POOH. UD RTTS and Retrieval Tool. 12:45 - 13:30 0.75 CLEAN P DECOMP RIH with 2 Stands of DP from Derrick. Engage RBP and Printed: 11/25/2008 11:01:23 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date !I From - To Hours !~ Task Code 10/31/2008 12:45 - 13:30 0.751 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 18:00 3.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 21:00 I 2.501 CLEAN P 11/1/2008 100:00 - 01:30 1.501 CLEAN P 01:30 - 02:15 0.75 I CLEAN I P 02:15 - 04:00 I 1.751 CLEAN I P 04:00 - 12:30 I 8.50 I CLEAN I P 12:30 - 15:30 3.00 CLEAN P 15:30 - 18:00 2.50 18:00 - 18:30 0.501 RU 18:30 - 00:00 5.501 RU 111/2/2008 100:00 - 17:00 17.00 RUN Start: 10/23/2008 Rig Release: 11/3/2008 Rig Number: NPT I Phase Page 5 of 7 Spud Date: 1 /12/1984 End: 11 /3/2008 Description of Operations DECOMP unseat. Pull Up Hole to confirm RBP was free and then RIH past Setting Depth to confirm RBP still on Retrieving Tool. DECOMP Circulate Bottoms Up at 10 bpm and 1600 psi. DECOMP POOH and Stand back DP. Stand back Drill Collars. DECOMP a own Halco 9 5/8" RBP. Both the Storm Packer and the P were recovered com lete._ clear and clean floor. DECOMP k u BHA #2 as follows: 8 1/8" Cut Lip Guide, WP Ext, WP Ext, WP Bushing, 3 5/8" RCJB w/4.43" Junk MITI, 5 3/4" Shear Pin Guide, 3 Jts of 2 7/8" PAC Drill Pipe, XO, Pump Out Sub, XO, Bumper Jar, XO, 6 ea 6 1/8" Drill collars, XO. DECOMP Continue trip in with BHA #2 and 4" Drill Pipe from Derrick. PUW = 200K. SOW = 140K. Drop ball. Tag top of 5 1/2" stump at 10,358' DECOMP Continue down inside 5 1/2" tubing stump. Tagged junk at 10.378'. Push funk down to 10, 382'. Junk fell away. Continue down to 10,422'. Bring pump on line at 4.0 bpm. Wash and rotate slowely down to 10,425'. Unable to make any fu[ther hole. Mill (4.43" OD) stopped at 5 1/2" x 4 1/2" XO. DECOMP Drop dart and open Pump Out Sub. Pump a 20 bbl sweep. Chase sweep back to surface at 11.0 bpm/2000 psi. Monitor well static. Blow down lines. DECOMP Start POOH with 4" Drill Pipe and BHA #2. Single down in Pipe Shed. DECOMP UD 6-1/4" DC's, UD 2-7/8" PAC DP and Shear Pin Guide. B/O and UD RCJB. One small piece of metal in junk basket the size of a quarter. Unknown where or what it is from. Found all but one of the fingers broken off in the reverse basket. The mill showed no wear on the bottom or inside but did have a small ring of wear on the very outer OD edge of the mill face. RUNCMP PJSM. Rig up Torque Turn equipment. Bring completion jewelry to floor. Perform final jewelry inspection. RUNCMP Pick up completion jewelry as follows: 9 5/8" x 5 1/2" Unique Overshot, X-Nipple Assembly w/RHC-M Plug (no shear), 1 full joint 5 1/2" 17 Ib/ft L-80 TCII Tbg, Baker 9 5/8" x 5 1/2" S-3 Packer, X-Nipple Assembly. All connections below the packer were Baker-Lok'd. Jet Lube Seal Guard used on all thread connections. RUNCMP Begin picking up 5 1/2" 17 Ib/ft L-80 TCII Cond B tubing from _ pipe she`c. orque connections to 4,350 fUlbs using Torque Turrn services. Note: Having to re-torque, clean and re-apply Jet Lube Seal Guard thread compound to many joints. Tbg is new but much of it looks like condition "B". There is an excessive amount of thread compound in most of the collars. Have 40 joints ran at midnight. RUNCMP Continue run 5 1/2" completion as designed. Still fighting to get correct make-up with torque turn. Found that most of the joints have a starting thread on the pin end that seems miss cut. The first 1/8 to 1/4 around on the starting thread is very sharp and rough to the touch. Excessive amount of thread compound on threads, feels gritty as if some dirt /debris in thread compound. Make-ups of the tbg improved when the collars and the pin ends were cleaned of thread compound, the beginning part of the starting thread is buffed so it is no longer Printed: 11/25/2008 11:0123 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ', From - To Hours Task Code NPT 11/2/2008 100:00 - 17:00 17.00) BUNCO 17:00 - 17:30 I 0.50 17:30 - 18:00 I 0.50 18:00 - 18:30 0.50 18:30 - 19:00 0.50 19:00 - 23:15 4.25 23:15 - 00:00 0.75 11 /3/2008 00:00 - 02:00 2.00 02:00 - 03:30 1.50 03:30 - 06:30 3.00 06:30 - 10:30 I 4.001 WHSUR I P 10:30 - 11:30 I 1.001 BOPSUR P 11:30 - 12:30 1.00 BOPSU P 12:30 - 14:00 1.50 WHSUR P 14:00 - 14:30 0.50 WHSUR P 14:30 - 15:30 1.00 WHSUR P 15:30 - 17:30 I 2.00 I W HSUR I P Page 6 of 7 Spud Date: 1/12/1984 Start: 10/23/2008 End: 11 /3/2008 Rig Release: 11/3/2008 Rig Number: Phase Description of Operations RUNCMP sharp to the touch, and another coat of Jet Lube Seal Guard is applied to the pin and the collar. UD Jt #132 and replaced with a joint from outside (#258 = 41.825 ft w/ thrd off). RUNCMP M/U Joint #246. P/U Wt = 195,000 Ibs; S/O Wt = 157,000 lbs. S/O and Tag 1st set of shear pins at 20.5 ft in, 2nd set of shear pins sheared at 28.5 ft in, and No-Go at 31 ft in. P/U off Tbg Stub and Repeat, No-Go again at 31 ft in. POOH and UD Joint #246. RUNCMP M/U Landing Joint to 13-5/8"x 7" FMC Tbg Hanger. M/U Tbg Hanger to Tbg String and Torque. Land Hanger in Tbg Spool at 21.15 ft. Unique O/S at 10370 ft with No-Go 4.33 ft off Tbg Stub. RUNCMP RILDS. Lay down landing joint. RUNCMP Hook up circulating lines and pressure test lines to 4,000 psi. RUNCMP PJSM. Stage Vac Trucks. Reverse circulate in with 245 bblsof hot Sea Water at 3.0 bpm/200 psi. Switch to 460 bbls of hot Sea Water containing EC-1124-A Corrosion Inhibitor. Continue pumping at 3 bpm/210 psi. End Pumping. RUNCMP PJSM. Spot and rig up Lil' Red Hot Oil Unit RUNCMP Test Lil' Red line at 4,000 psi. Reverse circulate in with 150 bbls of diesel. 2 bpm/400 psi. RUNCMP Allow diesel to u-tube and freeze protect tubing. RUNCMP Dro Packer settin ball and rod. Wait on same to fall. Walk ressure up to 4,000 si and set Packer. Test Tubing a' ate, 60 psi x 30 minutes (+). Good test. Bleed tubing pressure down to psi an s ut in tubing. Pressure up on Annu us to 4,000 psi. es nnulus for 30 mins. Good Test. OA pressure up to - 00 psi when bring up pressure on Inner Annulus. Pressure on OA held steady, it was then bled off to zero and remained at zero for the rest of the pressure test. OA pressure zero. RUNCMP Bleed down Tubing and Annulus pressures to zero. P/U CIW J Plug TWC and RIH. Set J Plug wf 7 left hand turns. Pressure est from above to 3500 psi for 10 mins on fact that there are no GLM's in the Tubing String and no way to circulate. Took a while to get good 3500 psi test on top of TWC. Bleed down and open blind rams, suck out stack, and examine. R/D Little Red. Rig up on rig pumps and flush stack with water. Close blinds and pressure test TWC to 3500 psi for 10 mins. Good Test. RUNCMP R/D Equipment for testing TWC. Blow down choke and kill lines. Suck Out Stack. RUNCMP N/D BOP Stack and Set Back on Pedestal. RUNCMP Prep Wellhead for adapter flange. N/U Adapter FMC 13-5/8" x 7" 5K Adapter. RUNCMP Pressure Test Adapter to 5000 psi for 30 mins. RUNCMP N/U CIW 6" Tree. Found loose nuts in the flange between the master valve and the surfacesafety vavle. Double check all nuts. Install Need vavle in blind flange on wing vavle. RUNCMP Fill Tree with Diesel and Pressure Test Tree to 5000 psi for 30 Printed: 11/25/2008 11:01:23 AM • • BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: 12-25 Common Well Name: 12-25 Spud Date: 1/12/1984 Event Name: WORKOVER Start: 10/23/2008 End: 11/3/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/3/2008 Rig Name: DOYON 16 Rig Number: Date. ,From - To Hours ~ Task Code NPT Phase; Description of Operations 11/3/2008 15:30 - 17:30 2.00 WHSUR P RUNCMP mins. 17:30 - 19:00 1.50 RIGD P POST Install Jewelry on tree. Rig down Secondary Annulus Vavle. Rig Down Cellar and Ready Rig to Move. Release Rig at 19:00 hrs. Printed: 11/25/2008 11:01:23 AM i Well History Well Date Summary 12-25 10/15/2008 *** WELL SHUT IN ON ARRNAL *** (pre-rw o) SET 5.05" NO-GO W/ 14' x 3-1/2" TBG JOINT ON TBG HGR FOR ENTRY GUIDE. ENTRY GUIDE TL= 15', MAX OD= 5.05", MIN ID= 2.992", 5-1/2" G-FN, MULE SHOE BTM. DRIFTED THRU ENTRY GUIDE W/ 2.70" CENT, S.BAILER TO 10,500' SLM (NO SAMPLE). ***RDMO, LEFT S/IN, NOTIFIED DSO OF WELL STATUS*** 12-25 10/16/2008 T/V0= 50/100/0+. Terrp= SI. TBG FL (pre IBP). TBG FL @ 90'. SV, WV= C SSV, MV= O Va, OA= OTG NOVP. 12-25 10/16/2008 ***WELL SHUT IN ON ARRNAL. INfTVaL T/VO: 0/100/0.*** BEGIN RIGGING UP FOR IBP. PT BEGUN. ***JOB CONTINUED ON 17-OCT-2008.*** 12-25 10/17/2008 *** WELL SHUT IN ON ARRNAL *** (pre-rw o) MIRU SLICKLINE UNIT#4515 TO FISH E-LINE TOOLS (2-1/2" BAKER IBP). ***CONT. JOB ON 10/18/08 WSR*** 12-25 10/1712008 ****JOB CONTINUED FROM 16-OCT-2008.**** RIH WfTH HEAD/ BAKER SETTING TOOL/ 2.5" IBP. CCL SIGNAL WASN'T STRONG ENOUGH TO PROVIDE GOOD JEWELRY LOG, POOH, SWAP OUT IBP RUNNING TOOLS AND RE RUN IBP STRING. UNABLE TO CORRELATE TO TUBING TALLY. TALLY IS INCORRECT AND DOES NOT HAVE TWO FULL 4.5" JOINTS BETWEEN PACKER ASSEMBLY AND X-NIPPLE AND TUBING TAIL ASSEMBLY. CORRELATED TO CAMCO JEWELRY LOG DATE 2-14-92. TRIED TO SET IBP AT 10495' 12' ABOVE X-NIPPLE) BUT IBP PRESSURED UP THEN FAILED TO SHEAR O OFF CABLE AND FOUND PLUG DID NOT SET, POOH WTTH PLUG ACCORDING TO WIGHT INDICATOR STOPPED WIRE AT 100', BELOW 3.5" TUBING GUIDE SHUT WIRELINE RAMS, CLAMPED CABLE AND CUT WIRELINE TRYING TO AVOID SITUATION OF IBP STICKING IN TUBING SLEEVE AND DRAGGING SLEEVE UP HOLE AND GETTING TOOLS STUCK ACROSS WELLHEAD VALVES. LEFT 100' OF WIRE IN HOLE AND ELINE HEAD AND IBP STRING. TOTAL STRING LENGTH IS 30' LONG AND HEAD HAS A 1.16" FISHNECK. IBP IS 2.5" DVaMETER BEFORE TRYING TO INFLATE THE IBP HAS TWO 6" SELAING AND ONE 1" STIFFENER RING. PE HAS COPY OF TOOLSKETCH FOR FISHING OPERATIONS. DSO NOTIFIED WELL IS SECURED AND CAPPED PRESSURE GEAR IS SUPPORTING WIRELINE ACROSS OPEN SWAB AND MASTER VALVES. SLICKLINE IN ROUTE TO START FISHING OPERATIONS. ***JOB INCOMPLETE*** 12-25 10/18/2008 ***CONT FROM 10-17-2008 WSR*** (pre-rw o) FISH OUT E-LINE TOOLS FROM BELOW TREE (2-1/2" BAKER IBP LEFT IN HOLE). RAN 4.50" LIB TO TGB HGR, CTl7RE~F~TRY GUIDE NO-GO (NO SIGN OF IBP). RAN 2.75" LIB TO 1000' SLM, DRAG MARK ON SIDE OF LIB (GOING BESIDE IBP). FISHED 2-1/2" BAKER IBP @ 1157' SLM MISSING ELEMENTS AND STIFFENERRIN_G. RAN 3 1/2" BLB & 2.62"' B, DRIFT OUT TT T ***CONT. JOB ON 10/19/08 WSR*** 12-25 10/19/2008 ***WELL SHUT-IN ON ARRNAL*** INITIAL T/VO: 100/100/0 RIH AND SET IBP WITH MID ELEMENT AT 10447 FT. SURFACE AND VISUAL INDICATION OF PLUG SETTING. RIH WITH HEADI SWNEL/ 2 WEIGHT BARS/ CCL/MPD/ 2 FT LOADED TBG PUNCHER/ BOWSPRING. ***JOB CONTINUED ON 20-OCTOBER-2008*** 12-25 10/19/2008 *** CONT FROM 10-18-08 WSR *** (pre rw o) RIH W/ 3-1/2" BL-BRUSH & 2.70" GRAB TO 10,600' SLM (NO ELEMENTS). CALIPEREO TBG FROM 9768' SLM TO 10,521' SLM. GOOD DATA. RDMO NOTE: IBP ELEMENTS AND STIFFENING RING LEFT DOWN HOLE *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 12-25 10/20/2008 T/V0=0/50/0 CMfT T x Va PASSED to 1500 psi MTT OA PASSED to 2000 psi (Pre RWO) Pressured up OA w/ 6.1 bbls crude to 2000 psi. OA lost 140 psi in 15 minutes an 0 psi in secon mnutes for a total 30 minute bss of 180 psi. Bled OAP (2.2 bbls fluid in 22 minutes). F1-essured up TxVa w/33.7 bbls DSL. T/Va lost 0/0 psi in 1st 15 min & 2010 psi in 2nd 15 min, for a total loss of 20 psi in 30 rrin. Bled OAP (5.7 bbls fluid in 23 min). ***Continued on 10-21-08 WSR*** Print Date: 12/3/2008 Page 1 oft Well Date Summary 12-25 10/20/2008 *"JOB CONTINUED FROM 19-OCTOBER-2008.*** RIH WffH HEAD/ SWNEL/ 2 WEIGHT BARS/ CCUMPD/ 2 FT LOADED TBG PUNCHER/ BOWSPRING. SHOOT SQUEEZE HOLES, INTERVAL FROM 10395.6 - 10397.6 FT. MAS WAB SHUT, WING SHIJf. ONE OF THE ROOF DOORS HINGES IS BROKEN. DSO NOTIFIED. FINAL T/VO: 100/100/0. **"JOB COMPLETED*** 12-25 10/21/2008 *`*WELL S/I ON ARRNAL***(pre rw o) D1JMP BAILED 2 BAGS OF SLUGGffS ABOVE BKR 2.50" IBP @ 10420' SLM _ BLED IAP FROM 150 psi TO 50 psi, MONITOR EVERY 2 HR SEE LLOOt~RY. CURRENTLY DUMP BAILING THIRD BAG OF SLUGGITS. ***CONT. JOB ON 10(22108 WSR'** 12-25 10121/2008 ***Continued from 10-20-08 WSR*** Bled WHPs post combo. DSO notified upon departure. FWHPs=O/0/0 ***Tags hung. Casing valves open gauges*** 12-25 10/22/2008 *" CONT FROM 10-21-08 WSR *** (pre rw o) DUMPm 3 BAGS (150 pounds)OF SLUGGETS @ 10416' SLM (On top of 2-1/2" IBP). PULLED 5 1/2" TO 3 1/2" WL ENTRY GUIDE FROM TBG HANGER. *"WELL LEFT S/I OPER NOTIFIED*** 12-25 10/24/2008 T/VO = 120/150/0 Set 5-1/8" FMC IS-A BPJ # 520 thru tree..tag @ 90" 1-2'ext. used...pre-rig..no problems. 12-25 10/27/2008 T/VO = 0/0/0 Balled 5-1/8" FMC IS-A #520 thru BOPS for Do on 16,_3-5' ext. and centralizer used R.K.B=21.55+ 3.75, TAG @ 0"....no pro lems. 12-25 11/4/2008 T/VO=Vac/0/0; Pulled 6-3/8" CNV "J" TWC thru tree Post Do on 16; 1-2' ext. used, tagged @ 108"; ***Complete*** (Best/Fraker 12-25 11/5/2008 *** WELL S/I ON ARRNAL*** (post rw o) PULLED B&R AND RHGM FROM X-NIP ~ 10335' SLM TAGGED IBP r7a 10425' IB, GOOD IMPRESSION OF FN PULLED 2 1/2" IBP W/ BAKER EEVE & 2" JUS *** CONT ON 11/06 08 * 12-25 11/6/2008 *** CONT FROM 11/05/08 *** (post rw o) ***STIFFENER RING OFF IBP LEFT IN HOLE *** DRIFTED TBG W/ TEL, 3.70" CENT, & 3.25" LIB, TAGGED TT @ 10,518' SLM (10518' MD, = 0' correction) TAGGED TD @ 11110' MD, LIB INCONCLUSNE. ***WELL S/I ON DEPARTURE, DSO NOTIFIED**' 12-25 11/26/2008 T/V0=40/VAC/VAC. SI. IA FL (pre AOGCC Mff-IA). IA FL near surface. No IA integral flange. SV=closed. WV,SSV,MV=open. IA & OA OTG. Print Date: 12/3/2008 Page 2 oft Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Derrick, George (Mackie) M [derrgm@BP.com] Sent: Monday, August 18, 2008 1:31 PM To: Maunder, Thomas E (DOA); Reem, David C Cc: Derrick, George (Mackie) M Subject: RE: PBU 12-25 (183-166) Workover Tom, First off, sorry for any confusion.. This well has sort of a complicated decompletion. There are two issues with the tubing: The first is that the tubing is parted at about 3' below the hanger and has fallen 10'-11'. Secondly, there is a slickline fish that is down hole. Because of these two problems we will be unable to set a low p-ug prior to the the rig moving onto the well. It is our fortune that the well was completed with the tubing being stabbed into the packer via a seal bore receptacle. Dave and I talked and with our prior success feel that we will be able to pull the tubing out of this particular seal assembly. This will then allow us to set an RBP @ 10450' and achieve our state required pressure test to then be able to recomplete the well for use as a water and/or MI injection. If you have any other questions please feel free to ask. Mackie sac is erric~ ~~,- BUG : 208 '+Nc?ekaver cr;«ineer BP Ex~laratian (Alaska; Inc. derrgm~bp__.com (~07j 564 581 (office} X907) ~5~ ?674 (celi~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 15, 2008.2:51 PM To: Reem, David C; Derrick, George (Mackie) M Subject: PBU 12-25 (183-166) Workover Mackie and Dave, I am reviewing the proposed Workover program and it appears that some steps are missing. It is stated that the plan is to cut and pull the 5-1/2" tubing, however I don't find a "cutting" step. Also, it is indicated that a TTP will be run after pulling the tubing. This seems contrary to the procedures I have reviewed before. Could you all look into my questions and the procedure in general and send me a revision if needed? Email is fine. Tom Maunder, PE AOGCC 8/18/2008 ~~TT~~v+ ry~ g 1'ss7~~~~il®~ ~ s7~7$ 1` David Reem Senior Drilling Engineer BP Exploration Alaska Inc. ~~,~~~ AUG ~ ~ 2008 • SARAH P,4LlN, GOVERPIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 Anchorage, AK 99519-6612 3' ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-25i Sundry Number: 308-287 Dear Mr. Reem: 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 ff 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. Sincerely, ,£~~, ,~ 't DATED this ~ day of August, 2008 Daniel T. Seam~ount, Jr. Chair Encl. ~~~~~ STATE ~F ALASKA ~~-DI - ~, f, ~: , p ALAS OIL AND GAS CONSERVATION COMMI SION ~J ' ~ ~;~ ~~ , APPLICATION FOR SUNDRY APPROVAL ~ . ~ ~~ 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 183-166 , 3. Address: ®Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21042-00-00 " 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 12-25i Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028331 ~ 73.0 • Prudhoe Bay Field / Prudhoe Bay Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11390 ~ 9210 - 11339 9172 None 2296'& 11140' Casin Len th Size MD TVD Burst Colla se Structural Conductor 180' 20" 180' 180' 1490 470 Surface 2591' 13-3/8" 2591' 2591' 4930 2670 Intermediate Pr uctio 10783' 9-5/8" 10783' 8745' 6870 4760 Liner 908' 7" 10489' - 11385' 8514' - 9206' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10790' - 11173' 8751' - 9048' 5-1/2" x 4-1/2", 17# x 12.6# L-80 10545 Packers and SSSV Type: 9-518" x 5-1/2" Baker FB-1 Permanent Packer Packers and SSSV MD (ft): 10418 7" x 4-1/2" Baker FB-1 Permanent Packer 10850 13. Attachments: 14. Well Class after proposed work: ^ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ® Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 1, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Name David Reem Title Senior Drilling Engineer Prepared By Name/Number: Phone 564-5743 Date Sondra Stewman, 564-4750 Signature ~~ ~ , ~~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness `` ^ Plug Integrity 'BOP Test ~ Mechanical Integrity Test ^ Location Clearance Other: ~~ ~ D~ ~ ~~, `~~ ~ S~t- Subsequent Form quired: ~---'~Q APPROVED BY ~~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Re ' d / 006 ~ Submit In Duplicate ORIGINAL ~ _ ~ ~ ~u%~92~U6 • by 12-25i Rig Workover C Scope of Work: Cut & Pull 5-1/2" L-80 completion, change out 9-5/8" casing packoffs, Run new 5-1/2" L- 80 completion. MASP: 3300 psi Well Type: WAG Injector Estimated Start Date: September 1st, 2008 Production Engineer: Olivia Bommarito Intervention Engineer: Mackie Derrick Pre-rip prep work: S 1 Drift fora 5-1/2" SSSV lu . Attem t to drift to acker C~ 10418'. Set 5-1/2" SSSV lu F 2 CMIT-TxIA to 4000 si. Bleed WHP's to 0 si. W 3 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. O 4 Set a BPV in the tubin han er. O 5 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE to 250 psi low, 4000 psi high. (Annular Preventor to 3500 psi) 2. Pull tubing hangar and lay down. ^S~c~ ~MC~1 ` .