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Home My WebLink About186-111Joe Engel for Sean McLaughlin By Grace Christianson at 3:26 pm, May 07, 2025 Digitally signed by Joseph Engel (2493) DN: cn=Joseph Engel (2493) Date: 2025.05.07 14:46:14 - 08'00' Joseph Engel (2493) 325-286 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. A.Dewhurst 27MAY25 10-407 DSR-5/8/25JJL 5/9/25 *&: 5/28/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.28 08:31:51 -08'00' RBDMS JSB 052925 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: May 7, 2025 Re:01-30 Sundry Request Sundry approval is requested to set a whipstock in the 01-30 wellbore as part of the drilling and completion of the proposed 01-30A CTD lateral. Proposed plan: See 01-30 Sundry request for complete pre-rig details - Prior to drilling activities E-line or coil will mill the XN- nipple. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2"x9-5/8" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the sag and lands in Ivishak Zone 4. The lateral will continue in Zone 4 TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in June 1st, 2025) 1. E-Line/Coil : Mill XN nipple to 3.80" 2. Valve Shop : Pre-CTD Tree Work 3. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in July 7st, 2025) x Reference 01-30A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,396 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2"x9-5/8" HEW - TOWS @ 9103 - 0 deg ROHS (pinch point at 9110' MD) 3. Mill 3.80” Window. 4. Drill build section: 4.25" OH, ~301' (35 deg DLS planned). 5. Drill production lateral: 4.25" OH, ~2683' (12 deg DLS planned). Swap to KWF for liner. 6. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 7. Pump primary cement job: 45 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 8. Only if not able to do with service coil extended perf post rig – Perforate Liner 9. Freeze protect well to a min 2,200' TVD. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~300’) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 01-30 Convert Inj to Prod Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-111 50-029-21606-00-00 9750 Conductor Surface Intermediate Production Scab Liner 9251 110 2519' 9716 5358 9350 20" 13-3/8" 9-5/8" 7" 8877 29 - 108 28 - 2519 26 - 9742 3481 - 8839 29 - 108 28 - 2519 26 - 9244 3476 - 8395 9350 , 9745 470 1540 4760 5410 9350 1490 3090 6870 7240 9190 - 9554 4-1/2" 12.6# L-80 23 - 8791 8727 - 9068 Structural 4-1/2" BKR S-3 , 4-1/2" BKR SB-3 8252 , 8444 8690 , 8890 8690 , 8890 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028329 23 - 8349 0 890 0 23652 0 3700 0 0 0 486 323-099 13b. Pools active after work:PRUDHOE OIL No SSSV 8690 , 8890 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:39 am, Aug 30, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.29 14:27:57 -08'00' RBDMS JSB 083123 DSR-8/31/23WCB 4-9-2024 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 01-30 Convert Inj to Prod Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-111 50-029-21606-00-00 ADL 0028329 9750 Conductor Surface Intermediate Production Scab Liner 9251 110 2519' 9716 5358 8976 20" 13-3/8" 9-5/8" 7" 8526 29 - 108 28 - 2519 26 - 9742 3481 - 8839 29 - 108 28 - 2519 26 - 9244 3476 - 8395 9350 , 9745 470 1540 4760 5410 9350 1490 3090 6870 7240 9190 - 9554 4-1/2" 12.6# L-80 23 - 87918727 - 9068 Structural 4-1/2" BKR S-3 , 4-1/2" BKR SB-3 No SSSV 8690 , 8890 8252 , 8444 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-15-2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 8:30 am, Feb 16, 