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Home My WebLink About190-1691 Carlisle, Samantha J (CED) From:Wallace, Chris D (CED) Sent:Tuesday, August 31, 2021 8:08 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 09-40 (PTD #1901690) failed MIT-IA From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, August 30, 2021 4:21 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>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 09‐40 (PTD #1901690) failed MIT‐IA Mr. Wallace, Injector 09‐40 (PTD #1901690) was Under Evaluation for TxIA communication. On 08/16/21 Slickline set a dummy SSSV and performed a failing MIT‐IA. A leak detect log has been planned to find the source of the TxIA. The well will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, August 3, 2021 5:10 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: UNDER EVALUATION: Injector 09‐40 (PTD #1901690) possible TxIA communication Mr. Wallace, Injector 09‐40 (PTD #1901690) has been shut‐in since March, 2019. An attempt was made to put it online today. During the start‐up, the IA pressure was bled more than what is expected for thermal expansion effects. The well was shut‐in and will now be classified as UNDER EVALUATION for up to 28 days for diagnostic work. Plan Forward: 1. DHD: PPPOT‐T 2. Fullbore: Offline MIT‐IA 3. Well Integrity: Additional diagnostics as needed 2 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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. Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, August 3, 2021 5:10 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Oliver Sternicki; John Condio - (C); Alaska NS - PB - Field Well Integrity; Aras Worthington Subject: UNDER EVALUATION: Injector 09-40 (PTD #1901690) possible TxIA communication Attachments: 09-40.pdf Mr. Wallace, Injector 09-40 (PTD #1901690) has been shut-in since March, 2019. An attempt was made to put it online today. During the start-up, the IA pressure was bled more than what is expected for thermal expansion effects. The well was shut-in and will now be classified as UNDER EVALUATION for up to 28 days for diagnostic work. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT -IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWellIntegrity@hilcorp.com> Sent: Monday, July 19, 2021 7:46 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Oliver Sternicki; Aras Worthington Subject: OPERABLE: Injector 09-40 (PTD #1901690) Surface repairs complete Mr. Wallace, Injector 09-40 (PTD # 1901690) surface repair work is complete and the well is ready to be put on injection post FS2 shutdown. The well is now classified as OPERABLE and AOGCC MIT -IA will be performed when the well is on stable injection. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ry_an.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 27, 2019 2:49 PM,,, To: 'chris.wallace@alaska.gov' <chris.wa1fi4ce@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK,'`OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS'P.rod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS -,Well Pad HUQ <AKOPSWellPad HUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPad LV@bp.com>; AK, OPS Well Pad M'1\( <AKOPSWeIIPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWE,LLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWLLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAneaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt`E,ngr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duonggbp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Thompson; Ryan <RYAN.THOMPSON@bp.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>``--. Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelldntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@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.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; 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: NOT OPERABLE: Injector 09-40 (PTD #1901690) will lapse on AOGCC MIT -IA due to surface repairs Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 27, 2019 2:49 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W, AK, OPS Well Pad Z, Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek; Peru, Cale; Thompson, Ryan; Wellman, Julie; Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Arras J Subject: NOT OPERABLE: Injector 09-40 (PTD #1901690) will lapse on AOGCC MIT -IA due to surface repairs All, Injector 09-40 (PTD # 1901690) is due for its 4 -year AOGCC witnessed MIT -IA by the end of the month. Surface repairs will not be completed before the well will lapse on the required AOGCC MIT -IA. The well is now classified as NOT OPERABLE for tracking purposes until it can be placed on injection and an AOGCC witnessed MIT -IA can be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,May 13,2015 Jim Regg I P.I.Supervisor i\e b 1c SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC 09-40 FROM: Lou Grimaldi PRUDHOE BAY UNIT 09-40 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,)— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-40 API Well Number 50-029-22118-00-00 Inspector Name: Lou Grimaldi Permit Number: 190-169-0 Inspection Date: 5/10/2015 Insp Num: mitLG150510195136 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - ------- - ---- ,ep j 09-40 Type Inj w TVD 8662 Tubing 1890 - 1903 - 1903 - 1857 - PTD 1901690 Type Test SPT Test psi 2166 - IA 709 2501 • 2477 - 2466 Interval 4YRTST P/F P OA 393 547 • li 541 535 —Notes: 4 I bbl's diesel pumped,4 0 returned.Good test.All required paperwork supplied prior to test. A 1-levja rssi.0- ( AA 9 wane (,Je SCANNED .JIJL 1 0 201`' Wednesday,May 13,2015 Page 1 of 1 • r-1 1r, Czis• ,.• • • • • • • ;14 • • • • • • • • • • • • • • • • Ur.; • • U/ • • • • • • -Y-: • • • TREE= FMC SAFE .JOTES:H2S READINGS AVERAGE 125 ppm - WELLHEAD= FMC 09-40- - WHEN ON MI. ACTUATOR= OTIS KB.ELEV= 52' BF. ELEV= ? KOP= 1600' Max Angle = 60'@ 8000' Datum MD= 14037' Datum TVD= 8800'SS 1 2213' 1-14-1/2"OTIS HRQ SSSV NIP,1D=3.813" 10-3/4"CSG,45.5#,J-55,ID=9.953" H 4160' Minimum ID = 2.37" @ 10600' 4-1/2" BKR PATCH r 10600°-10630' —14-1/2"BKR PATCH(05/11/07), ID=2.37" 4-1/2"TBG-IPC, 12 6#,L-80, .0152 bpf,ID=3.958" H 13676' TOP OF 3-1/2"TBG-IPC H 13676' 13676' _—14-1/2"X 3-1/2"XO 13684' _—i3-112"OTIS LOC SEAL ASSY >f</-1 13686' —17-5/8"X 3-1/2"OTIS BWP PKR TOP OF 5-1/2"LNR —I 13756' --T• ' 13785' -13-1/2"OTIS XN NO-GO NIP, ID=2.75" 13792' H3-1/2"OTIS SOLID NOSE SHEA ROUT SUB 3-1/2"TBG-IPC,9.3#,L-80, .0087 bpf,ID=2.992" —{ 13794' 13794' -i3-1/2"TUBING TAIL 13782' —I ELMD TT LOGGED 03/19/91 7-5/8"CSG,29 7#,L-80,ID=6.875" —1 14086' I PERFORATION SUMMARY REF LOG: BHCS ON 02/12/91 ANGLE AT TOP PERF:57°@ 14038' Note Refer to Production D8 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 8 14037- 14040 0 06/13/95 2-1/8" 14 14040- 14060 0 ' 12/24/96 2-1/2" 4 14060- 14083 O 03/19/91 2-1/8" 10 14083- 14085 0 03/31/95 2-1/8" 10/16 14085- 14105 0 " 12/24/96 2-1/2" 4 14105- 14132 O 03/19/91 PBTD H 14249' 111111 111111111111111 5-1/2" LNR, 17#,L-80, .0232 bpf, ID=4.892" —1 14297' i�iiiiiiii DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03103/91 ORIGINAL COMPLETION 05/11/07 GJB/PAG SET BKR PATCH @ 10600' WELL '09-40 11/29/01 RN/TP CORRECTIONS 01/11/12 TMN/JMD ADDED H2S SAFETY NOTE PERMIT No `1901690 02/07/03 JMP/KK WAIVER SAFETY NOTE AFI No. 50-029-22118-00 11/30/03 ATIYTLP"CSG CORRECTION SEC 1, T1ON, R15E,3754.57'FEL&1335.74'FNL 09/05/05 DAV/PJC SSSV CORRECTION 11/12/05 RP1-1fPJC WAIVER SFTY NOTE DELETED BP Exploration(Alaska) RECEIVED STATE OF ALASKA AUG 3 0 2012 e . ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Lf Repair Well U Plug Perforations U Perforate L] Other U Brightwater Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ � 190 -169 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 5 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22118 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: - ADL0028343 PBU 09-40 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 14296 feet Plugs measured None feet true vertical 8989.73 feet Junk measured None feet Effective Depth measured 14249 feet Packer measured See Attachment feet true vertical 8965.05 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20" 91.5# H -40 34 - 113 34 - 113 1490 470 Surface 4127 10 -3/4" 45.5# J -55 33 - 4160 33 - 3657.85 3580 2090 Intermediate None None None None None None Production 14054 7 -5/8" 29.7# L -80 32 - 14086 32 - 8878.75 6890 4790 Liner 541 5 -1/2" 17# L -80 13756 - 14297 8699.8 - 8990.26 7740 6280 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet , :)} _. i "∎ , Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service El ` Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL U GSTOR ❑ WINJ 0 _ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerha s / Title petrotechnical Data Technician • : — �f Phone 564 -4035 Date 8/30/2012 �— ft L Form 10-404 Revised 10/2010 ®MS AUG 31 1Q `�` � `� Submit Original Only , TA • • Daily Report of Well Operations ADL0028343 ACTIVITYDATE 1 SUMMARY T /I /O = 1759/760/300 Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4200 bwpd. Shut down for pigging operation. Pumped 17 gal. EC9360A (Surfactant) Pumped a total of 17 gal. since start of project. Pumped 20 gal. EC9398A ( Polymer) Pumped a total of 20 gal, since start of project 7/23/2012 ** *WSR Continued on 07/24/2012 * ** T /1 /0 = 1786/740/260 "`Continued WSK from 07- 23- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 4200 bwpd. Pumped 339 gal. EC9360A (Surfactant) Average of 15.95 gph for 21.25 hrs. Pumped a total of 356 gal. since start of project. Pumped 1663 gal. EC9398A ( Polymer) Average of 78.25 gph for 21.25 hrs. Pumped a total of 1683 gal. since start of project 7/24/2012 ** *Continued on WSR 07/25/2012 * ** 111 /0 = 1898 /150/320 """`Continued - WSR from 07- 24- 2012 *"* Temp =Hot (Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 4100 bwpd. Pumped 372 gal. EC9360A (Surfactant) Average of 15.5 gph for 24 hrs. Pumped a total of 728 gal. since start of project. Pumped 1695 gal. EC9398A ( Polymer) Average of 70.625 gph for 24 hrs. Pumped a total of 3378 gal. since start of project 7/25/2012 ** *Continued on WSR 07/26/2012 * ** 171/0 = 1871/7307300 """`Continued WSR from 0/- 25- 2012"""' Temp =Hot (Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4100 bwpd. Pumped 190 gal. EC9360A (Surfactant) Average of 13.1 gph for 14.5 hrs. Pumped a total of 918 gal. since start of project. Pumped 777 gal. EC9398A ( Polymer) Average of 53.5 gph for 14.5 hrs. Pumped a total of 4155 gal. since start of project Shut down due to well injection rates being to low, Standby for DSO to increase injection rate. 7/26/2012 ** *Continued on WSR 07/27/2012 * ** 1"/1 /0 = 1790/100/240 """Continued WSR from 07- 26- 2012'"' Temp =Hot (Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4100 bwpd. Pumped 0 gal. EC9360A (Surfactant) Average of 0 gph for 24 hrs. Pumped a total of 901 gal. since start of project. Pumped 0 gal. EC9398A ( Polymer) Average of 0 gph for 24 hrs. Pumped a total of 4155 gal. since start of project Could not get well injection to stabilize, Injection rates would drop off and rise dramatically. Worked with DSO to try to stabilize well and was unable to get well to stabilize 7/27/2012 ** *Continue to 07 -28 -2012 WSR * ** f /1 /0 = 1725 /680 /280 'Continued WSR from 07 -27- 2012 * ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Standby for well to stabilize 7/28/2012 ** *Continued on WSR 07/29/2012 * ** T/I/0 = 1956/650/200 "'Continued WSR from 07- 28- 2012 * ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 4100 bwpd. Pumped 105 gal. EC9360A (Surfactant) Average of 19.4 gph for 5.41 hrs. Pumped a total of 1023 gal. since start of project. Pumped 303 gal. EC9398A ( Polymer) Average of 56 gph for 5.41 hrs. Pumped a total of 4458 gal. since start of project 7/29/2012 ** *Continued on WSR 07/30/2012 * ** • • f /I /O = 1894 /600 /200 ** *Continued WSR from 07- 29- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Standby for well to stabilize. 7/30/2012 ** *Continued on WSR 07/31/2012* ** f /1 /0 = 1784/600/200 ** *Continued WSR from 07- 30- 2012*** Temp =Hot (Brightwater Reservoir Sweep Mod) Standby for well to stabilize 7/31/2012 ** *Continued on WSR 08/01 /2012*** f /1 /0 = 1730/600/200 * *"Continued WSR from OT -31- 2012" ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4100 bwpd. Pumped xx gal. EC9360A (Surfactant) Average of roc gph for 24 hrs. Pumped a total of roc gal. since start of project. Pumped xx gal. EC9398A ( Polymer) Average of roc gph for 24 hrs. Pumped a total of roc gal. since start of project 8/1/2012 ** *Continued on WSR 08/02/2012 * ** 1 1/1 /0 = 1730/600/200 ***Continued WSR from 07- 31- 2012 * ** Temp =Hot (Bnghtwater Reservoir Sweep Mod) 8/1/2012 Job canceled. Riged down. FLUIDS PUMPED GALS 1023 EC -9360A SUFACTANT 4458 EC -9398A POLYMER 5481 TOTAL • • Perforation Attachment ADL0028343 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 09-40 3/19/91 PER 14037 14132 8852.36 8903.34 09-40 6/13/95 RPF 14037 14057 8800.36 8811.15 09-40 12/24/96 RPF 14040 14060 8801.98 8812.77 09-40 3/31/95 RPF 14083 14103 8825.14 8835.86 09-40 12/24/96 RPF 14085 14105 8826.21 8836.93 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028343 SW Name Type MD TVD Depscription 09-40 PACKER 10600 7006.56 3 -1/2" WF Patch Packer 09-40 PACKER 10630 7023.12 3 -1/2" WF Patch Packer 09-40 PACKER 13686 8609.65 3 -1/2" Otis BWP Packer r Casing / Tubing Attachment ADL0028343 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 91.5# H -40 34 - 113 34 - 113 1490 470 LINER 541 5 -1/2" 17# L -80 13756 - 14297 8699.8 - 8990.26 7740 6280 PRODUCTION 14054 7 -5/8" 29.7# L -80 32 - 14086 32 - 8878.75 6890 4790 SURFACE 4127 10 -3/4" 45.5# J -55 33 - 4160 33 - 3657.85 3580 2090 TUBING 13645 4 -1/2" 12.6# L -80 31 - 13676 31 - 8656.2 8430 7500 TUBING 118 3 -1/2" 9.3# L -80 13676 - 13794 8656.2 - 8720.47 10160 10530 • • TRE = FMC • S NOTES: H2S READINGS AVERAGE 125 ppm WELLHEAD = FMC WHEN ON MI. ACTUATOR = OTIS 09-40 KB. ELEV = — -- 52' BF. ELS/ = KOP= 1600' Max Angle = 60° Oa 8000' KAmA/0 = 14037' Datum TVD = 8800' SS J 2213 H4-1/2" OTIS HRQ SSSV MP, ID 3.813" (10-3/4» CSG, 45.5#, J-55, ID = 9.953" H 4160 Minimum ID = 2.37" @ 10600' 4-1/2" BKR PATCH I 10600%10630' H4-1/2" BKR PATCH (05/11/07), ID = 2.37" I 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 13676' I 13676' j--I4-1/2" X 3-1/7' X0 I I TOP OF 3-1/2" TBG-IFC H 13676' 1 13684' J-13-1/2" OTIS LOC SEAL ASSY 1 13686' H7-5/8" X 3-1/2" OTIS BWP PKR 1 I TOP OF 5-1/2" LNR H 13756' 1 • 13785' H3-1/2" OTIS XN NO-GO NIP, ID = 2.75" I 1 13792' H3-1/2" OTIS SOLID NOSE SHEA ROUT SUB I (31/2" TBG-IPC, 9.3#, L-80, .0087 bpf, ID = 2.992" H 13794' I X Fr371I14' — 3-1/2" TUBING TAIL I 1 13782' H ELMD TT LOGGED 03/19/91 1 (7-5/8" CSG, 29.7#, L-80, ID = 6.875" H 14086' I • 1 PERFORATION SUMMARY REF LOG: BHCS ON 02/12/91 ANGLE AT TOP PERF: 57° @ 14038' Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 2-1/8" 8 14037 - 14040 0 06/13/96 2-1/8" 14 14040 - 14060 0 12/24/96 2-1/2" 4 14060 - 14083 0 03/19/91 2-118" 10 14083 - 14085 0 03/31/96 2-1/8" 10/16 14085 - 14105 0 12/24/96 2-1/2" 4 14105 - 14132 0 03/19/91 P8TD 14249' I ••••••• (5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" H 14297. DATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/03/91 ORIGINAL COMPLETION 05/11/07 GJB/PAG SET BKR PATCH (0 10600' 1NELL:139-40 11/29/01 RNITP CORRECTIONS 01/11/12 TMNIJMD ADDED I-QS SAFE1Y NOTE PERMIT No: '1 901690 02/07/03 JMPIKK WAIVER SAFETY NOTE AR No: 50-029-22118-00 11/30/03 ATD/TLP CSG CORRECTION SEC 1, T1ON, R15E, 3754.5T FEL & 1335.74' FNL 09/05/05 DAV/PJ0 SSSV CORRECTION 11/12/05 RPFVPJC WAIVER SFTY NOTE Da.ETED BP Exploration (Alas ka) • 0 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 -. _--- - Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5tAINEDFEB 2 a Z0 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission q o - 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 1 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09-12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09-14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09-16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09-17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09-19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09-21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09-22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10202011 09-25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09-29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09 -34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 1.2 NA 11.9 7/172010 - 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 , 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 10.2 7/18/2010 09-17 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 , 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 Dust Cover _ NA NA NA 3.4 10/20/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 22, 2011 TO: Jim Re 4 P.I. Supervisor / SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09 -40 FROM: John Crisp PRUDHOE BAY UNIT 09 -40 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .�L- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 09 - 40 API Well Number: 50 029 - 22118 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCrl 10517115504 Permit Number: 190 - 169 - Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial p 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -40 Type Inj. T w .I TVD 8662 - IA T 610 2410 • 2380 2380 - P.T.D 1901690 ' 1 SPT jest psi 2165 - OA 180 320 320 320 Interval 4 1' RT S T r p/F P - Tubing 1700 1700 1700 1700 Notes: 8.3 bbls pumped for test. - Wednesday, June 22, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 18, 2011 TO: Jim Regg 52 - 3 I I / ( SUBJECT: Mechanical Integrity Tests P.I. Supervisor � 1 - j� 1. g n' l BP EXPLORATION (ALASKA) INC 09 -40 FROM: John Crisp PRUDHOE BAY UNIT 09 -40 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry J NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 09 - 40 API Well Number: 50 029 - 22118 - 00 - 00 Inspector Name: John Crisp - Insp Num: mitJCr110517115504 Permit Number: 190 - 169 - Inspection Date: 5/13/2011 Rcl Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 09 -40 = Type Inj. W ' TVD i 8662 - IA 610 2510 1 2480 2480 - ' P.T.D[ 1901690 ' I TypeTest ! SPT T e s t ps 1 2165 "1 OA ' 180 320 320 320 -- ( - - Interval 4YRTST � - P/F P ` Tubing � 1700 1700 1700 1 1700 Notes: 8.3 bbls pumped for test. i ji M.A 2 6 20iF Wednesday, May 18, 2011 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: JimReggí'7v, 7(17(07 P.t Supervisor I~~ DATE: Tuesday, July 03,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-40 PRUDHOE BAY UNIT 09-40 Src: Inspector \ ~ 0 ~ ¡too¡ Reviewed By: P.I. Suprv :1ß¡e..