~vb~~S Q~~~ ~ ~~~~~ ~~ ~ ~ 3. Pull and lay down tubing string. ~ 4. Set 4-1/2" TTP C~ 10534' pressure test to 4000 psi. 5. Set Storm packer 1 stand below surface to 1000 psi. 6. Change out 9-5/8" casing packoffs through the stack. 7. Pull Storm packer and 4-1/2" TTP. 8. Run new 5-1/2" L-80 premium threaded tubing stacker packer completion with packer at -10350' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test Tubing 8~ IA to 4000 psi. Freeze protect to 2000' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. TREE _ • FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 3000' Max Angle = 50 @6400' Datum MD = 10947' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2591' Minimum ID = 3.81" @ 10534' 4-1 /2" Otis X Nipple 10408' 5-1/2" OTIS X NIP, ID = 4.56" 10416' 5-1/2" BAKER SEAL ASSY 10418' 9-5/8" X 5-1/2" BAKER FB-1 PERM PKR 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10436' 10436' 5-1 /2" X 4-1 /2" XO TOP OF4-1/2"TBG 10436' TOP OF 7" LNR 10477' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10545' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10783' PERFORATION SUMMARY REF LOG: BHCS ON 01/26/84 ANGLE AT TOP PERF: 39 @ 10790' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10790 - 10820 O 06/15/89 3-3/8" 4 10922 - 10960 O 12/07/84 3-3/8" 4 10970 - 10998 O 12/07/84 3-3/8" 4 11012 - 11028 O 12/07/84 3-3/8" 4 11031 - 11038 O 08/08/87 3-3/8" 4 11038 - 11086 O 12/07/84 3-318" 4 11100 - 11120 O 12/07/84 3-3/8" 4 11120 - 11142 O 08/08/87 3-3l8" 4 11152 - 11173 O 08/08/87 2 ~2 5 0~O(OS/30/0 )~ PARTED @ TBG HGR A FELL • 2179' S-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 2196' SLM SL TOOLSTRING w/'20' OF WIRE TOTAL LENGTH = 29' (07!29/06) { 10534' ~ 4-1 /2" OTIS X NlP, ID = 3.81 " 10545' 4-1l2" TUBING TAIL 10518' ELMD TT LOGGED 02/14/92 10$50' ~-~7" X 4-1/2" BAKER FB-1 PERM PKR (ELM) 11140' 4-1/2" TBG TAIL W/PXN PLUG AND HYDRAULIC GS ON BOTTOM - 4-1/2" OTIS XN NIP W/XN PLUG BODY, ID = 0.1" - 4-1/2" TBG TAIL (PBTD H 11339' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11385' TD 11390' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/31/84 ORIGINAL COMPLETION 02111 /92 LAST WORKOV 92 01/06/02 RN/TP CORRECTIONS 07/29/06 JCIWPAG TOOLSTRING FISH @ 2196' 11/21/06 DRS/PJC SAFETY NOTE- TBG PARTED PRUDHOE BAY UNff WELL: 12-25 PERMIT No: 183-1660 API No: 50-029-21042-00 SEC 17, T10N, R15E, 4994' EEL, 102' FNL BP Exploration (Alaska) TREE = FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 3000' Max Angle = 50 @ 6400' Datum MD = 10947' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 3.81" @ 10534' 4-1 /2" Otis X Nipple 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 4-1 /2" TBG TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 01/26/84 ANGLEATTOP PERF: 39 @ 10790' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10790 - 10820 O 06/15/89 3-3/8" 4 10922 - 10960 O 12/07/84 3-3/8" 4 10970 - 10998 O 12/07/84 3-318" 4 11012 - 11028 O 12/07/84 3-3/8" 4 11031 - 11038 O 08!08/87 3-3/8" 4 11038 - 11086 O 12/07/84 3-3/8" 4 11100 - 11120 O 12/07/84 3-3/8" 4 11120 - 11142 O 08/08/87 3-3/8" 4 11152 - 11173 O 08/08/87 PBTD I~ 11339' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 11385, TD 11390' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/31/84 ORIGINAL COMPLETION 02/11/92 LAST WORKOVER 01/06/02 RN/TP CORRECTIONS 07/29/06 JCM/PAG TOOLSTRING FISH @ 2196' 11/21/06 DRS/PJC SAFETY NOTE- TBG PARTED PRUDHOE BAY UNff WELL: 12-25 PERMfr No: 183-1660 API No: 50-029-21042-00 SEC 17, T10N, R15E, 4994' FEL, 102' FNL BP Exploration (Alaska) 2 ~2 5 S~TES:None Proposed RW O ~ 5-1/2" X NIPPLE, ID = 4.56" ~ 10330' ~ 5-1 /2" X NIPPLE, ID = 4.56" 10350' - {9-5/8" X 5-1/2" BAKER S-3 PKR 10390' 10416' 5-1/2" X NIPPLE, ID = 4.56" S-1/2" BAKER SEAL ASSY 10418' 9-5/8" X 5-1/2" BAKER FB-1 PERM PKR 10~ 5-1/2" X 4-1/2" XO 10436' 10436' 10534' ~4-1/2" OTIS X NIP, ID = 3.81" 10545' 10545' 4-1/2" TUBING TAIL 10783' 10518' ELMD TT LOGGED 02/14/92 10850' 7" X 4-1/2" BAKER FB-1 PERM PKR (ELM) 11140' 4-1/2" TBG TAIL W/PXN PLUG AND HYDRAULIC GS ON BOTTOM - 4-1/2" OTIS XN NIP W/XN PLUG BODY, ID = 0.1" - 4-1/2" TBG TAIL MEMORANDUM e State of Alaska It Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor l', -/ _}.;; ~/7') DATE: Wednesday, July 05,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-25 PRUDHOE BAY UNIT 12-25 'b' \ lot¡¡ \~ FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: '~'!2:7 P.I. Suprv "~ vi,¿"-- Comm Well Name: PRUDHOE SAY UNIT 12-25 API Well Number 50-029-21042-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG06070II2I558 Permit Number: 183- I 66-0 Inspection Date: 7/1/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 12-25 IType Inj. ! w TVD ! 8458 i IA I 20 2250 i 2210 i 2200 I I P.T. I 1831660 iTypeTest ¡ SPT Test psi I 2250 i OA i 2 ! 7 ! 2 i 2 .' I i Interval 4YRTST PIF P / Tubing I 925 920 i 920 i 920 i I Notes 6 bbl's pumped, Test "OK", NON-CONFIDENTIAL , 'f" \,Ü\\,f:.r \ )'/,f),\~ 'í:. "'¡¡,;."'~ ,\ {;.,; Wednesday, July 05, 2006 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Cammy O Taylor ~:~ TO: Chairman DATE: May 20, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX DS 12 PBU Prudhoe Bay Packer Depth Pretest Initial 15 Min, 30 Min. WellJ 12-02 I Type,nj.I S J T.V.D. J 8483 I Tubing 115O0 J1500 11500 J1500 J lntervalJ 4 P.T.D.I 179-032 ITypetestl P ITestpsil 2121 I Casing] 1300I 2380 I 2350 I 2350 I P/F I P Notes: WoIII 12-25 I Typelnj.I S I T.V.D. J 8458 I Tubingl 1200 J 1200 I 1200 J 1200 I lntervall 4 P.T.D.I 183-166 ITypetestl P ITestpsiI 2115 ICasingI 320 I 23201 23001 23001 P/F I P Notes: WellI 12-27A [Typelnj.I G I T.V.D. I~* I Tubing I 2200 I 2200 I 2200 12200 I lnterva, l 4 P.T.D.I 199-039 ITypetestl P ITestpsiJ 2099 JCasingJ 900 I 24201 2380J 2380I P/F I -P N ores: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 12 and witnessed the 4-year MIT on wells 12-02, 12-25 and 12-27A. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: 3 Attachments: Number of Failures: 0 -- Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. MIT PBU DS 12 5-20-02 CS.xIs 6/3/02 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 (Frac) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 73 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 StratigraphY__ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4427' FNL, 5113' FEL, SEC. 17, T10N, R15E, UM 12-25 At top of productive interval 9. Permit number / approval number 56' FSL, 5280' FWL, SEC. 17, T10N, R15E, UM 83-166 At effective depth 10. APl number 50-029-21042 At total depth 11. Field / Pool 102' FNL, 4994' FEL, SEC. 21, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 11390 feet Plugs (measured) PBTD tagged @ 10843' MD (5/18/98) true vertical 9209 feet PXN Plug @ 10865' MD. (4/7/98) Effective depth: measured 10843feet Junk(measured) ORIGINAL true vertical 8792 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80" 20" 1980, Poleset 80'~,;~;' [: ? ~.'i' I'!' i~-, ~ "' i~~ ~2~91~80' Surface 2518' 13-3/8" 2400 Sx Fondu/400 Sx PFC 2591' '~ ~ ' Production 10710' 9-5/8" 500 sx Class G & 300 Sx PFC 1 0783' 8745' Liner 908' 7" 300 SX Class G 11385' .._ Perforation depth: measured 10790' - 10820'; 10922' -10960'; 10970' - 10998'; 11012' - 11028'; 11031' - 11086'; 11100' - 11142'; 11152' - 11173'. true vertical 8750' - 8773'; 8854' - 8883'; 8891' - 8913'; 8923' - 8936'; 8938' - 8981'; 8991' - 9007'; 9031' - 9047'. Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80 Tbg @ 10436' MD; 4-1/2', 12.6#, L-80 Tbg @ 10545' MD & 10867' MD. Packers &SSSV (type & measured depth) 9-5/8'x5-1/2' Baker FB-1 Perm Packer @ 10418' MD; 7' x4-1/2' Baker FB-1 Perm Packer @ 10850' MD. 5-1/2' Camco BAL-0 SSSV @ 2179' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 1 n/a Subsequent to operation 2564 1502 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __ Gas ~ Suspended ~ Service~X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~'~~~ ~_.~~ Title Arco Engineering Supervisor Date Signed Erin 0 ~ ' Pre?areal by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 12-25 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date Event Summary 4/07/1998: 4/23/1998: 4/24/1998: 4/26/1998: 4/28/1998: 5/02/1998: RIH & set PXN Plug @ 10865' MD to isolate Zone 4 perf intervals. 10922' - 10960' (Zone 4) 10970' - 10998' (Zone 4) 11012'- 11028' (Zone 4) 11031' - 11086' (Zone 4) 11100' - 11142' (Zone 4) 11152' - 11173' (Zone 4) Injectivity Test on Sag perfs: 7 bpm @ 2550 psi. RIH & set 5-1/2" frac sleeve @ 2167' MD. MIRU & PT equip to 8000 psi. Performed a FB Hydraulic Fracture Treatment on a WAG Injector well using 20/40 mesh ceramic proppant, through the open perf interval: 10790' - 10820' (Sag) Pumped: (a) 400 bbls Pre-Pad @ 30 bpm, followed by (b) Shutdown. ISIP @ 2158 psi. Resumed pumpinq Frac Treatment (c) 554 bbls 40# Crosslinked Pad @ 30 bpm, followed by (d) 725 bbls Crosslinked Slurry @ 30 bpm w/proppant stages @ 1-10 ppg, followed by (e) 248 bbls 20# Gelled Flush @ 30 bpm, followed by (0 Shutdown. Placed a total of 95731 lbs of proppant into the FM. No screenout. RD. RIH & pulled frac sleeve. Tagged PBTD @ 10781' MD. MIRU CTU & PT'd equip to 4000 psi. RIH & performed FCO to 10866' MD. POOH. RD. RIH & tagged PBTD @ 10843' MD. Returned well to WAG injection. ARCO Alaska, Inc. Post Olfice B"--"~!00360 Anchorage/- .a 99510-0360 Telephone 907 276 1215 August 10, 1993 Ms. Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Outstanding Application Approvals Dear Ms. Miller: Per your 7/30/93 letter to Mr. James Cawvey, regarding the listed outstanding 10-404's (Report of Sundry Well Operations), the following summary is provided: Well 1-16: Approval # 8-988, Approved 12-28-88. Report Sundry attached covering Reperforating work. Well 3-16i: Approval # 9'740, Approved 8-23-89. Report Sundry attached covering Acid Stimulation, Cement Squeeze, & Reperforating work. Well 3-16i: Approval # 91-234, Approved 8-6-91. Report Sundry covering Perforatiing work was completed & sent to AOGCC 11/91. A copy of this Report is attached. previously 4) Well 5-18: Approval # 9-993, Approved 11-15-89. Report Sundry attached covering Initial Perforating work. Well 5-26:~Approval # 90-060, Approved 2-1-90. The approved Stimulation work for 2/90 was never-performed. Please ;cancel:-this approval. Well 7-06:' Approval # 90-666, Approved 8-27-90. The approved Gas Shutoff work for 9/90 was never performed. Please-cancel this approval. ~/- [ 9__~7) Well 11-2: Approval # 90-066, Approved 2-6-90. Report Sundry attached covering Tubing'Washes Reperforating work. R E C E IV E D ARCO Alaska, Inc. Is a Sub$1dla~f of Allantlc Richfield Company Alaska 0il & Gas Cons. Corn~nissio~ Anchorage ~Ms. Joan M¢le~ August 1 O, Page 2 - ~ ¢5N¢\ 8) ~~ 9) Well 11-27: Approval # 9-750, Approved 8-24-89. Report Sundry covering Perforatiing work was completed & sent to AOGCC 9/89. A copy of this Report is attached. previously Well 12-25: Approval # 92-019,' Approved 2-4-92. The approved Puli Tubing work for 2/93 was never performed. Please cancel this approval. Well 15-8: Approval # 90-526, Approved 7-12-90. The approved Stimulation work for 8/90 was performed 3/91. The Report Sundry is attached. Well 15-10A: Approval # 90-463, Approved 6-19-90. The approved Pull Tubing work for 8/90 was never.performed. Please cancel this approval. 12) '7~--/'{~ 13) Well LGI-4: Approval # 90-852, Approved 12-3-90. Re: the approved Stimulation/Reperforating work for 11/90: Since this is a Lisbume Well, reconciliation of this approval will be handled by the Lisbume Operations Group. I will notify the person responsible, in the Lisburne group to handle this outstanding Report Sundry. WGI-3: Approval # 8-76, Approved 2-10-88. Report Sundry attached covering Stimulation Treatment work. Sincerely, / John W. Peirce Engineering Aide JWP/010 Attachments cc. ,yz/d. L. Cawvey - (ARCO) - ATO- 1520 u M. Sloan - (BPX) - Drilling Dept. RECEIVED A U 6 1 9 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERYATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907') 279-1433 TELECOPY: (907) 276-7542 July 30, 1993 Mr. James L. Cawvey Engineering Supervisor ARCO Alaska lnc P.O. Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Cawvey, In making a review of well files we have found some files which contain approved Application of Sundry Approval forms (form 10-403) that have no subsequent Reports of Sundry Well Operations (form 10-404). Enclosed a list of the wells in question. To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the form 10-404 is required to be filed with 30 days following completion of work. We would also appreciate notification of any canceled work So that the corresponding Application on file can be marked accordingly. Your help in directing the enclosed list to the appropriate responsible parties will be appreciated. Sincerely, Joan Miller Statistical Technician pRUDHO~ BAY - ARCO Well No. DSl-16 DS3-16 DS5-18 DS5-26 DS7-6 DSll-2 DSll-27 DS12-25 DS15-8 DS15-10A LGI-4 WGI-3 Pern~t No. 78-8 79-93 89-76 89-113 78-14 81-128 86-148 84-155 88-85 88-13 79-49 Approval Date & No. 12-28-88, 8-988 8-23-89, 9-740 8-6-91, 91-234 11-15-89, 9-993 2-1-90, 90-060 8-27-90, 90-666 2-6-90, 90-066 8-24-89, 9-750 2-4-92, 92-019 7-12-90, 90=526 6-19-90, 90-463 12-3-90, 90-852 2-10-88, 8-76 Description Perforate 12-88 Perforate 8-89 Perforate 3 Q '91 Perforate 11-15-89 stimulate 2-90 Gas shutoff treatment 9-90 Perf., stimulate, perform CTU cement squeeze 2-90 Perforate 3 Q '89 Pull tubing 2-93 Stimulate 8-90 Pull %ubing 8-90 Stimulate, perforate 11-90 Stimulate 2-88 ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-19-92 REFERENCE: ARCO CASED HOLE FINALS ?~-~ 1-5ST ?~'-~? 7-1 FL- ?° 9-8 ~--~ ~ 9-27 12-1 ?~3 ~i ?-~I/ 12-6 -/?Y- 12-7A ~-/~ -12-25 Z~-~ 13-4 ~-~ 14-25 ~-/~/ 18-20 5-31-92 Prod Profile Run 5-29-92 Inj Profile Run 6-1-92 Inj Profile Run 6-1-92 Prod Profile Run 5-29-92 Prod Profile Run 5-28-92 Leak Detect .Run 5-29-92 Prod Profile R~n 5-29-92 Inj Profile 5-30-92 Prod Profile Run 5-30-92 Inj Profile Run 5-26-92 Prod Profile Run 1, 511 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the RECEIVED BY ~_.~__4~.~- Have a Nice Day!R E C E IV E D SonyaWallace JUN 2 9 1992 AT0-1529 Alaska Oil & Gas Cons. Commission Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL attached coPy as receipt of data. APPROVED Trans# 92123 # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO Alaslr~,, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 11-22 2-23-92 Prod Prof Rnn 1, 2"&5" ?t~/~? * 12-4A 3-7-92 Prod Proc Rnn 1, 5" ~- 5~ ~12-5 2-14-92 Jewelry Rnn 1, 5" ~12-5 2-14-92 Prod Prof Rl~n 1, 5" °Z-z°°/ 12-18 2-23-92 Collar Rl~m 1, 5" ~)-/g~ 12-25 2-14-92 Jewelry Run 1, 5" ~/-/~ 13-8 2-7-92 Prod Prof Rnn 1, 5" °°°-'¢~' 13-12 3-9-92 Gas Entry Rn_n 1, 2"&5" ~Z-z~ 13-23A 2-22-92 InJ Profile Rnn 1, 5" ~°z~-bff 13-24 2-22-92 InJ Profile Run 1, 5" Ja-~/ 13-25 2-27-92 InJ Profile Run 1, 5" CKlnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the attached copy as receipt of data. RECEIVED BY .... ~_ RECEIVED Have A Nice Day! Sonya Wallace ATO- 1529 .