2023 323-099 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.15 15:16:14 -09'00' DLB 02/23/2023 MGR16FEB23 X DSR-2/22/23 10-404 GCW 02/24/23JLC 2/24/2023 2/24/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.24 12:49:02 -09'00' RBDMS JSB 022823 From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-30 (PTD #1861110) Lapse 4 year MIT-IA Date:Tuesday, October 5, 2021 3:23:24 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 2:24 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 01-30 (PTD #1861110) Lapse 4 year MIT-IA All, Injector 01-30 (PTD #1861110) will not be on injection for 4 year AOGCC MIT-IA required this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 8:43 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-30 (PTD #1861110) Lapse 4 year MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 2:24 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 01‐30 (PTD #1861110) Lapse 4 year MIT‐IA All, Injector 01‐30 (PTD #1861110) will not be on injection for 4 year AOGCC MIT‐IA required this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 06,2017 TO: Jim RegRe,g P.I.Supervisor ' M SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 01-30 FROM: Bob Noble PRUDHOE BAY UNIT 01-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvjg€— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 01-30 API Well Number 50-029-21606-00-00 Inspector Name: Bob Noble Permit Number: 186-111-0 Inspection Date: 11/5/2017 Insp Num: mitRCN171105154228 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 01-30 !Type Inj w 'TVD 8252 ' Tubing 677 660 686 - 697 - t PTD 1861110 [Type ----- Test - i SPT Test psi 2063 1 IA j 28 1 2499 . 2453 - 2436 -- i ---- --- - BBL Pumped: 3.2 ' BBL Returned: 3 OA 43 _191 • 1 195 194 : Interval 4YRTST P/F P 7 Notes: -res}-6(4,4e. Cce. ZO\ 7 • u)Qt p..vi- c.)/\ Its t0I?sl,(,- dtl'ety at( ,&. ,AeZC sem,.l, Wive -443-1` — She_ e,A-46(4. e ,,-/, CANito '.E B 2 1 aim, Monday,November 06,2017 Page 1 of 1 • • Regg, James B (DOA) PA04 lz, :'-4GrCc S/ec /p /t AAA 2( tJ j'7 i(oSi's4zz From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, November 7, 2017 5:13 PM To: Regg,James B (DOA) �1 n/6(I Cc: Wallace, Chris D (DOA) Subject: RE: 01-30 (PTD #1861110) Upcoming State Witness MIT-IA It was put on injection on 10/29/17 and DHD performed AOGCC MIT-IA on 11/05/17. Let me know if you have any more questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization—Alaska Office:907-659-8110 Cell:307-399-3816 . From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, November 07, 2017 4:39 PM To: AK, GWO Well Integrity Engineer Cc: Wallace, Chris D (DOA) Subject: RE: 01-30 (PTD #1861110) Upcoming State Witness MIT-IA When did injection recommence in PBU 01-30 (PTD 1861110)? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK, GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent:Thursday, October 12, 2017 7:23 AM To: Wallace, Chris D (DOA)<chris.wallaceCc@alaska.gov> Cc: Regg,James B (DOA) <jim.regg@alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Projects Well Integrity <AKDCProiectsWelllntegrityEngineer@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: 01-30 (PTD#1861110) Upcoming State Witness MIT-IA Mr Wallace, 1 Water Injector 01-30(PTD#1861110) due for its 4 year State Witnessed MIT-IATy the end of October.The well " currently has a blind installed due to repairs on the seawater supply line.The line repairs are complete and the well is almost ready to be put back in service. Right now its scheduled to come back online