- Comm FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-40 API Well Number: 50-029-22118-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG070529 143844 Permit Number: 190-169-0 Inspection Date: 5/29/2007 Rei Insp Num: Packer Depth ""( Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- I I . I I I I ì Well 09-40 ¡Type Inj. ! W i TVD 8662 I IA ! 1010 2300 ¡ 2240 2230 I I ¡ I, I +---- P.T.D! 1901690 ITypeTest I SPT ! Test psi ! 2165.5 OA I 260 260 i 260 260 I I i I _~n ~ - Interval 4YRTST PIF P /' Tubing i 1470 1440 i 1440 1440 i I I --~~- Notes: 3.5 bbl's pumped, all fluid returned. Post patch installation test. Good test. ./ 5Q\NNED JUL 2 0 Z007 Tuesday, July 03,2007 Page I of I . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emailto:Winton_Aubert@admin.slale.ak.us;BobJleckenslein@admin.sIaIe.ak.us;Jim_Regg@admin.slale.ak.us;Tom_Maunder@admin.slale.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudoe Bay I PBU I OS 09 05129107 Anna Cube Lou Grimaldi \qó~lhq Packer Depth Pretest Initial 15 Min. 30 Min. Well109-4O I Type Inj. I W TVD I 8,662' Tubing 1470 1440 1440 1440 IntelVall 4 P.T.D.11901690 I Typetest I P Test psi I 2166 Casing 1010 2300 2240 2230 p/FI P Notes: AOGCC Witnessed MlT-1A post patch OA 260 260 260 260 restoring tubing integrity Weill Type Inj. I I TVD I Tubing Interval! PT.D.I Type test I I Test psi Casing p/FI Notes: OA Weill I Type Inj. I TVD I Tubing I IntelVall P.T.D.I I Type test I Test psi Casing P/FI Notes: OAI I Weill I Type Inj.1 I TVD I Tubing I Interval I P.T.D.I I Type test I I Test psi I Casing I P/FI Notes: OAI Weill I Type Inj.1 I TVD I Tubing IntelVall P.T.D.I I Type testl I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W=Water MIT Report Form BFl 911105 TYPE TEST Codes M = Annulus Moni1Dring p = Standard Pressure Test R = Internal Radioactive Tracer Survey A = T emperat.ure Anomaly Survey D = Differential T emperat.ure Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) S~e.D JUN 1 2 2007 MIT PBU ~ 05-~7.xls ii"CCL.r STATE OF ALASKA ~ MAY 2 1 2007 ALA A OIL AND GAS CONSERVATION COMN SION s-~-o~ REPORT OF SUNDRY WELL OPE~7Qc~ Cons. Commission 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulated er ~ PATCH TUBING Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~] Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~ 19o-lsso' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22118-00-00 " 7. KB Elevation (ft): 9. Well Name and Number: 52 KB < PBU 09-40 8. Property Designation: 10. Field/Pool(s): ADLO-028343 ~ Prudhoe Bay Field! Prudhoe Bay Pool - 11. Present Well Condition Summary: Total Depth measured 14296 - feet Plugs (measured) None true vertical 8989.73 ' feet Ju n k (measured) None ~~ pp,,~~ t Effective Depth measured 14249 feet ~j~ ~~ C19~~~ ~cJ~ ~t. ~~~~ true vertical 8965.05 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 34 - 113 34 - 113 1490 470 Surface 4127 10-3/4" 45.5# J-55 33 - 4160 33 - 3657.85 3580 2090 Production 14054 7-5/8" 29.7# L-80 32 - 14086 32 - 8878.75 ,6890 4790 Liner 541 5-112" 17# L-80 13756 - 14297 8699.8 - 8990.26 7740 6280 Perforation depth: Measured depth: 14037 - 14132 ,_ True Vertical depth: 8852.36 - 8903.34 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 32 - 13676 3-112" 9.3# L-80 13676 - 13794 Packers and SSSV (type and measured depth) 3-1/2" Otis BWD Packer 13686 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: ~ ~ ~ ~ ~ ~ ~ ~ Intervals treated (measured): ^ ~ ~ ~- ~cre- ~.. -~ c~.yi~~-~ ~t~. p~- ;~-~ ~S' Treatment descriptions including volumes used and final pressure: ~ ~ ~y)/j t~ ~ r t 13. Representative Daily Average Production or In}ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN 0 0 0 0 Subsequent to operation: SHUT-IN 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/16/2007 Form 10-404 Revised 04/2006 ;""_; ~ ~, gq F Submit Original Only ~V} ~ ~ ~ r~ /"'i ~ - r< w'41~~Y. Gib.` .~ 2~Q1 • 09-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTfV1TYDATE SUMMARY -- 5/9/2007 T!I!O = 650/6601260. Assist Slickline on brush and flush FWHP=1500/740/260 5/9/2007'*** WELL S/I ON ARRIVAL.**'` `RIH W/ 4.5" BLB, 3.80" G-RING SD C«~ 9633' SLM. *** UNABLE TO PASS THROUGH*** BRUSH 10500' -10700' SLM W/4.5" BLB. 3.75" G-RING. `LRS PUMPED AWAY 245 BBLS OF DIESEL. '***JOB COMPLETE, NOTIFIED DSO, WELL S/I ON DEPARTURE.*** 5/11/2007 "** WHP: 50/600/250 PSI *** WELL SHUT IN UPON ARRIVAL. RIH WITH E-LINE /BAKER 4.5" X 30' PATCH !' TO 10820'. MAX O.D. = 3.7" "SET PATCH FROM 10600' TO 10630' ELEMENT TO ELEMENT. '=OAL = 36.5', MIN ID = 2.37" 'FINAL WHP: 50/600/250 PSI *** ?PAD OPERATOR NOTIFIED UPON DEPARTURE. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL · . WELL LOG TRANSMITTAL RECEIVED ProActive Diagnostic Services, Inc. AUG 2 9 2006 I\laska Oil & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1J EDE Disk 2) 3) 4) 5J 6) 7J OS 09-40 06-Jul-06 Leak Detection - WLD S<;J.\NNED AUG 3 0 2005 Signed: C Qþp--- Date: 7J/8~! /)(~ Print Name: etA r ~ -h IÅ Q (11 oj ,u-LLP (A PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAil: PDSANCHORAGE@MEMORYlOG.COM WEBSITE : WWW.MEMORYlOG.COM UTe- tqO-1 foD, .b l'f07-S- C:IDocmnents and SettingsIPDS Anchorage - MPLIDesktoplTransmit_ Original.doc e e O,bP /.".~..~....... BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 November 15, 2005 RECEIVED NQV 2 3 2005 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: 09-40 (PTD'~ Application for Cancellation of Sundry #301-350 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 301-350. The sundry was for continued water injection with TxlA communication. The well will remain shut-in in preparation of an administrative approval. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, )It( ~ Joe Anders, P. E. Well Integrity Coordinator ~CANNEG DEC 1. ($ 2005 Attachments Application for Sundry Cancellation form 1 0-40..4 N .. STATE OF ALASKA ALAS-=>IL AND GAS CONSERVATION COMMeoN REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 52 KB 8. Property Designation: ADL-028343 11. Present Well Condition Summary: Total Depth measured 14296 true vertical 8989.73 Effective Depth measured 14249 true vertical 8965.05 Casing Conductor Surface Production Liner Length 79 4127 14054 541 Size 20" 91.5# H-40 10-3/4" 45.5# J-55 7-5/8" 29.7# L-80 5-1/2" 17# L-80 Perforation depth: Measured depth: 14037 - 14132 True Vertical depth: 8852.36 - 8903.34 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic feet feet feet feet MD 34 - 113 33 - 4160 32 - 14086 13756 - 14297 4-1/2" 12.6# 3-1/2" 9.3# 3-1/2" Otis BWD Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders / Anna Dube Printed Name Joe Anders, P.E. t"<t:lit:.IV1=U NOV ~ 3 ZDOS issi Stimulate D WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 190-1690 P1 6. API Number: 50-029-22118-00-00 9. Well Name and Number: 09-40 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) None None TVD Burst Collapse 34 - 113 1490 470 33 - 3657.85 3580 2090 32 - 8878.75 6890 4790 8699.8 - 8990.26 7740 6280 L-80 L-80 32 - 13676 13676 - 13794 13686 RBDMS 8Ft NOV 2 :1 2005 Tubing pressure o o Service P1 WINJ P1 WDSPL Sundry Number or N/A if C.O. Exempt: 301-350 Title Well Integrity Coordinator Date 11/15/2005 RE: 09-40 Reclassified from Waiver to Trouble e e -lL fTb I cr o-{ b Ct Sub.jeet: RE: 09-40 Rcclassificd from Waiver to Trouble From: "NSU, ADW Wclllnlcgrily Enginecr" <;-"'¡SL^DWWeIlJnlcgrityEngincer(f~}ßP.com> D~1tc: Sal, 12 No\" 2005 10:44:08 -0900 To: "Rossbcrg, R Steven" <RossbcRSC«BP.com>, "Engel, I"larry R" <EngclHR@BP.com>, NSUAD\VWcIIOpcrationsSupervisor@BP.com, "GPß, FS2 DS Ops Lcad" <:GPBFS2DSOpsLcad@BP.com>, "GPB, FS2/COTU Arca Mgr" <GPBFS2TL@BP.com>, "lmch, Victoria 'I <imchvI@BP.com>, "GPB, Optimization Engr" '<GPBOptimizationEngr@BP.com>, "GPB, Wells Opt Eng" <GPHWcllsOptEng@HP.com>, jimJcgg@admill.stale.ak.us, ...-:/7/( 1"3)IÎŠ winton_auhcI1(Z(:admin.slalc.ak.lIs \c..en CC: "Frazicr, Nicholas B" <fraznb@I3P.com>, "Hughes, Andrea (VECO)" <hugha4(£l?BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holl@BP.com>, "Recvcs, Donald F" <Rec"csD/(qjBP.com>, "NSlJ, ADW Well Integrity Engineer" <NSlJADWWelllntegrityEnginccr@BP.com>, "Rcese, Brent R." <recsbr@ßP.com> .iW.:IN(j Helloal!. Well 09-40 has been reclassified from Waiver to Trouble. A passing MITOA is required under the current waiver requirements and the current waiver is no longer applicable. FS2 Lead Operator, would you please ensure any waiver related signage is removed from the wellhouse. Ryan, would you please prepare a 10-404 to cancel the Sundry. Please call if you have any questions. Joe 1-907-659-5102 ;j(.;t\~~~fSLi " (' f.D ,,,,:,: From: Reeves, Donald F Sent: Saturday, October 29,20057:33 PM To: NSU, ADW Well Integrity Engineer Cc: Winslow, Jack L.; Luckett, Ely Z. (VECO) Subject: 09-40 waiver cancellation Hi Anna, Injector well 09-40 needs an OA Dwn squeeze to pass an MITOA before a new waiver can be written. I recommend the old waiver be cancelled until the OA downsqueeze is successful. The old waiver will have to be cancelled anyway. Currently the well is secured with a standing valve. ~ Thanks, Donald Reeves Well Integrity Engineer (907) 659-5525 (907) 659-5100 #1923 Pgr 1 of 1 12/13/2005 10:21 AM , f:\ ' '~f=ì ni 'I~ll'~T i?r' " \\" . :', i !!I~ \. I I : I" '. '",- I: 'if',I, ,I : ~ ~"~ ~\ ¡ ¡ / u \, ¡.! ': ¡ 'QV !.,J Lito. U Lb ) ¡fl' ~U',~,I :,I'Þ''-,ì...] II ~1¡~ \ I!' : ,-~ (Æ"l\\' [I'" I,"'¡'¡ 'W" " ' , ' ) II ;1 " , ! I I : , ~ I . ,/':" 'I .~~~~.' ~;.u¡~t {. i : /7'::""::\ \\U """"'''',, (l2) ,íj"\ J ~\'~ /J.J \ IT\J FRANK H. MURKOWSKI, GOVERNOR AIJASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. -rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 " \tA \,,\V Re: PBU 09-40 Sundry Number: 305-320 ~HEl! NO" () 2 21\\)~ Dear Mrs. Julian: , . . 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ DATED thisjPday of October, 2005 Encl. 1. Type of Request: C/4/o.W'· 05' '\ STATE OF ALASKA PN ~() 1\0 Is' ALl l.A OIL AND GAS CONSERVATION COMMk....~!ON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U / Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 WC¡~ËCE/IVED OCT 1 9 2005 Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend U Repair well 0 Pull Tubing D .AIMMrQ!!J& Gas C(m~~~~Jss¡Qn Stimulate D Time Extension D Anchorage Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 190-1690 / Perforate U Anchorage, AK 99519-6612 7. KB Elevation (ft): SerVi~ ø 6. API Number: 50-029-22118-00-00 / 9. Well Name and Number: 52 KB 09-40 // 8. Property Designation: ADL-028343 11. Total Depth MD (ft): 14296 Total Depth TVD (ft): 8989.73 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14249 8965.05 Plugs (measured): Junk (measured): None None Burst Collapse 113 1490 470 3658 3580 2090 8879 6890 4790 8990 7740 6280 Casing Length Size MD ~' TVD Conductor 79 20" 91.5# H-40 34 113 34 Surface 4127 10-3/4" 45.5# J-55 33 4160 33 Production 14054 7-5/8" 29.7# L-80 32 14086 32 Liner 541 5-1/2" 17# L-80 13756 14297 8699.8 Perforation Depth MD (ft): 14037 - 14132 <I" Perforation Depth TVD (ft): 8852.36 - 8903.34 Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Tubing MD (ft): 32 - 13676 Packers and SSSV Type: 3-1/2" Otis BWD Packer Packers and SSSV MD (ft): 13686 ./ 12. Attachments: Descriptive Sum m ary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ ~ Service ~ ,...' Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Na~ I Je~'fer Julian Title Wells Engineer Signature \... tJV\. ~ Phone 564-5663 C J' COMMISSION USE ONLY 10/31/2005 Abandoned 0 /' WDSPL 0 Contact Prepared by Sharmaine Vestal 564-4424 Jennifer Julian Date 10/17/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: CÐ5 ~ 3~O Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: COMMISSIONER APPROVED BY THE COMMISSION Date: 'ff~ Ap '--- r'~ 0--\'., l' ('","ï"", , Nt A L ~ \ 'l ,~l RBDMS BFl OCf 2 1 Z005 Submit in Duplicate bp ...,... ..'f'" ,I". . . '- .. I. ,. "',.,~- ) ) To: J. Bixby/ D. Cismoski Well Operations Team Leader Date: October 17, 2005 From: Janet Sack Design Engineer Subject: 09-40i OA Cement DownsQueeze Procedure PBD09WL40-N Est. Cost: $22M lOR: 500 BOPD Please downsqueeze the OA as described in the following procedure. This 'procedure includes the following steps: Step Type Procedure 1 FMC PPPOT-T 2 FP Depress OA FL to shoe Pending PPPOT - T results 3 FP OA cement downsqueeze 4 FP MIT OA cement downsqueeze after WOC /,- 09-40i is a PWI that is waivered for slow TxlA communication. On 09/08/05 it failed a MITOA to 2500 psi with a LLR of 2 bpm @ 2100 psi. The well passed a CMIT-TxIA to .,--- 2500 psi on 09/19/05. This program is designed to ensure communication is not through the wellhead. If communication is not through the wellhead, we will pump a column of cement from the shoe to approximately 500' above the shoe in order to obtain a waiver and AA for TxlA .-/ communication. The procedure includes the following major steps: 1. DHD 2. DHD Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. OA Downsqueeze M IT OA after waiting on cement. 3. 0 4. 0 If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Sack V.lmeh ') ) JOB PLANNING DETAILS: > 10/30/04: LLR IA = .75 gpm @ 2500 psi > 05/09/05: PPPOT-IC Passed to 3000 psi > 08/14/05: LLR IA = 0.04 gpm @ 2500 psi > 09/08/05: SET 3 1/2" STANDING VALVE @ 13773' SLM. CMIT-TxIA Passed to 2500 psi, MITOA Failed - LLR = 2 bpm @ 2100 psi > 09/19/05: CMIT-TxIA Passed to 2500 psi, AOGCC witness Jeff Jones Well has TxlA communication. OA= 10-3/4" 45.5# L-80 IA= 7-5/8" 29.7# L-80 Shoe at 4160' OAxlA Annular Capacity=.0397 bbls/ft Volume to shoe = 165 bbls 500' of cement = 20 bbls Displacement= 165 -5 (H20 spacer) - 20 (cement) - 5 (H20 flush) = 135 bbls ",/ Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 135 bbls at 30-60 degree F Crude: (volume needed to load OA) OS CW1 01: .1.Q bbls Arctic Set 1 Cement (15.7 ppg): 20 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): 1. PPPOT-T. Well has an FMC wellhead. Contact Jennifer Julian with results. DHD/FB: 2. Depress OA FL w/ AL per PE Guidelines. 3. Shoot FLs and record WHPs. 4. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 5. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping ) ) 6. Hold a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. 7. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 8. If well has IA x OA communication (well has not shown this communication to /' date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. 9. Flood lines with warm fresh water and pressure test lines to 3000 psi. 10. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent / times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. -250 barrels of 80° freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 20 barrels of 15.7 ppg Arctic Set 1 cement / f. 5 bbls of fresh water flush g. 135 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 125 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 11. Shut down pumps and leave the well SI. Please DO NOT try to achieve a / sQueeze or to build sQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 12. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. POST SQUEEZE FULLBORE: 13. MIT-OA to 2500 psi. Previous OA History: 09/08/05: MITOA Failed - LLR = 2 bpm @ 2100 psi. / TREE = WELLHEA D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = ') 09-40 FMC FMC .._._--_._~ OTIS .-...---."",.,.....-,,,,,,,,,,,...,,-...,,,,,,,,.,,.,, ? ---'-'-""'~'" --"...",.~.-- 1600' 60..@.~ggg~, 14037' 8800'SS ~,:i',,:,í:l,íl', ~ 110-3/4" CSG, 45.5#, ,J-55, ID = 9.953" l-l ~ 4160' Minimum 10 = 2.75" @ 13785' 3-1/2" XN NIPPLE 14-1/2" TBG-IPC, 12.6#, L-BO, .0152 bpf, ID = 3.958" l-i TOPOF3..1/2"TBG-IPC l-i 13676' 13676' \ / ~ ~ :8: ~ TOPOF 5-1/2" LNR l-i 13756' I ..;,.- I I 13-1/2" TBG-IPC, 9.3#, L-80, .0087 bpf, ID = 2.992" l-i 13794' I 1 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 1-1 14086' µ PERFORATION SUMMARY REF LOG: SHCS ON 02/12/91 A NGLE AT TOP PERF: 57 @ 14038' Note: Refer to Production DB for historical perf data SIZE SPF INTEI~.v AL Opn/Sqz DA TE 2-1/8" 8 14037.. 14040 0 06/13/95 2-1/8" 14 14040.. 14060 0 12/24/96 2-1/2" 4 14060 - '14083 0 03/19/91 2-1/8" 1 0 14083 - '14085 0 03/31/95 2-1/8" 10/113 14085 -14105 0 12/24/96 2-1/2" 4 '14105--14132 0 03/19/91 I PBTD 1-1 14249' ~ I 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 14297' DATE 03/03/91 11/29/01 02/07/03 11/30/03 09/05/05 COMMENTS REV BY COMMENTS ORIGINAL COM PLEfION RN/TP CORRECTIONS JMP/KK WAIVER SAFETY NOTE A TD/TLP CSG CORRECTION DA V IPJC SSSV / SFTY NOTE CORRECTION II DATE REV BY j! -~ I I :r:.. I , SAFF~1)TES: ***SLOW TBGX IA COMM. (02/07/03 W AIVER)*** 2213' 1---14-1/2" OTIS HRQ SSSV NIP, ID = 3.813" ' ~ 13676' 1-i4-1/2" X 3-1/2" XO I 13684' 1--13-1/2" OTIS LOC SEAL ASSY I 13686' 1-17-5/8" X 3-1/2" OTIS BWP PKR I 13785' l-i 3-1/2" OTIS XN NO-GO NIP, ID = 2.75" I 13792' l-i 3-1/2" OTIS SOLID NOSE SHEA ROUT SUB 13794' l-i 3-1/2" TUBING TAIL 1 13782' 1-1 ELMD TT LOGGED 03/19/91 PRUDHOE BA Y UNIT WELL: "09-40 PERMIT No: "1901690 API No: 50-029-22118-00 SEC 1, T10N, R15E, 3754.57' FEL &1335.74' FNL. BP Exploration (Alas ka) MEMORANDUM - e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K'c?¿f( 9(31)/05 DATE: Wednesday, September 21, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) lNC 09-40 PRUDHOE BAY UNIT 09-40 FROM: Jeff Jones Petroleum Inspector '$; Src: Inspector Reviewed By: P.I. Suprv .Tg,~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-40 API Well Number 50-029-22118-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ050920071423 Permit Number: 190-169-0 Inspection Date: 9/19/2005 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 09-40 IType Inj. ! N ¡ TVD 866\ I IA ! 80 2560 2520 I 25\0 1 i ì I , i P.T. I \90\690 ITypeTest I SPT I Test psi , i I 2\65.25 lOA 300 540 I 530 530 Interval REQVAR P/F P Tubing 545 I 2550 ! 2520 25\0 i Notes This well has known T x IA communication and a TTP was set @ 13,773' MD to facilitate the combo ~ well house inspected, no exceptions noted. 8CANk\1El. NOV (; ~ 2005 Wednesday, September 21,2005 Page 1 of I TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = e FMC FMC OTIS 52' ? 