~992 R VEr~ Alas~/~fkGas Cons. Commisslo0 APP 0 .-- --~-~'--- ~Anc~rage Trans# 92079 ~ # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLH~ PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 12-4A is 50-029-20384-01. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 2-21-92 {4-42 ,// 12-25 12-25 1-26-92 PDK-100/GR/CC~ Run 1, 5" Atlas 2-7-92 CCL (Pert) Run 1, 5" Atlas 2-6-92 PFC/GR (Pert) Run 1, 5" . Atlas 2-6-92 GR/~ Rim 1, 2"&5" Atlas 2-2-92 Perf Record Rim 1, 5" Sch 2-2-92 GR/~ R,n 1, 5" Sch 12-28-91 CBT R.n 1, 5" Sch ' 12-28-91 CET Run 1, 5" Sch 2-3-92 CCL (Ttlbing Cutter) R-n 1, 5" Atlas 2-8-92 Collar (Packer Record) R.n 1, 5" Atlas Please sign and return the attached co]}y as receipt of data. RECEIVED BY_~~~_=~ Have A Nice Day~ Sonya Wallace APPROVED ATO-1529 ...,- Trans# 9203~// ..- # CENTRAL FILES -- # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D #BPX # STATE OF ALASKA TEXACO RECEIVED FEB 2 5 1992 Alaska Oil & Gas Cons. Commission Anchorage MEMORANi.,dM Sta' e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION ~_-/_ ~.// DATE: February 12 TO: Lonnie C Smi~'~-:~ , 1992 Commiss ione~ FILE NO: HH212-1. DOC THRU: FROM: Blair Wondzell Sr Petr Eng Harold R Hawkins Petr Inspector TELEPHONE NO: SUBJECT: BOP Test ~-- ~o~ PBD PBU 12-25 I Prudhoe Oil Pool Tuesday., February .$, 1992 I witnessed a BOP test for PBD PBU 12-25 I. There were no failures. I filled out an AOGCC field report, which is attached. In summary, the BOP test on PBD PBU 12-25 I was satisfactorily performed by Doyon 16 crew. Attachment 02-00lA (Rev. 6/89) 20PI1/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg Wkvr Operator Well / Location: Sec T Drlg contrctr,-~O~J~ Location ~general> tTN~>t Housekeepin9 ~general > ~ R M Well sign Ri g DATE MUD SYSTEMS: Vi sual Trip tank Pit gauge F1 ow monitor V Gas detectors Audi o Week1 ¥,~ Other TEST: Initial Permit ~. ~ Casing set ~-/~,7,~'~I~ ft ACCUMU~TOR SYSTEM: Full charge pressure ~~ psig Press after closure /~ p~ig Pump incr clos press 200 psig ~ min ~ ~ec Full charge pre~ attained ~ min ~ sec -/ Controls: Master Remote ~ J~/iY Blind s~itch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure BOPE STACK: Lower Kelly Test pressure Test Pressure Annul ar preventer ~,~'~ Ball type Test pressure Pipe rams ~J-~) Inside BOP Test pressure Blind rams C~ ~ (~ Choke manifold ~ Test pressure~~y~F' Choke line valves ~~5> Number valves / HCR valve ~,~y~ ~j~-~7 ~ Number flanges ~Z~ Kill line valves =~_~ Adjustable chokes Check valve /~//y~ Hydraulically operated choke TEST RESULTS: Failures ~~ Test time ~ .~ hrs Repair or replacement of failed equipment to be made ~ithin_~s. Notify the I nspector~ and follo~ ~ith ~ritten/FAXed verification to Commission office. D~stribution: orig - AOGCC c - Operator c - Supervisor STATE WITNESS REQUIRED? yes~ no 24-HR NOTICE GIVEN? Waived by: Witnessed by: p.O~z lou-_a?-,._ 99510 ~cborage, Alass~ DATE: 1-2~-97, Aaco c~° ~o~ ~ I~n 1, 5" camco camco Rm~ 1, Il" CamCO Run 1, 5" Camco Run 1, 5" CamcO Run 1, 5" CamcO Camco Run 1, 5" CamCO Rmn 1, 5" Camco ~ ~, 5" Camco ~ 1, 5" Ca~co ~ 1, 5" Camco ~ 1, ~,'&5" Camco ~' - ~,'&5" CamcO ~ ~, z ~ Ca~CO ~ t, ~"~" ~}'~}'~/~1~.4 and. tetl.lx~ the attache cg~~ receipt oi ~ RECEIVED ~ ANlce ~ AppROVED ~s~ 92016 $onlm wallace A~O- 1529 D & ~[ ExpLO~TION # ~x~s~o~ # MOBIL ,lIPS R&D # ~ex a~s~ , S~,3's o~ ~co RECEIVED FEB 03 1992 Alaska Oil & Gas Cons. Commission 0 RIG Ab..~KA OIL AND GAS CONSERVATION COMMIS~,,~)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well~ Alter casing __ Repair well Plugging __ Time extension ~ Stimulate __ Change approved program Pull tubing x Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development__ Exploratory __ Stratigraphic__ Service x 4. Location of well at surface 850'FSL, 138'FWL, SEC. 17, TION, R15E At top of productive interval 56' FSL, 5280' FWL, SEC. 17, TION, R15E At effective depth 56' FSL, 5280' FWL, SEC. 17, TION, R15E At total depth 102'FNL, 261'FWL, SEC. 21, TION, R15E I ECEIVED JAN 1 t99 Alaska Oil & Gas Cons. Anchorage 6. Datum elevation (DF or KB) KBE = 73' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-25 9. Permit number 83-166 10. APl number 50- 029-21042 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 11390' feet Plugs (measured) 9209' feet BKB 11339' feet Junk (measured) 9171' feet BKB 11. Field/Pool Prudhoe Bay Field/Oil Pool Size Cemented Measured depth True vertical depth 80' 20" 1980# POLESET 80' 80' 2518' 13-3/8" 2800 sx Permafrost 2591' 2591' 10710' 9-5/8" 800 sx "G" 10783' 8745' 896' 7" 300sx"G" 11385' 9205' measured 11790~10820~ 10922~I0960~ 10970~10998~ 11012~11028~ 11031~11086~ 11100~11142~ 11152~11173' true vertical (subsea) 8750'-9047' (seven intervals) Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @10422'4-1/2" tailpipe to 10508' Packers and SSSV (type and measured depth) Baker FHL packer @ 10428' MD, SSS V @ 2189' Description summary of proposal x Detailed operations program BOP sketch x 13. AEachments 14. Estimated date for commencing operation 15. Status of well classification as: February 1, 1992 16. If proposal was verbally approved Oil~ Gas Name of approver ~k~e ~lind~ 01-30-92 Date approved Service Water Injector 17. I hereb~ cer;l,i:f:v-~at{'tl~fl~rego~g is true and correct to the best of my knowledge. Signed~'~'- ~~"/~/~ ' FOR cT~I;MOI~es;a~n;sS;P~ttYenden. Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test .~. Subsequent form required 10- E0~-! Approved by order of the Commission Original Signed By David W. donnston I Approval No./C:~_~ / ¢ ,; .i~' '..'./. ~,Li Commissioner Date '~/~ / ~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 OBJECTIVES: ATTACHMENT I WORKOVER DS 12-25i PLAN OF OPERATIONS Replacing a failed BAKER FHL packer by removal of the existing 5-1/2" completion assembly, milling/retrieval of the BROWN 9-5/8" x 5-1/2" FHL packer, cleanout to PBTD, testing casing, installation of an isolation packer, recompleting the well with a 9-5/8" x 5-1/2" permanent packer and a 5-1/2", L-80, IPC completion string. RIG OPERATIONS 0. 1. 2. 3. 4. 5. 6. 7. 8. MIRU. PULL BPV KILL WELL (BULLHEAD) ND/NU/TEST BOPE PULL TUBING/SEAL ASSEMBLY/PBR?? RETRIEVE PBR (PU DP) RETRIEVE PACKER SCRAPER RUN/CLEANOUT (PU COLLARS) XYLENE/DIESEL SOAK/WASH DISPLACE WELLBORE POOH LDDP GR/JB SET PACKERS ON E-LINE RUN 5-1/2" COMPLETION ASS'Y LAND TUBING/SPACEOUT FREEZE PROTECT/RELAND TUBING ND/NU. TEST TREE TEST TUBING/CASING. SECURE WELL. RELEASE RIG RECEIVED JAN 3992 Alaska 011 & 6as Cons. (;ommiss%on Anchorage BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRI PLE RAM STACK WORKO VER RISER ANNULAR PREVENTER ! 2" KILL LINE MANUAL HYDRAULIC GATE GATE PI PE RAMS I I PI PE RAMS I DRILLING SPOOL I 4" CHOKE LINE HYDRAUI_I C MANUAL GATE GATE BLIND RAMS I I I REC[ IV[D Al~.~im Oil ~s Cons. oommiSsioo Anchorage AF;:CO AI...A.'>;I<A, INC'., I::'~ 0, Ii-:OX 'i (:)(i.~S6(:) ' '~-" A N C I"1 (] c, A (:; E "' ""'" 9 9 5 ,.. , HL.M,~,('/ i 0 Ii"' F'lii: I:;t E" N C Iii: ' A I:;; (30 C: A S' Ii:: D I..I 0 I.. Ii..'. I= .[ N A !... S.'. 2 .... i6 ~. -'"'"' i ," -<), .... i ,::,"'-"':>i',. /"1 , '" "':'" ') .... '~" "' "?" uti ~ -5: .... '2 (:;' 4 .... "':' ~ '"' ? i 5 .... i..;-'::' 4 -'-8 "" <~, i 6'"' 2 (~ 4 .... 6'- 9' i "", ..... ,~ 4 .... 5'"9i i i .... i 4 .... i i "-4 4 .... i,='.'" -'" ,:. © ~3 4 ..... (5 '"' c., i i 2-'25 4 .... i ~- i 4- .... 2~3 S--:3 .... ?'i i 4 .... S 5 .4 ..... "{' lii:i't" .... '" I:- F-:. I.... ~.., T LI F;,' F...':. L.. E: F':'~ K l) li['T' I::' [_'3 '1- I 0 N i... I!!: A I-':.' i) E: 'T' EF. [::: "f' I O N I N ,j Ii". C: 'i' I [:J N C !-:-,' i- F' I.? r-) I> !J C' l" :1: C) N F' f;: 0 I) L! .F.:: l' I E) N I... Iii: r.'-; I< I".:' [':'. 'T' [-" C 'F I 0 N I... Iii: (:', I< I.':, Iii: "l' I:'!: C 'i" I 0 N C: [)I... I... A I~'. ,--" F' [.._' F,: F C.; ;.":', F'i hi A / C C I.../J Iii: I,..! Iii: L. F..' Y I....r..[ ,..':; K i) Ii.". 'i' Ii-' C 'i" :[ I':] N !... !ii: ;:':; K i) E: '1" Ei. C l I (:! N F:' I 'i" ;'?/I N JECT I ON I N J I"': C l' I 0 i'..! I N J Ii:: C 'l" I [:) N F' iR 0 D U C l' ]: 0 N [.'; [) L I._ A F.'. F:' F:..' 0 L'., U C T I f.] N ::-~:- .':, .....~, .-., 'i"1...,~1, ,.,I Ii'~,NI:..-:F: R'I_JN i, _., ~:'" CAHF:['I .... R! If,.I i ..... CAHCO RLJN i , t" CAHF~Fj RUN t , _,-";'" CAHC(] .~..,1"t RI..IN i , _.-':~'" I'? U N F;,'L!N t, 5" C;Ai'iCO IRl. Jiq i, F;.:LIN i , ")" ~' ='" · . ,,-.. ,,,_':;'l Ii--.I, i , RUN i, .;~;'" r:Ai'iCFi .... F:UN i, 5" CAHCL?. · '~' F;..'LJi'.~ i, _; · RUN I, 5" CAMUC) R' U N F.,'UNt , ..~':"" CAHCC! F;.:UNt, 5" CAi'-iCCt RUN i, 5;" CAHC:C) R'LJN i, 5" E;Ai'-iCO IL'UN t I::'L_Ei:r-'t.',~"Ei: ~"I(.';N ANI) I:;,'E.":'T'LI~:?N THE ATTACHE:I) C[]F'Y ,-.'",.Y F;'ECEIF:'T O1= I)ATA f.;. ~.:. . i .. - -. I-.I A V E." (}l i"~ ]' C E D A Y ! i) I Z T F.'. I B lJ i' ]: C] iq '"' C IF.': N T R A I... I:: .[ L_ E: ~' *il. C I..I Iii: V F: 0 N D & H '"' Ei: X TEi: i'.-! 3' I C) i".~ Ii. X F:'I...C) R A T ]: CI N 11' - · '"' E..E X X t) i',! '11' · "' M 0)'"~ I I.. · "' F'FilLLIF PB wr-..iLL FI'LE£' I:: & D ~: I':',' f:' X '"' ZI"ATE OF ALASKA i'Ev'Aco;: · x. THIS' IS A I)LJF'L.]:CA'I'E: OF THE I_.[)(:; YOL.I AL.F..'I~i:AI)Y F,'ECE!VED, EX[;EF'T THE AI::'I~: :[~? COF;,'F:ECTFD, I:'L['[(:~,~:IF THI;:OW THE PREVIOUS COPY WIi'H 1-HE WRONG AF'I:~,'. AWAY, ARCO ALASKA, P.O. BOX i00S60 ANCHORAGE, ALASKA 995i DATE: 8-2-89 REFERENCE' ARCO CASED HOLE FINAI_~ t i i-4 5-26-89 PERF RECORD i-t7 7-S-89 PERF RECORD 2-4 6-24-89 PERF RECORD 2-t6 7-S-89 PERF RECORD 5-9 5-i 0-89 COLLAR/F'ERF 4-5 6-it-89 PERF RECORD 4-t9 5:-;5i -89 PERF RECORD 7-i 6 5-i -89 COLLAR/PERF t t -t ,S 5-24-89 PERF RECORD tt-t6 5-24-89 PERF RECORD t t.-28 7-24-89 CBT i .i -28 7-24-89 CE'r t t-28 7-24-89 GR t2-2S 6-4-89 PERF RECORD 2-25 6-t5-89 PERF RECORD 2-S0 6-i-89 F'ERF RECORD 2-Si-- 6-2=89 - -PERF RECORD 2-5S 6-;5-89 PERF RECORD 4-2 7-3-89 F'ERF RECORD 4-27 6-29-89 PERF RECORD 7-9 6-t 6-89 PERF RECORD RUN t, RUN t, 5' HL~ RUN RUN RUN t, 5" I-iLS RUN t, 5" HL~ RUN i, 5" I-IL~' RUN i, 5" HL~ RUN t, D" FILS RUN i, 5" 14L~ RUN i,. 5" ~CH RUN t, ~" $CH RUN t, ~" $CH RUN l, ~" HL~ RUN t, 5" HL~ RUNS i-6, 5" HL$ RUN$..t-6, 5" HL$ RUN£ t-3, ~" HL$ RUN t, 5~ HL$ RUNS t&'~ 5" HL$ RUN 1, 5' HFS" PLEASE SIGN AND-RETURKL THE ATTACHED COPY .AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 - -- -? ;-j::.'i'~: - D.I~IR I BU'F I ON C ENT RAI~"-- F- I bE%~.:. - -.- CHEVRCN>¢ ';?~ ...... EXTEN~ZON EXPLOR~TZON EXXON H~R~THON ~OBZL F'HILLIF'~ F'B WELL F'ILE&' R & D BPX ~TATE OF ALA&'KA TEXACO ARCO ALASKA, INC, P,O, BOX iO(')S60 ANCI";OI:~AGE, ALASKA 995 t 0 DAI'E · 7-i 7-89 REFERENCE: ARCO CASED HOLE FINALS S-.t~ 6-29-89 SF'INi'~ER SURVEY S-~2 6-29-8'? SPINNER SURVEY .3-t5 7-7-89 TEMP SURVEY S-22 7-9-89 I"EMP SURVEY 5-.Z~ 7--i .-89 TEHP SURVEY 9-.2 7-5-89 TEMP SURVEY 9-6 7--5-89 TEMP SURVEY 9--7 7-5-89 'i"EMP SURVEY 9-.9 7-5-89 TEHF' SURVEY 9-28 7-5-89 TEMP SURVEY it-2 7-7-89 TEMP SURVEY ti-7 7-9-89 TEHP SURVEY ti-t6 7-t0-89 TEHP SURVEY t2-25 6-S0-89 TEMF' SURVEY t2-25 6-.~0-89 SF'INNER SURVEY t 6-20 7-8-89 TEMP a'URVEY F'I_EASE SIGN AND REI'URN RECEIVED BY _ HAVE A NICE DAY! SALLY HOFFECKER ATO- ~ 529 RUN t , 5" I:::tJN t, '5' R LJ hi I-( U N R UN i, 5: ' F:UN t , 5' RUN t , 5" I;:UN RLJN I, 5" RUN i RUN t, 2'&5" ':~ "& 5" RUN t, 2"&5' RUN i , I'.(UN t, 5" R tJ N THE ATTACHED COPY AS RECEIF'T OF' DAI"A ~ 'T'RANS~ 89'~9 DISTRIBUTION t. '" CENTRAL. ~IL£S .~. -.-'"' CHE VRO~'::',ii !~ · : 1~ ' :-~...."..L~ D &~ M ,¥; ;.' '" ':~, '"d, ' .~' EXTENStO~':.-[XPLORAT I ON -,-~' E: X X 0 N,:>,' ~' :"'~ '"' '~. ., , ,.. . :-~..;, HARAI'HO~ ',' MOBi,-:'- ":'" ~' ~ F'HILI_IF'S F'B WELL. FILES R & D ~ BF'X · ~, .. .,- STATE OF ALASKA "' TEXACO 01'I$ 0 "f' I $ 0 '1' .I..¥ 0 i"i S 0'1"i 0 'l" .1: S O'l'I S 0 T' I S 01' I S 0 'r I ,? OTIS OTIS OTIS OTIS 0 T I S OT I 2 ARCO Alaska, Inc. Prudhoe Bay E,,~lineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 30, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-25, Approval No. 9-497 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-13) W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA ~'. AND GAS CONSERVATION CC'~IISSION ~ REPORT SUNDRY WELL OPERATIONS 1. ©p~rations performed: Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Stimulate -- Plugging Perforate X Repair well Other X 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 850' FSL, 138' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At effective depth 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At total depth 102' FNL, 261" FWL, Sec. 21, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-25 9. Permit number/approval number 83-166/9-497 10. APl number 50 - 029-21042 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Intermediate 2518' Production 10710' Liner 896' 11390 feet Plugs(measured) 9209 feet 11339 feet 9171 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1980# Poleset 80' 80' 13-3/8" 2400 sx Fondu & 400 sx PF 'C' 2591' 2591' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 10783' 8745' 7" 300 sx CI 'G' 11385' 9205' Perforation depth: measured 10790-10820'; 10922-10960'; 10970-10998'; 11012-11028" 11031-11086" 11100-11142'; 11152-11173' true vertical 8750-8773'; 8854-8883'; 8891-8913'; 8923-8936'; 8938-8981 '; 8991-9007'; 9031-9047' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10422' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10508' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 10428' MD; Camco Bal-0 SSSV @ 2189' 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 Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 18257 0 0 20747 Tubing Pressure 1409 1737 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 '--~"~m'-~¢~-~-._ '~--~~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 Date 2/~,~ ,,/',~,~ SUBMIT IN DUPLICATE DS 12-25 Post Job Summary The Application for Sundry Approvals had proposed to (1) Perforate the Sag River Interval and (2) pump a hydraulic propped fracture treatment into the Sag River perforations. The hydraulic fracture treatment was not performed. In its place an inflatable through tubing packer was run and placed between the Sag River and Ivishak perforations. A sized orifice was placed in the packer to restrict the injection of waterflood water into the Ivishak perforations thereby allowing more water to enter the Sag perforations which was the goal of the fracture treatment. Sequence of Events: 1. Perforate Sag River interval with Halliburton 3 1/8" Go-Devil guns, 4 spf at 10790'-10820' MD (referenced to BHCS log dated 1/26/84) on 6/15/89. 2. MIRU with coil tubing on 7/30/89 and RIH with inflatable packer. Set packer at 10902' MD which is 20' above the top Ivishak perforation. 3. MIRU with slickline on 8/23/89 and RIH with injection orifice receptacle with 1" orifice installed and latch onto the inflatable packer at 10902' MD. 4. Place well back on injection. ARCO Alaska, Inc.f Prudhoe Bay _,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 10, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-25 Approval No. 9-313 Dear Mr. Chatterton' Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 pI(DS 12-25) W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/"-"~IL AND GAS CONSERVATION C "-""MISSION REPORT OF SUNDRY WELL OP,-RATIONS 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 850' FSL, 138' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At effective depth 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At total depth 102' FNL, 261" FWL, Sec. 21, T10N, R15E, UM 5. Type of Well Development X Exploratory Stral~graphic ~l~ 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-25 9. Permit number/approval number 83-166/9-313 10. APl number 50 - 029-21042 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' I nte rmediate 2518' Production 10710' Liner 896' 11390 feet Plugs(measured) 9209 feet 11339 feet 9171 feet Junk(measured) Size Cemented Measured depth 20" 1980# Poleset 80' 13-3/8" 2400 sx Fondu & 400 sx PF 'C' 2591' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 10783' 7" 300 sx CI 'G' 11385' True vertical depth 80' 2591' 8745' 9205' Perforation depth: measured 10922-10960'; 10970-10998'; 11012-11028'; 11031-11086'; 11100-11142'; 11152-11173' true vertical 8854-8883'; 8891-8913'; 8923-8936'; 8938-8981 '; 8991-9007'; 9031-9047' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10422' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10508' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 10428' MD; Camco Bal-0 SSSV @ 2189' 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 Representative Daily Average P~ or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 0 0 12000 -- 970 Subsequent to operation 0 0 17000 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run Ii ~ Daily Report of Well Operations -, Gas m Suspended 17. I hereby certify that the foregoing is true and correct to the b'"est of my knowledge. Signed ~r./"/~ j ~~ Title Service Operations Engineering Manager Date 970 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Drill Site 12-25i Full Strength Mud Acid Matrix Stimulation 5/24/89 ARCO Alaska, Inc., performed the following stimulation treatment: 1. Loaded the following fluids: a. 10000 gal of 12% HCI with additives b. 16500 gal of 12% HCL/3% HF with additives c. 5000 gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and abiocide. d. 700 bbl of 2% NH4CI water with a biocide. e. 150 bbl of methanol. f. 500 - 7/8" dia, 1.1SG, blister resistant ball sealers 2. MIRU transports and tanks. 