first week of November with testing to be completed after stabilization. Our plan is to keep the well classification as "Operable" until we can get the state witnessed testing completed. Please respond if in conflict with plan, Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 2 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, October 12, 2017 7:23 AM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA);AK, GWO SUPT Well Integrity;AK, GWO Projects Well Integrity; AK, GWO Well Integrity Well Information Subject: 01-30 (PTD#1861110) Upcoming State Witness MIT-IA Mr Wallace, Water Injector 01-30(PTD#1861110) is due for its 4 year State Witnessed MIT-IA by the end of October.The well currently has a blind installed due to repairs on the seawater supply line.The line repairs are complete and the well is almost ready to be put back in service. Right now its scheduled to come back online first week of November with testing to be completed after stabilization. Our plan is to keep the well classification as"Operable" until we can get the state witnessed testing completed. Please respond if in conflict with plan, Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 t s" 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg 4 AUG 7 l��L Alaska Oil and Gas Conservation Commission 333 West 7 Avenue � j Anchorage, Alaska 99501 p Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-01 01/20/12 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 NA qal 01 - 01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA I 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -198 2081770 50029208000200 0.1 NA _ 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA . 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA • 31-JAN -2012 Schkilnherger 5885 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -24A BINC -00093 INJECTION PROFILE 15-Jan-12 1 1 01 -25 BBSK -00105 INJECTION PROFILE 9-Jan-12 1 1 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28- Dec -11 1 1 01 -02 BVYC -00024 CROSSFLOW CHECK 30- Dec -11 1 1 • V -212 BAUJ -00106 MEMORY INJECTION PROFILE 26- Dec -11 1 1 S -110 BX69 -00018 USIT 7-Jan-12 1 1 01 -02 BYS4 -00015 CROSSFLOW CHECK 4-Jan-12 1 1 R -16 BG4H -00106 SBHPS 23- Dec -11 1 1 01-30 BD88 -00189 MEMORY INJECTION PROFILE 19- Dec -11 1 1 15-47 BG4H -00105 CEMENT BOND LOG SCMT 20- Dec -11 1 1 13 -12A BVYC -00018 ISOLATION SCANNER 30- Nov -11 1 1 MPI -18 BG4H -00107 ISOLATION SCANNER 25- Dec -11 1 1 NGI -10 BBSK -00102 USIT 16- Dec -11 1 1 Z -116 BBSK -00104 ISOLATION SCANNER 22- Dec -11 1 1 V -222 BUTT -00051 MEMORY INJECTION PROFILE . 26- Dec -11 1 1 V -106A BCRJ -00108 FSI 15- Aug -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 01/20/11 Sch labeller NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Seth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job B Log Description Date BL Color CD 14-43 BGZ7-00010 CROSSFLOW CHECK 44 & ... / -lic 11/13/10 1 Q,,066 ' 1 NGI-14 AV1H-00052 USIT . , — _ 12/23110 _ A, , • i 1 1 L-205 BLPO-00073 MEM LDL 0 , -os: 12/21/10 1 1 A-42A BL65-00012 MEM PRODUCTION PROFILE ..., 0 - a 01/06/11 1 :F.S. 1 01-30 BCZ2-00031 INJECTION PROFILE Z 4, , — i 1 12/03/10 1 g ,,.4 i .... 02-20 BBSK-00040 RST — 11/19/10 1 P. A -- 1 1 07-23B AY 123111M 1 K-11A BD88-00073 MingelligrAnPAG, 11/03/10 1 IF-'2•107P. 1 04-24 AY1M-00058 RST 1 , „ — () 12/05/10 1 Ft5TISTA 1 11-12 BCZ2-00033 RST 4 / — pa 6 12/07/10 1 : •,iii. 1 2-2813/0-19 BCRJ-00055 RST . .-rx.) 12/01/10 1 CI /. 1 1 al S-128 BCZ2-00035 USIT — / C.1 01/02/11 rt,, , • 1 1 W-220 BG4H-00025 USIT n —. ) ,, 12/27/10 L a . 