1600' 60 @ 8000' 14037' 8800'SS 110-3/4" CSG, 45.5#, J-55, ID = 9.953" I Minimum 10 = 2.75" @ 13785' 3-1/2" XN NIPPLE 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" I I TOP OF 3-1/2" TBG-IPC I 13676' 13676' TOPOF 5-1/2" LNR I 13756' 3-1/2" TBG-IPC, 9.3#, L-80, .0087 bpf, ID = 2.992" I 13794' 09-40 5 OTES: ***SLOW TBGX IA COMM. (02/07/03 WAlVER)*** 17-5/8" CSG, 29.7#, L-80, ID = 6.875" I PERFORA TlON SUMMARY REF LOG: BHCS ON 02/12/91 ANGLEAT TOP PERF: 57 @ 14038' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 8 14037 - 14040 0 06/13/95 2-1/8" 14 14040 - 14060 0 12/24/96 2-1/2" 4 14060 - 14083 0 03/19/91 2-1/8" 10 14083 - 14085 0 03/31/95 2-1/8" 10/1 14085 - 14105 0 12/24/96 2-1/2" 4 14105 - 14132 0 03/19/91 PBTDI I 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" DATE 03/03/91 11/29/01 02/07/03 11/30/03 09/05/05 REV BY COMMENTS ORIGINAL COM PLETION RNITP CORRECTIONS JMP/KK WAIVER SAFETY NOTE A TDITLP CSG CORRECTION DA V /PJC SSSV / SFTY NOTE CORRECTION DATE REV BY . 2213' -14-1/2" OTIS HRQ SSSV NIP, ID = 3.813" I 13676' -14-1/2" X 3-1/2" XO I COMMENTS 13684' -3-1/2" OTIS LOC SEAL ASSY I -7-5/8" X 3-1/2" OTIS BWP PKR I 13785' -3-1/2"OTISXNNO-GONIP,ID=2.75" I 13792' H 3-1/2" OTIS SOLID NOSE SHEA ROUT SUB 13794' -3-1/2" TUBING TAIL I 13782' H ELMD TT LOGGED 03/19/91 A trA<' i-\ Tn.Ç. il F ~ t"f'\ ~ . \ \ ~ ç l' q ;:LOO 1 l 4 ;1~ " PRUDHOE BA Y UNIT WELL: "'09-40 PERMIT No: '1901690 API No: 50-029-22118-00 SEC 1, T10N, R15E, 3754.57' FEL & 1335.74' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _ Water Injection Only Pull tubing _ Alter casing _ Repair well _ Other _X H20 INJECT ONLY 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3874' FNL, 5217' FEL, Sec. 01, T10N, R15E, UM At top of productive interval 1500' FNL, 3904' FEL, Sec. 31, T11N, R16E, UM At effective depth 1377' FNL, 1211' FEL, Sec. 31, T11N, R16E, UM At total depth 1336' FNL, 3755' FEL, Sec. 31, T11 N, R16E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 718443, 5942874) ~sp~ 724525, 5950711) (asp's 724637, 5950838) ~sp~ 724669, 5950878) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-40 9. Permit number / approval number 190-1690 / 301-350 10. APl number 50-029-22118-00 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 14297 feet 8988 feet Plugs (measured) TD Tag @ 14236' (10/26/1999) Effective depth: measured 14236 feet true vertical 8958 feet Casing Length Size Conductor 113' 20" Surface 4108' 10-3/4" Intermediate 14034' 7-5/8" Liner 541' 5-1/2" Junk (measured) Cemented 55 sx AS 1375 sx PFE, 320 sx Class 'G', 125 PFC 1716 sx MTC & 316 sx Class 'G' 125 sx Class 'G' Perforation depth: measured Open Perfs 14037' - 14132' true vertical Open Perfs 8852' - 8903' Tubing (size, grade, and measured depth) Measured Depth True Vertical Depth 165' 165' 4160' 3658' 14086' 8858' 13756' - 14297' 8700' - 8990' 4-1/2", 12.6#, L-80 POT @ 13676' MD. 3-1/2", 9.3#, L-80 PCT @ 13782'. Packers & SSSV (type & measured depth) 7-5/8" x 3-1/2" Otis BWP Packer @ 13686' MD. 4-1/2" Otis HRQ SSSV @ 2213' 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 10/14/2001 Subsequent to operation 11/16/2001 OiI-Bbl Shut-In Representative Daily Averaqe Production or Injection Data Gas-Mcr Water-Bbl 3834 Casing Pressure Tubing Pressure 1684 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil__ Gas_ Suspended__ Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.Schn~~r ~~~._ Title: Technical Assistant Date January 04, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · RBDNS BF L SUBMIT IN DUPLICATE 09-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/06/2001 10/14/2001 10/15/2001 10/20/2O01 11/15/2001 11/15/2001 11/16/2001 ANN-COMM: EVAL HIGH lAP ANN-COMM: PULL SSSV / SET TTP (PRE CMIT - ANN COMM) ANN-COMM: PULL SSSV / SET PXN TT PLUG (PRE-CMIT) ANN-COMM: CMIT-T+IA FOR SSSV WORK ANN-COMM: PULL TTP(POST STATE CMIT) START WATER INJECTION WATER INJECTION RATE EVENT SUMMARY 09/06/01 MITIA FAILED ON PRESSURE STABILIZATION, LOOSES 90 PSI/15 MIN. 10/14/01 DRIFT TO SSSV W/3.8" GAUGE RING. PULL 4 1/2" QOS SSSV 10/15/01 PULLED 4 1/2" QOS @ 2192' SLM (SERIAL# LQOS- 403). SET 3 1/2" PXN TT PLUG @ 13763' SLM (PRONG = 73" LONG W/1.75" F.N.) RDMO. LEFT WELL SHUT-IN FOR CMIT. NOTE ' PLUG NOT TESTED DUE TO INSUFFICIENT WHP. 10/20/01 CMIT-T+IA TO 2500 PSI FOR AOGCC SUNDRY (PASSED.) [Ann Comm] 11/15/O 1 PULL 3 1/2" PXN PRONG @ 13,750' SLM. RUN 2.8" GAUGE RING TO 13,754' SLM. PULL 3.5" PXN PLUG BODY @ 13,754' SLM. RDMO. TALK W/DSO. GIVE BACK FOR INJECTION. 11/15/01 WATER INJECTION STARTED. 11/16/01 WATER INJECTION RATE - 3834 BWPD. WHP - 1684 PSI. FLUIDS PUMPED BBLS 4 METHANOL WATER 22 50/50 METHANOL WATER 6 DIESEL 32 TOTAL Page 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE, NOVEMBER 2, 2000 E P M C:LORI~IV~'ILM.DOC L E W A T E R IA L U N D ER THIS M A R K E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3874' FNL, 5217' FEL, Sec. 01, T10N, R15E, UM At top of productive interval 1500' FNL, 3904' FEL, Sec. 31, T11N, R16E, UM At effective depth 1377' FNL, 1211' FWL, Sec. 31, T11N, R16E, UM At total depth 1336' FNL, 3755' FEL, Sec 31 T11 N, R16E, UM 12. Present well condition summary Total depth: 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X Other_ (asp's 718443, 5942874) (asp's 724525, 5950711) (asp's 724637, 5950838) (asp's 724669, 5950878) measured 14297 feet Plugs (measured) true vertical 'v/ 8988 feet 6. Datum elevation (DF or KB feet) RKB 52.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-40 9. Permit number/,¢'pproval number 1901690 10. APl number 50-029-22118 ''/ 11. Field / Pool Prudhoe Bay Oil Pool TD Tag @ 14236' (10/26/1999) Effective depth: measured 14236 feet Junk (measured) true vertical 8958 feet Casing Length Size Cemented Measured Depth Conductor 113' 20" 55 sx AS 165' Surface 4108' 10-3/4" 1375 sx PFE, 320 sx 4160' Class 'G', 125 PFC 1716 sx MTC &316 sx Intermediate 14034' 7-5/8" 14086' Class 'G' Liner 541' 5-1/2" 125 sx Class 'G' 13756' - 14297 True verticalDepth 165' 3658' 8858' 8700'-8990' RECEIVED Perforation depth: measured Open Perfs 14037'- 14132' D~'0 J. true vertical Open Pen's 8852' - 8903' ~lc3~a 0i~ & Gas C0o$. Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 PCT @ 13676' MD. 3-1/2", 9.3#, L-80 PCT @ 13782'. Packers & SSSV (type & measured depth) 7-5/8" x 3-1/2" Otis BWP Packer @ 13686' MD. 4-1/2" Otis HRQ SSSV @ 2213' MD. 13. Attachments Description summary of proposal ___X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation December 10, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service Prod Water Inj Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.~ ~ Title: Well Integrity Engineer Joe Anders, P.E. FOR COMMISSION USE ONLY Questions? Call Joe Anders 907/659-5102. Date: December 10 2001 Prepared b~/DeWayne R. Schnorr 564-5174 Conditions of approval:PlugN°tifYintegrityC°mmissi°n__ so representative. BOP Test mayt, witneSSLocationNJk~clearance~~' ~ ~)~''~ ~'''''~ - I Approval no. ,,..~ ~hanica,~LIIntegrity Test__-~ .~L$-~~,~C~_ S[Jb.~t~entform, re~uired 1~. ~ll~~k~ -- Original Signed Ely -- Commissioner Date Approved by order of the Commission ~,i:lllllll~~..~ ,~ C I I,~..! Form 10-403 Rev 06/15/88 · [ ~ ~ ~ [ I SUBMIT IN TRIPLICATE 09-40 Description Summary of Proposal 12/09/01 Problem: Injector with slow TxlA communication Well History and Status Well 09-40 (PTD 1901690) is an injector that failed an MIT-IA on 09/06/01 due to lack of pressure stabilization. The Drill Site Operator reported high IA pressure and an MITIA was conducted to evaluate the pressure source. The MITIA failed on pressure stabilization, loosing 90 psi/15 minutes. This calculates to a LLR of .5 GPM @ 2500 psi. Recent events: > 09/06/01: MITIA Failed on pressure stabilization, 90 psi/15 min > 10/15/01: SL set TTP > 10/20/01: CMIT TxlA Passed to 2500 psi > 11/15/01: Pulled TTP This sundry request is to allow for continued injection of water. The following supports the request: - A CMIT-TxIA Passed on 10/20/01 to 2500 psi against a tubing plug, demonstrating competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annual IA leak rate test will be conducted to monitor the leak severity. - A CMIT TxlA against a TTP will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Perform an annual IA leak rate test. 4. Perform combination MIT Tubing x IA against a plug every 4 years. 5. Submit a monthly report of daily pressures and injection rate. 6. Stop injection and notify the AC)GCC if there is any indication of loss of production casing integrity. TREE :, FMC WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 52' BF. ELEV = ? KOP = 1600' Max An le = 60 8000' !Datum MD = 14037' Datum TVD = 8800' SS Minimum ID = 2.75" @ 13785' 3-1/2" XN NIPPLE O9-4O 4-1/2"TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" I--[ 13676' [TOPOF3-1/2"TBG-IPC I'--I 13676' I TOP OF 5-1/2" LNRH 13756' I 3-1/2" TBG- PC, 9.3#, L-80, .0087bpf, ID= 2.992" Id 13794' 17~5/8"CSG, 29.7#,J-55, ID:6.875" I'--t 14086' PERFORATION SUMMARY REF LOG: BHCS ON 02/12/91 ANGLEATTOP PERF.' 57 @ 14038' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 8 14037-14040 O 06/13/95 2-1/8" 14 14040-14060 O 12/24/96 2-1/2" 4 14060-14083 O 03/19/91 2-1/8" 10 14083-14085 O 03/31/95 2-1/8" 10/16 14085-14105 O 12/24/96 2-1/2" 4 14105-14132 O 03/19/91 i 5-1/2" LNR, 17#, L-80, .0232 bpf, ID= 4.892" Id 14249' 14297' I · I SAFETY NOTES: INJECT. VALVE I 2213' Id4-1/2" OTIS HRQ SSSV NP, ID: 3.813" 14 1/2" QOS, SN Q058, ID =2.0" 13676' H4-1/2" x 3-1/2" xo J 13684' I-~3-1/2" OTIS LOC SEAL ASSY I 13686' Id 7-5/8" x 3-1/2" OTIS BWPPKR I 13785' I 13792' 13782' Id ELMDTTLOGGED03/19/91 I DATE REV BY COMMENTS DATE REV BY COMMENTS 03/03/91 ORIGINAL COIVPL ETLON 12/23/00 SlS-SLT CONVERTEDTO CANVAS 01/22/01 SIS-LG REVISION 11/29/01 RN/TP CORRECTIONS FRUDHOE BAY UNIT WELL: 09-40 PERMIT No: 190-1690 APINo: 50-029-22118-00 SEC 1, T1 ON, R15E 3754.57 FEL 1335.74 FNL BP Exploration (Alaska) Wavered Injection Well Document Prudhoe Bay Unit 09-40 PTD 190-169 Sundry 301-350 In mid July 2001, the Prudhoe Bay Well Integrity Engineer proposed a "categorization" method for Class Ii injection wells that had exhibited some form of mechanical integrity (MI) failure. A well has M! if the annular space between the tubing string and production casing (generally referred to as the Inner Annulus or IA) is capable of holding an applied positive pressure. The ability to hold such a positive pressure gives assurance that the tubing, casing and packer are competent. Occasionally, observations will indicated that some pressure communication has developed into the IA. Regulations require the operator to notify the Commission on the next working day and propose a diagnostic plan to determine the failure. If the MI failure occurs on a gas well (residue or miscible injectant), the well must be converted to water service or shut in. If the failure occurs on a well injecting water, permission may be obtained to begin performing the diagnostic tests while keeping the well in service. Depending on the results of the diagnostics, the regulations allow the well to be kept in service, provided MI is demonstrated by an alternate method and the daily operating pressures and rates are monitored and reported monthly to the Commission. Through the years, a number of wells throughout the state have experienced MI failures. As the failures and M! issues have been resolved, a number of similar yet different testing requirements have been put in place to assure the MI of the "damaged" well. The proposal advanced by the Well Integrity Engineer categorizes the wells based on the determined characteristics of the leak and proposed a consistent enhanced testing program for the wells, The determined categories, leak characteristics and MI test requirements are: Category IV Category ill Category !1 Category I Slow tubing x IA communication Leak rate < 10 gpm Rapid tubing x IA communication Leak rate > 10 gpm IA x OA communication Production casing leak Report daily rate and pressure Annual Leak Loss Rate Test/MITIA CMIT T x IA every 4 years Report daily rate and pressure CMIT T x IA every 2 years Report daily rate and pressure CMIT IA x OA every 2 years Report daily rate and pressure MIT OA every year On September 46, 2001, PBU well DS 09-40 failed a MIT IA after the operator reported observing high IA pressure. Subsequent diagnostic work determined that the well had a tubing leak with a rate of 0.5 gpm at 2500 psi. On October 20, the well passed a CMIT T x IA. BP has applied to keep the well on water injection only service since MI has been demonstrated using an alternate test. Based on the described classification system, this well is Category IV. I recommend that BP's proposal for a waver for the subject well be approved with monitoring and MI determinations as noted for Category IV above. om Maunder, E Sr. Petroleum Engineer 09-40 Failed MITIA (PTD 190-169) .......... Subject: 09-40 Failed MITIA (PTD 190-169) Date: Fri, 7 Sep 2001 17:40:06 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak. us> CC: "- Field Inspectors AOGCC (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak. us> Hello Tom. Injection Well 09-40 (PTD 190-169) failed an MIT-IA. On 09/06/01, an MIT-IA was attempted to evaluate high IA pressure. The IA was pressured to 2500 psi and lost 90 psi at 15 minutes, 180 psi total at 30 minutes. We repeated the test 2 times with similar results. Calculated leak rate based on volumes needed to. re-fill the IA is .5 GPM. The well is currently on water injection. Our plan is to set a tubing tail plug, pressure test the tubing and production casing then evaluate pursuing a sundry. Please call if you have any questions. Joe Joe Anders, PE / Kevin Yeager Well Integrity Engineer BP Exploration, Alaska Inc. (907) 659-5102 - Work (907) 659-5100, x1154 - Pager email: NSUADVVVVelllntegrityEngineer@bp.com 1 of 1 12/18/01 5:17 PM 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 ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3874' FNL, 5217' FEL, Sec. 1, T1 ON, R15E, UM At top of productive interval 1501' FNL, 1096' FWL, Sec. 31, T11N, R16E, UM At effective depth At total depth 1336' FNL, 3755' FEL, Sec. 31, T11N, R16E, UM 5. Type of Well: Development__ Explorato~___ Stratigraphic__ Service__X 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-40i 9. Permit number / approval number 90-169 10. APl number 50-029-22118 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 14296 feet Plugs (measured) 8990 feet Tagged PBTD @ 14236' MD (10/26/1999) Effective depth: measured true vertical Casing Length Conductor 1 13' Surface 4108' Production 14034' Liner 541' 14236 feet Junk (measured) 8958 feet Size Cemented 20" 55 Sx AS 1 0-3/4" 1375 Sx PFE, 320 Sx Class G, & 125 Sx PFC 7-5/8" 300 bbls MTC & 316 Sx Class G 5-1/2" 125 Sx Class G Perforation depth: measured 14037'-14132'. true vertical8852'-8903'. Tubing (size, grade, and measured depth) 4-1/2"12.6#, L-80 PCT @ 13676' MD; 3-1/2"9.3#, L-80 PCT @ 13794' MD. Measured Depth True vertical Depth 113' 113' 4160' 3658' 14086' 14297' 8858' 8990' Packers & SSSV (type & measured depth) 7-5/8" X 3-1/2" OTIS BWP PACKER @ 13687' MD. 4-1/2" OTIS HRQ SSSV @ 2214' MD. 13. Stimulation or cement squeeze summary ORiGiNAL Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mc'f Water-Bbl Prior to well operation - - 6815 Subsequent to operation 5127 Casing Pressure Tubing Pressure 1794 1847 15. Attachments J 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ Gas _ Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed-'~~ ~~~' Title ARCO Engineering Supervisor Erin Oba ServiceWAG Iniector Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-40i DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date Event Summary 10/01/1999: 10/07/1999: 10/10/1999: 10/23/1999: 10/25/1999: 10/26/1999: RIH &tagged PBTD @ 14062' MD. Performed MITIA- passed. RIH & set Frac Sleeve to 2196' MD. MIRU & PT'd equipment to 9500 psi. Performed a FB Hydraulic Fracture Treatment using 16/20 mesh ceramic proppant through the open perforation intervals listed below: 14037'- 14062' MD (Zone 1 B) Pumped: (a) 308 bbls Pre-Pad @ 35 bpm, followed by shutdown. (b) 200 bbls 40# Crosslinked Gel @ 35 bpm, (c) 100 bbls 1 ppg scour stage @ 35 bpm, followed by (d) 240 bbls flush @ 35 bpm, followed by (e) Shutdown. ISIP @ 1936 psi. Resumed pumping Datafrac Treatment: (f) 300 bbls 40# Crosslinked Gel @ 35 bpm, followed by (g) 215 bbls 20# Linear Gel Flush @ 35 bpm, followed by (h) Shutdown. Closure press -- 1685 psi. Resumed pumping Frac Treatment: RECEIVED 1 1999 Nas 0il & Gas Cons. C0mmissi0[ Anchorage (i) 600 bbls 40# Crosslinked Pad @ 35 bpm, followed by (j) 708 bbls Crosslinked Slurry @ 35 bpm w/proppant stages @ 1.0 - 9.2 ppg, followed by (k) Flush to top perforation, followed by (I) Shutdown. Placed a total of 128681 lbs of proppant into FM. This was 100% of the design amount. Max proppant concentration placed was 9.2 ppg (3.8 ppg on perfs). This well was treated at an avg surface press of 4000 psi @ 35 bpm. RD. RIH & tagged Proppant @ 14070' MD. Jet washed to 14200'. RIH & pulled frac sleeve. Tagged PBTD @ 14236' MD. Returned well to WAG injection service & obtained representative data. " STATE OF ALASKA ALASKA f~lL AND GAS CONSERVATION COIv, MlSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1404' FSL, 63' FWL, Sec 1, T10N, R15E, UM. At top of productive interval 1501' FNL, 1096' FWL, Sec 31, T11N, R16E, UM. At effective depth At total depth 1334' FNL, 1238' FVVL, Sec 31, T11 N, R16E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-40i 9. Permit number/approval number 90-169 10. APl number 50 - 029-22118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 14296 feet 8988 feet Effective depth: measured 14130 feet true vertical 8901 feet Plugs(measured) PBTD Tagged @ 14130' MD (12/21/96). Casing Conductor Surface Production Liner Junk(measured) Le n gt h Size Ce mented 113' 20" 55 Sx AS 4108' 10-3/4" 1375 Sx PFE, 320 Sx CI G, & 125 Sx P F C 13996' 7-5/8" 300 bbls MTC, 316 Sx CIG 540' 5-1/2" 125 Sx CIG Measured depth True vertical depth 113' 113' 4160' 3657' 14048' 8857' 14296' 8956' Perforation depth: measured 14037 - 14132' true vertical 8851 - 8901' ORIGINAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 13676' MD; 3-1/2", 9.3#, L-80, IPCT @ 13794' MD. Packers and SSSV (type and measured depth) Otis BWP Packer @ 13686' MD; Otis HRQ SSSV @ 2213' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. JAN 2 1 ]997 Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure tubing Pressure Prior to well operation 6544 - 3131 Subsequent to operation 7688 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2811 Service ~V~,Z~ ~ Injector Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date /-7- ¢"7 SUBMIT IN DUPLICATE~b 9-40i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 2/21/96 · RIH & tagged PBTD at 14130' MD. 1 2/24/96' RIH w/perforating gun & shot 40' of perforations as follows: Reperforated: 14040 - 14060' MD (Z1B) 14085 - 14105' MD (Z1B) Ref. Log: BHCS 1/12/91. Used 2-1/8" carriers & shot the perfs at 6 spf at 45 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to miscible gas injection & obtained a valid gas injection rate. ~"-- STATE OF ALASKA ALASKA. ". AND GAS CONSERVATION C( AISSION REPORT SUNDRY WELL OPEI'IATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1404' FSL, 63' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1501' FNL, 1096' FWL, Sec. 31, T11N, R16E, UM At effective depth At total depth 1334' FNL, 1238' FWL, Sec. 31, T11N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 09-40i 9. Permit number/approval number 90-169 10. APl number 50 - 029-22118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 113' 20" Surface 4108' 10-3/4" Production 13996' 7-5/8" Liner 540' 5-1/2" 14296 feet 8988 feet Plugs(measured) PBTD Tagged @ 14236' MD (3/30/95) 14236 feet 8956 feet Junk(measured) Cemented Measured depth True vertical depth 55 sx AS 113' 113' 1375 sx PFE, 320 sx G, 125 sx PFC 4160' 3657' 300 bbls MTC, 316 sx CIG 14048' 8857' 125 sx CIG 14296' 8956' Perforation depth: measured 14037-14132' true vertical 8851-8901' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 13676' MD; 3-1/2", 9.3#, L-80, IPCT @ 13794' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Packers and SSSV (type and measured depth)Otis BWP Packer @ 13~18~ ~ft~l~ SSSV @ 2213' MD Prior to well operation Subsequent to operation ,Itel 17 3995 Alaska 0il & Gas Cons. Commission Anchor;,,/ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1 O233 - 10628 ~" - - Tubing Pressure 3385 3270 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .'~j,~ /J,~. ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 cc' KZ, JWP SUBMIT IN DUPLICATE ~~. 9-40i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/1 3/95: MIRU & PT equipment. Reperforated: 14037 - 14O57' MD (Z1B) Ref. Log: BHCS Used 2-1/8" carrier & shot the perforations with the well overbalanced. Noted all shots fired. Rigged down. RIH w/perforating gun & shot 20' of reperforations as follows: 1/12/91. POOH w/perf gun. Returned the well to produced water injection (6/13/95), but later swapped the well to miscible gas injection (6/15/95). Obtained a valid gas injection rate. RECEIVED 1 1 1995 Alaska 0il & Gas Cons. Commission Anchor:' ,:~, 7/7/95 GeoQuest .. NO. 9557 500 w. International Airport Road . .,. f-~--D / Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 ATTN: Sherrie ~/'/"'.//,~ (~/~J _A v'/ (~ D . \ ir .~ Attn: Larry Grant 3001 Porcupine Drive /~) j/* I~| .~q ~'-" ~ Anchorage, AK 99501 ~~ L~~~C io~ Field: Prudhoe Bay Floppy Well riPt Date BL RF Sepia DIR MWD Disk · D.S. 4-24 z /,/'95181 CNTG/' / 950513 1 D.S. 5-6A 95226 DUAL BURST TDT-P 950630 1 D.S. 1-4 ~7~ ~'~-' ~ PROD PROFILE 95 061 3 I 1 O.S. 1-15 ~.Z~ POGLM SETTING RECORD 95 061 7 I 1 D.S. 3-22 c~ ~ RSTA 950601 1 1 D.S. 9-40 ~ ~ I ~..~ PERF RECORD 95 061 3 1 1 D.S. 11-31 C~ ~ | DUAL BURST TDT-P 950612 ..1 1 D.S. 16-21 1~ '~ ~ '7..-. PROD PROFILE 950612 1 1 D.S. 17-3 ~ ~ e~'")'~ PERFRECORD " 950614 I "'~ D.S. 17-11 ~ ~.Mk[ GAS LIFT SURVEY 950611 I 1 ....... ,, ,, ,, ,, ,, , SIGNED _ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED JUL 0 7 1995 DATE: Naska 0ii & Gas Uo~-Is. Anchorage ~ STATE OF ALASKA ~-- ALASI" _,L AND GAS CONSERVATION (, f.,vllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1404' FSL, 63' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1501' FNL, 1096' FWL, Sec. 31, T11N, R16E, UM At effective depth At total depth 1334' FNL, 1238' FWL, Sec. 31, T11N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 09-40i RECEIVED APR 2 4 1995 Alaska 0il & Gas Cons. Commission Anchor~., ~; feet 9. Permit number/approval number 90-169 10. APl number 50 - 029-22118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14296 feet true vertical 8988 feet Effective depth: measured 14236 feet {"~l i~ ~ ~ ! l~'~,~! ~, ~ true vertical 8956 feet Junk(measured) t--J ~ \ ~ "'"' ~ : ~ ~ ~ ~"" Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 55 sx AS 113' 113' Surface 4108' 10-3/4" 1375 sx PFE 320 sx G, 125 sx PFC 4160' 3657' Production 13996' 7-5/8" 300 bbls MTC, 316 sx CIG 14048' 8857' Liner 540' 5-1/2" 125 sx CIG 14296' 8956' Plugs(measured) PBTD Tagged @ 14236' MD (3/30/95) Perforation depth: measured 14037-14132' true vertical 8851~8901' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 13676' MD; 3-1/2", 9.3#, L-80, IPCT @ 13794' MD Packers and SSSV (type and measured depth) Otis BWP Packer @ 13686' MD; Otis HRQ SSSV @ 2213' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACH ED 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 3689 4706 Tubing Pressure 1692 1693 15. Attachments Copies of Logs and Surveys run.. Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~ '~. ~Z',L..- Title Engineering Supervisor Form 10-404 Rev 06/15/88 CC: KZ, JWP Date /--/-2_0- ?.,C'- 9-40i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/30/95. RIH & tagged PBTD at 14236' MD. 3/31/95' MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 20' of reperforations as follows: 14083 - 14103' MD (Z1B) Ref. Log: BHCS 1/12/91. Used 2-1/8" strip carrier & shot 6 spf at 0 degree phasing. Shot perforations with well overbalanced. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. RECEIVED APR 2 4 1995 Alaska Oil & Gas Cons. Commission Anchor~, ~r GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9409 Company: 4/1 3/95 Alaska Oil & Gas Cons Comm Attn' Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field' Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-'22A 95110 !MWDGR '" 010995 1 D.S. 15-08A 95148 ~MWDGR 102693 1 D.S. 2-24 PROD PROFILE 040395 I 1' D.S. 3-19 INFLATABLE BRIDGE PLUG 040395 I 1 D.S. 5-12 PROD PROFILE 040395 I 1 ........ D.S. 9-25 PERF RECORD 032795 I 1 D.S. 9-25 PERF RECORD 032895 1 1 D.S. 9-40 PERFRECORD 0331 95 I 1 ,., D.S. 11-6 PATCH SETTING RECORD 032595 I 1 ............. D.S. 14-3 PATCH SE'I'TING RECORD 040495 I 1 D.S. 15-17'- GCT ........ 040595 I 1 ................ D.S. 16-23 COLLAR & JEWELRY LOG 0331 95 I 1 D.S. 16-23 PERF RECORD 040395 I 1 D.$. 18-02A GCT 0401 95 I 1 ..... ...... ............. "' ,,, APR 1 ........... '.~. ~,l .¢,, ~.~ ,~ I,,¢,,, SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest ~]0 W. Intemalional Airl~rt Road Anchorage, AK 99618-1199 ATTN: Sherfle NO. 8882 Company: Alaska 011 & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 8/24/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar ~'/-- r........~: D.S. 4.4 - PERF RECORD (8/2/94) 1 1 ..... "Y.~'-'~ 'D.S. 4-7 5T#1 ' PROD PROFILE (8/7/94) .... 1 .... 1 ~ ' / ~ D.S. 9-~ STA~C PRE~URE SURVEY (8/2/94) 1 1 ~ - ~ D.S. 11 -~ PERF RECORD (8/3/94) .... 1 .. 1 ~-~ D.S. 11-~ .. J~LRYL~(8/3/94~ ...... 1 1 ~/'-2~ ~ ~ ~ D.S. 12-~ INJEC PR~ILE (8/4/94} 1 1 _ ~ D.S. 12-~A ~PROD PROFILE (8!4/94) 1 - "'1 ...... G3 D.S. 15-~ STA~C PRE~URE SURVEY (8/1/94) 1 1 D.S. 15-~ J~LRY L~ (7/30/94) 1 1 " ~-~ 3 D.S. 15-~ PERF REC~D ~/30/94) 1 1 ~ D.S. 15-~ STA~C PRE~URE SUR~ (8/1~94) 1 1 ~ ~ D.S. 15-37 PERF RECORD (8/1/94) 1 1 ~ D.S. 15-37 J~LRY L~ (8/1/94) 1 .. 1 ..... Please sign and return one copy of this transmittal to Sherrle at the above addre~. Thank you. ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360, .;chorage, AK Transmittal #: 94021 99510,~ ~, Subject: From/Location: BHP Report John Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution Weil Log Date Tool Type Run, Scale C~ntractor Number (M-D-Y) i-9 12-17-92 BHP .... - ....... Camco' i, , 1-14 8-11-92 BHP - Carn(~ 1-14 8-11-92 . BHP - . Camco .. 2-2 1-10-93 BHP - Camco , ~ 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP - Camco 3-15A 3-20-93 BHP - Camco , , , 3-20 12-18-92 BHP - Camco t 4-7ST '5-17-92 BHP - Camco 4-14 1-9-93 BHP Camco 4-29 12-28-92 BHP Camco 4-42 4-27-92 BHP - Camco ,,, 5-9 2-21-93 [ BHP - Camco 5-16 2-21-93I ..... BHP " - "Camco 5-25 2-21-93 BHP " - Camco 5-31 2-21-93 BHP - Camco , , ~ 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 2-15-93 BHP - Camco 9'40 1-25-93 BHP - Camco 9-51 3-20-93 BH P - Camco 12-7A 12-6-92 BHP - Camco , 12-7A 12-10-92 BHP - Camco , , 12-9 12-10-92 BHP Camco 12-29 12-14-92 BHP Camco , ~ 13-15 7-3-92 BHP Camco , 13-20 7-4-92 BHP - Camco "'1~-23,&, 7-4-92 BHP ' - 'Camco , 13-32 7-3-92 BH P - Camco 14-11 11-23-92 "' B'HP ' - camco 16-:19' 10-i9-'92 BHP - camco 16-21 10-19.92 BHP - Camco 16-30 9-28-92 BH P - Camco , ,, 17-3 12-12-92 BHP - Camco ' '1~-i0 .... 11-8-92 ' 'B'HP - Camco 17-11 2-8-93 BHP - ' Camco 17-20 12-21-~2 .... BHP ' ~ ....... ~3~'n"x~ , , , 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco ARCO Aiaalm, ~ I$ a Sub~¢~ of All.nlcRIchf~dr.,Onl~ny t ECEIVED Alaska 0il & Gas Col~s. Anchorage C°rmN$$ion ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ~' *~1-24A 2-7-93 ~.~/~3-20 4-6-93 .~~2~2001 4-13-g3 4-28-93 4-23-93 4-23-93 ~ 3-30 ~ ~ 1-29-93 4-16 ~-~ 4-18-93 -10 ZZ~ V~ 1-2-93 -16 7~ 4-20-g3 -12A ~ ~ d 4-19-93 ~6-12A ~' , / 4-24-93 ~6-17 ~0 4-25-93 -7A ARCO CASED HOLE FINALS GR/CCL/Jewelry/Temp Tubing Cutter 8BT/GR/CCL Perf Record Jewelry/GR/CCL Tie-In CNL/GR Color USIT/GR Color Leak Detect Static Press/Temp Leak Detect Prod Profile Production Log Pressure Build*Up Press/Temp Perf Record Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run ~2~ g 4-23-93 Production Log ~$~13 ? 4-21-93 Dual Burst TDTP (Borax) .~9-27 ~1~9~ 4-20-93 Perf Record -31A ~-5~ 4-19-93 PFC/GR (Packer Set) ~-~9-40 ~O~/~ 1-1-93 InJ Profile /~]e~e~~~2-13 ~/~ ~ ~ 1-2-93 ~ ~tect **~2-148T F/~IJ~4-27-93 ~ ~tect ~3-20~-~ 4-25-03 ~ ~tect ~13-25 ~-~/ 12-26-03 InJ ~ome ~-43 ~ */~ 1-3-03 ~od ~o~e ~-~7-13 ~;7~ 4-18-93 ~ ~tect ~Ol-0 ~.~ 4-11-03 SBT/GR/CCL Ple e ret ~ re~ of ~. RECEIVED BY iTO- 1529 ~~ 9305~ ~ CLOT C~~ ~ BPX ~ E~ON ~ MOB~ Camco Atlas Atlas ach Sch Sch Sch Camco Sch Sch Camco ach Sch Sch Sch Sch Sch 2ch Atlas Camco Camco ach 8ch Camco Camco Camco ach Atlas The Correct well nnme for this log is 1-24~ The correct APl# for 3-20t is 504)29-209804)1. The correct API# for 12-14ST is 50-029-2065~. ALASKA OIL AND GAS CONSERVATION COMM~6SION I . WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~, Siatus of Well Classification of Service Well O,L I---I GAS r-i SUSPENDED r-'l ABANDONED I--I SERV,CE 17~ WATER ~ECTOR' 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-169 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22118 4 Location of well at surface ? ................... ,~ 9 Unitpr Lease Name 1405' FSL, 62' FWL, SEC 1, TION, R15E UM ~ .... ~ PRUDHOE BAY UNIT At Top Producing Interval~ ~.i ~ ......... .~ 10 Well Number 1501' FNL, 1096' FWL, SEC 31, T11N, R16E UM ~_.~.!i.,,_, ~,~.. ~..~; 9-40' At Total Depth 11 Field and Pool 1334'FNL, 1238'FWL, SEC 31, T11 N, R16E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 52'I ADL 28343 12 Date Spudded 12/21/90. 13 Date T.D. Reached 01 / 10/91. 14 Date Comp. , Susp. or Aband.03/20/91 * [ 15 Water Depth, if offshore N/A feet M SL 110 NO' Of COmpletiOns 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 14296' MD/8988' TVD 14249' MD/8963' TVD YES [~ NO U 2213' feet MD 1900' (approx) 22 Type Electric or Other Logs Run DIL/BHCS/GR/SP, DENSITY/CNL/GR/CAL, CET/CBT/GR, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo-FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 113' 30" 55 SX AS CMT 10-3/4" 45.5# J-55 SURF 4160' 13-1/2" 1375 SX PF 'E' & 320 SX CLASS TOP JOB W/125 SX PF 'C' 7-5/8" 29.7# L-80 SURF 14048' 9-7/8" 1300 BBL MTC & 316 SX CLASS G , 5-1/2" 17.0# L-80 13756' 14296' 6-3/4" 1125 SX CLASS G , 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 4-1/2" 13794' 13686' 14037'-14132'MD/8851'-8901'TVD W/4 SPF 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD FIowTubing iCasing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~. 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE · NOTE: DRILLED 1/17/91. TUBING RUN 3/2/91. PERFORATED WELL 3/20/91. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE DEC Submit in duplicate / c0mmtSsiOtl Alaska 0il & Gas Cons. Anchorage GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. -, , TOP SADLEROCHIT 14038' 8851' BASE SADLEROCHIT 14132' 8902' NONE 31. LIST OF A'i-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my' knowledge Signed , Title AREA DRILLING ENGINEER Date ,, , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21: Indicate whetherJfrom 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 ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 995 DATE: 7-t2-911 REFERENCE: ARCO CASED HOLE FINALS t-11 t 6-5-9t t-t 11 6-5-9t t -2t 6-7-9t 2-4 6-30-9t 4-t 6-t 11-911 qi.1, 7 (4-36 6-t9-9t X. 4,-36 6-2t -9t £4-37 6-211 -911 J4-37 6-2t-9t -28-9 j ~-33 7-2-9t 7-~ 5 6-3e-9~ * 9-6 6-~6-9~ 9-8 9-9 6-23-9~ ** 9-~e 4-~-9~ 9-~ 8 6-~ 9-33 6-~ 4-9~ -1{~9'47 6-8-9t ~ ~ -5 6-~ 2-9 t2-t2 t~-t5 6-t7-9t **** ~ 3-t 6 6-t 7-9t t6-t6 6-t3-9t ~7-t 6-t6-9t t7-~ ~ 5-8-9t PROD F'ROFILE-'-' GR-COLLAR PROD F'ROF'ILEf CCL-PERFJ GAS LIFT/ CBT/ CET~ F'FC-GR (PACKER SETTING)" CBTj CET~- F'FC-GR (PACKER SETTING)-' GR-CCL-~- COLLAR-PERFJ F'RODUCTION PACKER-- SBL/GR/CCL- CCL-PERF-- LEAK DETECTIONs' PERFORATION BREAKDOWN/ COLLAR-PERF-- INJ PROFILE~' JEWELRY-~ LEAK DETECTION-~ INJ PROFILE-~ DATA FRAC TEMF'--~ LEAK DETECTION--' PROD PROFILE~-. PDK--t (}G/GR/CCL-BORAX-- LEAK DETECTION-- INJ PROFILE--- INJ PROFILE-- INJECT I ON/PRODUCT I ON-- PRISM-- LEAK DETECTION_~ RUN 11, 5" CAMCO RUN 11, 5" CAMCO RUN 11, 5" CAMCO RUN 4, 5" ATLAS RUN t, 5' CAMCO RUN 4, 5" SCH RUN t, 5" SCH RUN 11, 5' ATLAS RUN 4, 2"&5" SCH RUN 11, 2"&5" SCH RUN t, 5" ATLAS RUN 4, 5" ATLAS RUN 11, 5" Al'LAS RUN 4, 5' ATLAS RUN t, 5" ATLAS RUN t, 5" ATLAS RUN t, 2'&5' CAMCO RUN 4, 5" CAMCO RUN t, 5" ATLAS RUN t, 5' CAMCO RUN t, 5' CAMCO RUN t, 2" CAMCO RUN t, 5' CAMCO RUN 4, 5' CAMCO RUN t, 5" CAMCO RUN t, 5" CAMCO RUN t, 5" ATLAS RUN t, 2"&5" CAMCO RUN t, 5" CAMCO RUN t, 5' CAMCO RUN t, 5' CAMCO RUN t, 5' ATLAS RUN t, 2"&5' CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY. AS HAVE A'NICE DAY! SONYA WALLACE AT0-11529 RECEIPT OF DATA. DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON - MARATHON MOBIL ' APPROVED F'B WELL FILES ~0 0~. BPX STATE OF ALASKA TEXACO * CORRECTED LOG INTERVAL FOR 9-6 IS 6700-7708 ** REFERENCE MIX UP ON TRANSMITTAL 91159 - POSSIBLE DUPLICATE *** CORRECTED LOGGED INTERVAL FOR 9-40 I$ 11~95t-t425t **** CORRECTED API~ FOR t~-116 IS 50-029-2082J LOG~ -, .... p'~'O"~'BOX' ~ O~Z&~ '. ..... ---.--'----? -'.~ ~--~??,.,-~,~-~-,~-~"-',~--.:~ -.~ '~.'-..-" . -- ...... ~' '~. '- '. ~ .:,- ? '..,' ', '. ~ ~"-.:~:-~:~.~';'~.-.~-, ,.. - '~,,~,,,~c~ : ~-~KA' ~995~ e ::-~:'~, :Y~.~?:-~.:-:;---;~ :.' .'._'.-~: ~ ..~~z~-~~.:~~~~:~ ~~- ] ~ . ~.~~ '-~' ~ ~:. ;'~ .... - .....- ....... ...- ~ ..... . - ~ . .. ..... ~.,.. ~..,...- . -~' --; .... x ~;~;; ~'-'~;~.7-::;~ ~;-': [ ,-z-~ ~.~ ,~..~_ ~...--....~,;~-:~ :~.~;~-~',~}~-~-r~-;~ ?:~; .... .-. ~ ~-'.'~;~?--~ .~' -";- ..... ' ~,Gr~'?~;?~'. :~'~-~ ~'9~ :..-"" ,*:_;77~-:~*~?~?;~¥-?~b~w, ...... ~ ........ -" ~-.-:: '_: ...... ;:..~-;-~.~~~':~~ .-..x..: - .................. ~ '~. ' , -, . -~ ~-¥ '..'--~r,=.~,.-¥,~.~ *~:~ ~"-~':~ '~-',;' ;~: ; ' . , ~?.. -~'- · : -' .... ~." ~ ~ ~" .;-- ....... -' ".' ~ L -r.. ~ .. RE~'E' E': .... ARc0' CA~ED'~HOLE'"FINAL~' ~;~--'' ' "" "" "'"'?'~ ~*' ' '- - ' RENC ' . ... .... ~ .... ~-~ .. ;_~g-.-=_,-.-.,-',:~..-*, ~-.;r.r:~ ..-,.*':-~-.-~ ~. ~_~ '.--:-~ .:.~ ~.-.: ::~._ ~ .*-,-.~--,~-,-~-~ ~. ~-~'=.~ -.~. ~'--,.-'-,,-'- ,~ -.:~'~-'-"- - - ~-~ .... ;.',FER~R~CORD-,--~-,-,~-.' .......... -~;~ ........ ~'.. -~' ......... 4 Se ~ ........ ~ .................... ~ ....... - .......... - ............... . .......... .......... CAM .__ :.-~. ,-~,,_.~.. ~_.-,,.~;~-~- -_~ ..... '-~,~ '- .......... ~-,.-~ ;:~-~--~.~-- - .... . ..... -; .' -:~. RUN .... S .~. ,- .......... .~-~--,~,~,.,~. -~ -~.~r?~->-,,~."_,.-~,,-'.".., .... ,..-,.,.-- .. .... ._ RUN-t ~ ;-. 5 · . ...... _ .... S -.- . -. -______.~ - ...... . ....... - ............ , ...... ~ .......... - ~RUN,.~., ....5.. .... .:~...~.~... ., _ .... ~ ~w ..... ~,..r-:-. =' ' ~--. .... - .... COEEAR~~~-~;~:;.-~,-~..,.~-.~.~.'?:;-~-~?'..~'-.,-'?,'~,~.-'-,~---.~--:~: .?x ...... i ",'~-'"'~; CO .... --,-- 5-5 ~ -.,-.,- .............................. ~-~-.-~ ..... -~-.--- - - .... .~, ........... - ,'.' 5 --' ..... ' ' '"' 3 ~? .... "~' - ......... -""~-~ ...... '~ ........ N" ............. : ...................... RUN · ~ , - 2 & .... _ ..,~.~...~..._ ~ ...... _-~r~LEAK~-..DETECT[O ~-~--: :.-: -.. ... . ... , -'- , .--~-;- . ""' <'-?;' .... -4-t~-~ -?- ~' -~- ~'- '- " ............................ 5 ...... CAHCO .- - 5-3 - .- ~.,. .---~,- ..... '-. ---- .............. · RUN t, ....... ........ &~& ....... ~t t;gi .... ' ~AHHA-'RAYZCCL-"TA~ · "- ' "' ' ' "~'UN"t "' 5' '?...:~":-?:~CH" . , ...;~ :..;~ - ._ . - . -. ._ .' .?. . ~ ,:~-. ,-s, 9?9 .... ...... STATE OF ALASKA '" ~ ,SKA OIL AND GAS CONSERVATION ;/IMISSIOI~ ~ j WELL COMPLETION OR RECOMPLETION REPORT AND Clariten Of W~l 1 Status of Well OIL ~] GAS r'~ 2 Name of Operator 7 Permit Number ARCO Alaskar Inc 90-169 3 Address P.O. Box 100360r Anchorage, AK 99510-0360 4 Location of well at surface 1405' FSL, 62' FWL, SEC 1, T10N, R15E UM At Top Producing Intewal 1501' FNL, 1096' FWL, SEC 31, T11N, R16E UM At Total Depth 1334'FNL, 1238'FWL, SEC 31, T11N~ R16E UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 52' 12 Date Spudded I 13 Date T.D. Reached 12/21/90. I 01/10/91. 17 Total Depth (MD+TVD) 14296' MD/8988' TVD 14249' MD/8963' TVD ADL 28343 14 Date Comp., Su~o. or Abe~. 03/20/91° 19 Directional Sun~ey 18 Plug Back Depth (MD+TVD) 8 APl Number 50-029-22118 9 Unit or Lease Name PRUDHOE BAY UNIT 10 Well Number 11 Field and Pool PRUDHOE BAY FIELD PRUDHOE BAY OIL POOL J 15 Water Depth, if offshore [16 No. of Completions N/A feet MSLJ 1 20 Depth where SSSV set 21 Thickness of permafrost 2213' feet MD 1900' (approx) 22 Type Electric or Other Logs Run DIL/BHCS/GR/SP, DENSITY/CNL/GR/CAL~ CET/CBT/GR~ GYRO 23 CASING, LINER AND CEMENTING RECORD HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30' 55 SX AS CMT 13-1/2' 1375 SX PF 'E' & 320 SX CLASS C SETTING DEPTH MD CASII',~3 SIZE WT. PER FT. Gl:lADE TOP B33T(]~ 20' 91.5# H-40 SURF 113' 10-3/4' 45.5# J-55 SURF 4160' 7-5/8" 29.7# L-80 SURF 14048' 5-1/2" 17.0# L-80 13756' 14296' 24 Perforations o )eh to Production (MD+TVD of Top and Bottom and interval, size and number) TOP JOB W/125 SX PF 'C' 9-7/8' 300 BBL MTC & 316 SX CLASS G 6-3/4' 125 SX CLASS G 25 TUBING RECORD 14037'-14132'MD/8851'-890 I'TVD WI4 SPF SIZE DEPTH SET (MD) 13794' PACKER SET (MD} 4-1/2' 13686' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL [MD) N/A AMOUNT & KIND OF MATERIAL USED 27 N/A Date First Production Date of Test Houm Teated Flow Tubing CaNng ~ Press. 