3. Stimulated the entire perforated interval (10992' - 11173'MD) by pumping the following fluids down the tubing: a. 71 bbl b. 100 bbl c. 60 bbl d. 130 bbl e. 24 bbl f. 150 bbl g. 24 bbl h. 25 bbl i. 60 bbl j. 130 bbl k. 24 bbl I. 150 bbl m. 24 bbl n. 25 bbl o. 60 bbl p. 130 bbl q. 24 bbl r. 400 bbl gelled 2% NH4CI water with ball sealers at 4 balls/bbl (300 balls total). Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2% NH4CI water gelled 2% NH4CI water with ball sealers at 4 balls/bbl (100 balls total) Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2% NH4CI water gelled 2% NH4CI water with ball sealers at 4 balls/bbl (100 balls total) Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2% NH4CI water 4. Rigged down and moved out. 5. Resumed SWl. Reference Log: BHCS 1/26/84 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 9, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-25 Permit No.83-166 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-25)W1-3 RECEIVED JUN ! 2 989 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC ,/IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Vadance Perforate Other 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 850' FSL, 138' FWL, Sec. 17, T10N, R15E, UM . At top of productive interval 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At effective depth 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At total depth 102' FNL, 261' FWL, Sec. 21, T10N, R15E, UM 12. Present well condition summary Total depth: 5. Type of Well Development Exploratory Stratigraphic Service measured true vertical Effective depth: measured true vertical 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit feet Casing Length Conductor 80' Su dace 2518' Production 10710' Liner 896' 11390 feet Plugs(measured) 9209 feet 11339 feet 9171 feet Junk(measured) R 8. Well number 12-25 9. Permit number 83-166 10. APl number 50 - 029-21042 11. Field/Pool Prudhoe Bay Oil Pool ECEIVED JUN ! 21.989 Alaska 0il & Gas Cons. C0mmlss~0ri True vertical depth 80' 2591' 8745' 92O5' . Anchoraoe _ Size Cemented Measured'depth 20" 1980# Poleset 80' 13-3/8" 2400 sx Fondu & 400 sx F 'C' 2591' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 10783' 7" 300 sx CI 'G' 11385' Perforation depth: measured 10922-10960'; 10970-10998'; 11012-11028'; 11031-11086'; 11100-11142'; 11152-11173' true vertical 8854-8883'; 8891-8913'; 8923-8936'; 8938-8981 '; 8991-9007'; 9031-9047' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10508' MD; 4-1/2", 12.6g, L-80, PCT tail @ 10508' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 10428' MD, Camco Bal-0 SSSV @ 2189' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signed .~/c//~y,f ~~~/_~.4.,~.~-.- Title Operations Engineering Manager FOR COMMI~;ION U.~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil x Gas Suspended Date ORIGINAL SIGNED BY LO_NU!E C_ SMITH J Approval No. 9 --~' ''~ ~,pproved Copy Returne~ Commissioner Date SUBMIT IN TRIPLICATE F'iq/') IQ A, r~_lo, moon Drill Site 12-25 Proposed Hydraulic Fracture Treatment ARCO Alaska Inc. proposes the following 1. . . . . . . . . hydraulic fracture procedure. 10790'-10820' MD referenced to Perforate Sag River interval 1/26/84. Isolate Ivishak perfs 10922'-10960' 10970'-10998', 11086', 11100'-11142', 11152'-11173 'MD with a sand Tag fill with wireline to insure top of sand depth. MIRU fracturing service company Pressure annulus to 2500 psig. Pump propped fracture treatment for Sag River zone 10790' - 10820' using gelled water and 16/20 mesh Carbolite proppant. a. 100 bbl formation breakdown b. 40 bbl pump-in/ shut-in c. 250 bbl Pad d. 180 bbl Slurry at 2-14 PPG e. 250 bbl Flush RDMO fracturing service company. MIRU slickline unit and tag fill. Cleanout proppant and sand with CTU to 11330' MD. Return well to injection and run spinner log to determine Sag River injection. BHCS log dated 11012'-11028', 11031'- slurry pumped fullbore. ,5 4 2 COILED IUBINg UNIT~ BOP EDU I PI, lENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYD~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX iI i IdIRELINE BOP EOUIPHENT _ _ i 1. 5000 PSI 7" W£LLHEAI) CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .3.5000 PSI 4 1/6" LUBIRIOATOR 4. 5000 PSI 4 1/~" FLOW TUBE PAOK-OIrF ARCO ALASKA, INC, F'.,O, BOX 4eo56e ANCHORAGE, ALASKA 99540 DATE: 4-26-88 REFERENCE: ARCO I]',A.~'EI) HOLE FINAl.. 6---~ 4-t ?-88 NOI,.~E LOG 2-t ~ 4-i ,,4,. -88 F'T T,~ ~ 4- t 5-8.8 ,?F' :1: NN F..".[;' $.,,.-.,...8 4 SR 88 ~:3.-4 7 4--t t.--88 IN...IEF.:'T'll[)N F'[~'OFII...E 12- 21 4-17- 88 I:~'I.INt : .~' P ITS ~ RUN 1 , 5" PI..[.r.A,~'E ,~I~N ANO RETI. JRN '~E AT'~~-.' REt:FI. PI' OF.' .~.¢,'i'~., . ~, ~. ~, ~ ~.,o.-~,,0r?~n AF:'F:'ROVF!') .......................................... D T ,~ T [~' I .Itl. IT ,.~'CH .~F:H . I] T '[ ,~ SCH P~[:.NI- 'RAI.." FIt._E$ CHEVRON ........ FXTEN$ION FYF'LORA'F!ON EXXON MARATHON MOBIl... F'H I !...I... I F',.~' F'B WEt I. I:' T I... F',~ ,.~TATE f..)F AI_A,~KA TEXACO STATE OF ALASKA AI~'~.KA OIL AND GAS CONSERVATION COMI~ APPLI(.;ATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program __Pull tubing Re-enter suspended well __ Time extension Stimulate '7' Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 . Type of Well: Development x Exploratory Stratigraphic Service ., Location of well at surface 850' FSL, 138' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 56' FSL, 5280' FWL, Sec. 17, T10N, R15E, UM At effective depth 56' FSL, 5280' FWL, Sec. 17, T10, R15E, UM At total depth 102' FNL, 261' FWL, Sec. 21, T10N, R15E, UM 6. Datum elevation (DF or KB) 73' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-25 9. Permit number 83-166 10. APl number O29-21O42 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Intermediate 2518' Production 1 071 0' Liner 896' 11390 feet Plugs (measured) 9209 feet 11339 feet Junk (measured) 91 71 feet Size Cemented 20' 1980# Poleset 1 3- 3/8" 2400 sx Fondu & 400 sx PF 'C' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 7" 300 sx CI 'G' REC,.EIVED APR 2 .0il & Gas Cons, Cc,~rdssior; Mea~sure~lipll~g~ True vertical depth 80' 80' 2591' 2591 ' 10783' 8745' 11385' 9205' Perforation depth: measured 11100-11142'; 11152-11173' true vertical 8991-9007'; 9031-9047' Tubing (size, grade, and measured depth): 10922-10960'; 10970-10998'; 11012-11028'; 11031-11086'; 8854-8883'; 8891-8913'; 8923-8936'; 8938-8981'; 5-1/2", 17#, L-80, PCT @ 10422' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10508' Baker FHL packer @ 10428' MD; Camco Bal-0 SSSV ~ 2189' MD Packers and SSSV (type and measured depth): 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch x 14. 16. Estimated date for commencing operation May 1989 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 ~/.~~~~ Title Operations Encjr. Mcjr. Date FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subse0RiGl~/~l_qStGl~EOl~r~¥e required 10- Approved by order of the Commissioner 0NNIE C. SMITH Co . ~ 0o9~ Form 10-403 Rev 06/15/88 001 J. C.Braden, 263-4536 IApproval No. SUBMIT IN TRIPLICATE Drill Site 12-25i Full Strength Mud Acid Matrix Stimulation ARCO Alaska, Inc., proposes to perform the following stimulation treatment: 1. Make a slickline tag with a bailer to ensure there are no obstructions and tag bottom. If the PBTD is above 11275'MD, then perform a nitrified fill cleanout and bring the fill to surface. The last PBTD was 11285'MD on 4/15/88. 2. Load the following fluids: a. 10000 gal of 12% HCI with additives b. 16500 gal of 12% HCL/3% HF with additives c. 5000 gal of 2°/, NH4Cl water with 40 Ibs/Mgal HEC polymer and abiocide. d. 700 bbl of 2% NH4Cl water with a biocide. e. 150 bbl of methanol. f. 500 - 7/8" dia, 1.1SG, blister resistant ball sealers , MIRU transports and tanks. Stimulate the entire perforated interval (10992' - 11173'MD) by pumping the following fluids down the tubing: a. 71 bbl b. 100 bbl c. 60 bbl d. 130 bbl e. 24 bbl f. 150 bbl g. 24 bbl h. 25 bbl i. 60 bbl j. 130 bbl k. 24 bbl I. 150 bbl m. 24 bbl n. 25 bbl o. 60 bbl p. 130 bbl q. 24 bbl r. 400 bbl gelled 2% NH4CI water with ball sealers at 4 balls/bbl (300 balls total). Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2% NH4CI water gelled 2% NH4CI water with ball sealers at 4 balls/bbl (100 bails total) Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2% NH4Cl water gelled 2% NH4CI water with ball sealers at 4 balls/bbl (100 balls total) Methanol 12% HCI with additives 12% HCI/3% HF with additives 12% HCI with additives 2°/, NH4Cl water 9. Rig down and move out. 1 0. Resume SWI. RE('E,[VED ,',~aska.OJJ& Gas Cons, '" ~ ' ' , Anchorage Reference Log: BHCS 1/26/84 H2S Concentration - Minimum ID is Camco DB-5 Nipple @ 10496' MD not available 3.813 in 5 4 3 2 COILED TUBI~ IJHIT BOP EOU I PME N~ 1. E~000 PSI '7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSi 4 1/§" SH£AR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 HIREL]NE BOP EOU]PMENT _ 1. 5000 PSI ?" W£ LLHEAD CONNECIOR FL~_~AN~E 2. 5000 PS1 WIRELINE RAMS (VARIABLI~i SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA: INC. P.,O., BOX ~¢83&.¢ ANCHORAGE~ ALA,.~KA 99.5~(3 -DATE' REFERENCE ARCO .CASED HOlE FINAl.. 'i - ~,:..9 ~,;_- f O-R..9 FI...OWHETER / FI..I.I .T. D- .'[. D/HP F'M. R'llN. t -52 2-t ~-R8 PR'I)., PR'FL.E./,.~F'.T. N/WHI.IT/.D .F.N.~ RI. IN t -~4 2-t 0-88 PR'l) , F'RFLE/HF'FM/WHI.IT RI.IN TEHF'ER'ATI.IR'E / ~F' T NNE R' R'IIN F'I...EA,~E SI6N AND RETURNT~~_ .~~.i~., ~~, ~f4'ECET. F,T ~,ATA,.~ HAVE A NICE DAY PEGGY BENNETT AT0-t529 Nssk[~ Oil & G~s Cons. commbsbf~ /,.acbora[P TRAN.~ ~88 APPROVED DI~TP~BI.ITTRN CENTRAl._. FILE.? CHEVRON EXTEN%ION ... EXF'I...DRAT T ON EXXON MARATHON MOBIl... "" PHT! I... T F' '"' PR WFI...!. FTI F'.r.,' R t,, D ~~ .~AF'C ~ ,~TATE OF AI..A,~KA STATE OF ALASKA ALASK/, OIL AND GAS CONSERVATION L, OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~] Water/Gas Injector 2. Name of Operator ' 7. Permit Number ARCO Alaska, Inc. 83-166 , 3. Address 8. APl Number ?.0. :Box 100360, Anchorage, Alaska 99510 50- 029-2104`2 4. Location of well at surface 9. Unit or Lease Name 850'FSL, 138'~WL, Sec. 17, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 56'FSL, 5280'FWL, Sec. 17, T10N, R15E, UM 12-25 At Total Depth 11. Field and Pool 102'FNL, 261'FWL, Sec. 21, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 73' RKB ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/12/84 01/26/84` 02/08/84` 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 l1390'MD, 9209'TVD 11339'MD, 9171'TVD YES~ NO [] 2199 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, LDT/CNL/GR/Cal, CBL/CET~ G~ro 23. CASING, LINER AND CEMENTING RECORD sETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-4`0 Surf. 180' ' ~0" Ins~l d w/] 980~ Pn] 13-3/8" 72.0# L-80 Surf. 2591' 17%" Cmtd w/24`00 sx Fond~z & ZOO mx ~¥ "C" 9-5/8" 4`7.0# L-80 Surf. 10783' 12~" Cmtd w/500 gxa "G" eme ~ ~OO .~w.~ PF "C" 7" 29.04A L-80 104`89' 11385' 8~" Cmtd w/300 sxs "G" cmt 24. Perforati'°ns' open to'Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10922-10960', 10970-10998', 11012-11028 ', 5½ q 0508 1 11031-11086'~ 11100-1114`2' ~ 11152-11173'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8854-8883', 8891-8913', 8923-8936', 8938-8981', 8991-9007', 9031-904`7'TVD N/A Ref: BHCS 1/26/84` 27. PRODUCTION TEST Date First Production I Method of OperatiOn (Flowing, gas lift, etc.) 12/16/84`I Water/Gas In~ ection Date of Test' Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 8/16/87 24, TEST PERIOD I~ .... 97'~7 ~1~I -- Flow Tubing casing pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1297 -- 24_HOUR RATE ~ .... 9737 -- 28. CORE DATA ~, %~ ~/~lrl Brief descripti°n of li'hology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,f/~ t~r~li~ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE "~ - - ' - NAM ' _ ' - ........... ~ ............ ~ ............. i~l~-de~nte~l t~sted, pressure d~a, all fluids r~ove~ and'graviW; ' ,-~.~ ~ , ~:"" ~ ~ ~:' MEAs. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. '" . ..;..: , .................. -. ..- .. , Top Sadler~htt ~-' 10920' - --8851' N~E - ~ ~ '.O C-~.'3;O 0J-~f;'; · ;:.:' ~ ~ ' '-'~'-¥:~[~.". . ": :'~ ::;'~: · O/W Contact - . ~228, 9~9,-- . . . : ,~ r. , '~. ' · , ;2 .... '. . _ ,~ . ~ .:;, -.~:~/_'- : .m'i .~_~': . ;~;'.; '~" ,-: .:F :' ', , " ."', ,' : ' ~/~ .~.;-, ,. ;. . ~,. · ~, ~; '~', ... ,. - , . ~ . ~ - .. . . _ 31. LIST OF A~ACHMENTS . . . 32. I hereby certify tha~' t~e f°~ing'is'-tru~ ahd ~orr~t t~"~e ~st of m~ '~wledge- ~- '~" .... -' Signed "-~ Title7.::{ :~er: ~d~. Ng~. '-Date · INSTRUCTIONS . ~ .~-,:, ~. ~ · · ,. General: This form is designed for submitting a complete and c~rr'eCt'~,ell completion report and I°g on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: G'a'{' injection, water injection, steam inject, !on, air injecti~3n, 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 eadh addition~] interval to be separately produced, showin~j:'the data pertinent..to such interval. _. .. -. I'terfl 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 STATE OF ALASKA ~- ALA,....A OIL AND GAS CONSERVATION COk ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ,~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 850'FSL, 138'FWL, Sec. 17, T10N, R15E, UN At top of productive interval 56'FSL, 5280'FWL, Sec. 17, T10N, R15E, UN At effective depth 56'FSL, 5280'FWL, Sec. 17, TION, R15E, UN At total depth 102'FNL, 261'FWL, Sec. 21, TiON, R15E, UM 5. Datum elevation (DF or KB) 73' RKB Feet 6. Unit or Property name Prudh0e Bay Unit 7. Well number DS 12-25 8. Approval number 7-412 9. APl number 50-- 0?_q-21042 10. Pool Pr ldhoe Bay 0il Pool' 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length feet 11390 feet 9209 11339 feet 9171 feet Size Plugs (measured) Junk(measured) None Fill - 11304' Cemented Measured depth True Vertical depth Conductor Intermediate Production Liner Perforation depth: 80' 20" 91 5# 2591' 13-3/8" ,72# 10783' 9-5/8" ,47# 896' 7" 29# measured 10922-10960', 11100-11142', true vertical 1980# Poleset 2400 sx Fondu, 400 sx PF "C" 500 sx "G" & 300 sx PF"C" 300 sx Class "G" 10489'-11385' 8513'-9205' 10970-10998', 11012-11028', 11031-11086', 11152-11173' Surf - 80' Surf - 80' Surf - 2591' Surf - 2591' Surf - 10783' Surf - 8745' 8854-8883' 8891-8913' 8923-8936' 8938-8981' 8991-9007' 9031-9047' Tubing (size, grade and measured depth) 5½", 17#, L-80, Surface to 10508 'MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10428'MD, Camco Bal-O SSSV fa 2189'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED SEP o 9 Naska 0ii & Gas Cons. Commission Anchorage 12. Prior to well operation Representative Daily Average Production or Injection Data 8/4/87 OiI-Bbl Gas-Mcf Water-Bbl .... 9333 Casing Pressure .