4 1 1 S-41A 10AKA0108 OH MWD WO EDIT 4,...) — 2' 0 I 10/15/10 2 ' AI. . 1 S-41AL1 10AKA0108 OH MIND/LWD EDIT '„ .—. A _ 10/15/10 2 oef7trii. „erYil 1 H-11 BGZ7-00014 RST 1 'SD — hie if 12/18/10 1 I a li iralP_ _ 9 hbl fra. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503-2838 • f '1,4 NNNI MAR 3 4 2 l' `',■',,--" ' ' ''' - ' . ,S ---- ,,(2 , ,9,-)„ :1, „ . .. .. ., 19 u MEMORANDUM TO: Jim Regg ~~'~~ 1(~ u~a`~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC OI-30 PRUDHOE BAY UNIT 01-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-- Comm Well Name: PRUDHOE BAY UNIT 01-30 Insp Num: mitCS091030151842 Rel Insp Num: API Well Number: 50-029-21606-00-00 Inspector Name: Chuck Scheve Permit Number: 186-111-0 Inspection Date: 10/29/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I of-30 ~ Type Inj. ; N TVD --~ ~ _ _ Is6111o slrr szsz T IA i o ~ 2aoo ~ zsoo i z3oo ' ~- ~ 20 Test psi P.T.D; !TYP I --L------- ~------~--' -- ! 2063 pA o ~ zo -~----~- ~ --- ---- --- ~ ----- - --- ~F, P WRKOVR - Tubing goo ~ goo ~ goo goo ~ p Interval -- - -----1--- _ --- --- _ __ --~ ---- - --- Notes: `;~' ~t;~i~~~~~' 1~1~ ~ `` 20~C i..ti~ No Monday, November 02, 2009 Page 1 of I , _ ;~ ~~Y~~ ~; _ . ....i ...~.. 4 ..~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM~ION , ~ ;, , ~ W = REPORT OF SUNDRY WELL OPERATIONS , „ti _„~~~,, s;~~ 1. Operations Performed: ^ Abandon ~ Repair Well ^ Plug PerForations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Convert to Injector 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 186-111 r 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21606-00-00 ,, 7. KB Elevation (ft): 70, 9. Well Name and Number: PBU 01-30 W~- 8. Property Designation: 10. Field / Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9750' ~= feet true vertical 9251' ~ feet Plugs (measured) 9350' Effective depth: measured 9350' feet Junk (measured) (Below Cmt) 9745' true vertical 8877' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surtace 2519' 13-3/8" 2519' 2519' 3450 1950 Intermediate Production 9742' 9-5/8" 9742' 9244' 6870 4760 Liner Scab Liner 5358' 7" 3481' - 8839' 3476' - 8395' 7240 5410 , ~ _ _~~; -~ ~~,~{; a: ~ ~_ a ~,.~ :: ; ~~ ' Perforation Depth MD (ft): 9190' - 9315 „ ~~ ` Perforation Depth TVD (ft): 8727' - 8844' 4-1/2", 12.6# L-80 9007' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~~~ x 4-1/2" Baker'S-3' packer; r~ 8690'; 9-5/8" x 4-1/2" Baker'SB-3' packer ~q~,~ 8890' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Plug existing perfs w/ 23 Bbls LARC, cleaned out to - 9350'. Cut, pull and dress tubing to -8829'. Run 7" (26#, L-80) scab liner and cement w/ 162 Bbls Class 'G' 1.16 Yield . Run new com letion. Perf ost ri : 3-3/8" Gun Diameter, 6 s f. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ~ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 309-113 Printed Name errie Nubble Title Drilling Technologist , Prepared By Name/Number: ~ Signatur Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~:~ .~` ;,.~ 1~~~.. r~6 ~ t~: 2~0~ Submit Original Only ~~~~ j ~~., ~,~~~~' ~ ~~ ~ ~ • ~ - il Hi Pr Ri Workover 01 30, We story ( e g ) Date Summary 4/25/2009 T/I/O=SSV/550/200, Temp=Sl. PPPOT-T (FAIL), PPPOT-IC (FAIL). Pre RWO. PPPOT-T: Stung into test port (0 psi). Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi, lost 1000 psi in 15 min. Torqued LDS to 600 Ib/ft. Repressured void to 5000 psi lost 1000 psi in 15 min, lost 1000 psi in second 1 b min (FAIL). Bled void to 0 psi. PPPOT-IC: Stung into test port (650 psi), unable to bled to 0 asi (qas),. Functioned LDS, all moved freely (600 Ib/ft). Still unable to bleed to 0 psi. Pumped through void, clean returns. Unable to pressure void above 1000 psi (FAIL). 