28 PROOUCTION TEST IMeemd of Operatfon (Flowing, ga~ lift, etc.) CALCULATED OIL-BaL MCF CORE DATA WATER-BBL WATER-BBt. Brief description of lib~logy, porosity, fractures, apparent dips and preaerx:e of oil, gal or water. Submit core chipe. ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (con') NONE *NOTE: DRILLED 1/17/91. TUBING RUN 3/2/91. PERFORATED WELL 3/20/91. Submit in dupiicate,~/~ Form 10-407 Rev. 7-1-80 WELL HISTORY ADDENDUM WELL WORK LOG Well Ct 9-40 Date' Work performed: INITIAL PERFORATIONS AFE: AS3951 3/1 9/91 -3/20/91 RU Halliburton. RIH w/ gun #1, shoot interval f/ 14117'-14132' w/ 4 spf, 3 shots didn't fire. RIH w/ gun #2, shoot interval f/ 14097'-14117' w/ 4 spf, ASF. RIH w/ gun #3, shoot interval f/ 14077'-14097' w/ 4 spf, ASF. RIH w/ gun #4, shoot interval f/ 14057'-14077' w/ 4 spf, ASF. RIH w/gun #5, shoot interval f/ 14037'-14057' w/ 4 spf, ASF. RD. Perforated f/ 14037'-14132' w~ 4 spf DRILUNG SUPERINTENDENT RECEIVED · AIo..::Jifct 0JJ & Gas [.;otis. t;ommissto~ Anchorage ARCO O~ ~dGm~' 0 Well History - Initial Report IItlt~'ll~l~ll~: Pmplrl al~d ~ ffrlt Wadnelday aftar a well il spuddld or wol'l<ovlr ol~lrltlonl afl itl~ted. on the form giving incluliYe datel only, Daily .ork ~ t~Tl~l~ml~ld ~CO ~SK~ District IState ICounty,parish or bOrOUgh NORT .H SLOPE Lease or Unit ~]~J~iL: 28343 Title COJv~D LET~.. AK Field .. JWell no. PRUDHOE BAY I DS 9-40 Auth. or W.O, no. A53951 API: 50-029-22118 Operator IARCO W.I ARCO 21. 7800 Spudded or W.O, begunAcCEPT IDate 02/28/91 IH°ur 1530 H~S IPri°rstalus~faW'O' Date and depth as of 8:00 a.m. 02/10/91 03/01/91 ( TD: 0 PB:14249 SUPV:RWO 03/02/91 ( TD: 0 PB:14249 SUPV:RWO Complete record for each day re~ed NABORS 2ES ~0) MIRU SOS, RIH, LOG CET/CBT/GR F~ 14249'-13000' & 10945'- 7100'. RA/g GR F/ PBTD-4150' POOH, RU AND LOG GYRO F~ SURF-14200' RD $35,059 COMPLETION RUN GR/JB/CCL. 7-5/8"@14086' MW: 9.1 NaC1 RIG ACCEPTED @ 15:30 HAS, 2/28/91. N/D TREE. N/U BOPE. PULL BPV. TEST BOPE. RIH TO 573'. CIRC OUT DIESEL. POOH. TEST CSG. R/U ATLAS. RIH W/ GR/JB/CCL TO 13758'. POOH. RERUN. DAILY:S33,370 CUM:$2,333,249 ETD:S598,365 EFC:$4,660,884 RIH W/ TUBING. 7-5/8"@14086' MW: 9.1 NaCl RIH W/ GR/JB/CCL. POOH. M/U OTIS 7-5/8 .... BWD" PERM PKR W/ 3-1/2" TT. RIH. PKR NO SET. POOH. C/O CHRGES. RIH. SET PKR @ 13686'. R/D ATLAS. RIH W/ TBG COMP. DAILY:S47,473 CUM:$2,380,722 ETD:S645,838 EFC:$4,660,884 The above ia corr~c! '~ · ~· ~or form p~l~m'~tlon ~ Pmcedum~ M~ual, ~1~ 10, Drilling, Pages 88 and 87. DttlHng SUpt. AR3B-459-1-D I Number i/I daily w/Il hllto~y forml conlecutively they ace prlplmd for tlch will. ARCO ~ and Gas Company Daily Well History-Final Repor Instructions: Prepare and submit th~..~~' ..oft ~ fl~'~ Wednesday after all.owable has Dean assigned or Well is Plugged, Abandoned, or. Sold. . "Final Rel~rt" s~ould be submltt~ am ~,lapefN:led I.or an mdehmte or a~prec, l_a.ble, lengt?~,o,f t,me. On workove~ whren a~ othcial test ~a not required upon completion, rel~ort ~ r~'~e~tafl'w~ test date in blocks provided. /ne Plnal Reflort form may be used rot sporhng the entire operation if space is available. '~ ~ ~.. IAccounting coat center code Slate AK IWell no. DS 9-4C District . - _ - ICounty or Parish ARCO ALASKA INC. { NORTH SLOPE Field JLea,~e or Unit PRUDHOE BAY I ADL: 28343 Auth. or W.O. no. ITitle AS3951 [ COMPLETE API: 50-029-22118 Operator ~:~.C O IA.R.Co. W.I. S0udded or W.O. begun Date ACCEPT 02/28/91 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bsndonment of this well 21. 7 8 0 0 our IPrior slatus if a W.O. 1530 HRS J Date and depth as Of 8:00 a.m. 03/03/91 ( TD: 0 PB:14249 SUPV:RWO Complete record for each day reposed NABORS 2ES 32) RIG RELEASED @ 24:00 HRS. 7-5/8"@14086' MW: 8.6 Seawater RIH W/ 4-1/2" TBG. M/U CNTRL LINES TO SSSV. STING SEAL ASS'Y INTO PKR. TEST SAME. M/U GEN IV HGR. DISP OUT 9.1 BRINE W/ 8.6 SF~AWATER. DISP W/ 110 BBLS DIESEL. LAND TBG HGR. TEST TBG. N/D BOPE. N/U TREE. TEST TREE. SET BPV. SECUR~ WELL. RIG R~LEASED @ 24:00 HRS, 3/2/91. OTIS 4-1/2" "HRQ" SSSV @ 2213', OTIS 7-5/8" X 4 .... BWD" PERM PKR @ 13686' TT @ 13794'. DAILY:S315,183 CUM:$2,695,905 ETD:S961,021 EFC:$4,660,884 Old TD I New TO PB Oel~th I Released rig I Date Kind of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data · W~ll no. Date Reservoir Producing Interval Oil or gasTest time Production OII on lest Gas Der ~ay Pump size, SPM X' length Choke size T.P. C.P. Water % GOR Gravily Allowable Effeclive Ca!e corrected · ;or form prepar~i"~n and d~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INuml~r ail daily well history forml con~cullvely ~age ~o they are prepared for each well. ARCO G. ~,td Ga. ~. ~) Well Hlatory - Initial Report - Dali Pl~plrl ~ Ikdgl~t tlll~~ ~l~ ~ l~tlt Widely Iftlt a inclulivl dltll only, lal~: Dilly wort ~ t~-~tWIImlrlzld o~ the form glvtng will il Ipuddld or workov~r ARCO ~. NORTH District '~'~:...~..: -' ICounty. pln~horbgh .... PRUDHOE ~' - ~/:)L: 2R~aq , Field AS3951 I''"'~ Dr un't DRILL }Well~ 9-40 Aura. o, W.O. no. ITme I API: -~O-n?9-22!!_m ARCO Operator IARCO WJ. 21. -/8 0 0 SPUD 12/~1/90 12; 3G 1 NA~ORS 128E Date and depth ea o~ ~:oo i.m.12/21/90 ( 'z'u: ~U' ( SUPV: ZR 12/22/90 TD: 1094' SUPV: ZR 12123/90 TD: 2663' SUPV:ZR 12/24/90 ( TD: 4172'( SUPV:ZR 12/25/90 ( TD: 4172'( SUPV:ZR 1'2/26/90 ( Complete rlcord for each day m~ 1) N/U DIVERTER. 80) (, 2) (:1014) (3) (1569) 4) 1509) R/D FLOOR, PIT. MOVE PITS OFF DS 9-47. LEVEL SUB. R/U FLOOR. N/U DIVERTER. HRS, 12/21/90. DAILY:S16,000 CUM:$16,000 -.--~-.; 0.¢ ....,~o; 0 MOVE SUB. SPOT & RIG ACCEPTED @ 05:00 ETD: $16,000 EFC: $2,926,000 DRILLING. MW: 8.9 VIS:300 N/U DIVERTER. P/U BHA. TEST DIVERTER. DRLG F/ 113'-491". POOH. RIH. DLRG F/ 491'-1094'. RIG SPUDDED @ 12:30 HRS 12/21/90. ' DAILY:S83,127 CUM:$99,127 ETD:S83,127 EFC:$2,942,000 DRILLING. MW: 9.1 vis:400 DRLG Fl 1094'-2663'. CBU. DROP SSS & PILL. POOH CHANGED BHA. RIH. ' DAILY:S77,385 CUM:$176,512 ETD:S250,000 EFC:$2,852,512 MW: 9.2 VIS:300 TD 13-1/2" HOLE. DRLG F/ 2663'-4172' DAILY:S67,444 CUM:$243,956 ETD:S320,000 EFC:$2,849,956 5) PERFORMING TOP JOB. 10-3/4"@ 4160' MW: 9.2 VIS:300 ~.~.C~_Z._I~C. SHORT TRIP TO HWDP. CBU. POOH. RUN 10-3/4" CSG. ~~T COLLAR @ 4066'. FLOAT SHOE @ 4158'. PUMPED CMT JOB: ~~~ w~TER SPACER. ~ PLUG. 1375 SX PF 'E' C,T ,/ S,320 SX 'G' TAIL CMT W/ ADDITIVES, TOP PLUG, 391 ~'~L~Y:~55,494 CUM:$299,450 ETD:S320,000 EFC:$2,905,450 6) DRILLING OUT. 10-3/4"@ 4160' MW: 8.4 VIS: 0 4172'( SUPV:ZR 12/27/90 ( TD: 5960'( SUPV:L~ 12/28/90 ( TD: 7437'( SUPV:LP o) 7) ;788) l) 1177) PERFORM TOP JOB N/ 125 SX PF 'C' CMT. L/D CSG TOOLS. L/D TOP JOB. N/U FMC WELLHEAD & BOPE. P/U 9-7/8" BHA. RIH. TAG FLOAT COLLAR @ 4077'. CBU. DRLG FLOAT COLLAR TO 4090'. DAILY:S266,206 CUM:$565,656 ETD:S700,000 EFC:$2,791,656 DRILLING. 10-3/4"@ 4160' MN: 9.2 VIS: 38 CBU. PERFORM L.O.T. (EMW - 14.8 PPG). DRLG F/ 4182'-5741'. CBU. SHORT TRIP TO SHOE. DRLG F/ 5741'-5960'. DAILY:S70,398 CUM:$636,054 ETD:S800,000 EFC:$2,762,054 DRILLING. 10-3/4"@ 4160' MN: 9.3 VIS: 43 DRLG F/ 5960'-6620'. CBU. DROP SURVEy. POOH. C/O BIT. RIH. DRLG F/ 6620'-7437'. DAILY:S67,348 CUM:$~03,402 ETD:S975,000 EFC:$2,654,402 Title AR3B-459-l-D INum~er ill ~ w~il h~im'y to~ml iPage no. ARCO C ~d Gas Company Daily Wall History--lnteri |ltll/l~: 'rhi,,. foll'~ il ull(I (~urir~ dnlllr~ or workov~r oplrlliOnl, if tilling, coring, or D~rforlllng, Show Iormllio~l nlme m dllCnhmg work Oerformed. Numar all drill Item tilts ~egl~le~flMly. Alla~ de~:ri!~lion of all corel. Work ~erformed by Producing SeCtion wdl be reported on "la[aftra" coml01ltion. Rl1:4311 official or rel~rll~eet~ve teal en "Fk~6" form. t) SuOmlt "leterlm" ,~le[I when tilled out Out not Itll tre~3uently thin every 30 alye. or C2) ~ Wednlldly OI the we. ex in w~ich oil Mrln,~ il I~t. ~P, Jbmlt weekly for workovere and IolJowlng selhng Ot OH strm§ until completion. Dltl and del;m el of 8:00 &m. I Count¥ Or ALASKA INC. I NORTH SLOPE ! I Lelll or Unit DS 9 40 PR~HOE BAY - NABORS 28E 12/29/90 ( TD: 8542'( SUPV:LP 12/30/90 ( TO: 9600'( SUPV:LP 12/31/90 ( TD:10197' ( SUPV:LP 01/01/91 ( TD:ll018' ( SUPV:LP 01/02/91 ( TD:12612' ( SUPV:LP 01/03/91 ( TD:13745' ( SUPV:ZR 01/04/91 ( TD:13903' ( SUPV:ZR 01/05/91 ( TD:14068' ( SUPV:ZR 01/06/91 ( TD:14104'( SUPV:ZR JSllle 9) .105) LO) L058) L1) 597) L2) 821) 3) 594) 4) 133) 5) 158) 6) 165) 7) 36) AK Iwell no. POOH FOR BIT. 10-3/4"@ 4160' M-W: 9.5 VIS: 41 DRLG F/ 7437'-8542'. CBU. DROP SURVEY. POOH. CIRC. POOH SLOW. DAILY:S65,714 CUM:$769,116 ETD:S1,050,000 EFC:$2,645,116 DRILLING. 10-3/4"@ 4160' MW: 9.6 VIS: 53 POOH. C/O BIT. RIH. DRLG F/ 8542'-9567' SHORT TRIP 11 STDS. DRLG F/ 9567'-9600' DAILY:S69,852 CUM:$838,968 ETD:S1,150,000 EFC:$2,614,968 RIH. 10-3/4"@ 4160' MW: 9.6 VIS: 55 DRLG F/ 9600'-10197' CBU. DROP SURVEY. POOH. L/D JARS. M/U NEW BIT. RIH. DAILY:S83,867. CUM:$922,835 ETD:S1,200,000 EFC:$2,648,835 DRILLING. 10-3/4"@ 4160' MW: 9.7 VIS: 48 RIH. DRLG F/ 10197'-11018' DAILY:S62,812 CUM:$985,647 ETD:S1,275,000 EFC:$2,636,647 DRILLING. 10-3/4"@ 4160' MW: 9.8 VIS: 52 DRLG F/ 11018'-12074' SHORT TRIP 20 STDS. DRLG F/ 12074'-12612' DAILY:S77,534 CUM:$1,063,181 ETD:S1,400,000 EFC:$2,589,181 DRILLING. 10-3/4"@ 4160' MW: 9.8 VIS: 58 DRLG F/ 12612'-13492'. CBU. 16 STDS SHORT TRIP. DRLG F/ 13492'-13745' DAILY:S68,661 CUM:$1,131,842 ETD:S1,520,000 EFC:$2,537,842 R~AM TO BTM. 10-3/4"@ 4160' MW: 9.8 VIS: 45 DRLG F/ 13745'-13903'. CBU. POOH. L/D BHA. TEST BOPE. P/U BHA #8. RIH TO 13790'. REAM TO BTM. DAILY:S94,687 CUM:$1,226,529 ETD:S1,575,000 EFC:$2,577,529 LOOKING FOR TOP OF SADLEROCHIT10-3/4"@ 4160' MW:10.1 VIS: 51 DRLG F/ 13903'-14051'. CBU. DRLG F/ 14051'-14068' CBU. DAILY:S68,328 CUM:$1,294,857 ETD:S1,575,000 EFC:$2,645,857 RUNNING 7-5/8" CSG. 10-3/4"@ 4160' MW:10.2 VIS: 53 DRLG F/ 14068'-14104'. CIRC SWEEP. SHORT TRIP 44 STDS. CIRC. POOH. RIH. CIRC. SPOT 40 BBLS PILL LCM ON BTM. POOH. R/U TO RUN 7-5/8" CSG. RIH W/ 7-5/8" CSG. DAILY:S55,564 CUM:$1,350,421 ETD:S1,575,000 EFC:$2,701,421 Ddlltng Supt. AR38-459-2-8 INumDer all daliV well hiStOry fofmg con.lecuhvely ]: :;= --' as they are ~;reoerea lo, each well ARCO ~ nd Ga. Company Daily Well History--Inter Iltla'll~'t:l~l~ ?All fOl'~ il ulld dl,ltlr,~ dlllllng or wo~ ol)~rltiOnl. If tilting, coring, or oerforltmg. ShOW formation name m delcr~bing work 0erformed. Numl3.lr ail drill item teltl ~o~tlall~,. Attl~fl dl.l~rll3tion ot ail corel. Worl~ Olrformed by P~ducing Section will I~e rl~orled On "lnt~rfe~" ;heell until tmal completion. RII=,O~ official or re~'l~lllat'twl I~11~ O1~ "Fill~" form. 1) SuOm~t "IRIIHJ" sheets when fille(~ out I~u! not leis trecluently lain every 30 days. or (2) on Wednel~l&y of IAi wi. Ill iN wl~ic~ Oil I~tl'l~ il I~! S. UI~I~'II! weekly roi' workovere Ina following selling ot o*1 strmG unhl complellon County or Perish OIItriot I NORTH SLOPE ARCO ALASKA INC. ! ILIII~ Or Unit ;i,~ I DS 9-40 PRUDHOE BAY Completl record lot each day while drilling or wor~over ~n pr~re~ ~ABO~S 28~ 01/07/91 ( TD:14104' ( SUPV:ZR 01/08/91 ( TD:14104' ( SUPV:ZR 01/09/91 ( TD:14150' ( SUPV:ZR 01/10/91 ( TD:14296' ( SUPV:LP 01/11/91 ( TD:14296 PB: 0 SUPV:LP 01/12/91 ( TD:14296 PB: 0 SUPV:LP 01/13/91 ( TD=14296 PB: 0 SUPV:LP AK IWoll oo i ) o) 1') 0) ) 46) ) 146) 2) 3) 4) N/U BOPE. 7-5/8"@14048' MW:10.2 VIS: 43 RIH W/ 7-5/8" CSG. CIRC. PUMP 50 BBLS ARCO PRE-FLUSH. DROP 1ST PLUG. PUMP 300 BBLS MTC. DROP 2ND PLUG. PUMP 316 SX 'G' CMT @ 15.8 PPG, YIELD 1.15, W/ 1.3% FL-20, .1% CD-31. DROP TOP PLUG. DISP W/ 644 BBLS MUD. NO BUMP PLUG. FLUSH /MNNULUS W/ 300 BBLS WATER. N/U BOPE. SET EMERGENCY SLIPS. SET PACK OFF. DAILY:S200,464 CUM:$1,550,885 ETD:S1,950,000 EFC:$2,526,885 P/U 3-1/2" DP. 7-5/8"@14048' MW: 0.0 VIS: 0 N/U BOPE. TEST SAME. L/D 5" DP & BHA. M/U BHA #9 & 3-1/2" DP. DAILY:S72,220 CUM:$1,623,105 ETD:S1,950,000 EFC:$2,599,105 DRILLING. 7-5/8"@14048' MW: 9.7 VIS: 37 RIH W/ 3-1/2" DP. CBU. DRLG HD CMT F/ 13916'-13961' CIRC. TEST CSG. DRLG FLOAT COLLAR & HD CMT TO 14027' CIRC. TEST CSG. DRLG CMT & FLOAT SHOE & 10' NEW HOLE F/ 14027'-14114' PERFORIVLED EMW TEST TO 12.5 PPG. DRLG F/ 14114'-14150'. DAILY:S63,374 CUM:$1,686,479 ETD:S2,000,000 EFC:$2,612,479 TD 'WELL. CBU. 7-5/8"@14048' MW: 9.8 VIS: 40 DRLG F/ 14150'-14296'. CBU. DAILY:S48,405 CUM:$1,734,884 ETD:S2,050,000 EFC:$2,610,884 RIH. 7-5/8"@14048' MW: 9.8 WBM 3 $TDS SHORT TRIP. CBU. POOH. R/U ATLAS W/L. W/L RUN #1 DIL/BHCS/GR/SP. L/D TOOLS. W/L RUN #2 DENSITY/CNL/GR/CALIPER. TOOL'STUCK. R/D LUB. CUT LINE. STRIP OVER WIRE. RIH STRIPPING OVER W/L W/ DP & TSA FISHING TOOL. DAILY:S46,975 CUM:$1,781,859 ETD:S0 EFC:$4,707,859 RETRIEVE W/L SHIVE. 7-5/8"@14048' MW: 9.8 WBM RIH STRIP OVER W/L. CIRC @ 14077' FREE FISH. POOH 5 STDS. POOH W/ FISH. REMOVE SOURCE. L/D TOOL. RETRIEVE W/L SHIVE F/ CROWN. DAILY:S43,658 CUM:$1,825,517 ETD:S43,658 EFC:$4,707,859 RIH W/ LNR. 7-5/8"@14048' MW: 9.8 WBM M/U BHA. RIH TO 14204' REAM F/ 14204'-14296'. CBU. SHORT TRIP TO SHOE. PUM~ SWEEP. POOH. R/U TO RUN LNR. RIH W/ LNg. DAILY:S181,406 CUM:$2,006,923 ETD:S225,064 EFC:$4,707,859 AR38-459-2-B Drilling Supt. NumOer all dadv well hlllOry formg conseCullvely a~ lhey a~e oreoareO ~o~ each well ARCO l, nd Gas Company Dally Well History--Inter h~: This form il ul~l dglflglg drllllt~ or ~O~r O~lliO~l. I~ tilting. COnn.. Or Derforll~ng. lhow ~ormll~on Alii ,~ d/scr~b~n~ wor~ performed. Num~r III ddll stem {l~l ~u~U~ly. i~ d~flDlion ot III corll. WOA ~rformld Dy Producing SeChOn will be riddled on "I~WH~" ~nelts unhl hnat On Wldnl~ly of Ihe w~k i~ ~iCh oil ~d~ il ~t. Su~it w~kJy tot worko~ and tollowl~g Selling Ot OH slrmg until comolll~on. ARCO ALASKA INC. ORTH SLOPE ~=illd ILee~ or Unil PRUDHOE BAY I DS 9-40 Coml~lltl r~corcl for tach day while drdling or workovmr m orogrels NABORS 28E a~ of a:O0 I.m. 01/14/91 ( TD:14296 PB: 0 SUPV:LP 01/15/91 ( TD:14296 PB:14249 SUPV:LP 01/16/91 ( TD:14296 PB:14249 SUPV:LP 01/17/91 ( TD:14296 PB:14249 SUPV:ZR 5) 7) For form ~r~lrat~ ~rt~ diltribulioh ~ Pr~Cedurl~ M~u~l ~ectidn 10, AK POOH. 5-1/2"@14048' MW: 9.8 WBM RIH W/ 5-1/2" LNR. CIRC @ 14296'. PUMP 20 BBLS PREFLUSH, 38 BBLS 'G' (125 SX) W/ 50% S-8, 100 GHS BA-86L, 1% FL-20, .3% CD-31, .06% A-2. CHASE CMT W/ 94 BBLS MUD. BUMP PLUG TO 3000 PSI. SET HGR. POOH. M/U BIT. TAG CMT @ 13653' DRLG CMT TO 13757'. CIRC. POOH. FLOAT SHOE @ 14297', FLOAT COLLAR @ 14250', TOL @ 13756'. DAILY:S121,894 CUM:$2,128,817 ETD:S346,958 EFC:$4,707,859 LDDP. 5-1/2"@14048' MW: 9.1NaC1 L/D BHA. P/U 4-3/4" BIT. RIH TO TOL @ 13757' DRLG CMT F/ 13757'-13800'. WASH & REAM F/ 13800'-14145' DRLG CMT F/ 14145'-14202' (LANDING COLLAR). TEST LNR LAP. DRLG LANDING COLLAR & HD CMT TO FLOAT COLLAR @ 14249'. TEST LNR. PUMP SWEEP CHASED BY 250 BBLS SEAWATER CHASED BY 9.1 PPG BRINE. CIRC. POOH. DAILY:S64,350 CUM:$2,193,167 ETD:S411,308 EFC:$4,707,859 RIG MAINTENANCE. 5-1/2"@14048' MW: 9.1 NaC1 POOH. FREEZE PROTECT TOP 500' W/ DIESEL. L/D DP & BHA. N/D BOPE. N/U DRY HOLE TREE. TEST TREE. RIG MAINTENANCE & REPAIR. DAILY:S42,158 CUM:$2,235,325 ETD:S453,466 EFC:$4,707,859 MOVING RIG. 5-1/2"@14048' MW: 9.1NaC1 CLEAN RIG FLOOR. CHANGE STAB BLADES FOR BHA. CHANGED WHEELS ON SKATE. CHANGE ROTARY CHAIN. R/D RIG FLOOR. MOVE RIG. SPENT DAY WAITING ON WEATHER. DAILY:S64,554 CUM:$2,299,879 ETD:S518,020 EFC:$4,707,859 Drilling Supt. Drilling, AR30-459-2-8 NumOer all ~al~v well h~$1Ory Iorms as ~ey are prepared for elc~ well ARCO ~.. ~, and Gas Company InltrMolMl: Prepare ind "FIlial ~lwrt" should recruited upon completlol% operation it space ia availli~ll~ DiStrict ARCO ALASKX Field PRUDHOE BAY Auth. or W.O. no. AS3951 Dally Well History-Final Repor Wedneldly after allowable has been elllgne(~ or well Is Plugged, AbenOoned. or Sold. for an indefinite or appreciable length of time. On work~overl when an official felt is not test (]eta in blocks provided. The "Flnit I~el)erl" form may be used for reporting fha entire Counly or ParishN, oRTJ,.{ SLOPE LeeS. orUnif ADL: 28343 Title DRILL Operator ARCO IA.FI. Co. W.I. Spudded Or W.O~T~ I Date 12 / 21 / 9 0 ! Date and depth Complete record for each day c~o_rted as of s;oo a.m. NABORS API: 50-029-22118 21.7800 tAccounling cost center code State AK Iotal number of wells lactJve or inactive} on this os( center prior to plugging and I b)andonment of this well our ~.2 . 30 IPrlor slatus if a W.O. 01/18/91 (9) TD:14296 PB:14249 SUPV:ZR RIG RELEASED @ 09:00 HRS. 7-5/8"@14086' MW: 9.1NaC1 RIG RELEASED @ 09:00 ERS, 1/17/91. DAILY:SO CUM:$2,299,879 ETD:S518,020 EFC:$4,707,859 ECEIVE Alaska Oil & Gas Cons. Commissiou Anchorage Old TO { New TD I PB Depth Released rig l{Oate IKind of rig / Classifications (oil, gee, etc.) Type completion (lingle, duel, etc.) Producing method Official rilervolr name(a) Potentlll teat data We~! no. 6ate ReServoir' Produ<~ing Inte~el 1611 or' g~,,' Test lir~e ProdUction ' , , , 011 on test G'as 0er Clay , Pump size, SPM X' lengtl~ Choke IlzS T.P." C.I~. Water % GOR Gr&viiy Allowable Elfect,,e" '~'a,e corrected .. Drilling, Pages 86 and 87. ., AR3~-459-3-C INumberIii dlily will hlltory fermi conSecutl~,lly I they are prepared for each well. SUB- SURFACE DIRECTIONAL SURVEY r~ UIDANCE ]-~ ONTINUOUS ~ OOL APR 2 9 ~g9~ Oil .