-- Subsequent to operation 8/16/87 -- 9797 Tubing Pressure 1241 1297 14. Attachments 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 :¢WY~ j~~__~'~ Title Operations Engineering Mana§er Form 10-404 Rev. 12-1-85 (;T&TIR/C,N 19_9r-, M I~ (11~nn (?RR-RRII'I~ Date ~/,~/~,~ Submit in Duplicate DS 12-25 Daily Report of Well Operations Add ?erfs 8/8/87 SI well. Pump in A/L gas down well. PT equip, to 3000 psig. OK. RIH w/select fire, 3-3/8" Hyper Jet I perf gun (1', 2', 7'), 4 SPF, 60°/120° phasing. Tag PBTD @ 11304' Shoot 11152' to 1~153' (1'), 11118' to 11120' (2'). Pressure up well to 500 psig, then bleed to atmospheric pressure. Shoot 11029' to 11036' (7'). SI well. POH - all shots fired. Pump in A/L gas down well. PT equip, to 3000 psig. OK. RIH w/20', 3-3/8" Hyper Jet II perf gun, 4 SPF, 60°/120° phasing. Bleed wellhead pressure to test separator. Shoot 11120' to 11140' (20'). SI well. POH - all shots fired. Pump in A/L gas down well. PT equip, to 3500 psig. OK. RIH w/20', 3-3/8" Hyper Jet II perf gun, 4 SPF, 60°/120° phasing. SI A/L gas to well. Shoot 11153' to 11173' (20'). POH - all shots fired. ARCO ALmska, Inc I', O, Box Anchormge, A L m.s'km 995 DAI'E' August ~8, ~987 REFERENCE: ARCO Cased Hole Final 12-25 8-7-87 CCL/F'erf. Record Run t, 5' t2--25 8-8-8'? CCl./Perf· Record Run 2, 5 t2.--27 8-'?-87 CCL/Perf, Record Run ~3-~0 8-t0-87 CCL/Perf· Record Run 2, ~3-22 8-t 2-87 Spinner Profi[e Run t, 5' $c h $c h ~'ch F'[emse .sign and ret'urn the attached copy a~ receip'~ of data, Re. cei ved By HAVE A NICE DAY'! Ro.~m nne Peek TI:~AN3~ ~:87426 Ap p roved DISTRIBUTION ~" Cen+raL Fi Les ~ Phi lLips T - ~' '"~r Chevron F'B Well Fi l.e~; D & M R & P ~ ~oh i o ~ Extension Exp[ora$ion ~ ~ Exxon ~ ~$a~e of Alaska MaraShon ~ Texaco ~ Hob i [ ARCO Alaska, Inr~ Prudhoe B~,y Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 23, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: DS 12-23 Permit Number' 84-58 DS 12-25 Permit Number' 83-166 DS 12-27 Permit Number: 84-23 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEH:sd Enclosures CC' Standard Alaska Production Co. File P1(DS12-23)W1-3 Pl (DS12-25)W1-3 P1(DS12-27)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '-'" AL/- ,A OIL AND GAS CONSERVATION CO~ ~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension D Change approved Program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator . 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 73' RKB feet · 3, Address 6. Unit or Property name Post Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit ac 4. wle. 18qtFSW ec. '17, T10N, R15E, UM At top of productive interval 56'FSL, 5280'FWL, Sec. 17, T10N, R15E, UM At effective depth 56'FSL, 5280'FWL, Sec. 17, _TION, R15E, UM At total depth 102'FNL, 261'FWL, Sec. 21, TION, R15E, UM 7. Well number DS 12-25 8. Permit §~_m~; 9. APl number 50-- 029-21042 10. Pool Prudhoe Ba~v 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 113900 feet Plugs (measured) 9209 feet 11339 feet Junk (measured) 9171 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Intermediate Production Liner 896' Perforation depth: measured true vertical 80' 20", 91.5# 1980# Poleset 2591' 13-3/8",72# 2400 sx Fondu, 400 sx PF "C" 10783' 9-5/8",47# 500 sx "G" & 300 sx PF"C" 7" , 29# 300 sx Class "G" 10489'-11385' 8513'-9205' 10922-10960', 10970-10998', 11012-11028', 11038-11086', 11100-11120' Surf - 80' Surf - 80' Surf - 2591' Surf - 2591' Surf - 10783' Surf - 8745' 8854-8883', 8891-8913' , 8923-8936' , 8944-8981:'.,:~899!-~007' Tubing (size, grade and measured depth) 5½" 17# L-80 Surface to 10508'HD Packers and SSSV (type and measured depth) Rakmr FHI Par'l~,~r 0 10~_R'M~, _camco 12.Attachments Description summary of proposal ~--[~etail~'c~erations program ~ BOP;'~6t'C~' [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver July 20, 1987 Date approved Approved by 15. I hereby certify that the fo_regoing is true and correct to the best of my knowledge Signed 4~C,,,.y~d,~~--~_~ TitleOperations Engineering Manaeer Date Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No.~ ~ Plug integrity ~ BOP Test ~ Location clearance ~'~ l~ ~. ~{~ by order of - Commissioner Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. P·O· Box i00560 Anchorage, Alaska 995te DATE: June 23 ,1986 REFERENCE: ARCO Cased Hole Final 3-7 6-9-86 Injection Profile ~-~3~ ~ 5-28-86 Spinner In j, pr-ofi le 2-25 6-2-86 Spinner Inj. profi[e Run i 5 · Run i 5" Run i 5' Ca ;llC o Camco Ca plc o HAVE A NICE I)AY! Linda Hulce ATO-1 529 TRANS ~86375 ed copy a~ receipt of data. DISTRIBUTION Central Fi les Chevron Extension Exploration Exxon Marathon Mobil Phi llips F'B Well F'i Les R & D Sohio Slate of Alaska Texaco ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 21, 1985 ' : Reference- ARCO Pressure Data 6-7/Static Gradient 4-28-85 Camco 9-6 ~PBU 5-24?25-85 DA 12-25 ~PFO 5-22-85 Camco 14-35 q~BU 5-31-85 Camco 14-35~Flowin§ Gradient 5-30/31-85 Camco 15-~ PBU 9-11-84 SS 15-7/PBU .9-11-84 SS 15-8/PBU' 2-29-84 . SS 15-8/PBU 10-20-84 SS 15-8/PBU 10-20-84 SS 17-5 'PBU 5-29-85 Camco sign as ReCeived by Alaska 0il & Ga~ C0r~. [;emmission Anchormje pam Lambert ATO 1429C .Trans 176 . . .. : _ o .- . Chevron .. P & M Phillips Expl.. Services PB Well Files Ext.'Exploration R & D Exxon Sohio Marathon state-of Alaska Mobil Texaco ARCO Alaska, Inc. Post Office Box 100360 &ncnorage. Alaska 99510 Telephone 907 276 1215 Date: June 11, 1985 Reference: ARCO CH Finals' 1-18~. Collar Log ~'2-13/,. Neutron GR 5-12-85 ---3-9 /~ Neutron GR 5-15-85 ---_42_9__~___~/~ Gamma Ray~ 5-17-85 ..... 6-2/CET 3-7-85 ~-~--6--1'0 / Neutron GR 5-10-85 --- 6-24/. Neutron GR 5-18-85 ~. 7-26 //Neutron GR 5-16-85 ~--12-21/.Spinner 5-15/16-85 ~12-22/. Collar Log 5-20-85 ~12-22/ Spinner ' 5-21-85 ~12-25 /Temp. Log · 5-22-85 ~'-12-25 ~ Spinner ~' 5-18-85 ~12-28 /Spinner - 5-17/18-85 ~ 12-29 / Spinner 5-16/17-85 '~-14-15 / Neutron. GR ,': 5-11-85 ~14-35/~Neutron GR / 5-11-85 ~--15-9 / CBL 11-8-84 5-20-85 Run i 5" Camco 1 5" DA 2 5" DA 1 5" DA 1 5" Sch 1 5" DA 1 5" DA 1 5" DA I 5" Camco I 5" Camco 1 5" Camco 1 5" Camco I 5" Camco i 5" Camco I 5" Camco I 5" DA 1 5" DA i 5" Sch Please sign as reciept of data. Received by Pam Lambert ATO 1429C Trans 148 Chevron Expl.. Services PB Well Files . Ext. Exploration R & D Exxon- Sohio Marathon $=a~e' ~f Al. aska t~bil .T, exac o ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: April 23, 1985 Reference: ARCO CH Finals 3-8/ 1! 6-11~ Collar/Perf 12-25-84 5" ll-12~DT 3-20-85 5" 12-23b/Spinner/Temp 4-8-85 5" ~2~2~.~ Collar/Perf 12-7-84 5" 12-26/Collar/Perf 12-2-84 5" 12-29J Collar/Perf 12-10-84 5" 14-35~ Collar/Perf 3-33~85 1 5" 17-10~S/pinner 4-4-85 1 5" sign as receipt of d~'ta. Perf Log 1-9-85 Run 1 Sch 6-5 ~ Collar Log 1-12-85 1 Sch 1 Sch 1 Sch 1 Camco 1 Sch 1 Sch 1 Sch GO GO Received by Pam Lambert ATO 1429C Trans 081 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon ~a~e~6f Alaska Mobil Texaco ARCO Alaska. Inc. Post Office~...e~x 100360 Anchorage, ~ska 99510 Telephone 907 276 1215 Date~: February 4, 1985 Reference: ARCO Pressure Reports 16-11 Pressure Data 12-1-84 GO 15-2 Pressure Data 11-29-84 GO ~~S~Pressure 'Data 12-10-84 GO 16-4 Pressure Data 1-24-85 Camco' . 12-3 Pressure Data 1-19-85 Camco 15-7 Pressure Data 1-25-85 Camco 14-28 Pressure Data 1-23-85 Camco - _ 14-5 PreSsure Data 1-23-85 Camco _ ~ . sign and return the attached copy as receipt of data. ,;f Received by Pam Lambert ATO 1429C Trans 017 Chevron D & M Exploration~Services Extension Exploration Texaco · Mobil - Mobil- E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska .. ARCO Alaska, Inc. is a Subsidiary ol AtisntlcRichfieldCompany ARCO Alaska, ~ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907' 263 4248 Donald F. Scheve Regional Operations Engineer December 27, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-21 DS 12-22 DS 12-25 Permit No. 84-48 Permit No. 84-60 Permit No. 83-166 Dear Mr. Chatterton: · Attached are Well Completion reports for the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company · File Pi(DS 12-21)W4-3 File Pi(DS 12-22)W4-3 File Pi(DS 12-25)W4-3 ARCO All.ks, Inc. I. · Sublldlary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION O ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Water Injector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-166 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21042 4. Location of well at surface 9. Unit or Lease Name 850' FSL, 138' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Unit .,. At Top Producing Interval 10. Well Number 56' FSL, 5280' FWL, Sec.17, T10N, R15E, UM 12-25 At Total Depth 11. Field and Pool 102' FNL, 261' FWL, Sec.21, TiON, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 73' RKB 'I ~ ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1 15. Water Depth, if offshore 116. No. of Completions 01/12/84 01/26/84- 02/08/84I N/A feet MSLI 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 l1390'MD,9209'TVD 11339'MD, 9171'TVD YES ~] NO []I 2199 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, LDT/CNL/GR/Cal, CBL/CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf 80' 30" Instld w/1980# Poleset 13-3/8" 72.0# L-80 Surf 2591' 17-1/2" Cmtd w/2400 sx Fopdu & %00 sx PF "C" 9-5/8" 47.0# L-80 Surf 10~783' 12-1/4" Cmtd w/500 sxs "G" cmt + 300 sx.~ PF "C" 7" 29.0~ L-80 10,489' 11,385' 8-1/2" Cmtd w/300 sxs "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) 5-1/2" 10; 508 ' 1 O; ~, ?R ' 10922 - 10960' MD Perfed on 12-7-84 w/4 SPF 10970 - 10998' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11012 - 11028' MD TV]) of ?errs: 8854 - 9006' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11038- 11086' MD N/A 11100 - 11120' MD 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R£CEIVED Alask~ Oil & Gas Cons. ~' J i~'OIIIITI'SS-oi? Anchorage Form 10~,07 Submit in duplicate Rev. 7-1-80 DP~/WCZ0 CONTINUED ON REVERSE SIDE 29. ,. ~.~ ': --~ :'~_~",l - ' ......... ~" '~ '3 ' . .... - · .~"'c' .... . ' . ,. .:.~ .._; ~:._: ~. ,:,,,,, NAME Include inte~al tested, prossuro data, all fluids rocovered and g~avity,' . 'MEAS; DEPTH TRUE VERT. DEPTH GOR, an¢ time of each phase. . , - - . : . ._ ,. . . Top' 8adlerochft 10~ 920 ~ 8851~ ~0~ O[~ Contact .11~-~28~ 9089~ Base 8adleroch~t. ~0~' ~ ~ ....... - ....... . . ..... .. . , . ~ . . . . : ;. .. . . . . . ._ . . . .. . . . . 31. lIST OF A~ACHM~TS - . 32. ~ hereb~ cer~ifg that the forefloinfl is tree and correc~ to the best of m~ kno~led~o Signed -- - - - , Title RegiOnal ~er. ~g. 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,r Prudhoe ,=ay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 27, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-4 Permit No. 76~51 DS 3-11 Permit No. 79-47 DS 3-12 Permit No. 79-58 DS 3-13 Permit No. 79-71 DS 3-17 Permit No. 79-102 DS 12-21 Permit No. 84-48 DS 12-22 Permit No, 84-60 DS 12-25 Permit No. 83-166 Dear Mr. Chatterton: Attached are Sundry Notices for above-mentioned wells. DV.~~.~truly yours DFS/JEB/mjb Attachments CC: Sohio Alaska Petroleum Company File Pi(DS 3-4)W1-3 File File File File File File File P1 (DS 3-11)W1-3 PI(DS 3-12)W1-3 PI(DS 3-13)W1-3 Pi(DS 3-17)Wl-3 Pi(DS 12-21)W1-3 Pi(DS 12-22)W1-3 Pi(DS 12-25)W1-3 work completed on the RECEIVED DEC 2 81984 Alaska Oil & (]as Cons. Commission Anchorage ARCO Alagka, Inc. Ig · Subaldlary of AllanllcRIchfleldComp·ny STATE OF ALASKA ' '"'~ ALASKA tJIL AND GAS CONSERVATION Cb,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. COMPLETED WE L L :::~3X Water Injector 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well (Surface) 850' FSL & 138' FWL, Sec 17, T10N, (Producing Interval) 56' FSL & 5280' FWL, Sec 17, T10N, (Total Depth) 102' FNL & 261' FWL, Sec 21, T10N, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease 73 ' RKB I ADT. Check Appropriate Box To 12. 99510 R15E, UM R15E, UM R15E: UM Designation and Serial No. 2R'~R1 7. Permit No. 83-166 8. APl Number 50-- 029-21042 9. Unit or Lease Name Prudhoo~ 10. Well Number DR 1 2-25 11. Field and Pool OTHER [] Prudhoe Bay Field Prudhoe Bay Oil Pool Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 12/5/84. RU perforating unit and pressure tested equipment. RIH w/gun ~1, shot interval 11100-11120' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 10940-10960' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 10922-10940' MD (4 SPF). Shut-in well, POOH, all shots fired. Shut-in the well for the night 12-7-84 Resumed perforating operationjRIH w/gun #4, attempted to shoot interval 11070-11086' MD (4 SPF).~.Shut-in well, POOH. Top 2' of charges didn't fire. [11072-11086' MD (4 SPF) was shot.] RIH w/gun #5, shot interval 11048-11072' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #6, shot interval 11012-11028' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #7, shot select fire interval 11038-11048' MD (4 SPF), pulled up and shot select fire interval 10990-10998' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #8, shot interval 10970-10990' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS: 1-26-84 RECEIVED 14, I her tify tha ego_lng is_t, rue and correct to the Signed . , Title Regional Operations The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, ,. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 28, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 12-21 DS 12-22 DS 12-23 DS 12-25 DS 12-26 DS 12-27 DS 12-28 DS 12-29 Permit No. 84-48 Permit No. 84-60 Permit No. 84-58 Permit No. 83-166 Permit No. 84-14 Permit No. 84-23 Permit No. 84-31 Permit No. 84-32 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. .. Very truly yours, D. F. S cheve DFS/WT / imh At tachments cc: Sohio Petroleum File PI(DS 12-21)W1-3 File Pi(DS 12-22)W1-3 File Pi(DS 12-23)W1-3 File PI(DS 12-25)W1-3 File PI(DS 12-26)W1-3 File Pi(DS 12-27)W1-3 File PI(DS 12-28)W1-3 File PI(DS 12-29)W1-3 RECEIVED AI~ ~;~ ~, ~s Cons. Co~Isslo~ Anchorage ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichfieldCompany STATE OF ALASKA -' ALASKA OIL AND GAS CONSERVATION L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLi~ OTHER [] Wa~_er Injector 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 850' FSL, 138' FWL, Sec 17, T10N, R15E, UM (Producing Interval) 56' FSL, 5280' ~L, Sec 17, T10N, R15E, UM (Total Depth) 102' Fk~, 261' FWL, Sec 21, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28331 7. Permit No. 83-166 8. APl Number 50- 029-21042 9. Unit or Lease Name Prudhoe Ba.¥ Unit 10. Well Number DS 12-25 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. 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 (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. proposes to perforate well 12-25 at selected intervals within, the Sadlerochit Sand of the Prudhoe Ba_v Unit. All wireline work will be done through a 5000 psi WP BOP/Lubrica. tor, tested, to 1.2 times ~e maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals 10922 - 10960' MD (38') 10970 - 10998' MD (28') 11012 - 11028' MD (16') · 11038 - 11086' MD (48') 11100 - 11120' MD (20') Ref: BHCS 1-26-84 Subseq~ent Work Reported Alaska Oit & G~.s Cuns. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~/_ ~'~-~-//"~ ~e-_-_~¢..... Title Regional Engineer Signed The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER ^pproved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALaska, Inc, P.O. Box i00360 Anchorage, Alaska DATE' September REFER[:NCE' -ARCO 8-24-84 OH -$2040 DA 8--9-84 OFI ~20S5 I)A 7-24-84 OH tape :::2025 DA 8-t 6-84 CH/CN$~°°i870 GO t-~z--84 OH ~6947~ Run t Sch 8--22-84 CH CNL. ~69494 . . Run 8 Sch '?'--8--84 CH DIi_ ~6942S Run tS Sch 9-'5-84- CH L. IS -.-~'~z°~'n~, ~..-, Run 7 Sch 7-t5-84 OH rape ~69370 Run i Sch 8--i2-.84 OH ~69448 Run 1 Sch .E~..p~q"7~SOHiO - .eo:e ..S' ! 81'id gn copy prey i ou.s' Ly sen't by Sch [un'~l)erger, ret.'urn t'he at:t'ached copy as' receipt; of Received By ............... ' ", ~ ' ~ ',,' ~-'. ........ .~.. _~.S_ ,. , Ke L Ly McFar Land Ataska O~t & Gas Cons. Commission ATO-~ 429F ~ , TRANS. ~S2S DISTRIBUI'ION d a t a, (onLy OH) Ch e¥~- Ol~ ExpLoration Services, Extension ExpLoration i:E x x o n Getty Mara fhon Mob i L Mobil E & F' F'hi L L ip.s F'rudhoe Bay Wet L R &D Soh i o State of Alaska I::il. es (NC) Answer) ALASKA OIL AND GAS CONSERVATION COMMISSION Bill Sheffield ' Goveruor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TEL EPHONE (907) 279.'-t433 We wish to bring to yOur attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed /~_~-~c~ . : Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman ~IL~tS~(~I OIL ~I#D G~$ CO#S£RV~ITIOfl O,O~MI$$10~ RE: Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501';-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention yet received the following required items on the which our records indicated was completed gT~- 7 that the Commission has not subject well Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please-submit the above missing material. Sincerely, Chairman STATE OF ALASKA ~-..