& Gas (Sons. ~Anchorage Company ARCO ALASKA, INC. Well Name D.S. 9-40 (1405' FSL, 62' FWL, SEC_ 1, T10N, R15E, UM) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 74367 Loqqed By: SCHWARTZ I Date 10-FEB-91 Computed By' KOHRING II * SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: lO-FEB-1991 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ, DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 41DEG 32 MIN EAST COMPUTATION DATE: 24-FEB-91 PAGE ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 10-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN -52 O0 48 O0 148 O0 248 O0 347 99 447 97 547 90 647 71 747 38 846 99 0 0 N 0 0 E 0 15 N 7 12 E 0 15 N 45 45 E 0 15 N 55 57 E 0 54 N 60 54 E 1 28 N 49 46 E 2 52 N 42 5 E 4 14 N 37 18 E 4 57 N 37 3 E 5 16 N 37 4 E 0.00 IO0.O0 200.00 300.00 399.99 499.97 599.90 699.71 799.38 898.99 998 44 946.44 6 48 58 1045.58 7 57 51 1144.51 8 52 23 1243.23 9 18 95 1341.95 9 9 63 1440.63 9 28 17 1539.17 10 16 26 1637.26 12 21 57 1734.57 14 23 71 1830,71 17 22 N 39 27 E N 41 11 E N 41 55 E N 40 51 E N 39 19 E N 37 50 E N 37 51 E N 40 33 E N 41 5 E N 39 30 E 0 O0 100 O0 200 O0 300 O0 40000 500 O0 600 O0 7OO O0 800 O0 900 O0 1000 O0 1100 O0 1097 1200 O0 1196 1300 O0 1295 1400 O0 1393 1500 O0 1492 1600 O0 1591 1700 O0 1689 1800 O0 1786 1900 O0 1882 2000.00 1977 51 1925 51 19 58 36 23 20 5O 25 8 6O 26 2 63 25 38 78 25 39 85 25 54 16 28 18 87 30 42 22 32 29 ENGINEER: SCHWARTZ 2100.00 2070 2200.00 2161 2300.00 2251 2400.00 2341 2500.00 2431 2600.00 2521 2700.00 2611 2800.00 2697 2900,00 2783 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 36 2018 5O 2109 6O 2199 63 2289 78 2379 85 2469 16 2559 87 2645 22 2731 0 O0 0 16 0 49 1 08 184 3 75 744 13 52 21 59 30 39 3000.00 2865.99 2813.99 35 47 3100.00 2945.91 2893.91 37 47 3200,00 3024 72 2972.72 38 19 3300.00 3101 56 3049.56 41 39 3400.00 3174 96 3122.96 43 35 3500.00 3246 61 3194.61 44 47 3600.00 3317 21 3265.21 45 19 3700.00 3385 37 3333.37 49 14 3800.00 3448 88 3396.88 51 30 3900.00 3509 90 3457.90 53 15 40 85 53 88 68 46 84 43 100 41 116 53 133 54 152 93 175 93 203 41 N 38 7 E 235 18 N 36 12 E 272 12 N 35 17 E 313 O6 N 35 43 E 356 18 N 38 11 E 399 56 N 40 3 E 442 81 N 39 52 E 486.24 N 38 44 E 531.16 N 37 38 E 580.86 N 37 31 E 632.84 0 O0 0 O0 0 77 0 48 0 68 0 95 1 21 1 22 0 01 0 85 0 O0 N 021 N 0 43 N 0 85 N 1 14 N ,2 36 N 4 96 N 9 68 N 16 16 N 23 21 N 1 2 5 9 14 19 0 O0 E 0 01 E 0 25 E 0 67 E 48 E 99 E 62 E 47 E 33 E 63 E 0 O0 N 0 0 E 0 0 1 1 3 7 13 21 3O 21 N 2 5 E 5O N 3O 12 E 08 N 38 28 E 87 N 52 22 E 81 N 51 41 E 50 N 48 34 E 54 N 44 22 E 59 N 41 34 E 39 N 40 13 E N 36 55 E 688.78 N 36 47 E 748.65 N 37 17 E 810,01 N 38 49 E 873.87 N 39 24 E 941.71 N 39 43 E 1011.43 N 40 23 E 1082.22 N 41 16 E 1155.35 N 40 50 E 1232.58 N 40 6 E 1311.78 1 51 0 72 1 37 0 31 0 17 0 69 1 17 2 42 313 2 39 31.44 N 41.40 N 52.26 N 64.26 N 76.49 N 89.09 N 102.63 N 117.70 N 26 12 E 40.87 N 39 43 E 34 53 E 53.91 N 39 50 E 44 26 E 68.48 N 40 16 E 54 79 E 84.45 N 40 27 E 65 09 E 100.43 N 40 24 E 75 16 E 116.56 N 40 9 E 85 54 E 133.60 N 39 49 E 97.77 E 153.01 N 39 43 E 134.98 N 112.94 E 176.00 N 39 55 E 156.01 N 130.65 E 203.48 N 39 57 E 3 62 2 68 1 75 1 09 0 99 0 49 0 30 531 0 64 2.80 180.64 N 150 76 E 235 28 N 39 51 E 210.30 N 172 98 E 272 243.69 N 197 04 E 313 279.09 N 222 09 E 356 313.85 N 248 28 E 400 347.41 N 275 62 E 443 380.69 N 303.55 E 486 415.38 N 332.13 E 531 454.62 N 362.79 E 581 495.90 N 394.56 E 633 30 N 39 26 E 38 N 38 57 E 67 N 38 31 E 18 N 38 21 E 46 N 38 26 E 89 N 38 34 E 83 N 38 39 E 63 N 38 35 E 72 N 38 30 E 3.26 0.70 1 .62 3.40 1 .66 1 .00 1 .94 4.52 2.10 1 .68 540 56 N 428.52 E 689 81 N 38 24 E 588 637 688 740 794 848 904 962 1022 69 N 464.48 E 749 86 N 501.52 E 811 22 N 540.96 E 875 86 N 583.85 E 943 64 N 628.28 E 1013 96 N 673.72 E 1083 19 N 721.66 E 1156 37 N 772.45 E 1234 70 N 823.80 E 1313 87 N 38 16 E 41 N 38 11 E 38 N 38 10 E 27 N 38 14 E 01 N 38 2O E 80 N 38 26 E 87 N 38 36 E 03 N 38 45 E 22 N 38 51 E COMPUTATION DATE: 24-FEB-91 PAGE 2 ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3568 64 3516 64 54 51 4100.00 3624 4200.00 3679 4300.00 3734 4400 O0 3789 4500 O0 3844 4600 O0 3898 470O O0 3953 4800 O0 4007 4900 O0 4060 87 3572 87 56 41 36 3627 36 56 55 04 3682 04 56 32 33 3737 33 56 35 39 3792 39 56 40 86 3846.86 57 2 67 3901.67 56 53 82 3955.82 57 35 19 4008.19 59 30 N 39 25 E 1392.67 N 38 31 E 1475.27 N 38 29 E 1558.99 N 38 55 E 1642.62 N 38 35 E 1725.86 N 38 44 E 1809.21 N 38 35 E 1892.98 N 38 9 E 1976~49 N 37 44 E 2060.39 N 37 50 E 2145.39 2 13 1 ,97 0 74 0 77 1 12 0 62 1 23 1 17 0 64 1 38 1084 86 N 875 61 E 1394.13 N 38 54 E 1149 1214 1280 1345 1410 1475 1541 1607 1675 18 N 927 87 N 979 23 N 1032 08 N 1084 41N 1136 81N 1188 44 N 1240 75 N 1292 08 N 1344 57 E 1476.82 N 38 55 E 68 E 1560.66 N 38 53 E 01 E 1644 39 N 38 52 E 32 E 1727 72 N 38 52 E 29 E 1811 19 N 38 51 E 78 E 1895 05 N 38 51 E 64 E 1978 69 N 38 50 E 31 E 2062 75 N 38 48 E 50 E 2147 92 N 38 45 E 5000.00 4110 45 4058 45 59 59 5100.00 4160 17 4108 5200.00 4210 38 4158 5300.00 4260 36 4208 5400.00 4309 90 4257 5500.00 4362 15 4310 5600,00 4415 92 4363 5700.00 4470.91 4418 5800.00 4525.87 4473 5900.00 4580.53 4528 17 60 11 38 59 44 36 60 17 90 60 2 15 57 24 92 57 8 91 56 28 87 56 50 53 56 49 N 37 39 E 2231.65 N 37 48 E 2318.22 N 37 43 E 2404.51 N 37 37 E 2490.93 N 37 18 E 2577.58 N 37 48 E 2662.61 N 38 6 E 2746.77 N 37 56 E 2830.13 N 37 55 E 2913.50 N 39 2 E 2997.12 0.47 O.6O 0.33 0.77 2.08 0.79 1 .94 0.83 0.55 0.70 1743 48 N 1397 37 E 2234.36 N 38 43 E 1812 1880 1949 2017 2085 2152 2217 2283 2349 09 N 1450 43 N 1503 O0 N 1556 98 N 1609 59 N 1661 06 N 1712 82 N 1764 78 N 1815 37 N 1867 47 E 2321.11 N 38 41 E 47 E 2407.58 N 38 39 E 38 E 2494.18 N 38 37 E 18 E 2581.03 N 38 34 E 10 E 2666.26 N 38 32 E 98 E 2750.57 N 38 31 E 46 E 2834.09 N 38 30 E 74 E 2917.63 N 38 29 E 80 E 3001.37 N 38 29 E 6000 O0 4635.52 4583.52 56 24 6100 6200 6300 6400 6500 6600 6700 68OO 6900 O0 4691.62 4639.62 55 26 O0 4748.28 4696.28 55 33 O0 4804.22 4752.22 56 22 O0 4859.91 4807.91 55 53 O0 4915.96 4863.96 55 57 O0 4971.82 4919.82 56 24 O0 5026.35 4974.35 57 39 O0 5080.10 5028.10 57 25 O0 5133.10 5081.10 58 13 N 39 28 E 3080.58 N 40 7 E 3163.32 N 40 11 E 3245.70 N 40 39 E 3328.57 N 41 23 E 3411.62 N 42 31 E 3494.43 N 43 14 E 3577.35 N 42 35 E 3661.14 N 42 43 E 3745.46 N 42 51 E 3830.23 1.19 0.68 0.41 0.76 1.12 1 .26 0.91 0.73 1 .31 0.66 2414 03 N 1920.66 E 3084 88 N 38 30 E 2477 2540 2603 2666 2728 2788 2850 2912 2974 66 N 1973.61 E 3167 64 N 38 32 E 60 N 2026.80 E 3250 01 N 38 35 E 76 N 2080.47 E 3332 86 N 38 38 E 45 N 2134.95 E 3415 84 N 38 41 E 01 N 2190.35 E 3498 52 N 38 46 E 75 N 2246.83 E 3581.26 N 38 51 E 01 N 2304.05 E 3664.86 N 38 57 E 16 N 2361.04 E 3749.02 N 39 2 E 39 N 2418.64 E 3833.64 N 39 7 E 7000 O0 5185 14 5133 14 59 20 7100 O0 5235 7200 O0 5286 7300 O0 5337 7400 O0 5389 7500 O0 5442 7600.00 5495 7700.00 5545 7800.00 5595 7900.00 5646 26 5183 11 5234 63 5285 59 5337 52 5390 10 5443 32 5493 76 5543 60 5594 26 59 47 11 59 15 63 58 49 59 58 22 52 57 45 10 59 22 32 59 59 76 59 11 60 59 46 N 42 42 E 3915 61 N 42 35 E 4002 N 41 53 E 4088 N 41 19 E 4173 N 41 9 E 4259 N 41 23 E 4344 N 41 13 E 4429 N 41 44 E 4515 N 41 13 E 4602 N 41 18 E 4688 12 21 92 36 2O 26 73 08 19 1 83 231 0 38 0 44 1 28 0 13 2 04 1 O8 0 53 0 68 3037 10 N 2476 60 E 3918 87 N 39 12 E 3100 3164 3228 3292 3356 3420 3485 3549 3614 58 N 2535 44 N 2593 53 N 2650 73 N 27O6 55 N 2762 46 N 2818 33 N 2875 88 N 2933 65 N 2989 40 E 4005 23 N 39 16 E 15 E 4091 23 N 39 20 E 07 E 4176 87 N 39 23 E 44 E 4262 26 N 39 25 E 34 E 4347 07 N 39 27 E 47 E 4432.08 N 39 29 E 65 E 4518.50 N 39 32 E O0 E 4604.79 N 39 34 E 75 E 4690.87 N 39 36 E COMPUTATION DATE: 24-FEB-91 PAGE 3 ARCO ALASKA INC. D,S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 10-FEB-'1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 5696 38 5644,38 60 28 8100 8200 8300 84O0 8500 8600 8700 8800 8900 N 42 38 E 4774 91 O0 5745 O0 5796 O0 5849 O0 5903 O0 5956 O0 6007 O0 6058 O0 6111 O0 6165 59 5693,59 60 5 N 42 53 E 4861 91 5744,91 58 23 N 42 0 E 4947 75 5797,75 57 54 N 41 42 E 5032 08 5851,08 57 40 .N 42 19 E 5117 05 5904,05 58 26 N 42 1 E 5202 33 5955.33 59 27 N 42 35 E 5287 74 6006,74 58 28 N 41 38 E 5373 87 6059,87 57 37 N 40 38 E 5458 20 6113,20 57 55 94 75 65 24 05 89 65 36 N 39 45 E 5542,93 1 62 1 61 0 56 1 07 0 68 1 20 1 44 2 92 0 26 1 11 3679,14 N 3047,73 E 4777.53 N 39 38 E 3743.06 N 3106,83 E 4864.45 N 39 42 E 3806.41 N 3164,73 E 4950.17 N 39 44 E 3869,79 N 3221,21 E 5035,02 N 39 46 E 3932.59 N 3277.88 E 5119.55 N 39 49 E 3995,38 N 3334,91 E 5204.29 N 39 51 E 4058,69 N 3392.88 E 5290.05 N 39 54 E 4122.26 N 3450.46 E 5375,75 N 39 56 E 4186.27 N 3505.96 E 5460.46 N 39 57 E 4250.81 N 3560,64 E 5545.04 N 39 57 E 9000,00 6218.09 6166.09 58 21 9100.00 6269,93 6217.93 59 7 9200.00 6321.17 6269.17 59 21 9300.00 6372 15 6320.15 59 15 9400.00 6423 33 6371.33 59 16 9500,00 6474 34 6422.34 59 16 9600,00 6525 50 6473,50 59 14 9700,00 6576 66 6524,66 59 17 9800,00 6627 54 6575.54 59 39 9900,00 6678 14 6626,14 59 24 N 39 1 E 5627 74 N 38 51 E 5713 N 38 8 E 5798 N 37 28 E 5884 N 37 5 E 5970 N 36 42 E 6056 N 36 21 E 6141 N 36 12 E 6227 N 35 56 E 6313 N 36 5 E 6398 17 92 76 43 16 76 32 O0 88 1 35 0 57 071 0 57 051 0 83 0 44 0 59 0 96 1 15 4316 45 N 3614.44 E 5629,91 N 39 56 E 4382 4450 4518 4586 4655 4724 4793 4863 4932 99 N 3668,16 E 5715.41 N 39 56 E 19 N 3721,62 E 5801,26 N 39 54 E 18 N 3774.32 E 5887,23 N 39 52 E 57 N 3826.31 E 5973,05 N 39 50 E 34 N 3877,98 E 6058.95 N 39 48 E 40 N 3929.10 E 6144.74 N 39 45 E 65 N 3979,95 E 6230,50 N 39 42 E 32 N 4030.53 E 6316.41 N 39 39 E 95 N 4081.43 E 6402.51 N 39 36 E 10000 O0 6729 78 6677,78 58 24 10100 O0 6782 10200 O0 6836 10300 O0 6890 10400 O0 6946 10500 O0 7002 10600 O0 7058 10700 O0 7113 10800 O0 7167 10900 O0 7222 N 36 50 E 6484 15 57 6730,57 57 52 N 37 11 E 6568 09 6784,09 57 27 N 37 21 E 6653 33 6838 33 56 31 N 37 10 E 6736 47 6894 47 55 44 N 38 24 E 6819 65 6950 65 56 11 N 38 31 E 6902 01 7006 01 56 26 N 38 43 E 6985 14 7061 14 56 48 N 38 40 E 7068 72 7115 72 56 48 N 38 38 E 7152 76 7170 76 56 30 N 38 29 E 7235 81 06 82 42 O2 19 52 21 58 1 32 1 23 0 89 3 46 0 62 1 53 0 28 0 69 0 4O 0 67 5001,97 N 4132,13 E 6488.00 N 39 34 E 5069,85 N 4183.16 E 6572.84 N 39 32 E 5137,00 N 4234,42 E 6657,26 N 39 30 E 5203,95 N 4285.16 E 6741.20 N 39 28 E 5269,16 N 4336,11 E 6823.92 N 39 27 E 5334,04 N 4387,43 E 6906.63 N 39 26 E 5399,03 N 4439.51 E 6989.90 N 39 26 E 5464.16 N 4491,65 E 7073.33 N 39 25 E 5529,61 N 4543,97 E 7157,11 N 39 25 E 5594,95 N 4595.95 E 7240.59 N 39 24 E 11000 O0 7277 72 7225 72 57 0 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 7330 O0 7382 O0 7433 O0 7485 O0 7537 O0 7588 O0 7639 O0 7690 O0 7741 85 7278 28 7330 71 7381 40 7433 22 7485 67 7536 84 7587 76 7638 14 7689 85 58 34 28 59 14 71 58 54 40 58 48 22 58 50 67 59 11 84 59 19 76 59 31 14 59 59 N 4O 2 E 7319 O5 N 40 54 E 7403 N 41 29 E 7489 N 41 11E 7575 N 40 26 E 7660 N 39 51 E 7746 N 39 16 E 7832 N 40 39 E 7917 N 40 40 E 8004 N 40 14 E 8090 75 51 27 87 37 O7 94 O0 36 2 09 1 01 0 36 0 68 0 85 1 09 0 47 081 0 46 0 75 5659 69 N 4648.73 E 7324 13 N 39 24 E 5724 5788 5852 5917 5983 6049 6115 6180 6246 07 N 4703,79 E 7408 54 N 4760,35 E 7494 87 N 4817,06 E 7580 65 N 4873.03 E 7665 01 N 4928,18 E 7751 14 N 4982.78 E 7837 11 N 5037.81 E 7923 32 N 5093,98 E 8009 02 N 5150,05 E 8095 82 N 39 25 E 54 N 39 26 E 25 N 39 27 E 83 N 39 28 E 35 N 39 29 E 10 N 39 29 E 01 N 39 29 E 06 N 39 30 E 42 N 39 30 E COMPUTATION DATE: 24-FEB-91 PAGE 4 ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 10-FEB-1991 KELLY BUSHING ELEVATION: 52,00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET · 12000 O0 7790.83 7738.83 60 27 N 39 42 E 8177.11 12100 12200 12300 12400 12500 12600 12700 12800 12900 O0 7840.21 7788,21 60 5 O0 7889.90 7837.90 60 15 O0 7939.84 7887.84 59 32 O0 7990.40 7938 40 59 38 O0 8041.78 7989 78 58 43 O0 8093.44 8041 44 58 56 O0 8144.56 8092 56 59 23 O0 8195.39 8143 39 59 32 O0 8246.00 8194 O0 59 19 13000.00 8297.41 8245 41 59 1 13100.00 8348.74 8296 74 59 10 13200.00 8400.02 8348 02 59 10 13300.00 8452.34 8400 34 57 52 13400.00 8506.05 8454 05 57 26 13500.00 8559.63 8507 63 57 46 13600.00 8613.64 8561 64 56 55 13700.00 8668.16 8616.16 56 57 13800.00 8722.70 8670.70 57 5 13900.00 8776.57 8724.57 57 9 14000.00 8830.77 8778.77 57 5 14100.00 8884.80 8832.80 57 37 14200.00 8937.46 8885,46 58 18 14296.00 8988.05 8936.05 58 19 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET DEG MIN N 39 41 E 8264.02 N 39 23 E 8350.75 N 39 24 E 8437.32 N 39 20 E 8523.54 N 40 13 E 8609.29 N 39 52 E 8694,88 N 39 40 E 8780.79 N 39 37 E 8866.86 N 39 34 E 8953,05 N 39 21 E 9038.77 N 38 51 E 9124.52 N 38 13 E 9210.25 N 39 42 E 9295.37 N 38 56 E 9379.66 N 38 21 E 9463.99 N 39 45 E 9548.04 N 40 50 E 9631.86 N 40 25 E 9715,67 N 39 41 E 9799.88 N 40 35 E 9883.89 N 40 33 E 9968,02 N 40 6 E 10053,02 N 40 6 E 10134.57 0.52 1.12 6379 0.97 6446 0.87 6513 0.90 6580 0.63 6646 1.37 6711 0.35 6777 0.99 6843 0.81 6910 6312 55 N 5205.78 E 8182 20 N 39 31 E 56 N 5261.21 E 8269 40 N 5316.54 E 8355 47 N 5371 39 E 8442 16 N 5426 13 E 8528 04 N 5481 07 E 8614 57 N 5536 19 E 8700 64 N 5591 15 E 8786 93 N 5646 12 E 8872 44 N 5701 03 E 8958 16 N 39 31 E 94 N 39 31 E 57 N 39 31 E 85 N 39 31 E 64 N 39 31 E 26 N 39 31 E 21 N 39 31 E 32 N 39 31 E 57 N 39 31 E 0.32 1.16 0.55 1 .24 0.71 0.67 3.09 4.15 0.00 2.21 6976 59 N 5755.63 E 9044.34 N 39 31 E 7043 7110 7176, 7241 7307 7373 7437 7500 7565 13 N 5809.83 E 9130.16 N 39 31 E 32 N 5863.27 E 9216.00 N 39 31 E 69 N 5916,71 E 9301 20 N 39 30 E 82 N 5970.32 E 9385 55 N 39 30 E 74 N 6023.08 E 9469 98 N 39 30 E 45 N 6075.66 E 9554 13 N 39 29 E 02 N 6130.30 E 9637 93 N 39 30 E 74 N 6184.75 E 9721 74 N 39 30 E 50 N 6238.64 E 9805 99 N 39 31 E 1 .07 1 .41 7.22 0.00 7629.73 N 6292.84 E 9890.02 N 39 31 E 7693.48 N 6347.75 E 9974.15 N 39 32 E 7758.29 N 6402.76 E10059.15 N 39 32 E 7820.51 N 6455.52 E10140.72 N 39 32 E COMPUTATION DATE: 24-FEB-91 PAGE 5 ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0 O0 1000 O0 998 200O O0 1977 3000 O0 2865 4000 O0 3568 5000 O0 4110 6000 O0 4635 7000 O0 5185 8000 O0 5696 9000 O0 6218 0 O0 -52 O0 0 0 44 946,44 6 48 51 1925 51 19 58 99 2813 99 35 47 64 3516 64 54 51 45 4058 45 59 59 52 4583 52 56 24 14 5133 14 59 20 38 5644 38 60 28 09 6166 09 58 21 N 0 0 E 0.00 N 39 27 E 40.85 N 38 7 E 235.18 N 36 55 E 688.78 N 39 25 E 1392.67 N 37 39 E 2231.65 N 39 28 E 3080.58 N 42 42 E 3915.61 N 42 38 E 4774.91 N 39 1 E 5627,74 0.00 1 .51 3.62 3.26 2.13 0.47 1 .19 1 .83 1 .62 1 .35 0 O0 N 31 180 540 1084 1743 2414 3037 3679 4316 44 N 26.12 E 40 64 N 150.76 E 235 56 N 428.52 E 689 86 N 875.61 E 1394 48 N 1397.37 E 2234 03 N 1920.66 E 3084 10 N 2476.60 E 3918 14 N 3047.73 E 4777 45 N 3614.44 E 5629 0.00 E 0 O0 N 0 0 E 87 N 39 43 E 28 N 39 51 E 81 N 38 24 E 13 N 38 54 E 36 N 38 43 E 88 N 38 30 E 87 N 39 12 E 53 N 39 38 E 91 N 39 56 E 10000 O0 6729 78 6677.78 58 24 N 36 50 E 6484.15 11000 O0 7277 72 7225.72 57 0 N 40 2 E 7319.05 12000 O0 7790 83 7738.83 60 27 N 39 42 E 8177.11 13000 O0 8297 41 8245.41 59 1 N 39 21 E 9038.77 14000 O0 8830 77 8778,77 57 5 N 40 35 E 9883.89 14296 O0 8988 05 8936.05 58 19 N 40 6 E 10134.57 1 32 2 09 0 52 0 32 1 07 0 O0 5001.97 N 4132 13 E 6488 O0 N 39 34 E 5659.69 N 4648 73 E 7324 13 N 39 24 E 6312.55 N 5205 78 E 8182 20 N 39 31 E 6976.59 N 5755 63 E 9044 34 N 39 31 E 7629.73 N 6292 84 E 9890 02 N 39 31 E 7820.51 N 6455 52 E10140 72 N 39 32 E COMPUTATION DATE: 24-FEB-91 PAGE 6 ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 52 O0 152 O0 252 O0 352 O0 452 02 552 05 652 18 752 45 852 82 0 O0 52 O0 152 O0 252 O0 352 O0 452 O0 552 O0 652.00 752.00 852.00 -52 O0 0 O0 100 O0 200 O0 3OO O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 10 N 5 25 W 0 11 N 74 10 E 0 24 N 44 36 E 0 3O N 79 6 E 1 4 N 47 48 E 2 8 N 45 46 E 3 28 N 38 50 E 4 40 N 36 46 E 5 3 N 36 49 E 0 O0 0 02 0 34 0 80 1 30 2 7O 5 34 10 3O 17 59 26 18 0.00 0.67 0.54 0 61 1 44 0 60 1 78 1 74 0 87 001 0 O0 N 0 03 N 0 37 N 0 68 N 0 92 N 1 67 N 3 44 N 7 13 N 1295 N 19 84 N 0 O0 E 0 01W 0 10 E 0 44 E 0 92 E 2 19 E 4 17 E 7 48 E 11 91 E 17 09 E 0 O0 N 0 0 E 0 0 0 1 2 5 10 17 26 O3 N 19 33 W 38 N 15 21 E 81 N 32 5O E 30 N 44 44 E 76 N 52 40 E 41 N 50 26 E 33 N 46 22 E 60 N 42 36 E 18 N 40 45 E 953.26 952.O0 1053.99 1052.00 1000 1154.98 1152.00 1100 1256 20 1252.00 1200 1357 51 1352.00 1300 1458 81 1452.00 1400 1560 22 1552.00 1500 1661 93 1652.00 1600 1764 38 1752,00 1700 1867.90 1852.00 1800 O0 8 25 O0 9 15 O0 9 10 O0 9 18 O0 9 53 O0 11 23 O0 13 30 O0 16 31 900 O0 6 6 N 38 15 E O0 7 36 N 40 9 E N 42 7 E N 41 9 E N 39 55 E N 38 32 E N 37 18 E N 39 15 E N 41 33 E N 39 42 E 35.61 47.64 61.71 77 37 93 66 109 82 126 61 145 10 167 34 194 06 181 1 11 0 93 0 06 0 33 0 36 0 86 2 72 1 83 2.87 27.36 N 36.67 N 47.24 N 58.93 N 71.28 N 83.81N 97.12 N 111.69 N 128.53 N 107 148.80 N 124 22 82 E 3O 39 5O 6O 71 81 92 35.62 N 39 50 E 46 E 47.67 N 39 43 E 73 E 61.73 N 40 4 E 16 E 77.39 N 40 24 E 78 E 93.67 N 40 27 E 01 E 109.85 N 40 16 E 30 E 126,66 N 39 56 E 74 E 145.18 N 39 42 E 27 E 167.41 N 39 51 E 69 E 194.14 N 39 58 E 1972 94 1952 O0 1900 O0 19 6 2080 2189 230O 2411 2522 2633 2746 2863 2982 02 2052 52 2152 44 2252 50 2352 44 2452 57 2552 81 2652 19 2752 78 2852 O0 2000 O0 2100 O0 22O0 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 N 39 6 E O0 22 48 N 36 19 E O0 24 57 N 35 24 E O0 26 2 N 35 44 E O0 25 37 N 38 26 E O0 25 40 N 40 5 E O0 26 12 N 39 44 E O0 30 2 N 37 56 E O0 31 33 N 37 34 E O0 35 12 N 37 3 E 226 15 264 29 3O8 65 356 37 404 52 452 53 500 99 554 O0 613 38 678 77 3 32 251 1 81 1 09 0 97 0 45. 1 32 2 5O 2 31 3 94 173.57 N 145 12 E 226.24 N 39 54 E 203.95 N 168 33 E 264.45 N 39 32 E 240.06 N 194 47 E 308.95 N 39 1 E 279 25 N 222 20 E 356 87 N 38 31 E 317 76 N 251 35 E 405 15 N 38 21 E 354 84 N 281 88 E 453 18 N 38 28 E 392 02 N 312 99 E 501 64 N 38 36 E 433 33 N 346.30 E 554 71 N 38 38 E 480 44 N 382.68 E 614 22 N 38 32 E 532 53 N 422.48 E 679 77 N 38 26 E 3107 71 2952 O0 2900 O0 37 49 3234 3368 3507 3650 3805 3971 4149 4332 4513 99 3052 4O 3152 61 3252 O0 3352 O0 3452 28 3552 72 3652 51 3752 89 3852 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 39 10 O0 43 7 O0 44 51 O0 46 47 O0 51 34 O0 54 21 O0 57 6 O0 56 21 O0 56 46 N 36 49 E 753.37 N 37 49 E 831.87 N 39 17 E 920.02 N 39 43 E 1016.80 N 41 6 E 1118.13 N 40 47 E 1236.48 N 39 41 E 1369.28 N 38 23 E 1516.88 N 39 2 E 1669.69 N 38 47 E 1820.82 0 57 361 1 O5 0 94 5 24 2 29 1 64 1 61 0 83 081 592 47 N 467.32 E 754 59 N 38 16 E 655 724 798 876 965 1066 1181 1301 1419 22 N 514 88 E 833 O8 N 57O 77 N 631 18 N 697 32 N 775 81 N 86O 82 N 953 29 N 1049 47 N 1143 O8 E 921 71 E 1018 14 E 1119 01 E 1237 71 E 1370 47 E 1518 05 E 1671 56 E 1822 32 N 38 10 E 56 N 38 13 E 38 N 38 20 E 69 N 38 30 E 93 N 38 46 E 73 N 38 54 E 48 N 38 54 E 49 N 38 52 E 81 N 38 51 E ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 24-FEB-91 PAGE 7 DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4696 95 3952 O0 3900 O0 56 51 4883 5083 5283 5481 5665 5847 6029 6206, 6385 88 4052 56 4152 15 4252 09 4352 76 4452 79 4552 64 4652 58 4752 87 4852 O0 4000 O0 59 16 O0 4100 O0 60 16 O0 4200 O0 60 12 O0 4300 O0 57 32 O0 4400 O0 56 29 O0 4500 O0 56 54 O0 4600 O0 56 3 O0 4700.00 55 35 O0 4800.00 55 58 N 38 9 E 1973 94 N 37 53 E 2131 N 37 48 E 23O3 N 37 39 E 2476 N 37 42 E 2646 N 38 4 E 2801 N 38 24 E 2953 N 39 37 E 3105 N 40 11 E 3251 N 41 15 E 3399 54 99 34 70 64 45 19 12 91 1 15 2 03 0 13 0 75 2 06 0 40 1 33 1 27 0 48 0 98 1539,43 N 1239.06 E 1976.14 N 38 50 E 1664.12 N 1335.98 E 2134.04 N 38 45 E 1800.82 N 1441.73 E 2306.85 N 38 41 E 1937.41 N 1547.46 E 2479.55 N 38 37 E 2072.98 N 1651.34 E 2650.31 N 38 32 E 2195.33 N 1746.89 E 2805.54 N 38 31 E 2315.26 N 1840.44 E 2957.65 N 38 29 E 2433.03 N 1936.34 E 3109.51 N 38 31 E 2544.74 N 2030.30 E 3255.43 N 38 35 E 2657.66 N 2127.22 E 3404,14 N 38 40 E 6564 32 4952 O0 4900.00 56 7 6747 6935 7133 7327 7517 7713 79'10 8112 8304 85 5052 93 5152 09 5252 75 5352 78 5452 36 5552 75 5652 79 5752 23 5852 O0 5000.00 57 29 O0 5100.00 58 23 O0 5200.00 59 27 O0 5300.00 58 48 O0 5400.00 57 47 O0 5500.00 60 2 O0 5600.00 59 50 O0 5700.00 59 51 O0 5800.00 57 54 N 43 1 E 3547 69 N 42 26 E 3701 53 N 42 48 E 3860 78 N 42 11 E 4030 66 N 41 20 E 4197 66 N 41 22 E 4359 24 N 41 49 E 4527 30 N 41 23 E 4697.48 N 42 48 E 4873.00 N 41 45 E 5036.23 1 10 0 64 1 78 0 7O 0 24 0 29 1 11 0.94 1,97 1.19 2767.10 N 2226~55 E 3551 67 N 38 49 E 2879.80 N 2331 2996.80 N 2439 3121.67 N 2554 3246.35 N 2665 3367.84 N 2772 3493.96 N 2883 3621.62 N 2995 3751.17 N 3114 3872.46 N 3223 32 E 3705 42 E 3864 64 E 4033 74 E 4200 28 E 4362 35 E 4530 89 E 4700 35 E 4875 59 E 5038 17 N 39 0 E 14 N 39 9 E 73 N 39 18 E 59 N 39 23 E 10 N 39 28 E 06 N 39 32 E 16 N 39 36 E 50 N 39 42 E 60 N 39 47 E 8492 25 5952 O0 5900.00 58 21 8687 8875 9065 9260 9456 9651 9848 10042 10229 04 6052 16 6152 19 6252 54 6352 22 6452 80 6552 45 6652 25 6752 49 6852 O0 6000.00 58 41 O0 6100.00 57 51 O0 6200.00 58 53 O0 6300 O0 59 21 O0 6400 O0 59 23 O0 6500 00 59 12 O0 6600 O0 59 38 O0 670000 58 8 O0 6800 O0 57 15 N 41 58 E 5195.45 N 41 51 E 5362.58 N 40 3 E 5521.90 N 38 53 E 5683,36 N 37 42 E 5850.92 N 36 55 E 6018.64 N 36 17 E 6186.08 N 36 17 E 6354.64 N 36 52 E 6519.97 N 37 13 E 6677.82 0.50 2.19 1 .35 0.57 0.67 0.49 0.35 0.92 0.45 0.73 3990 47 N 3330 48 E 5197 69 N 39 51 E 4114 4234 4359 4491 4625 4760 4897 5030 5156 01 N 3443 67 N 3547 75 N 3649 29 N 3753 19 N 3855 26 N 3955 10 N 4055 71 N 4153 75 N 4249 08 E 5364, 14 E 5524 44 E 5685 64 E 5853 42 E 6021 47 E 6189 19 E 6358 69 E 6523 46 E 6682 69 N 39 56 E O0 N 39 57 E 58 N 39 56 E 33 N 39 53 E 35 N 39 49 E 17 N 39 43 E 15 N 39 38 E 89 N 39 33 E 06 N 39 29 E 10409 83 6952 O0 6900 O0 55 47 10589 10771 10953 11140 11335 11528 11723 11921 12123 13 7O52 23 7152 08 7252 83 7352 41 7452 61 7552 84 7652 74 7752 65 7852 O0 7000 O0 7100 O0 7200 O0 7300 O0 7400 O0 7500 O0 7600 O0 7700 O0 7800 O0 56 27 O0 56 58 O0 56 37 O0 59 5 O0 58 55 O0 58 58 O0 59 21 O0 60 5 O0 60 6 N 38 22 E 6827.53 N 38 45 E 6976.15 N 38 38 E 7128.14 N 39 12 E 7279.82 N 41 14 E 7438.67 N 40 56 E 7605.59 N 39 40 E 7770.85 N 40 46 E 7938.44 N 40 6 E 8109.19 N 39 44 E 8284.51 0.50 0.27 0.80 1 .47 1 .96 0.54 0.45 0.14 0.75 0.72 5275 52 N 4341 16 E 6832 04 N 39 27 E 5391 5510 5629 5750 5875 6001 6130 6260 96 N 4433 78 N 4528 46 N 4623 41 N 4726 73 N 4836 85 N 4943 65 N 5051 41 N 5162 6395.33 N 5274 84 E 6980 92 E 7133 71 E 7284 73 E 7443 98 E 7610 85 E 7775 19 E 7943 20 E 8114 3O E 8289 85 N 39 26 E 01 N 39 25 E 88 N 39 24 E 73 N 39 25 E 56 N 39 28 E 85 N 39 29 E 51 N 39 29 E 25 N 39 30 E 66 N 39 31E ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 24-FEB-91 PAGE 8 DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTh SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12323 98 7952.00 7900.00 59 33 12519 12714 12911 13106 13299 13485 13670 13854 14039 71 8052 O0 8000.00 58 49 62 8152 74 8252 37 8352 36 8452 70 8552 25 8652 44 8752 14 8852 N 39 25 E 8457.97 N 40 11 E 6626.13 O0 8100.00 59 25 N 39 40 E 8793.36 O0 8200.00 59 14 N 39 37 E 8963.14 O0 8300 O0 59 10 ' N 38 48 E 9129.98 O0 8400 O0 57 52 N 39 42 E 9294.83 O0 8500 O0 57 47 N 38 25 E 9451.92 O0 8600 O0 56 58 N 40 58 E 9606.89 O0 8700 O0 57 42 N 39 48 E 9761.53 O0 8800 O0 57 13 N 40 45 E 9916.76 14227.36 8952.00 8900.00 58 19 N 40 6 E 10076.18 14296.00 8988.05 8936.05 58 19 N 40 6 E 10134.57 0.22 0.88 0.65 0 93 1 18 1 25 0 65 3 06 2 56 1 75 0.00 0.00 6529 44 N 5384.51 E 8463,24 N 39 31 E 6658 6787 6918 7047 7176 7298 7418 7535 7654 92 N 5491.95 E 8631 49 N 39 31 E 32 N 5599.19 E 8798 22 N 5707 47 E 8968 39 N 5813 26 E 9135 27 N 5916 37 E 9300 26 N 6015 57 E 9457 15 N 6113 93 E 9612 94 N 6214 18 E 9767 67 N 6314 25 E 9922 79 N 39 31 E 66 N 39 31 E 63 N 39 31 E 66 N 39 30 E 89 N 39 3O E 97 N 39 30 E 62 N 39 31 E 89 N 39 31 E 7775.84 N 6417.89 E10082.31 N 39 32 E 7820,51 N 6455.52 E10140.72 N 39 32 E ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER BOTTOM 10 3/4" CASING TOP 5 1/2" CASING TOP SADLEROCHIT ZONE 18 BOTTOM 7 5/8" CASING BASE SADLEROCHIT LAST GCT READING PBTD BOTTOM 5 1/2" CASING DRILLERS TD COMPUTATION DATE: 24-FEB-91 PAGE 9 DATE OF SURVEY: 10-FEB-1991 KELLY BUSHING ELEVATION: 52,00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1405' FSL & 62' FWL, SEC1 TION R15E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 4160 O0 13756 O0 14038 O0 14038 O0 14048 O0 14132 O0 14200 20 14249 O0 ]4296 O0 14296 O0 3657 58 8698 68 8851 39 B851 39 8856 80 8901 75 8937 56 8963 37 8988 05 8988 05 3605.58 8646 68 8799 39 8799 39 8804 80 8849 75 8885 56 8911 37 8936 05 8936 05 RECTANGULAR C'OORDINATES NORTH/SOUTH EAST/WEST 1188.58 N 7472.68 N 7653.95 N 7653.95 N 7660.31N 7714.13 N 7758.42 N 7789.92 N 7820.51N 7820.51N 958.83 E 6160 84 E 6313 63 E 6313 63 E 6319 12 E 6365 37 E 6402 87 E 6429 75 E 6455 52 E 6455.52 E COMPUTATION DATE: 24-FEB-91 PAGE 10 ARCO ALASKA INC. D.S. 9-40 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER TOP SADLEROCHIT ZONE lB BASE SADLEROCHIT LAST GCT READING PBTD DRILLERS TD DATE OF SURVEY: lO-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: SCHWARTZ **~********* STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION : 1405' FSL & 62' FWL, SEC1 TION R15E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 14038.00 14038.00 14132.00 14200.20 14249.00 14296.00 8851 39 8851 39 8901 75 8937 56 8963 37 8988 05 8799.39 8799.39 8849.75 8885.56 8911.37 8936.05 7653.95 N 7653.95 N 7714.13 N 7758.42 N 7789.92 N 7820.51N 6313 63 E 6313 63 E 6365 37 E 64O2 87 E 6429 75 E 6455 52 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14296.00 8988.05 8936.05 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 10140.72 N 39 32 E SCHLUMBERGER B I REC T I ONAL SUR V E Y COMPANY ARCO ALASKA INC. 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I'- I'll II PROJECTION ON VERTICAL PLANE 42, - 222, SCALEO IN VERTICAL OEPTI-~S HORIZ SCALE = 1/2000 IN/FT Teleco Oilfiel¢ ~ 'vices Inc. 6116 Nielson w~ Anchorage, AK 99518 (907) 562-2646 January 18, 1991 JOB #795 ARCO ALASKA, INC. WELL: DS9-40 PRUDHOE BAY RIG: NABORS 28E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G. Mapes Field Operations Supervisor JGM/el Enclosures A ,~iJJ'l' COMPANY Company: Well: Location: Rig: ARco ALASKA INC. DS9-40 PRUDHOE BAY NABORS 28E TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 01/06/91 TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 795TAK 0.0° 30.8° 30.8° 41.5° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' TIE IN TO VERTICAL 150 0 0.0 74.4 150.00 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO MWD SURVEYS 451 301 0.8 74.4 450.99 1.80 0.58N 2.06E 2.14 N 74.21E 0.26 598 147 3.1 49.8 597.90 6.60 3.42N 6.08E 6.98 N 60.63E 1.63 780 182 5.3 34.7 779.40 19.82 13.51N 14.63E 19.92 N 47.27E 1.34 960 180 6.7 35.4 958.41 38.51 28.91N 25.45E 38.51 N 41.36E 0.78 PAGE 1 Company: ARCO ALASKA INC., Well: DS9-40, Location: PRUDHOE BAY, Riq: NABORS 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 1149 189 8.9 41.7 1145.65 64.10 48.81N 41.56E 64.11 N 40.41E 1.25 1336 187 10.0 37.8 1330.11 94.78 72.46N 61.14E 94.81 N 40.16E 0.69 1524 188 9.4 35.0 1515.42 126.34 97.94N 79.97E 126.44 N 39.23E 0.41 1712 188 12.7 42.1 1699.92 162.27 125.86N 102.64E 162.40 N 39.20E 1.90 1901 189 17.7 39.2 1882.25 211.78 163.56N 134.75E 211.92 N 39.48E 2.68 2091 190 23.5 36.4 2060.03 278.43 216.48N 175.52E 278.69 N 39.03E 3.10 2282. 191 25.9 35.4 2233.55 357.84 281.15N 222.29E 358.40 N 38.33E 1.28 2469 187 26.3 40.6 2401.50 439.88 345.90N 272.91E 440.60 N 38.27E 1.24 2593 124 26.3 40.6 2512.66 494.81 387.61N 308.66E 495.50 N 38.53E 0.00 2783 190 30.7 38.5 2679.60 585.38 457.57N 366.28E 586.11 N 38.68E 2.37 2972 189 35.0 37.5 2838.33 687.68 538.38N 429.35E 688.61 N 38.57E 2.30 3160 188 38.0 37.5 2989.42 799.25 627.11N 497.43E 800.44 N 38.42E 1.60 3348 188 43.3 39.9 3132.01 921.52 722.56N 574.08E 922.86 N 38.47E 2.93 3538 190 45.5 41.0 3267.75 1054.42 823.69N 660.35E 1055.71 N 38.72E 1.23 PAGE 2 Company: ARCO ALASKA IN~,, Well: DS9-40, Location: PRUDHOE BAY, Riq: NABORS 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Verto Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0' 3727 189 50.7 42ol 3393.93 1195.04 928.88N 753.67E 1196.18 N 39.05E 2.78 3913 186 53.7 40.6 3507.92 1341.99 1039.22N 850.72E 1343.02 N 39.30E 1.73 4102 189 57.1 39.2 3615.23 1497.47 1158.57N 950o46E 1498.56 N 39.36E 1.90 4296 194 56.1 41.3 3722.03 1659.37 1282.18N 1055.09E 1660.48 N 39.45E 1.04 4487 191 56.5 39.9 3828.01 1818.24 1402o83N 1158.49E 1819.35 N 39.55E 0.64 4672 185 56.3 41.3 3930.39 1972o30 1519.82N 1258.76E 1973.41 N 39.63E 0.64 4860 188 57.7 39.9 4032.78 2129.94 1639.54N 1361.35E 2131.05 N 39.70E 0.97 5112 252 58.9 39.6 4165.20 2344.24 1804.38N 1498.44E 2345.45 N 39.71E 0.49 5362 250 60.6 38.2 4291.14 2559.95 1972.45N 1634.03E 2561.37 N 39o64E 0.83 5676 314 56.7 38.5 4454.48 2827.63 2182.72N 1800.37E 2829.42 N 39.52E 1.24 6022 346 56.1 40.6 4645.96 3115.62 2404.92N 1983.84E 3117.58 N 39.52E 0.53 6335 313 55.9 41.7 4820.99 3375.10 2600.31N 2154.59E 3376.96 N 39.64E 0.30 6555 220 55.8 44.2 4944o51 3557.08 2733.56N 2278.62E 3558.72 N 39.81E 0.94 PAGE 3 Company: ARCO ALASKA INC., Well: DS9-40, Location: PRUDHOE BAY, Riq: NABORS 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° 6862 307 58.1 43.8 5111.93 3814.16 2918.66N 2457.36E 3815.39 N 40.10E 0.76 7185 323 59.1 45.2 5280.22 4089.47 3115.28N 2650.60E 4090.31 N 40.39E 0.48~ 7500 315 57.8 42.8 5445.05 4357.63 3308.32N 2837.07E 4358.21 N 40.61E 0.77 7856 356 59.0 43.5 5631.56 4660.73 3529.54N 3044.46E 4661.15 N 40.78E 0.38 8159 303 58.4 45.9 5788.97 4919.23 3713.56N 3226.54E 4919.47 N 40.99E 0.71 8472 313 58.5 44.2 5952.75 5185.45 3902.00N 3415.31E 5185.55 N 41.19E 0.46 8780 308 57.8 41.3 6115.31 5446.97 4094.07N 3592.88E 5447.04 N 41.27E 0.83 9095 315 58.8 38.5 6280.85 5714.82 4299.66N 3764.74E 5714.92 N 41.21E 0.82 9409 314 59.3 38.9 6442.34 5983.78 4509.82N 3933.11E 5983.97 N 41.09E 0.19 9723 314 59.4 36.8 6602.43 6253.32 4723.11N 4098.85E 6253.66 N 40.95E 0.58 10068 345 58.3 38.9 6780.90 6547.93 4956.24N 4279.98E 6548.48 N 40.81E 0.61 10375 307 55.8 39.9 6947.87 6805.34 5155.31N 4443.45E 6805.99 N 40.76E 0.86 10691 316 57.0 40.6 7122.72 7068.49 5356.20N 4613.53E 7069.19 N 40.74E 0.43 PAGE 4 Company: ARCO ALASKA INC.,. Well: DS9-40, Location: PRUDHOE BAY, Riq~ NABORS 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 11006 315 57.7 42.1 7292.65 7333o71 5555.29N 4788.76E 7334.40 N 40.76E 0.46 11352 346 59.1 41.7 7473.94. 7628.39 5774.63N 4985.56E 7629.04 N 40.81E 0.42 11667 315 59.5 42.4 7634.76 7899.23 5975.76N 5166.97E 7899.83 N 40.85E 0.23 11977 310 60.6 41.3 7789.53 8167.83 6175.84N 5346.16E 8168.38 N 40.88E 0.47 12324 347 59.9 41.0 7961.72 8469.08 6402.67N 5544.42E 8469.64 N 40.89E 0.21 12642 318 59.5 41.0 8122.16 8743.63 6609.85N 5724.59E 8744.20 N 40.89E 0.13 12960 318 59.2 40.6 8284.27 9017.17 6816.92N 5903.36E 9017.77 N 40.89E 0.15 13271 311 57.1 41.7 8448.38 9281.32 7015.85N 6077.16E 9281.92 N 40.90E 0.74 13616 345 57.1 42.1 8635.77 9570.98 7231.45N 6270.61E 9571.54 N 40.93E 0.10 13838 222 57.4 41.3 8755.87 9757.69 7370.86N 6394.82E 9758.24 N 40.94E 0.33 13986 148 57.4 42.1 8835.61 9882.37 7463.95N 6477.76E 9882.91 N 40.95E 0.46 PAGE 5 TE~:CO Oilfield Servic~ PLAN VIEW ARCO ALASKA ZNC. DS9-40 PRUDHOE BAY NABORS 28E JOB# 795TAK/O0 SCALE: 1 .inch = 1600 feet 13986 ' 12960 ' 12324" + 11006 ' i0375 ' 9723 ' 9095 " 8472 ' 7856 ' 7185 ' 6555 ' 6022 ' 5362 ' 467~ ' 4102 ' 3348 ' ~46g ' 12800 11200 9600 8000 Z 0 6400 4800 3200 1600 1600 3200EAST 487~t) 6400 8000 96OO TE,_£CO OilfielU Service, VERTICAL PROJECTION 0 2000 4000 6000 8000 lO000 12000 2000 4000 -~6000 ~8'000 >10000 12000 14000 ,i6000 18000 960 ' 8.7 ~24 ' 9.4 ~eg ARCO ALASKA INC. \2o9~ ' ~3.~ ~g 0S9-40 ~- PRUDHOE BAY ~~ ' ae.~ ~ NABORS 28E ~eo ' ae.o~ ~e~ JOB~ 795TAK/O0 ~~ ' 50.7 ~.~ SCALE: ~7 ' 5e.~ ~.~ ~ inch = 2000 feet ~6 ' 57.7 deg 7 ' 80.6 deg deg 57, deg VERTICAL SECTION (ft) PERMIT# ~:~lO - COMPLET!ON DATE. AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST lJQcJ WELL NAME ~J~L,l, J~ ~--gO 3 i ~ i~[ CO, CONTACT ~~ ~ c~mck off or list data as it is ' drilling histo~' cored intervals core analysis list received date for 407, if not reouired list as NR survey well tests core descri~tio~ dh/ditch intervals ital data -/'70 R! 9) 11] 13| 16} 17) 18.1 INTERVALS I SCALEI {to thc nearest footI I [inch1100'} I ' i I ARCO AI_ASKA, INC. F'.O. BoX J00360 "'ANCHORAGE, ALASKA Fi: I!~. F: Ii" F;: Iii: N C ~"i; ' A F;.'. C [) C: A Z E D H O !._ ILr. F:' I N A i... ,.'l.: F:' L_ E!: A,? Ei: $ I [.; N A i".! I) F;,',r:i:'T' LJ F;.: N T I'-I E: (.i i' -f' A r; H E D C: [) F-' Y A S I:;.; E C E I F' "f' '¥ H E: A F' I ~ !) I $ T I:;~ I !'}: LJ l" I 0 N .... ~'""~ lES :,",:L.[:.I,, I F:.~.:~L.. FIL. · '~.,,- C I--I IE ",/' F;:. C) N · ". [=XT[!:N,?Ir'.,N I.:.UF'L.[)RAI'Ir')N '11' ,. · · · ~ E. X X (:) N iqAF~.:A I"HON · . ':"f' -029- F'CiF: t6-'8 IS .)'2 20549. ,,. F' H I I... L. I F' $ F'B WELL F:IL.E.S I::: & I) EI'ATI=Z OF AI_A,S'KA TEXACO RECEIVED 1 8 1991 Alaska Oit & Gas cons. commission Anchorage A N C i--I O R A (;- Ii", A I.. A,? !< A Ii:' F:' E I::.: E N C E · A F;,'C 0 C A,?; E D t"! 0 I... IE F:' I i'4 A I... :ii.' P I... Ii!; A S' !ii; ;S' i (;- i',! A N 'D R IE'f' U F;.: N 'f' I'-t Ii-"_ A'f' 'f' A C H lis D C C' F:' Y I:'.'[ ;!; R iE C E J. F:' f' U F:' t') ~:'~ I A, HAV!!i: A N:!ZCE DA"/! ..'ii.' I-.I ~':"-i i:;.' f'i i'-.l l,J ]] i ,:' .... :, I .......... ~... ,.':. Eli'..: ....... : 1:7 -*% f", f:':',' I U ..... l ..,'-,::. 7 D t .!: if' R I B U T ;i.i 0 i-.l! C i:)F;.: I:;.: Ii:' C 'T' Iii. D A I::' I :Il: F: 0 R i 4 -" i (') :1. :S' '.ii. (-) ..... '.:";, 2 9 .... '2 (i:' 5': 2 8, RECEIVED MAI'(, ', 1991 Alaska Oil 8, Gas L;uns. Commission Anchorage- TO: THRU: FROM: MEMORANDUM State of Alaska ALASY~%_ .~OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi.~h=---~i~-' DATE: February 26, 1991 Commissioner FILE NO: LG225- 2 TELEPHONE NO: SUBJECT: Louis R. Grimaldi ~ Petroleum Inspector RIG/BOPE Inspection AAI PBU DS9-40 Prudhoe Oil Pool Friday_i/l!/91- I performed a RIG/BOPE inspection on Nabors 28E drilling well DS#9-40 for ARCO PBU. The choke line had targeted flanges in the wrong direction in two places. The BOP hoses had frayed fire protection and there were two turns on the kill line that were 45 degrees and not tarqeted. I informed the tootpusher, Mike Downy, of the problems and recieved assurance that they would get prompt attention. All else on the rig looked good. Their last BOP test was on 1/7/91. In summary: Nabors 28-E has some problems with their kill line (IE turns and targets). Doug Amos is due to arrive on 1/15/91 and I plan to reinspect 28-E with his assistance. 02-00lA (l~v. 6/89) 20/ll/MEMO1.PM3 ANCHORAGE: ALASKA 995'i(~ HAVE A N ii] C: !i:_' DAY! E: i..~ A R '-.-' N,,:.: W i L.,? r" N:., A'i"O'-' 'i 529 ARCO ALASKA, INC. P.O. BOX ~)~60 ANCHORAGE, AL. ASKA 99~ D A T E ' i - 2 .]~ -9 i F'i... tie A S E S 'J: (:~ i",! A N D R Iii: T U R i'".] T l"! F- A T'i' A C i-'i iE D C C)F:: Y A,S' R E C E ]: P 'i" O F:' D A'i" A ~ R Ii:.' C E ]: V ii!: D B Y HAV["' A NiCE DAY! SHARON W I L.,~': ;'; N:.: A 'T (]--- i '.:.:..'-' ::29 .'1.') ]: S' T R I B U 'i" I 0 N C'ENTRAL F'I[.ES (CH) C H r-i: v R O N D & H TAHMA;:i: Bi::<OWN (OH/C;CT) EXXON HARAi"HON H O '~:; '~' ~ · ,~ P H ! L L_ i F:' PB WEI...L. F']:LE,S' R & D -Ii: B P X S TA'[' lie O I:= A t... A,S' !< A T E X A C 0 Al,,"~:;.ka Oil & (;:-:~ [;:~ris. IJon-imission F,.: U !',.! 'i 2" ,!!... '::" j:,.: I..j ?...! -i ::.'..:" .i!..: :ii::" F' i._ i::'Z r:':'~ ;i.i.' iii: :!i." ZiZ i:~. i',i ~-.":-~ N )Z.':, F;.'. iii:'T U J::: i-.~ T i-.! ii." ~'~'~'J" 'i" F'.'~ C i-.liii:.O Z:} (')J::' Y ,,'.":'~ 5/ i:;.', i!i: C tiiZ Zl: F:' 'i" L! I::' D,,:':'~ 'i" ~'~, TO: THRU: MEMORANOUM Stale of Alaska ALASKA OIL ~.~2~D GAS CONSERVATION COMi-IISSION / Lonnie C. Smi DATE: December 26, 1990 Com~.is s ioner FILE NO: JT.LG.1226.10 TELEPHONE NO: SUBJECT: Diverter inspection AAI PBU well DS 9-40 Prudhoe Oil Pool Permit No. 90-169 FROM: Louis R. Grimaldi ('o~ Petroleum Inspector Friday 12/21/90: I performed a diverter inspection on Nabors 28-E preparing to ~-~iil well #40 on DS #9 for ARCO Prudhoe Bay Unit. The rig and diverter looked fine with the exception that the valving for bifurcation was not fail safe. I called Lonnie C. Smith for a verbal variance and received same. I o.k. 'd operations at this time. in summary: Nabor's 28E and it's diverter system appears in good shape for drilling 9-40. 02-001A (Rev. 6/89) 20/11/M]gMO1.PM3 STATE OF ALASKA ~ OIL AND GAS CONSERVATI~ COMMISb,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska, Inc. _ Suspend _ Operation Shutdown_ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program ~ Pull tubing _ Variance _ Perforate _ Other_ 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ 99510 Service _ 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 1404' FSL, 63' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1781' FNL, 1318' FWL, Sec. 31, T11N, R16E, UM (APPROX) At effective depth N/A At total depth 1689' FNL, 1399' FWL, Sec. 31, T11N, R16E, UM (APPROX) 12. Present well condition summary Total Depth: measured true vertical feet feet 6. Datum elevation (DF or KB) RKB 52' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-40 9. Permit number 90-169 10. APl number 50-029-2211 8 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Length Size Cemented Measured depth True vertical depth Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operation program_ BOP sketch 14. Estimated date for commencing operation December 20, 1990 16. If proposal was verbally approved Lonnie Smi th Name of approver 12/20/90 Date approved 15. Status of well classification as: Oil X Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ..~/QJ'DA/,_~ ~ .~ Title Drilling Analyst FOR COMMISSION USE ONLY Conditions of approval' Plug integrity __ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Notify Commission so representative may witness Location clearance Subsequent form require 10-'~O7 ORIGINAL SIGNED BY LONNIE C. SM!TH Commissioner Date /2'2/'- ~ IApprov No. , SUBMIT IN TRIPLICATE Approved Copy eturp~ed PBU DS 9-40 REVISED OPERATIONS SUMMARY 10. 1. MIRU ddlling rig. NU diverter and function test same. 2. Drill 10-3/4" hole to 500 ' TVD/MD. Kick off and build angle at 1.0 degrees/100 ft. from 500 to 1500'MD, continue to build angle from 1500' MD to 2500' MD at 1.5 degrees/100 ft., increase build rate to 2.0 degrees/100 ft. from 2500' MD to 4171'MD ( EOC ). 4. Set 10-3/4" casing and cement same. Nipple up BOPE and test to 5000 psi. 5. Pick up 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform leakoff test. 6. Drill 9-7/8" hole to 8787' TVD, 13931'MD,( 10' 'I-VD above Sadlerochit top). 