-~ 0 R 16 I N A ? .... ALASKL_ ...:~L AND GAS CONSERVATION C /1MISSION -- WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I--IXX Water Injector . _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-166 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21042 4. Location of well at surface 9. Unit or Lease Name 850' FSL, 138' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 56' FSL, 5280' FWL, Sec.17, T10N, R15E, UM 12-25 At Total Depth 11. Field and Pool 102' FNL, 261' FWL, Sec.21, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 73' RKBI ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/1 2/84 01/26/84 02/08/84I . N/A feet MSLI 1 1'~. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11390'MD,9209'TVD 11339'MD, 9171 'TVD YES i--IX NO [] 2199 feet MDI 1900' (Approx) ., 22. Type Electric or Other Logs Run D IL/BHCS/SP/GR, LDT/CNL/GR/Cal, CBL/CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Instld w/1980# Poleset 13-3/8" 72.0# L-80 Surf 2591' 17-1/2" Cmtd w/2400 sx Fondu & 00 sx PF "C" 9-5/8" 47.0# L-80 Surf 10,783' 12-1/4" Cmtd w/500 sxs "G" cmt 300 sxs PF "C" 7" 29.0# L-80 10,489' 11,385' 8-1/2" Cmtd w/300 sxs "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) NONE 5-1/2" 10 ~508' 10~428' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press, '24-HOUR RATE ~ :~. CORE DATA Brief description of lithol°gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10407 Rev. 7-1-80 ?~2h0 ~ge ~'O/T/~in duplicate DRN/WC10 CONTINUED ON REVERSE SIDE 29. -'- .. .... _ , NAME Include interval tested, pressure data, all fluids recovered and gravity, : , m MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Sadlerochit 10~920~ 8851' NONE :':': ' 0/W Contact 11 ~228~ 9089~ Base Sadlerochit ".-: NOT REliED ' , " - , . . . . (... . : . . 31. LIST OF ATTACHMENTS ::. .- .. ' Drilling 'History~ Gvro~nnnie-Survev" f2 conies) -~ · "~ 32. I hereby c~rtifv that the foregoing is ~fue and.correct to the ~st of my knowledge - - Area Drilling Engr. Signed 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::-M~tl~od of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I qie.ctiOn, Shut-in, Other-explain. .. .. Item 28: If no cores'taken, indicate "none". DS 12-25 DRILLING HISTORY NU 20" hydril & diverter. Spudded well @ 0600 hrs, 01/12/84. Drld 17-1/2" hole to to 2615' Ran 65 jts 13-3/8" 72#/ft ,w,/FS @ 2591' Cmtd 13-3/8" csg w/2400 sxs F~ndu + 400 sxs PF "C". ND ~0 hydril & d~verter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd cs.q to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok - held to 11.0 EMW. Drld 12-1/4" hole to 10,811'. Ran 265 jts 9-5/8" 47#, w/FS @ 10,783'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11,390' (01/26/84). Ran DIL/BHCS/SP/GR f/11,370' - 10,780'. LDT/CNL/GR/Cal f/11,370' - 10,780', GR to 2550'. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs PF "C" + 131 BB A.P. Ran 22 jts 7" 19#/ft, f/10,489' - 11,385'. Cmtd 7" lnr w/300 sxs "G" cmt. Drld cmt to 11,339' (PBTD). Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Run CBL/CET f/11,330' - 10,375'. Ran 5-1/2" completion assy w/tail @ 10,508' & pkr @ 10,428' & SSSV @ 2189' Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 0900 hrs, 01/31/84. DRN/DH57'tw RECEIVED APR 2 7 19B4 Alaska Oil & Gas Cons. Commission Anchorage · - ~ :~ :: :: l~:::: :,~:: ! ~:?. :h ~, .~ %::.~:..- :~ ~ h.-.-: ~: · ~..,- :: ~ :. :~ ~:': ~:~ ~ 'i~:.~i~:: L: ::~:::~ :::~:~:~:::?::~:~.~:::~::~::~:~ :.:~i:5.<' :.' ~ .": : ,:'..z ~:~:z. :d:si:;~::~ ~:: !?~:?~;~:~::n~u. . x ?::~.'."-:?::-'. ......... 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()0 :5::200 .00. 61 ...,':'. ~& S: 47.,: y. o~ ~ 191:3.27 .'2/-,. _ . :23 ,:,.:, 7.:, (') 0 ::~ :'a (") (-). 00 G.: .... 4 ::: (') 2.2'~ E 1 '~ '"" ~ ::: . 1 ():312 '-' '"'' .... ' .. '"'R '2~F? '~ . .... ........ ~ _. ?._~ ~. :26 26 '"" ' '-' '-' ' "l ':'~ ::: 1 () 4-:3 :~: ,::, 4- 7 c:,. ()0 ,:, 4. (..~ ~... 00, 664. ~ c, S 4 ,_,':' 74 . 11 E 1965 .. '42 .~ ... :..:; . ~ .~,.: ~:'. ::~...~&~::.~:::~....~:~::~:~:..~:~..~::.::~:~:`::~..~:~.`:~.~..~:~:~:~:~:~:~.:.~.::~:::.:.::~.~:`::~::.:~::::.:.::::::...~:~:~:~:~.~:~:~:~::~:~:~:::~:.~:`~`.~:~:::~.:.:~::..:.::~`::..:~:::~.~.:.:.::~:~~:..:::~::~:::::~:::::~::::: ........................... ::::: ................. ::::::::~ ........................... ~,:.:.:.:~:.~ ................................................. :.: ............. ( ....... I ( ~ ~. 4. ~ ,.:,,-, 7.:,, (.~.~ ,::, ,:, L} L} . <..)(.~ ,:,{~. 76 o .... , ~ ._,6. 7 ~ E ~()74. ~,~ .~. 7 ..... 1107~, ""',:,~':~'7.:,.00'-'::: '~ () (} . OC) 84:3. lA ~: ~5:226. '77 ~ :2~ O.~h 2~ "" ''"' 5'7 11 'F'~"~ 7 'F~ () 7:3 00 '~ r~ ("~ ("~ 00 ,:, o 6 '~ ~;S ?~ :~-~'~"~. ,:~.~ ''"' ' E 2 ~ :34, .~4'-' ....":' ~ 02 ...... . ..... ~ . ~ .... ~, · ~. _, :~ -~ ~ . , . ....... ,, ..,.~. ~., ....~.~.~.~ ~ *~"'"~' '~"-~" ~ ' " ~' ~'~' "~'~'"¥'"~'"'~'~"~ .................... ~i'" ...... ·: :..:. x:::: : ,. :.:::....:~ ............... . :::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::, ::' "I"I.-IIE C:f~L.C:LIL~T'ICIN F'RCiC:EDURES; L.I:5;E: ~ LINEAR INTERF'OI_f~TION BE"F~EEN 'THE IqE~REST :2(:~ FC~CIT I,'l[I (F:IRCII9 IR~BIUS OF C:URV~TI_IRE:) F'OZIqTS; ,, . DS #12-25 (:SEC: 17 TION R15E) CCIMF'LiTATION DATE I<LIF'ARLIK FEBRUARY 13, 1'~84 JOB NUMBER AL. ASK:A . ?<ELLY BLISHING ELEV. = 7:3.00 FT. TRUE SUB-'.:-;E~ TOTAL ,-IE'AL:;LIRED VERT I CAL VERT I CAL RECTANGLILP~R C:OF~RD I NATES ' · ::i,:i:.:: :~.T · ...... 'i: ~ : ::::::::::::::::::::::::::::::: ~Q~H,~,,~,?:,~,,?.~;,E:~S~E~ ~..':~l~:.-.':~;~!~~i i!~ ii !i ::~ ,, ::::i:i::::!i~!i~!:ii~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .'.i !: i : .::': ::i: .:: ~::;',:::: :::::::::::::::::::::::::::::::::::::::::::::::: .... "i::;!;:::;t,,~_".:" :i:!:~:!:!: ,.:!:!:!:!::!:i:::!::i:E::i::~:::M'~:!...... 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' -: :: ' STRAT I GRAF'H I C SLIMMARY DERIVED USING DIL DEPTHS AND SPERRY .:,LN L~URVE¥ DATA TOF' SAG RIVER ,10789 8749.12 TOF' '._:;A[~LEROCH I T 10920 8851..'_::4 'l'C~F' ZONE :3 11187 9(:)57.71 C~IL../WATER COI',ITACT 1122:-:-: ,,,~ ~.,-~-.wp,.l:I. _......~....~.., ........ , ........ ,_~._,... ,,.,, ......... ~._ ,,. ........ ,., .............. , ..... .' :::':.: ...'::': ...,,. · ~..': .~,:: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: ::~:~ :, ..::':: :::::::::::::::::::::::::::::::::::::::::::::: ~:,:i4!:.~?: :':~f: ¥ i;:::i:i:.~!~ .F::B:].. E. ? ??: ::~! i~i~:~i !:'.~:. i::. i~!~i ::~i i:::~tii~i~i:::::ii:;~iiii iii:. ::iiii~i!::~ ii :.'.'i~i ii i~i~i !~ili::~i~i~i ~ ~! ~::ii:::::~4i::i i~:: '?::.!i iii ~: ::.::,::.,:::: ...... : .... : '? :.::..' 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':',,..: :,'.::,,2: S::,t.:::I:,.:: ',',' :1: ::: .::, !~'~'t',~i;~i~(.~ ~:: ."..:~'..~.~ :~ 11:'.!;~iFi.<.~E~ i F ::::~iiF~iiiiiii~;F ::.>.::.,%':~:!i?:::~.i::::!.''.:iFF :ii:~'i~:ii:::::,.'.::::iliiiiii!i!i:i:i~iiii:ifii:: <:;:2.F~,, ,! !::: .3Z! :::,: i !: : ::: ~~K",::!~ !: :~.:: ::i::::z :::! !!::::; h: ::::::::::::::::::::: ::::;:!:ii:iT !:!: !:::!!: x:n. i:i:',x :i:! !:!:::::! :!:!:! ! i:::i:i:i: :!,:~ ,i:i !:::::::::!:::!:::i:! ?~:!:!:i:!',!:i:!:Z:::::~:i~i::::: ~ :i:i::!: :i: ,i:i~:::,: ]:i~: '!. :'~'~ ," .' Suggested form to be inserted in each "Active" well folder to dleck for tirr~ly ccrt~liance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: ~ --~ Date Required Date Received Remarks -- Ccmpletion Report Yes · _Well_ History. . , Yes -.. Samples Core Chips -' Core l~scr±ption ..Registered. Survey Plat _/Ye5 /-o~ ~_-q- gz/ O/~ _ ional Drill St~ Test Re~s .. .~d ~ O~ _ ~d~dn T~t Re. rte .. ~s R~. Yes ARCO Alaska, Inc. Post Office-'~'ox 360 Anchorage. ,aska 99510 Telephone 907 277 5637 April 13, 1984 Reference' ARCO Cased Hole Finals D.S. i-iA 2-3-84 D.S. 9-21 2-6-84 D.S. 9-22 J'' 2-1-84 D.S. 12-25/ 1-29-84 D.S. 12-25~ 1-29-84 D.S. 14-14~ 1-12-84 D.S. 17-6/. 3-24-84 CBL/VD Gyro Continuous Tool GR CBL/VD CET EPL Collar/Perf Run 1 5" Sch Run 1 Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO · . f P~~lea'se sign and return the attached copy as receipt o'f data. · FRIDAY THE 13th is upon us -Have a Nice One! Kelly McFarland ATO-1429F Trans. #144 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smi t:l:~ State of Alaska · ' ....... ?:l .~ ~as Cons. CommJssiorl Anchorage ARCO Alaska, Inc. Post Officz~-~ox 360 Anchorag. ,laska 99510 Telephone 907 277 5637 April 2, 1984 Reference: ARCO Open Hole Finals D.S. 1-iA fl-30-84 ..1-30-84 .,1-30-84 ~-1-30-84 ~1-30-84 .,-1-30-84 D.S. 9-22 ~-2-6-84 ,~ 2-5-84 ,~2-5-84 ~-2-5-84 ,--2-5-84 D.S. 12-25 -'1-26-84 /1-26-84 jl-26-84 ~-~1-26-84 .~1-26-84 ,~1-26-84 CPL / Cyber 1 ook BHCS/CR DI~,/SFn/OR CDL / CNL / GR ( Raw ) CDL/CNL/GR (Poro) CNL/GR/CCL CPL/Cyber look BHCS/GR - DIL/SFL/OR LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) CPL/Cyberlook BHCS/GR DIL/SFL/GR LDT/CNL (Raw) LDT/CNL (Poro) GR in casing _--Run 1 5" Sch Run 1-2" & 5"'-- Run 1 ~2" & 5"-~ Run 1 5" Run 1 5" Run 1 5" Run 1 5" Sch Run 1 ,2" & 5"-- Run 1--2" & 5''~-- Run 1 5" Run 1 5" Run 1 5" Sch Run 1 ~'2" & 5''~' Run 1 *-2" & 5"- Run 1 5" Run 1 5" Run 1 5" ~~Please sign and return the attached copy as receipt of data. HAVE A HAPPY EASTER! Kelly McFarland ATO-1429F DISTRIBUTION Trans. f~ 126 Chevron Mobil ~- . D & M Mobil E & P Dallas Phillips Drilling Prudhoe Bay Well Files Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska "~ ~ ~ : ,~-,. STATE OF ALASKA __. ~ ALASKA LAND GAS CONSERVATION C(. ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS- · Drilling well ~ Workover operation [] 7. Permit No. - 83-166 2. Name of operator ARCO Alaska, inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 835t FSL, 203' FWL, Sec.17, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28331 8. APl Number 50-- 029-21042 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 12-25 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. January ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0600 hrs, 01/12/84. Drld 17-1/2" hole to 2615'. Ran, cmted & tested 13-3/8" csg. Drld 12-1/4" hole to 10,811'. Ran, cmted & tested 9-5/8" csg. Drld 8-1/2" hole to 11,390'. OH logs. Arctic packed 13-3/8" x 9-5/8" annulus. Ran 7" lnr. Ran CBL. Ran 5-1/2" compl, assy. Secured well & RR @ 0900 hrs, 01/31/84. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. Instld w/1980# Poleset. 13-3/8" 72.0#/ft, L-80, BTC csg w/FS @ 2591'. Cmtd w/2400 sxs Fondu + 400 sxs PF "C". 9-5/8", 47.0#/ft, L-80 BTC csg w/FS ~ 10,783'. Cmted'.w/500 sxs "G" cmt + 300 sxs PF "C". 7", 29#/ft, L-80 BTC csg f/10,489' - 11,385'. Cmtd w/300 sxs "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/SP/GR f/11,370' - 10,780'. LDT/CNL/GR/Cal f/11,370' - 10,780'. GR to 2550'. CBL/CET f/11,330' - 10,375'. 10. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ............. ~ --'"~ ...... / - / NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 nD~/MI~ Submit in duplicate DS 12-25 DRILLING HISTORY NU 20" hydril & diverter. Spudded well @ 0600 hrs, 01/12/84. Drld 17-1/2" hole to to 2615' Ran 65 jts 13-3/8" 72#/ft ,w,/FS @ 2591' Cmtd 13-3/8" csg w/2400 sxs F~ndu + 400 sxs PF "C". ND ~0 hydril & d'iverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE& tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok - held to 11.0 EMW. Drld 12-1/4" hole to 10,811'. Ran 265 jts 9-5/8" 47#,_~w/FS @ 10,783'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11,390' (01/26/84). Ran DIL/BHCS/SP/GR f/11,370' - 10,780'. LDT/CNL/GR/Cal f/11,370' - 10,7~8~0~' GR pto 2550'. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs PF "C" +-,. 'DB A.-. Ran 22 jts 7" 19#/ft, f/10,489' - 11,385'. Cmtd 7" lnr w/300 sxs "G" cmto Drld cmt to 11,339' (PE~TD). Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Run CBL/CET f/11,330' - 10,375'. Ran 5-1/2" completion assy w/tail @ 10,508' & pkr @ 10,428' & SSSV @ 2189'. Tested hanger and packoffs to 5000 psi - ok. ND BOPEo NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkro Secured well & released rig @ 0900 hrs, 01/31/84. DRN/DH57'tw ARCO Alaska, Inc. ~'-"~, Post Office L--_ .. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 19, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - DS 12 Wells 21, 25.-29 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU5/L134'tw Enclosure ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany · /.AT · 7~'/$'o$, ~1 . ~f,~ ~ y · .~' ~ 31G G 2. .f o ,047': ?'o'/3 ' o,~. fl /.,f. ~ Z~.,V4 =/.-fO'.z~'/d. 'T/-,f. /..47' ; 70'/3 'c7/. ~ 3 0 " I7 2O 19 20 -F'/;,~: A,~(.O Alas,~a, Inc. ,, o~ "; ~c_t::f':ry of ~tlontic Richfield Compony ~[ M EMORAN OUM State of Alaska ALASKA OIL AND GAS CONSERVATION COM}tlSSION TO: C.V.//~a~e~rton Chai~ ~tRU: Lonnie C. Smith Commissioner Petroleum ~¢ctor DATE: January 18, 1984 FILE NO: 3I. 8 TELEPHONE NO: SUBJECT: Inspect Diverter System on ARCO's DS 12-25, Sec. 7, T10N,R12E,Ubl, Permit No. 83-130 Friday, January 13, 1984: After completing the inspection of the di'verter system` on Hemi-Springs State ~1, I went to Parker Rig 176 and inspected the diverter system on DS 12-25. This system also met A.P.I. and A.O.G.C.C. rules. In summary I inspected the diverter system on ARCO's DS 12-25. MEMORANDUM State of Alaska TO: THRU: FROM: C.V.(~[er~on DATE: January 16, 1984 Chai~ ~ ~'/~i FILE NO: 3I 9 Lonnie C. Smith ! Commissioner Bobby Foster Petroleum Insp%ctor TELEPHONE NO: SUBJECT: Witness BOPE test on ARCO's DS 12-25, Sec. 17, T10N,R15E,UM, Permit No. 83-166. S.a.t.u. rday, January 14.., 1984: The BOPE test began at 11:30 am and was concluded at 1:30 pm. As the attached BOPE test report shows the kill line check valve leaked. This is to be repaired and tested· In summary, I witnessed the BOPE test on ARCO's DS 12-25. Attachment i was notified by Joe McInnes, ARCO drilling foreman that the check valve had been repaired. 02-00IA(Rev. 10/79) STATE O[" A¼~ S}<,% ALASKA 0I.~% 'CAS OONSERVATION CCMMISSION B.t.P.E. Inspection Rcport Operator Well Location: Sec / ~illinq ~n~a~or ~~~/ - ~tion, ~neral_ · Well Si~ C~neral Ho~e~g ~~e pit Annular Preventer Blind Rams Test Pressure / Representative.~-~/~' ~,~. f ~HI~,K-. · Permit #_ .~ ~_~/~r/~/ · l~Casing .Set @.~ ~'-~/1 ft. Rig f,~ ~ePresentat ive-~/~ ~z~//~m/j ACCL%~UIATOR SYSTEM IFul 1 Charge Pres sure ~ o ¢ O Pressure After Closure J ~'~' psig psig Pump incr. clos. pres. 200 psig_ -- min~ sec. Full Charge Pressure Attained: ~ min~ © sec. Controls: Master Remote f,z~ Choke Line Valves. H.C.R. Valve Kill L~ne Valves Check Valve~ / Kelly and Floor Safety Valves Upper Kelly~ / .Test Pressure_ Lo%er Kelly, /. Test Pressure Ball Type / Test Pressure Ins ide BOR ~/ Test, Pres sure Choke Man/fold c~ ~ ~ Test Pressure ! vmves . No. flanges Adjustable Chokes ~ t~fdrauically operated choke , Test Results: Failures. Repair or. Replacement of failed equipmsnt to be made within. Inspector/Ccmmission office notified. ,.~' ," ~ r ' ~ ' ~ , ~. , ~ ~' / Test Tima' ~ . hrs.. days and Distribution , orig. - AO&CCC CC - Operator /~, //~' //'? ,._ ~. /, November 17, 1983 ~r. D. S. Smiley Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 12-25 ARCO Alaska, Inc. Permit No.. 83-I 66 Sur. Loc. 835'FSL, 203'FWL, Sec. 17, T1ON, R15E, Btmhoie Loc. 276'FSL, 475'~, Sec. 16, T10N, R15E, Dear Mr. Smiley: Enclosed is the approved application for permit to drill the above referenced welt. If coring i~ cond~cted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous' directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Mmny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Depar~ent of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alask~ Administrative Code, Cb~apter 70) and by the Federal Uater Pollution Control Act, as amended. Prior to co~encing operations you may be contacted by a representative of the Department of Enviror~ental Conservation. To aid us in scheduling filld work, please notify this office 2~ hours prior' to com. m~ncing installation of the blowout ~. D. S. S~iley ~udhoe Bay Unit ~S 12-25 ~-iovember 17, 1983 prevention equipment so that a representative of the Con~ssion may be present to witness testing of the equipment before the surface casing shoe is drilled. ~.~cre a diverter system is required, pI~a~e also notify this office 24 hours prior to c~Jenczng equipment installation so that the Com~nission ~ay witness testing before drilling below the ~hoe of the conductor pipe. In the eveng of suspension or abandonraent, ploase give this office adequate advance notification so that we may have a ~tne~s pre,eat. Vory truly yours, C" V. Chatterton Chairman of Alaska Oil and Ga~ Conservation Com~is~ion be:6~H/A Enclosure cc~ Department of Fish & Game, !{abitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 7, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-25 Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 12-25 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. We anticipate spudding this well on January 26, 1984. have any questions, please call me at 263-4610. · Sincerely, D. S. Smiley ~ Area Drilling Engineer If you DSS/JG'tw GRU5/L27 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ALASKA OmL AND GAS CONSERVATION COIvfMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE ~ STRATIGRAPHIC SINGLE ZONE [~ MULTIPLE ZONE 4. Location of well at surface 835' FSL, 203' FWL, Sec.17, T10N, R15E, UN At top of proposed producing interval 308' FSL, 161' FWL, Sec.16, T10N, R15E, UN At total depth 276' FSL, 475' FWL, Sec.16, T10N, R15E, UPI 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 73' AOL 28331 12. Bond 'information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Un.it ~,. 10. Well number '~;~d~,¢ 12-25 -'~. 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 1 mi. NE of Deadhorse miles 276 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11430' MD, 9210'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2700 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 12-6 we11121' @ 2220' TVD feet 18. Approximate spud date 01/26/84 3166 3838 psig@__ Surface .psig@ 9210 ft. TD (TVD) SIZE Hole Casing Weight ~0" 20" 91.5# i7-1/2" 13-3/8" 72.0# 2-1/4" 9-5/8" 47.0# 9-5/8 x 3-3/8" A -1/2" 7" 29.0# 22. Describe proposeO program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade I Coup,ingJ Lengt, L-80 J BUTTI L-80 / BUTTI ~ctic Pac~ J L-80 / BUTTI 906 SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 80 30' I 30' 2570 30' I 30' I 10795 29' I 29' 10524' 18571 ' MD BOTTOM TVD 110'1 110' 2600'12600' 10824'18783' 11430' Ii 9210' (include stage data) 2000# Poleset 2300sx CSIII & 400sx CS I 500sx Class G 300 sx CS I 400 sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 11430' MD (9210' TVD) to inject into the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, and packer will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud. DS 12-25 will be 121' away from DS 12-6 ¢ 2220' TVD. There are no other close wellbores anywhere downhole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space b ;ommission use ~/ DATE //--~-- B~ Samples required []YES ~qO Permit number APPROVED BY Form 10-401 ~'RUS/Pi~07 ~ CONDITIONS OF APPROVAL Mud Iogrequired I DirectionaI Survey required APl number I--lYES ,j~4NO I ~YES I--1NO J s0- ¢'z.~- ~,i o ¥~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 17, 1983 by order of the Commission Submit in triplicate W 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 1000 ~00 3000 4000 '5[100 6000 ' ' I I I I t I I I I I I I I I I I I I I I I I I I I I I [ I I tO' CASING TV[~ --I10 N /././ --/ . kRCO ALASKA, I iC. + $ 13- 3~8' CASING "VD -- 2600 (OP TVD = 2.5 ~ 12,5 S~: 203'~, 835'FSL, Sec 17, - T10N~ ~7.5~ T~"310~FSL, 135~g~, Sec 16, ~ 22.~ T10N, ~/.D 42.5 Eoc ~o- 4324 TMDim 4806 DEP ' 8';6 ~(TO TARGET) K-lO TVD ~ 718 ! TMD ~ 8556 D[P m 3545 ~ ~}, ~" -E/8' CASIHG 1 VD = 8783 TMQ = 10824 DEP SAG RIVER VVD=8793 TM~--1~838 DEP SHUBLIK TVQ =8819 TM ) =1087~ DEP = 5.;88 T(IP SADLEROCHH TV~=8895 TM~=1~983 DEP: 5264 O~WCON1ACT T~D=gl0; TMD=11280 D;P-5478 TD TVD -- 92'10 TMD BASE SAI ILEROCHIT ~D = 9457 TMD 0 ~ 0Q0 ~0~0 30~0 ~000 ~00 ~000 ~00~ 7000 0 100£ 200C 300C 4000 5000 6000 7000 80OO 9OOO DS i2-2?' · E N 30RD! NR.TE5 .,-, - ! 000 0 ! 000 2000 5000 4000 5000 81~ ~/ I_'~1~ _- I! I~ I I I I TARGET TVD-- 8869' 'livE): i0,946' DEP= 5238 5212' EAST 525' South -835' 1-2©' I I ISF~L'203'~, 835'FSL, Sec 17, ,' i T10N, RISE, UM ·i, THL'135'~, 310'FSL, Sec 16', 510' ' 00'0 0 T10N, R15E, UM 2000 3000 ~000 Z F. - W OOOROINB~F.S o - 1.000 0 1000 2000 3000 4000 5000 6000 7000 8000 ! ' ! ! ' ' ' ! ' ' ' ' ' I 1 I I p ! , , , , ! ! , [ i , , ~ , , , , , , , , i , , , , , , , , , i , , i , i , , , , i , , i , i i i , , , , , , , , , , i i ] , t OS 1~ 5 , . DS 12- 25 ~ ~ ~69 I I [I I · · I i i i , ] ~ , , , , , ~ , , , '1 , , , , , , , , ,', , i , , , , , , , , i , , i , , , , , , , i , , , , , i , , , , , , , , , , i , , , , , ', , 1 , , , , , , ,", ,' - tO00 0 1000 2000 3000 ~000 50[[0 6000 7000 80( E - N O00ROINBTES - ' :. , . ': ' i 100 200 500 ~00 500 6 '2. UU -/UU ~ ~' ~-' .... ~ 2999 3484 _ _ 2 4 1..~~_ ~ 4-2 i; 3931 , ~13. 39:.i ' I- ,. .~ ~ .~ .'i'i"/. · . . ~,:;.//, !:J" ;'~ ) - i i i ~l I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ......................... ~nN . _ _ ,-,,-,,-, '~nn ANN o CO- O 0 Zo I Z I o o I I I -200 - O0 0 100 200 300 E - N COORDINIqTES NOTE' I~LL PATHS EXTEND BEYOND VIE],~ING WINDOW. ANNULAR PREVENTER LIND_ RAMS PIPE RAMS PIPE RAMS 13-5/8' BOP STACK DIAGRAM Accumulator Caoacit,v 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 simultane- ously and record the time and pressure remaining after all units are closed with charging p~np off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8' BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock do~ screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3; minutes, then tes~l~high pressure. 5. Increase presure to / OQ~_~QO ps~j~and hold for a minimtma of 3 minutes. Bl~ pressure to zero. 6. Open annular preventer and close tto~ pipe rams. Increase pressure to. and hold for at least 3 minutes. sure to zero. 7. Close valves directly upstream of chokes and, open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to SOO0 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with SO00 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to SO00 psi. 14. Test Kelly cocks and inside 80P to 5000 psi with Koomey pumP. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOP[ daily. Rev. -, [ ,....'C LC '- ' -' - SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC'. SCHEMATIC .~ IO" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) IO" HYD. OPR. BALL VALVE ALL 90° TURNS ARE "TEE" CUSHION I RESERVE PIT AREA NOTE · FLOWL INE F DR ILL ING R I SER L ~O~10" D~VERTER 20" 2000 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 202..60102 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc C'~.:./'"~___._ /:.-.'.~- ,.~: ~ thru 8) 1. Is the permit fee attached ................. 2. Is well to be located in a ~i~ ~i .ii.i .... iii.ii]ii ..... 3. Is well located proper distance from property line ................ 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage available in this pool .... 6. Is well to be deviated and is well bore plat included .... '''''.' 7. Is operator the only affected party ............................... 8. Can permit be approved before ten-day wait ........................ (3) Admin :/L,-'x~' /"-/'~'~ ~ 9. ~(9'" thru 1 i) 10. 11. ( 4 ) .C a s g ~?~"' /I-/~- ~,f (i2 thru 20) (5) BO PE ,z,~/.e..,,,4~..// (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO ::.:~' REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed Is conductor string provided ........................................ ~f Is enough cement used to circulate on conductor and surface ......... //~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ..................... /~ Will surface casing protect fresh water zones ....................... ~. Will all casing give adequate safety in collapse, tension and burst.. ~/~, Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... //~ L Is a diverter system required ........ ;g~ ~ ''':''''~ '~'';'~ a rams v,,ter Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Geology: Engiq.e~r.ing: WVA J~ .~ M~/;~. r~: 12/06/82 " INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effod has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING LVP OlOoHO2 VERIFICATION LISTING PAGE I ** REEL HEADER SERVICE NAME :EDIT DATE : 8~/0Z/27 ORIGIN : REEL NAME :135101 CONTINUATI,gN ~ :01 PREVIOUS REEL COMMENTS :LIBRARY TAPE ~ TAPE HE&DER *~ SERVICE NAqE :EDIT DATE : 84/0Z/27 ORTGIN :0000 TAPE NAME :3956 CONTINUATION -# :01 PREVIOL}S T~.PE : COMMENTS :LIBRARY TAPE ;** FILE HEADE.R FILE NAME :EDIT .001 SERVICE NAME : VERSION # :)ATE : MAXIMUM LENGTH : 102¢ FILE TYPE : PREVIOUS FILE : ,', INFORMATION RECORDS 'MNEM CO~TENTS CN : ARCO ALASKA INC ~,N : 12 -2 FN : PRUDHOE SAY RANG: TOWN: I'0N SECT: 17 COUN: N. SLOPE ST AT: AL CTRY: USa, UNIT TYPE CATE SIZE CODE DO0 000 016 065 000 000 005 065 000 000 '012 065 000: 000 00~ 065 000 000 00¢ 065 ,000 000 002. 0,6,5 '000 OOO 00.8 065 000 000 006 06S 00,0 000 00.4 055 LVP 010oH02 VERIFICATION LISTING PAGE SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY = ATLANTIC RICHFIELD COMP&NY WELL = 12-25 FIELD = PRUOHOE BAY COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 68956 RUN ~1, DATE LOGGED: 26-JAN-8~ LOP: CASING : 9.625~m @ 10768~ - BIT SIZE : TYPE FLUID = LIGNOSULFONAT~ OENSITY = 9.9 L~/G EM VISCOSITY = 3~,.0 S RMF PM = 11.5 RMC FLUID LOSS = ~-6 C3 RM AT BMT = 1.090 @ 76.0 DF = 0.g&O @ 76.0-'DF = 1.z, 30 @ 76.0 DF = O.~Ta @ 18Z.O DF MATRIX SANDSTONE LVP OIO. H02 'VERIFICATION LISTING PAGE ** DATA FORMAT RECDRD ** ENTRY BLOCKS TYPE SIZE REPR £DDE 4 1 66 B 4 73 9 4 65 0 1 65 DATUM MNEM SPECIFICATION SERVICE SERVICE ID ORDER # SFLU DIL ILD DIL ILM DIL SP DIL GR DIL DT BHC GR BHC NPHI LDT DRHO LOT RHDB LDT NCNL LDT 'FCNL LOT CALI LOT NRAT LDT RNRA LD'T PEF LOT G.R LOT GR CNL 5LOCKS UNIT AP! API API AP! FILE LOG TYPE CLASS ROD NO. FT 0 0 0 0 0 OHMM 7 0 0 0 0 OH'MM 7 12 aB 0 0 OHNM ? 0 0 0 0 MV 7 ! 0 0 0 GAPI 7 31 32 0 0 US/F' 60 52 32 0 0 GAPI 60 3i 32 0 0 P'U 0 68 2 0 0 G/C3 0 44 0 0 0 G/C3 0 35 1 0 0 CPS 0 34 92 0 0 CPS 0 34 93 0 0 IN 0 28 3 0 0 0 42 1 0 0 '0 0 0 0 0 0 0 0 0 0 GAPI 0 31 32 0 0 GAP~ 42 31 32 0 0 ENTRY 1 60 .lin 0 SIZE PROCESS LEVEL 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 ~ 0 ~ 0 ~ 0 4 0 0 0 SAMPLE 1 REPR CODE 6B 6B 68 68 68 63 68 68 68 68 68 68 68 68 DEPT SP hiP HI FCNL PEF 11~01.0'000 SFLU -999..2500 GR 32o32~2 DRHD 3.ogl8 GR DEPT SP ~P.HI FCNL 11.~00. 0000 SFLU -999.25'00 GR 32.32.42 OReO ll4~,.OOOO CALl 3.0'9~8 ~R OEP'T SP NPHI 11300.0000 SFL'U -86- 937.5 GR 29.58'98 DRHO -99~.2500 ILO -999-2500 O'T 0.0918 RHOB 3.7832 NRAT_ 24.8437 GR -999.2500 ILO -999.2500DT 0.0918 RHOB : 3.7,832 NRAT 24°8437 GR 3.5195 ILO 36,7813 DT 0.0166 RHDB ,-99'9.2500 ILM --999.2500 GR 1.9453 NCNL 2'5957 RNRA -999.2500 -999. Z500 ILM -9'99.2500 GR 1.. 9453 NCNL 2,.:595'7 RNRA -99 9,. 25:00 2.08~0 I.LM 90.0000 GR' Z. 2637 NCNL -999.2500 -99'9. Z500 3136.0000 2°7402 -'999.2500 -99go2500 3136.0000 2.7402 2.1289 3822.0000 LVP OIO.HOZ V'ERIFICA'TI~N LISTING PAGE 4 FCNL PEF DEPT SP NPHI FCNL PEF OEPT SP NPHI FC NL PEF DEPT SP ~PHI FCNL PEF DE PT S'P NPHi .~C NL PEF OEPT SP NP'H I FCNL PEF OEPT SP NPHI FCNL PEF OEPT SP NPH! FCNL P E F DEPT SP NPHI FCNL PEF OEPT SP )4PflI 1373.0000 CALI 11200.0000 SFLU -84.2500 17.2363 D R:,,I 0 2176.0000 CALl 1.9795 GR 11100.0000 SFLU -7Z.3750 GR 24.1211 DRHO 1371.0000 CALI 2.7813 GR 11000.0000 SFLU -87.9375 GR 25.830.1 DRHO 1.336.0000 CALI 3.,.4648 GR 10900o 0000 SFLU -33o0313 GR 13.8154 DRHO 2258. 000'0 CALI 4. 0273 GR :1:080,0.0000 SFLU -35.0938 GR 22.2656 ORHO I082.0000 CALl Z..1973 GR 10700.0.000 SFLU -999.2500 GR 5 B. 6426 OR 336.0000 CAL! 29. 5781 GR 10600.0000 :SFLU · -999.2500 GR -999.2500 9RHO -999.2500 CALI -999.2500 GR 10500.0000 ,S F L U -999.2500 GR -99 9- 25-00 DRND -999.25 O0 C,ALI -999.2500 GR 10~00~.0000 -999.2500 -999.2500 DRHO 7.7930 ~R~T 36.7813 GR 11.7578 34.0938 DT 0.0142 8.5781 ~RAT 34.0938 GR 13.73~4 ILO 37.8437 3T -0.0283 RHOB 8.5156 NRAT 37.8437 GR 32.3750 iLD 25.9062 OT -0.0151 RH00 8.3125 NRAT 25.9062 GR 226.6250 ILO 97.2500 DT 0.0254, RHOB 9.1719 NRAT 97.2500 GR 17.953,1 [LO 67.6250 DT 0.0,464 RHBB 13.3672 ~RAT 67.62'50 GR -~9'~,.,7.500 -999.2500 DT 627 NR~T 6,6.375.0 S R -999.2500 ILD '-999.2500 DT -999-2500 8'HOB -999.2500 NRAT --999.2500 GE NRAT --999. 2500 GR -999°2500 'ILO DT RHOB 2.6523 RNRA -999.2500 9.0313 77.0000 2.3867 NCNL -999.2500 14.0625 ILM 89.7500 GR 2.3613 NCNL 2.3496 RNRA -999.2500 55o7813 ILM 87.3750 GR 2.3379 NCNL 2.4453 RNRA -999.2500 $$.0000 ILM 72.3750 GR 2.5625 NCNL 1.7168 RNRA -999.2500 84°3750 GR 2.3496 NCNL 2.~766 RN~A 76.8125 --999°2500 ILM -999. 2500 GR 2. 1016 NCNL 3.9746 RNRA 75.2500 -999. 2500 ILM -999.2500 GR -999.2500 NCNL -99'9'. 2500 RNRA 6 3,. 2..813 -999.2500 ILH -999.250'0 GR -999.2500 NCNL -999°2500 RNRA 72.,.1250 -999.2500 -999.2500 G'R -999.25~0 NCNL 2.7832 8.0859 34.0938 4292.0000 1.9717 11.8672 37.8437 3~32.0000 2.502.0 24.9687 25.9062 3646.0000 2.7285 36.0313 97.2500 4540.0000 2.0098 15.6016 6'7.6250 2842.0000 2.6250 -999.2500 -99'9.2500 1647.0000 4.8984 -999.2500 -999.2500 -999.2500 -999.2500 -999.250'0 -999.25D0 -999.2580 -999..2500 -999.~50"0 '-999.2500 -999.2500 LVP 010.H02 VERIFICATION LISTING PAGE 5 FCNL PEF DEPT SP NPHI FCNL DEPT SP NPHI F C NL DEPT SP NPHi! 'FCNL PEF DEPT SP FCNL PEF OEPT SP NPHI FC NL PEF DE P'T SI= FCNL PEF OE~T 'S P NPHI FCNL P E F DE:PT SP NPHI FC NL PEF DEPT SP NPHI -999.2500 CALI --999.2500 GR 0300.0000 SFLU -993. Z500 GR -999. Z500 ORHO -399.2500 CALI -999.2500 GR tOZO0,. 0000 SFLU -999.2500 GR -99'9. 2500 ORHO -999.2500 CAL! -999. Z500 GR lOlO0.O000 SFLU -999.2500 GR -399.2500 3R~O -999.2500 CALI -999.2500 GR lO000.O000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 CALI -999.2500 GR 9900.0000 SFLU -999.2500 GR .-999. Z500 DRHD -999.2500 CALI -9'9'9.2500 GE gBo0oo000 SFLU -99'9.Z500 GR -999.2500 DRHD -999°2500 CALI -999.2500 GR 9700.0000 SFLU -999,.2500 GR -999.2500 DR~O -999. 2500 CALI -999. 2500 GR 9500..0000 SPLU -999.2500 'GR -Og9. ZS'OOORMD -999.2500 CALl -999.2500 GR 95,00-00'00 SFLU -99'9.2500 GR -99'9.25'00 DR'HO -999.2500 NRAT -999.2500 GR -999.2500 ILO -999.2500 3T -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILD -999°2500 DT -999,.2500 RflOB -999°2500 NRAT -999.2500 GR -999.2500 -999.2500 DT -999.2500 RHOB -999.2500 '-999.2500 GR -99.9.2500 ILO -999.2500 DT -999.2500 NRAT -999.2500 GE -999.2500 ILO -999.2500 DT -999oZ500 RH, O5 -999. Z500 NRAT --9'99°2500 GR -99'9.2500 -999.2500 OT -999.2500 -999o2500 NRAT -999.250'0 GR -999'2500 -999°2500 : --999,,2500 -999.2'500 ILO BT RHSB NR~T GR ILO DT RHOB NRAT GR RHOB -999..2500 RNRA 160.1250 -999°2500 iLM -999.2500 ER -999.2500 NCNL -999.2500 ~NRA 122.1250 -999. Z500 ILM -999.25O0 GR -999.2500 NCNL -999,.2500 RNRA 69.6875 -999°2500 -999°2500 GR -999.2500 NCNL .-999.2500 7'7.1875 -999.2500 ILM -999.2500 GR -999.2500 NCN,L -999.2500 RNRA 108.. 317.5 -999-2500 ILM -999.2500 GR -999°2500 NCNL -999.2500 RNRA 93.0,625 -999'2500 ILM -999.,2500 GR -999.2500 NCNL -999.2500 RNR~ 115.,1250 -99'9.:2'500 ILM -999,.2500 GR - 999° 2'50 O NCNL -999. Z500 RN~A 53.8.125' -999,.2500 ILM -999°2500 GR --999°12500 NCNL -999o 2500 R,NRA 53.1250 -999-2500 ILM -999.2500 GR -999-Z~00 N.CNL -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -:399.2500 -999.250'0 -999.2500 -999°2500 -gg~.zSO0 -999.2500 -ogg,.Z500 ,,-999o25~0 -999°2500 -999.2500 -999.2500 -999.25'00 -99'9.2500 -999.2500 -999°2500 -999.25'00 -999.2500 -999.2500 .-999.2500 -999.2500 - 99'9.2500 LVP OlO.H02 VERIFICATION LISTING PAGE FCNL PEF DEPT SP ~PHI FCNL DEPT SP NPHI ~:CNL PEF OEPT SP NPHI PCNL DEPT SP NPHI FCNL PFT: SP FCNL PEF DEPT SP NPHI PCNL DEPT SP NPHI FCNL PEF DEPT SP N'P HI FCNL PEF DEPT SP NPHI -999.2500 CALI -999.2500 GR 9GO0.O000 SFLU -`99@o2500 GR -999,.2500 DRHO -999. 2590 CALi -99'9°2500 GR 9300°0000 SFLU -999°250'0 GR -999o2500 DRHO -`999.2500 CALI -999.2500 OR 9200.0000 SFLU -999°2500 GR -999,.2500 DRgD -99'9. 2500 CALI -999.2500 GR 9100.0000 SFLU -999.2500 ORHO -999.2500 CALI -999,2500 GR 9000o0000 SFLU -999,. 2500 GR -999.2500 DRHO -99:,9,2500 CALI -999.2,500 GR 8900.0000 SFLU -999'2500 GR -999. 2500 DRHa -999,.2500 CALI -999- 2500 GR 8800°0000 S:FLU -999.2500 GR -999o2500: ORHO -9'99.2500 CALI -999.2500 GR B700,O000 SFLU -999.2500 GR -999,.25000RH0 -999.2500 CALI -999.2500: GR 8600-0000 SFLU -99:9.25'00 C,R -999. 2500 ORHO -999.2500 NRAT -999.2500 GR -999.2500 ILO -`999.2500 DT -999.2500 RHOB -'999.2500 NR&T -999.2500 GR -999.2500 ILD -999o 25*00 DT -999.2500 RHDB -999.2500 NRAT -999.2500 GR -999.2500 ILO -999.2500 DT -999°2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILO -999,.2500 OT -999.,?.500 RHgB -999.2500 NRAT -999,.2500 GR -999.2500' ILg -999.2500 DT -999,,2500 RHOB -999°2500 NRAT - 999 o 25:00 G R -999.2500 ILO -999.2500 DT -999.2:500 RHOB '-999.250'0 NR~T -999.2500 GR -'9'9 ge 25,09 ILO -999.250~0 OT -999"2500 : RHOB -999.2500 NRA'T -999' ,7. 500 GR -999..2500 ILD -999.250,0 OT -999'2500 RHDB -99'9,. 