7. Set 7-5/8" casing and cement same. 8. Pick up 6-3/4" BHA ,GIH. Test casing to 3000 psi. 9. Drill 10' of new hole and perform EMW test. Drill 6-3/4" hole to TD @ 8946' TVD,14234'MD, condition hole to run OH logs 11. Run wireline logs as programmed. 12. Set 5-1/2" liner and cement same. 13. Clean out the liner and test liner to 3000 psi for 30 minutes. Circulate well to bdne. Release Drilling Rig. 14. Run cased hole logs. 15. Move in with Completion rig and run 4-1/2" tubing and packer assembly with GLMs, treater string and SSSV. Test tubing and casing to 3000 psi. Freeze protect with diesel. 16. N/U tree and test to 5000 psi. Release Completion rig. 17. Rig up Wireline and perforate. NOTE:.In the event that the mud weight requirement is less than or equal to 10 Pl:X:J at the intermediate csg. point( 8757' TVD/13583'MD) the option to drill the 9-7/8" hole to TD (8949TVD ,13920'MD will be evaluated. DS 9-41,DS9-42, DS9-43, DS9.44, DS9-45 and DS 9-46 required a 9.8 ppg mud weight to drill the K5 shale interval. o Antcipated BHP: 3775 psi (8.2 ppg EMW) @ 8800' 'I-VD o Maximum Anticipated Surface Pressure: 2800 psi o Planned Completion Fluic~. 9.3 ppg Brine NOTE; PBU DS 9-40 OPERATIONS SUMMARY CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Minimum distances of wells within 200 ft. of the proposed well are: o DS 9-24 · 37.00' @ 3700' MD / 3104q'VD O DS 9-11 · 50.00' @ 1000' MD / 997' TVD o DS 9-12 '60' @ 500'MD / 500' TVD O DS 9-10 · 140.5' @ 500'MD / 500' TVD o DS 9-13 · 180 @ 500' TVD/500' MD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). e. Based on previous logs on DS 9, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. DS 9-40 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) GELS GELS CC/30MIN (%) (%) TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 GEL-BENEX to to to to to SPUD MUD 10-3/4" 9.2 100 40 6 csg pt. SET 10-3/4" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 10-3/4" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 UGHTLY to to to to to to to to TREATED 7-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 7-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 7-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9.2 15 10 4 10 6 6 POLYMER SET5-1/2" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. 0 $00 1495 2OO0 2448 1'10~500. 0'0' 0.00 SEC. I'10~ 1500. 10'0' :87.05 SEC. I I ..... I I ~,0 #~0 400O ,20OO 0 SCALe' I ' ~ 20OOFT. NOTE~ OOORDINATF~ RELATIVE: TO SLOT 36?6 TVD 8113 139S0. 2O00 443430 1141 '33~E December 18, 1990 Telecopy: (907)276-7542 J. D. Gi!!espie Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Prudhoe Bay Unit DS 9-40 ~A~.~.CO Alaska, Inc. Pe_~nit No. 90-169 Sur. Loc. !404'FSL, 63'~-~_~, Sec. 1, T10N, R!5E UM. Btmho!e Loc. i689'F}~, !399'~.~-U~, Sec. 31, TII~!, R16E Dear Mr. Gi!lespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not autnor~z~ conducting dri!i~ng o~erations until ~ll other required permitting determinations are made. The Commission will advise you of those BOPS tests that it wishes to witness. ~ncere!v, r~-~-~ - David ~. Johnilston Chairman Alaska Oil and Gas Conservation Conzmission BY ORDER OF T~E d!f Enclosure cc Department of ~is~ & Game, r.abztat Section w/o encl Department of Environm. enta! Conservation w/o encl. ~-- STATE OF ALASKA ALASKA .LANDGAS CONSERVATION C 1MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ]Z Redrill--I of ,,~,,. Exploratory ~' Stratigraphic Test m Development Oil Re-Entry -- Deepenr-I Service -- Developement Gas :_- Single Zone -- Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1404'FSL, 63'FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1781'FNL, 1318'FWL, Sec.31, TllN, R16E, UM At total depth 1689'FNL, 1399'FWLt Sec.31, TllN, R16E. UM 12. Distance to nearest property line 1444 ' feet 5. Datum Elevation (DF or KB) RKB 52 ' feet 6. Property Designation ADL: 28343 7. Unit or property Name Prudhoe Bay Unit 8. Well number PBU DS 9- 40 9. Approximate spud date 12/2~/cj0 10. Field and Poop Prudhoe Bay Field Prudhoe Bay Oil Pool 11. Type Bond lsee 20 AAC 25.025) Statewide Number No. U-630610 Amount $2oo ..o00. 13. Distance to nearest well D~?~-2a:~ 3104'~¥D 3~fO~i)t' 16. To be completed for deviated wells Kickoff depth~ 00, feet 18. Casing program size Casing 30" 20" 13-1/2" 10-3/4" 9-7/8" 7-5/8" Q-7/R" 7-~/R"' 19. 5507' Maximum hole angle Specifications Hole Wee, IhtI Grade I CouplingI Length 94 I IH-40 Iweld I 80' 45.;#lJ-55 | BTC 14357' 29. '# If.-80 [¢TC/BTC IMOD 13 i,,-80t Tc /567, ~9.7 ~ IL-80 /FTC ~0808' TO be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: measured true vertical 14. Number of acres in property MD 2560 15. Proposed depth (MD and TVD) 1~" ~?D feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface P. R 0 ~ Setting Depth Top Bottom MDI TVDI MDI TVD 35'! 35'I 115't 33'I 33' I 4390'I 52' 31i' 31' 113583'I 13353' ~624' 113920'I 31' / 3!, i !392~, )erations. feet Plugs (measured) feet psig At total depth (TVD) 115' Quantity of cement (include stage data) 3500' 8757' 280 sx C1 G 8949' 100 sx C1 G ~9~@' 280 sx CS II ] 1500 sx CS III/320 sx~L G 2.40. s×. C1 ,G Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth RECEIVED D EO 1 4 1990 Alaska, 0il & Gas Cons. Commissiot~ ;Anchorage True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch ~' Diverter Sketch ~r Drilling program ~ Drilling fluid program [] Time vs depth plot ~ Refraction analysis FI Seabed report Q 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the beSt of my knowledge SignedNu /~' Z'~-'~'~u~m~e Title Regional Drillin~ Engineer Dat_e/~ Commission Use Only (MRC) PD4/017 er n ...._.r~_ ~-,,2//~::~ . ] Appro!/~l/d~/90 [ See cover letter ..... Permit l for other requirements Conditions of approval Samples required Q Yes ~No Mud log requi[e.d L--'J Yes ~ No Hydrogen sulfide.measures ~ Yes ~i~ No Direotional survey required ~Yes ~ No Required working pressure for BOPE '~2M; [] 3M; .~!~.' 5M; Other: ~ Form 10-401 Rev. 12-1-85 ~. \ [] 1OM; [] 15M Commissioner by order of the commission I Submit in triplicate PBU DS 9-40 OPERATIONS SUMMARY 1. MIRU ddlling rig. NU diverter and function test same. 2. Drill 10-3/4" hole to 500 ' TVD/MD. 3. Kick off and build angle at 2.0 degrees/100 ft. to 55 deg 7' in the N 41deg 32' E direction. End of build is at 2850' TVD / 3256' MD. Drill to 4390' MD / 3500' TVD. 4. Set 10-3/4" casing and cement same. Nipple up BOPE and test to 5000 psi. 5. Pick up 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform leakoff test. 6. Drill 9-7/8" hole to 8757' TVD, 13538'MD,( 10 "TVD above Sadlerochit top). 7. Set 7-5/8" casing and cement same. 8. Pick up 6-3/4" BHA ,GIH. Test casing to 3000 psi. 9. Drill 10' of new hole and perform EMW test. Drill 6-3/4" hole to TD @ 8949' TVD,13920'MD, condition hole to run OH logs 11. Run wireline logs as programmed. 12. Set 5-1/2" liner and cement same. 13. Clean out the liner and test liner to 3000 psi for 30 minutes. Circulate well to brine. Release Drilling Rig. 14. Run cased hole logs. 15. Move in with Completion rig and run 4-1/2" tubing and packer assembly with GLMs, treater string and SSSV. Test tubing and casing to 3000 psi. Freeze protect with diesel. 16. N/U tree and test to 5000 psi. Release Completion rig. 17. Rig up Wireline and perforate. RECEIVED 9 EC 1 4- 199 J Alaska 0il & Gas Cons. Anchorage o Antcipated BHP: 3775 psi (8.2 ppg EMW) @ 8800' TVD o Maximum Anticipated Surface Pressure: 2800 psi o Planned Completion Fluid: 9.3 ppg Brine NOTE: In the event that the mud weight requirement is less than or equal to 10 ppg at the intermediate csg. point( 8757' TVD/13583'MD) the option to drill the 9-7/8" hole to TD (8949TVD ,13920'MD will be evaluated. DS 9-41,DS9-42, DS9-43, DS9-44, DS9-45 and DS 9-46 required a 9.8 ppg mud weight to drill the K5 shale interval. NOTE; a. PBU DS 9-40 OPERATIONS SUMMARY CONT. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Minimum distances of wells within 200 ft. of the proposed well are: o DS 9-24 : 37.00' @ 3700' MD / 3104'TVD O DS 9.11 : 50.00' @ 1000' MD / 997' TVD o DS 9-12: 60' @ 500'MD / 500' TVD o DS 9-10: 140.5' @ 500'MD / 500' TVD 0 DS 9-13 : 180 @ 500' TVD/500' MD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). e. Based on previous logs on DS 9, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. RECEIVED Alaska 0il & Gas Cons. commission Anchorage DS 9-.40 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL (TVD) (PPG) GELS GELS CC/30MIN (%) SOLIDS (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 10-3/4" 9.2 100 40 6 csg pt. SET 10-3/4" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 10-3/4" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 UG HTLY to to to to to to to to TREATED 7-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 7-5/8" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 7-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9.2 15 10 4 10 6 6 POLYMER SETS-1/~"' 'N ~_: ~ER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. R ( EiVEP D E C 1 4. 199L~ Alaska.0ii & Gas Cons, Commissio~ ;Anchorage NABORS 28E MUD SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PILL PIT 20 BBLS PIT #6 135 BBLS TRIP TANK 170 BBLS PIT #3 137 BBLS 179 BBLS EOUIPM~T - D~TT.T.ING FLUID SYSTEM (3) DERRICK FLO-LINE Cw.~.a/~ER (1) DERRICK MOD Gw.~.~NER (1) BP3t~)T CF-2 ~&~~ (1) PI~ ~ I ~'~~~ (1) ~G B~T ~ BUS~ (1) D~ D~S~ (1) ~ S~~R P~ PIT w/ ~~ ~ a~o ~g ~~~s (1) ~~R m~ PIT (1) D~~ ~ SH~ S~SOR W/ r~ut con~~t to t~ ~iller's ~~ole NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILLJJP UNE RISER FLOWMNE I 20" ~ PSI DIVERTER I 10" BALL VALVE 117' BALL VALVE I ~ I I CONDUCTORI ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE THE SECOND VENT MNE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS 1fi' VENT UNE 1fi' VENT UNE DIVERTER UNES DISCHARGE 100 FT. FROM RIG IGNmON SOURCE. ALL TURNS ARE TARGETED TEE& THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT ARCO ALASKA, INC. DS9-407 - N 41 32' E E - W COORDINATES -I(XX) 0 1000 20~ 3000 4000 5000 6(X)0 7000 8(XR} X I I i ...... I I I ...... I I ...... I ...... I I II I I I I I I I I I I i , i i i i i ........................... ( 9-;4 500( ~,,~o8 ~( . 4000 200C ... ~,r~,,~.s~--~ 62, ~' 60 80 2 . 5r.,~t.~ . ~11fl ~ ~ln 7~9~ : ~_[~-~~~4 8~ 0 1~TM .............. Oq-13~*'~ I~0~*~ - ~~~- ~,~, ........................................... ~ 10~ 0 1~0 2000 3~ 40~ 5~ 60~ 71)00 8~0 40O RECEIVED Alaska Oil & 6as Cons. Commissto~ Anchorage I I I I 1 I T } } I I I I I I T~.~ I I I I I I I I I II 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 I I I I ~ ~ ' 0 RKI~ F~IJEYATION 52' 20"Conductor TVI =112 TMD=-ll, AR(20 ALASKA, Ii ;{C. 2.0 . DS9:401 8.0 3000 ~o SCALE: 'l" - ',,,~u '~12.0 ~4.o SHL: U 1 aN 1SE 1 1404' FSI, 63' FWL · THL: U llN 16E 31 1781' F}~L 1318' FWL ~2z~ 2°m°o BHL: U llN 16E31 1689' FlqL 1399' FWL it24.o N41 32' F, ~.o 2000 ' go 'q~o ~.o EOC TVD=-2tS0 TMD=3256 DEP=I227 3000 TVD=3500 TMD--43~ DEP=-2157 4000 <r~ 0 TMD=6138 DEP=35 > 5000 m i(45 lyf>=5182 TM~=7331 AVERAGE ~ NGLE = 55 7' 6000 7000 ~ -- 8000 '~~0 ,vr~ao52 ~=~:~ ~=~o~, 1)['- r,,, '1 ~., ~,mt'~.~., .~=8322 7MI~12822 DEP=9075 giasi~a.0ii gnohorago 7-5/8" Casing TVD=I~/57 TMD=13583 DEP::9699 LCU T' 1)=-8767 TMD=13601 )EP=9714 : ~,- 9000 Fop Sadlerochit TVD=8 ~67 TMD=13601 DEP= }714 ~ TARGET rVD=8822 TMD=13697 DEP---9793 Base Sadlerochit TVD= ~822 TMD=13697 DEI'--9793 D TVD=8949 TMI:~l:1920 DEP=9975 10000 ................................................................ 7000 8000 9000 10000 11000 12000 13000 14000 VERTICAL SECTION ARCO Alaska. ~ Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 September 21, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 · SUBJECT: DS 9-39, 40, 42, 43, 44, 45 Dear Mr. Chatterton: Enclosed are copies of the subject As-buiits for your information. If you have any questions, please call me at 263-4618. rely, .. Danieile Warner Engineering Aide DW cc: File W1-1 RECEIVED SEP 2 71990 0il & Gas Cons. ~Ss~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~2 'l e22 , · ~LL A.S.P. PLANT GEiGOETIC CELLAR LCX~ATIOe¢ NO. C(X)RDS. COORO~; POSITION BOX {[LEV. IN S[CTION i 5,945,434.84 N 2439.87 70'14'53.258' 1999' F.~L .39 717,276.98 E 653.08 148'14'40.293' 20.6 1085' F.E.L S.2 5,942,874..37 N 1619.96 70~4'47.417' 1405' F.S.L 40 718,441.97 E 1652.70 14~'14'0~.901' 19.6 62' F.W.L S.1 5,943,376.56 N 2579.68 7094'52.679' 1940' F.S.L 42 717,291.21 E 653.09 14~'14'39.g29' 20.0 1073' F.[.L 5,943,457.`35 N 2219.87 70'14'53.189' 19.4 1992' F.~L 43 718,3430.56 E 1653. O4 14~'14'10.520' 62' F.FL 5,943,107.27 N 1859.69 7094'49.725' 1639' F.S.~ 44 718,585.17 E 1652.54 14894'08.555' 20.2 15' F.W.~ S.1 5,942,991.22 N 1740.17 70'14'48.574' 1522' F.S.L 45 718,415.74 E 1652.88 148'14'07.625' 20.0 58' F.W.L. $.1 LOCATED WIT]lIN PROTRACTED SECTIONS 1.2,11.12. T1ON, R1DE. U.M., ALASKA. 7-28-g0 IDATE I ISSUED FOR INFORMATION REVISIONS JMF DRAWN 12 VICINITY MAP NOTES SURVEYOR'S CERTIFICATE [ HEREBY CER'I']FY THAT I AM PRO- PERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 28, 1990. 1. BASIS O4' LOCATION iS D.S. MONUMENT~ 9A AND 2. COORDS. ARE ALA,~(A STAT[ PLAN{[, ZONE 4. k-.g999539. 5. BASIS O~ ELEVATION lS ARC ,~ATIJM (M.LLM.). 4. REFE'R~NC~ FIEI.D BCX)K IS P~I~, I~.~ 1,~ LEGEND SEP 2 ? zg.g~ · EXISTING W~LLS [4, · ~~D ~s ~'~ Oil & ~as Cons. ~ C~CT~S STAK{[D ~IS F. ROeER T ARCO Alaska Inc. CONDUCTOR AS-BUILT DS 9 WELLS 39,40,42,43,44,45 PA2004AA CHECK LIST FOR NEW WELL PERMITS ITEMFee APPROVE ~ (1) _ f<r i. (2) Loc .,, 2 thru 8) ' () ~hr'u~ 10. (10 and 13) 12. 13. (4) Cass (14 thru 22) (23 thru 28) Company ZfC~z~ Lease & Well No. ~ · - YES NO Is the permit fee attached .......................................... ~ -- 2. Is well tG be located in a defined pool ............................. . .... 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 wellbore plat included ................ 7. Is operator the only affected party ................................. ,,, 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... . 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... 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 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 wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached, zggF Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER thru If)'' (6) Add: Geology: Engi;~ee~ing: i~.... ' DWJ LCS ~ ~BEW~ rev: 01/30/89 6.011 For 30. ~l. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No special 'effort has been made to chronologically organize this category of information. ,o ~PROGRAM: LISCAN REVISION: 5 2 PART NUMBER: W5790-MICRO Start of execution: Thu 17 JAN 91 l:13p **** REEL HEADER **** LIS 91/ 1/17 AWS 01 **** TAPE HEADER **** LIS 91/ 1/17 01 n te l.l/,&] Q© . FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT · : ARCO ALASKA INCORPORATED : D. S. 9 - 40 : PRUDHOE BAY : NORTH SLOPE · : ALASKA * COMMENT RECORD * API NO. 50-029-22118 LOG DATE: 1/10/91 FILE = MAIN PASS (13880 - 14320 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 12 CURVES : NAME CODE SAMPLE~ UNIT BYTES 1 AC 68 1 US/F 4 2 CAL 68 1 IN 4 3 CHT 68 1 LBF 4 4 CILD 68 1 MMHO 4 5 GR 68 1 API 4 6 RFOC 7 RILD 8 RILM 9 SP 10 SPD 11 TEMP 12 TTEN 68 68 68 68 68 68 68 OHMM 4 OHM~ 4 OHMM 4 ~ 4 F/~ 4 DEGF 4 LBF 4 * DATA RECORD DEPTH GR SPD 14320.000 -999.2500 -999.2500 14270.000 0.0000000E+00 23.99760 14220.000 120.0367 24.95590 14170.000 115.8797 23.99760 (TYPE~ AC RFOC TEMP -999.2500 -999.2500 -999.2500 71.13077 4.554295 159.9356 73.95515 8.292370 159.9950 81.21196 5.455479 159.7669 o) 994 BYTES * CAL RILD TTEN -999.2500 -999.2500 -999.2500 CHT RILM -999.2500 -999.2500 1.205200 1712.669 4.496198 4.325891 8109.391 2.298800 973.4023 7.613939 7.179817 6553.180 2.219901 870.4229 4.557294 4.354053 6279.832 14120.000 75.62735 2.978400 787.6592 88.29955 13.83124 13.44178 12.23412 23.99760 159.1172 6133.613 070.000 79.50003 75.56862 10.94059 23.99760 158.2881 14 14020.000 67.39906 77.57072 0.2082274 23.99760 157.8614 1.494400 854.7915 11.92515 12.33423 6241.633 0.2760005E-01 868.0964 5.280797 10000.00 6200.203 -1.228400 865.8809 5.379811 10000.00 6167.090 6.000000 500.0000 0.2000000 0.2000000 5500.000 13970.000 54.69725 103.3763 0.2160339 23.99760 157.1681 13920.000 52.83908 118.3773 0.2000000 0.0000000E+00 0.0000000E+00 CILD SP -999.2500 -999.2500 222.4102 8.764267 131.3380 5.426849 219.4285 4.425751 74.39491 -2.378754 83.85637 -60.61732 189.3654 -105.8782 185.8801 -76.46297 0.0000000E+00 -105.0000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 47 14320.00 ENDING TAPE DEPTH = 13880.00 FILE ff 2 LIS .002 **** FILE HEADER **** 1024 CN : ARCO ALASKA INCORPORATED WN : D. S. 9 - 40 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA COMMENT RECORD * API NO. 50-029-22118 FILE = REPEAT PASS (13890 - LOG DATE: 14270 FT. ) 1/10/91 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 12 CURVES : NAME CODE SAMPLE# UNIT 1 AC 68 1 US/F 2 CAL 68 1 IN 3 CHT 68 1 LBF 4 CILD 68 1 MMHO 5 GR 68 1 API 6 RFOC 68 1 OHMM 7 RILD 68 1 OHMM 8 RILM 68 1 OHMM 9 SP 68 1 MV 10 SPD 68 1 F/M/g 11 TEMP 68 1 DEGF 12 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# 0 ) 994 BYTES * DEPTH AC CAL GR RFOC RILD SPD TEMP TTEN 14270.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14220.000 72.95929 0.0000000E+00 6.082879 15.99840 158o4782 14170.000 83.90526 123.1028 5.392255 19.99800 159.2321 2.766601 7.386943 7847.156 1.946501 4.545142 6485.875 14120.000 76.11797 1.140000 86.34482 13.57452 13.39554 21.99780 159.3964 6451.914 14070.000 78.86890 74.96593 11.45807 21.99780 159.0152 2.548900 12.50746 6543.055 CHT RILM -999.2500 -999.2500 969.1001 7.053643 908.2354 4.351284 851.1384 12.39952 903.4563 12.48490 CILD SP -999.2500 -999.2500 135.3740 7.460022 220.0151 9.596720 74.65169 4.620447 79.95226 -55.91025 14020.000 54.15779 -1.582400 911.5911 191.6183 77.61737 21.99780 0.2074559 158.6437 13970.000 102.6808 21.99780 54.11446 0.2133644 158.1540 13920.000 50.00000 122.1014 0.2000000 0.0000000E+00 0.0000000E+00 5.218709 6468.375 -1.156800 5.335843 6455.961 6.000000 0.2000000 5500.000 10000.00 915.9565 10000.00 500.0000 0.2000000 -107.9488 187.4118 -79.45273 0.0000000E+00 -80.00000 TOTAL DATA RECORDS : 41 STARTING TAPE DEPTH = 14270.00 ENDING TAPE DEPTH = 13890.00 **** FILE TRAILER **** **** TAPE TRAILER **** LIS 91/ 1/17 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 101 **** REEL TRAILER **** LIS 91/ 1/17 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 102 TOTAL RECORDS IN THIS PHYSICAL REEL: 102 End of execution: Thu 17 JAN 91 l:14p Elapsed execution time = 22.96 seconds. SYSTEM RETURN CODE = 0