25.00 NRAT -999,2500 GR -999,,2500 ILD -999.2500 DT - 99:~D,. :2500 RHB:B -999.Z5~0 RNRA 53.0313 -999.2500 -999.2500 GR -999° 2500 NCNL -999.2500 RNRA 42.6875 -999.2500 ' -999,.2500 GR -999.2500 NCNL -999.2500 RNRA 57.5000 -999°2500 ILM -999..2500 GR -999,2500 NCNL -999.2500 RN~A ~2o3125 -999.2500 ILM -999.2500 GR -999.2500 NCNL -99'9.2500 RNRA 55.7813 -999. 2500 ILM · -999. 2500 C,R -999. 2500 NCNL -99'9.- 2500 R'NRA 45.8437 -999.2500 [LM -999°2500 GR -99'9..2500 NCNL -999.2500 RN'RA 50°0938 -9'99, ~ 5"0,0 ILM GR -999o2S00 NCNL --999.. 2500 RNRA 39oS437 -999-2500 ILM -999.2500 NCNL -999.2500 RNR,A 7'2.1250 -999.. 250'0' -999.2580 GR -999. 2500 NCNL -999.2500 -999°2500 -999.2500 -999.2500 -999.2500 -399.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -993.2500 -999°2500 -999°2500 -999.2500 ,-999.2500 --999.2500 .-999.2500 -999.2500 -999o2500 -999.2500 -999°2500 -999°2500 -999.2500 -999o2500 -9'99.2500 -999.2500 -999.2500 --999.2500 -999.25'00 -'999.2~00 -999.2500 -999.2500 -999.2500 -999.250,0 .-999.2500 -999.2500 EVP OlD.H02 VERIFICATION LISTING PAGE 7 OEPT SP ,4PHI FCNL PEF DEPT SP NPHi F:CNL PEF QEPT SP NPHI FCNL PEF DEPT SP NPHI FCNL PEF DEPT SP NPHI FCNL PEF 'DEPT SP NPHI ~CNL PEF OEPT SP N.PHI FCNL PEF OEPT SP NPMI FCNL PEF DEPT SP NPHI -99'9. 2500 CALI -99 ~. 2.500 GR 8500.0000 SFLU -399°2500 GR -999. Z500 ORHD -999.Z500 CALI -999.2500 GR 8GO0oO000 SFLU -99'9.Z500 GR -999.2500 ORHO -999.Z530 CALI -999.2500 ~R 8300.0000 SFLU -999oZ50.0 GR -999.2500 OReO -999oZ500 CALI -999°2500 GR 8ZO0oO000 SFLU -999.2500 5R -999. Z500 DRHO -999. Z5.00 CALI -999.2500 GR 8100,0000 SFLU -999.2500 GR -993.2500 ORNO -99'9°2500 CALI -999.250'0 ER 8000.0000 SFLU -999.2500 GR -999.2500 ORHO -999,.2500 CALI -999. 2500 GR 7900.0000 SFLU -999.2500 GR -'999-Z500 D.RHO -999°2500 CALI -999°2500 GR 7~00-00:00 SFLU -999.2500 9RHO '-999.Z500 CALI -99'9.2500 ER 7700.0000: SFLU -999o2500 GR -999,. 2S00 ORHO -999.2500 NR~T -999°2500 GR -999,.,2500 ILO -999.2500 DT -9gg. ZSO0 RHOB -999.2500 NRAT -'999.. 2500 GR -999,.2500 ILO -999.2500 DT -999.2500 RHOB -999.2500 fiRST -999.2500 GR -999.Z500 ILO -999.2500 DT -999.2500 RHOB -999.25'00 NRAT -999°2500 GR -999.2500 -999.Z500 -999oZ500 RHOB ,-999.2500 NRAT -999.2500 -999.2500 ILO -999°2500 DT -99'9.250'0 RHOB -999.,Z500 NRAT -999°2500 GR -999.2500 ILO -999.25.00 DT -999.2500 RHOB -999.2500 NR~T -999.:2500 GR -999-2'50:0 ILO -999.2500 OT -9'99'Z5:'00' RHOB -999.2500 NRAT --999'2500 GR -9:9:9.25.00 ILO -999.2500 DT -999.~500 ~MOB -'999. 500 'RAT -999.Z500 9-2500 I,LO -999.2500 OT 99:9,. ,2500 RH 0 B -999°2500 RNRA 70.3750 -399-2500 -999o2500 SR -999.,2500 NCNL -999. Z500 RNRA 58.6875 -999. Z'500 ILM -999o2500 GR -999.2500 NCNL -999°2500 RNRA 56.0938 -999.2500 ILM -999.2500 GR -999.2500 NCNL -999.2500 RNRA 67o8125 -999,. 2.500 ILM -999.2500 GR -999.2500 NCNL -999.2500 RNR~ ,67.3125 -999..,250.0 -999.Z500 GR -999. 2500 NCNL -999.2500 RNRA ,~'9. 2500 -999.2500 -999.Z500 GR -999'2500 NCNL -999. Z500 ~NRA ~3.'2500 -999.2500 -999.25'00 GR -999.2:500 NCNL -999.2500 RNRA -9'99 .50~0 GR -~ 99. Z 500 NC NL -~99.25,00 RNRA 4 'g. 375 0 '-999. 2500 ILM '-999.2500 GR --999' 2500 NCNL -999oZ500 -999.2500 -999.250D -999.2500 -999°2500 -999°2500 -999.2500 -999°2500 -999o25O0 -999.2500 -999.Z500 -999.2500 -999.2500 -'999.Z500 -999.2500 -999.2500 -999°2500 -999.2500 -999o2500 ,-999.2500 -999.2500 -999.2500 -9'9'9.2500 -999.250.0 -999.2500 -999.Z500 '99)o2500 -999.2500 -999.2500 -999.2500 -999.25:00 -999.2500 -999.2500 -999.2'500 LVP 010.HOZ VERIF!CATI'DN LISTING PAGE 8 ~C~4L PEF DEPT SP NPHI FCNL PEr DEPT SP NPHI FCNL PEF DEPT SP NPH! FCNL PEF DEPT SP F'CNL PEF DEPT SP NPH! FCNL DEPT SP NPHI FCNL DEPT SP ~'CNL PEF D~PT SP F C N L PEF DE PT SP NPHI -999.2500 CALI -999.2500 GR -999.2500 NRAT -999o2500 GR 7500°0000 SFLU -999°2500 5R -999.2500 DRHO -999.2500 CALI -999.2500 GE -999.2500 -gg9.2SOO DT -999o2500 RHD5 -999.2500 NR~T -999.2500 GR 7500.0000 SFLU -999.2500 -999°2500 DRHO -~9~o2500 CALI -999.2500 GR -999°2500 ILO -999.2500 OT · -999.2500 RHDB -999. 250'0 NRAT -999.2500 GR 7600.0000 SFLU -999°2500 GR -999.2500 OR~D -999.2500 CALI -99~.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NRAT -999.2500 GR 7300°0000 SFLU -999.2500 GR -999.2500 ORHO -999.,2500 CALI -999.2500 GR -999.2500 ILO -999.2500 OT -999.2500 RHOB -999.2500 NRAT -999°2500 GR 7200.000'0 SFLU -999o250.0 GR -999.2500 ORHO -999.2500 CALl -999.2500 GR -999.2500 -999°2500 DT -999.2500 RHOB -999.2,50.0 ,~RAT --999o2500 7[00.0000 SFLU -~9 9. 2500 ~R -999.2500 DRHO -999.2500. CALl -999° 2500 GR -999.2500 ILO -999. 2500 OT -999.2500 ~HOB -999.2500 NRAT -'999.2500 ~'~R 7000.0000 SFLU -999.2500 OR -999.2500 DRH-O -999.2500 CALI -999.2500 GR -999- 2500 I~LO -999,.2500 DT -999'2500 GR 6900.0000 SFLU -~99.2500 GR -999.2500 ORHO -999o2500 CALI -999.2500 GR - 999-2.500 ILO -999.2500 DT -999, 2. S00 eHOB -999.25 0',0 NRAT -999,. 2:50'0 GR 6800.00,00 SFLU -999.250D GR -999.2500 ORHO -999. 2500 iLO gT RH~B -'999.2500 RNRA 45.1562 -999.2500 ILM -999.2500 GR -999.2500 NCNL -999.2500 RN~A 51.5000 -999.2500 ILM -999.2500 GR -999°2500 NCNL -999.2500 RNRA 39.2813 -999.2500 ILM -999.2500 GR -999. 2500 NCNL -gg9.oZSO0 2NRA 35.5313 -999.2500 -999°2500 -999.2500 NCNL -999.2500 RNRA -999.2500 ILM -999.2500 ~R -999. 2500 NCNL -993.2500, RNRA 43.1250 --999.2500 ILM -999.2500 GR -999.2500 N,CNL -999.2500 R'NRA 2'9.3125 -9'99. 2500 IL~ -999.2500 GR -999° 2500 NCNL -999.2500 RNRA '- g 99 . 2500 I L M -999.2500 3R -999. 2500 RNRA 36.4.375 -999.2500 ILM -999.2500 GR -999.2500 NCNL -999.25D0 -999.2500 -993.2500 -999.2500 -ggg.zsO0 -gDg. Z500 -999.2500 -999.2500 -999o25~0 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -1999o.2500 -999.2500 -999.Z$00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2'50,0 -'999.2500 -999.2500 -999.2500 -999.25:00 -ggg.zSOO -999'2500 '-999.2500 -999.2500 l m~."~ m~ i i i m i ] ,i:4 ii! [;~ ~ LVP O1D.HOZ VERIFICATION LISTING PAGE g FCNL PEF ~EPT SP NPHI FC~L PEF DEPT SP NPHI ~:CNL PEF OEP? SP NPHI FCNL PEF OEPT SP FCNL PEF OEPT SP FCNL PEF DEPT SP NPHI FCNL PEF ~EPT SP NPHI FCNL PEF SP NPHI FCNL PEF OEPT SP NPHI -999.2500 CALI -999.2500 GR -999.2500 NRAT -999.2500 GR 6700.0000 SFLU -999.2500 SR -999.2500 DRMO -999.2500 CALI -999.2500 6R -999o2500 ILO -999.2500 OT -999.2500 RHOB -999.2500 NRAT -99'9.2500 GR 6500.0000 SFLU -999.2500 GR -999,.2500 DR~O -999.2500 CALI -999.2500 GR -999.2500 ILO -999.2500 OT -999.2500 RHO$ -999.2500 NRAT -999.2500 GR 6S00°0000 SFLU -999.2500 GR -99'9.2500 DRHO -999.2500 CALi -999.2500 ~R -999.2500 ILO -999.2500 OT -999.2500 RHOB -999.2500 NRAT -999°2500 GR 6~00o0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 CALI -999.2500 GR -999.2500 ILO -999.2500 DT -999..2500 RHOB -999.2500 NRAT -999.2500 GE 6300°0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 CALI -999°2500 GR -999,2500 ILD --999. 2500 OT -999'2500 RHOB -993..2500 NRAT -999'2500 GR 6200.0000 $ iF L U -999,.2500 -999"2500 -999.2500 CALI -999.2,500 -999-2500 ILO -999'2500 OT -999-250'0 RH 0 B --999.2500' NRAT '- 99'9 - 25 O0 G R 610,0.0000 SFLU -999.2500 GR -999° 2500 DRHO -999.250'0 CALI -999,. 2500 GR -999-:250'0 ILO -999.2500 OT -999°2500 GR 60,00~0000 -999.2500 -999,2500 ' -999°250'0 -999.2500 SFLU -999' 250'0 ILO GR -999.2500 OT ORHO -:999-2500 RHO'B CALI -99'9,. 2500 NR AT G R - 999' Z 5,00 G R 5900.00'00 SFLU -99'9.2500 GR -999°25'00 ORHO -999-2500 ILO, - 999.25'00 D T - 999.. 2500 RH08 -999.2500 RNRA 30.8125 -999.2500 ILM -999.2500 -999.2500 NCNL -999-2500 RNRA 36-5000 -999.2500 ILM -999.2500 GR -999. 2500 N£NL -999.2500 RNRA 49.8125 -999.2500 ILM -'999.2500 GR -999°2500 NCNL - '99 go 2500 R N R A 30o ,3~, 3 8 -999o2500 -999.2500 GR -999,.2500 NCNL -999°2500 RNRA 37o7188 -999.250,0 ILM -999.2500 GR -999.250.0, NCNL -999. 250'0 RNRA 47.,:B125 -999,250'0 IL~ -999.2500 GR -9'99,'2500: ~CNL --999.2500 RNRA 51o375:0 -99,9.25,00 -999.2500 GR -999.2500 NC:NL -999. 2500 RNRA · 3"' 93'? 5 -999.2500 ILM -999. 250,0 GR '-999. 2500 NCNL -999.2500 RNRA 3 ?. 3438 -999-2500 -999.2500 GR -999'2500 NCNL -999.2500 --999.2500 -993°2500 -999.2500 -999. ' ~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999o2500 -999.250'0 -999.2500 -999.2500 --999.2500 --999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.. ZSO0 -999° 2500 - 9 g g. 250 O -999.25.00 -99'9,.2500 - 999.25 0-0 -999. 2500 -999,o2500 -99'9.2500, -99'9.2500 LVP OlO.HOZ VERIFICATION LISTING PAGE 10 FCNL PEF SP NPHI FCNL PEF DEPT SP NPHi FCNL PEF SP NPHI FCNL PE F DEPT SP NPHI FCNL PEP DEPT SP NPHI FCNL PEF OE'PT SP NPHI FCNL PE F DEPT S,P N'PHI PEF SP NPHI PEF OE PT SP NPHI -999.2500 CALI -999. 2500 GR 5500.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 CALI -999.2500 GR 5700.0000 SFLU -999o2500 GR -999.2500 ORHO -999.2500 CALI -999.2500 GR 5600.0000 SFLU -999.2500 GR -'999.2500 ORqO -999.2500 CALi -999.2500 GR 5500.0000 SFLU -999.2500 SR -999.2500 DRH'O -999.2500 CAL! .,-999.2500 GR 5~00o0000 SFLU -999.2500 GR -999,.2500 ORHO -999.2500 CALI -999.2500 GR 5'300.0.000 SFLU -999.2500 GR -999°2500 ORHO -999.2500 CAL[ -999.2500 GR 5ZO0oO000 SFLU -999.2500 GR --999°2500 ORHO -999.2500 CALI -99'9,.250,0 ~R 5[OO. OOOO SFLU -999.2500 GR -999.2500 9RHO -999.2500 CALI -999.2500 GR $000o0:000 SFLU -999.25'00 GR -999. Z500 ~RHO -999. Z500 NR~T -999.2500 GR -999.2500 IL3 -999.ZS00 2T · -999. Z500 RHDB -999°2500 NRAT -999°2500 GR -999.2500 iLD -999.2500 OT -999.25.00 RHQB -999.2500 NRAT -999.2500 GR -999.2500 ILD -999.2500 OT -999°2500 RHOB -999.2500 NRA? -999.2500 GE -999.,,2500 I.LD -999.2500 -999.2580 RHOB -9'99. 2500 NRAT - 999.2500 'G R -999.2500 ILO -999.2500 DT -99'9.2500 ~HOB --999.2500 NRAT -999°2500 .GR -999.,Z500 -999.2500 DT -999.2500 RHO5 -99'9.2500 NRAT -999.2500 GR -9'99.2500 -999.2500 DT -999°2500 -999.2500 NRAT -999'2S00 GR '-9'99-:2500 ILD -999.25.00 D'T -99:9o2500RH'0~ -999. Z50"0 NRAT -999'2500GR -'999-2500 ILO -999.250'0 DT -999.:2500 -999.2500 38.~688 -99'9.2500 ILM -999.2500 GR --999° 2500 NCNL -999,.2500 RNRA 43.5313 -999.2500 ILM -999. 2500 GR -999.Z500 NCNL -999.2500 RNRA 4,0.3750 -999.2500 ILN -999.Z500 GR -999.2500 NCNL -999.2500 qN~A 3~.4,688 -999.2500 IL~ -999.2500 GR -999.Z500 flCNL -99'9.25,00 RNRA 31.5469 -999.2500 ILM -999.2500 GR -999.2500 NCNL ,-~99o2500 RNRA 35.8750 -999.2500 ILM -999.Z500 GR -999.2500 NCNL -999.2500 RNRA 3'7.2500 -999-2500 [LN -999.2500 GR -999- ZSO0 N,CNL -999. Z50'O RNRA g:',[,. 75:00 '999.2500 ILM · -'999. Z 500 G R -999..2500: NCNL -999.2500 RNRA 43.1562 --999.,2500 ILM -999.Z500 GR -999.,2500 NC~L -999,,.2500 -999.2500 -999°2500 -999.2500 -999°2500 -999°2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -99'9.1500 -999.1500 -999.2500 -999.2500, -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999,.2500 '-999.1500 -999.2500 -9'99.2500 -999.1500 -999.2500 -999.2500 -9'9'9.2500 -9'99. Z500 -999.1500 -999. Z500 LVP OlO.H02 VERIFICATION LISTING PAGE FCNL DEPT SP NPHI FCNL PEF OEPT SP NPHI FCNL PEF DEPT SP NPHI ,~CNL PEF DEPT SP NPH! FCNL PEF DEPT SP NPHI FCNL PEF DEPT SP NPHI mCNL PEF OEPT SP NPHI FCNL PE F O~PT SP NP'HI FCNL P~F SP NPHI -999.2500 CALI -999..2500 GR 4900o0000 SFLU -999. 2500 -jR - ~99., 2500 ORHO -999.2500 C.ALI -999.2500 r.,R CBO0. 0000 SFLU -999.2500 GR -399.2500 DRHO -999. 2500 CALI -999.2500 GR 4700.0000 SFLU -999.2500 GR -999.2500 ORNO -999.2500 CALI -999.2500 GR .~$00o0000 SFL.U' -999.2500. GR -999.2.500 DRHO. -999.2500 CALI -999.2500 GR 4500. 000'0 SFLU -999.2500 GR -999. 250'0 DRHO -99'9. 2500 CALI -999.. 2500 GR 4.½00.000:0 SFLU -999. Z50.0 GR -999.2500 ORHO -999.2500 CALI -999.2500 GR Z~ 300. 0000 SF:LU -999. 2500 'ER -999.2500 DRHO -999°2500 CALI -999.2500 GR 4ZO0.O, O00 SFLU -999.2500 GR -99'9.2500 -999.2500 CA.LI -999.2500 4100.000:0 SFLU -999°2500 GR -999. 2500 ORHO: -999.2500 NEAT -999.2500 GR -999o2500 ILO -999°2500 OT -999o2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILO -999.2500 OT -999.2500 RHOB -999.2500 NEAT -999.2500 GR -999.2500 ILO --999.2500 DT -999.2500 RHOB -999.2500 NR~T -999.2500 GR -999.2500 ILO -999.2500 OT -999°2500 RHO5 -999°2500 NEAT -999.°2500 GR. -999.250'0 ILO -999°2500 DT -999.2500 EH08 -999.2500 NR,~T -999.250.0 GE - 999.2 S 00 I L D -999. 2500 OT ,-'999' Z$OO RHOB ,-999.2500 NEAT -999°2500 ,GR -999' Z50O ILD -999. 2500 DT RHgB NR AT -g 99"':2500 G:R '-999'2500 - 999' 2500 IL O DT RHOB NRAT GR ILO DT Ri,lOB -'99'9. 2500 RNRA 24o5313 -999.,2500 ILM -999°2500 GR -999°2500 NCNL -999,.2500 RNRA 42.533.3 -999.2500 ILM -999.2500 GR -999.2500 NCNL -999.2500 RNRA 24°5469 -999.2500 ILM -99'9.2500 GR -999.,2500 NCNL -999.2500 RNRA 4'9.0000 -999.2500 ILM -999°2500 GR -999.2500 NCNL -999.25'00 RNRA 3B.4375 -99-9o2500 ILM -999°2500 GR - 999....2500 NCNL -999.2500 RNRA 39°0625 -99'9.2500 ILM -999. 2500 'GR -999.2500 NCNL -999.2500 RNRA 33.7500 -999. 2500 ,ILM -999.2500 GR -999-2500 NCNL -999.2500 RNRA .-999.2500 ILM -999,Z 50'0 GR -999.2500 NCNL -999.,2500 RNRA 3:8- 7500 -99~. 2500 I'LM -999. 2590 GR --999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.250'0 -999.2500 --99'9.2500 -999.2500 --999.2500 -9'99.2500 -999.2500 -999o.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25:00 -999.2500 -999°2500 -999.2500 -999.2500 -9'9'9oZ500 -999-2500 -999.2500 -999,. 250.0 -999. 2590 -999.2500 LVP OlO.H02 VERIFICA'TION :LISTING PAGE 12 FCNL -9'99. 2500 CALI PEF -999,.2500 GR DEPT 4000.0000 SFLU gP -9'99..2500 GR NPHI -999.2500 DRHO FCNL -999.2500 CALI PEF -999.2500 GR DEPT 3900.0000 SFLU SP -999.2500 GR NPHI -999.2500 DRHO FCNL -999.2500 CALI PEF -999.2500 GR DEPT 3800.0000 SFLU SP -999.2500 GE NPHI -999.2500 DRMO FCNL -999.2500 CALI PEF -999.2500 GR OEPT 3700.0,000 SFLU SP -999.2500 GR NPHI -999.2500 ORHO. FCNL -999.2500 CALI PEF -999.2500 GE DEP'T 3600,.0-00'0 SFLU SP -99'~,. 2500 GR NPHI -999° 25,00 DRHO FCNL -999°2500 CALI PEr -999.2500 GR OEPT 3~.0,0.0.000 SFLU SP -99 9.25 OC NPHI -999.250.0DRHO FCNL -999.2500 CALI PEF -999.2500 DEPT 3,~00. 0000 SF LU SP -999,.2500 ~R N P H I - 999' 25 O0 0 R'H O FCNL -999. 2500 CALI PEF -9'9 g. 2'50,0 GR ~EPT 3300°0000 SFLU SP -999.2500 GR NPHI '-~99. 2500 ORMO FCNL --99 9~. 25'00 CALI PEP -999.2500 GR DEPT 32,00.0000 SFLU SP -99'9°2500 GR NPHI -99'9.2500 ORHO -999.2500 NRAT --999.2500 GR -999o2500 ILO -999.2500 OT -999.2500 RHOB -999.2500 ~RAT -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILO --999.2500 OT -999.2500 RHOB -999.2500 NRAT -999.Z500 SR -999.2500 ILD -999.2500 DT -999'2500 RHOB -999.2500 NR~T --999.2500 GR -99'9.2500 ILO -999.2500 OT - 99:9.2500 RHOB -999.2500 NRAT --999-2500 GR -999.2500 -99'9.2500 OT -999.2500 RHOB -999.2500 NRAT -999.2500 GR - 999,,, 2500 IL -999.2500 OT -999' 2500 -999,. 250'0 NRAT '-999o2500 GR --9'99.2500 ILO -999.2500 DT -999-2500 RHOB -999.2500 NRAT -999',2500 GR __-'~:9'9. 2500 ILO 999.2500 ~T -999°2500 RHOB -999.2500 RNRA 43.0313 -999.2500 ILM -999. 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OOOO SFLU SP -993.2530 GR NPHI -999.2500 DEMO FCNL -999.2500 CALI PEF -999.2500 GR -999.2500 ILO -999.2500 DT -999.2500 RHOB -999.2500 NEAT -999.2500 GR DEPT 3000.0000 SFLU SP -99'9.2500 GR NPHI -999.2500 DRHO FCNL -999. 2500 ,gALI PEF -999.2500 GR -999.2500 ILO -999.2500 OT -999.2500 RHOB -999°2500 NEAT -999.2500 GR DEPT 2900.00,00 SFLU SP -999. 250'0 GR NPHI -9'99. 2500 ~CNL -999.2500 CALI PEF -999.2500 -999.2500 ILD -999.2500 DT -999.2500 RHDB -999.2500 NRAT -999.2500 GR DEPT 2800.000'0 SFLU SP -999.2500 GR NPHI -999.2500 DEMO FCNL -999.2500 CALT PEF -999.2500 GR -999.2500 ILD -999.2500 DT -999.2500 RHOB --999.25.00 NRAT -99'9.2500 GR DEPT 2700.0000 SFLU SP -999.2500 GE NPHT -999. 2500 DRHO FCf~L -999,. 2500 CALI ~EF -999.2500 ~R -999.2500 [LO -999.2500 DT - 99,9.250,0 -'999. 2500 ~RAT -999.2'500 OEPT 2600,. 0000 SFLU SP -999.2500 GR NPHI -'999. 2500 DRRO FCNL -999,,,2500 CAL! PEF -999.25:00 GR -999.Z500 IL.D -999.25000 DT -999'250 EM05 -999.2500 NEAT -999,, 2500 GR OEPT 2500.0000 SFLU SP -999.2500 GR NPHI -999.2500 FCNL -'999.2500' CAL! PEP --999.2500 -:99'9,- ,Z 5 O0 I L 8 -999.2500 BT --999'2500 RHgB -999. 250:0 NEAT -:999,, Z 5 O0 GR OEPT 2&O0-'O'O'O'O S'FLU SP -999.2500 GR NPHI --r99'9'2500 FCNL -999°2500 CALI PEF -999.2500 GR 9EPT 23~loSO'O,O SFLU SP -999.2500 GE NPH! -999.25'00 O'R~O - 9 99.. 250.0 . I L D, -999.2500, DT - 999.25-00 RHOi8 -999. 2500 RNRA 39.1562. -999-2500 ILM -999.2500 GR -999.2500 NCNL -999.2500 RNRA 35.2813 -99'9.2500 ILM -999.2500 GR -999.2500 NCNL -999.Z500 ~N~A 35.3750 -999.2500 ILfl -999.,.2500 GR -999,.2500 NCNL -999.2500 RNRA 33.1250 -999.2500 -99~.2500 GR -999.2500 NCNL -999.2500 ~NRA ~0o'1875 -999.2500 ILM -999.2500 GR -999.2500 NC. 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