6/17/2009 T/I/O=SSV/600/400, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0 psi). Pumped through void, clean returns. Press~red void to 5000 nsi lost 0 psi in 30 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely (.75"). PPPOT-IC: Stung into test port (500 psi), unable to bled to 0 psi (qas). Stung into INJ port ( 500 psi), would not bleed to 0 psi. Pressured INJ port to 3500 psi w/ Hyd fluid. Test void bled to 0 psi. Pumped through test void, clean returns. Pressured void to 3500 psi for 30 min test I~st 100 psi in 15 min. lost 0 osi in second 15 min (PASS1. Bled void to 0 psi. Functioned LDS, all moved freely. 1 LDS appears to be longer than the rest, functioned good. 6/21/2009 T/I/O = 180/610/130. Temp = SI. Tbg & IA FL (pre CTD). Tbg FL C~3 306' (5 bbls). IA FL C~ 2676' (145 bbis . SV, WV, SSV = Closed. MV = Open. IA & OA = O . . 6/22/2009 T/I/0= SSV/600/130. Temp= SI. Bleed IAP to CLP (pre-FB). AL spool disconnected. .IA FL Q 2280' (53 bbls). Bled IAP from 600 psi to 20 ~si in 45 minutes (all ga~, Monitored for 30 minutes, IAP increased 10 psi. " welihead & IA has hardline rigged up. Final WHPs= SSV/30/130. SV, WV, SSV = closed. MV = open. IA, OA = open to gauge. NOVP. 6/22/2009 T/I/O = 200/100/0 Assist Slick-line/ Load well/ Perform injectivity tesU MIT-T to 3000 psi. (RWO Prep) Pumped 5 bbls neat methanol spear and 210 bbls 110° 1% kcl. Let well stabilize. rvPVar r.a~yqht fl~id for injection rate test, well was on a vac. Pumped 3.2 bpm at 100 psi on pump. Freeze protected tbg with 50 bbls crude. 6/24/2009 T/I/O=VACNACNAC. Temp=Sl. T& IA FL's. (assist FB). Unable to get fluid shot due to well on Vac. 6/26/2009 WELL S/I ON ARRIVAL. LOAD TBG W/ CRUDE. SET 2 3/8" XX-TTP IN NIPPLE REDUCER QQ 8976' SLM / 8995' MD. ATTEMPT MIT-T, FAILED. ESTABLISHED LLR OF .17 bpm. PULL 2 3/8" XX-TTP FROM 8976' SLM / 8995' MD. WELL S/I ON DEPARTURE, TURNED OVER TO DSO. 6/26/2009 Assist slick-line with MIT T FAILED to 3000 psi (RWO prep) Load Tbg. Pumped 140 bbls of 90° crude down TBG to load. SL set plug @ 8995' in nipple reducer. Pumped 39 bbls of crude to try and bring to test pressure. No increase in in TP. Pumped 3 more bbls of crude down TBG and TP increased to 2100 psi. IA went from a vac to 1780 psi. Pumped 5 more bbls of crude to increase TP and IAP. Max 1800 psi. on IA. Let pressure stabilize. Pumped 7 more bbis of crude down TBG. Max IAP 2000 psi. Pumped 2 more bbls of crude to establish LLR of .17 bpm. SL still on well at LRS departure. Final W HP = 260/400/0 6/27/2009 Rig up. Pump 1" bali to drift coil. RIH for 1.75" drift and taq 9530', puh 10' flag pipe. RIH w/ PDS logging toois. Tag btm C~ 9530' log @ 40 fpm to above packer G 8800'. Pooh. Logging data good. MU 1.5" cmt nozzle and RIH. 6/28/2009 Continue RIH w/ 1.5" cmt nozzle while loading well down backside. Stop C~ flag, correct depth. Lay in 23 bbl LARC plug. yGot 16 bbls returns 7 bbls behind pipe. est TOC C~ 9303. Pull to safety and bump s~c ueeze pressure up to 500 psi. Swap to Biozan and cleanout to 9340. Freeze protect weil from 2500' w/ 38 bbls 50/50 methanol. Job complete. Page 1 of 2 • ~ - i r R' Workover 01 30, Well H story (P e~g ) Date Summary 6/30/2009 WELL SHUT IN ON ARRIVAL. RAN 1.75" CENT/SAMPLE BAILER TO TOC AT 9.490' SLM_(+23' corr = 9513' md). RECOVER SAMPLE OF WHAT APPEARS TO BE CE T. P PPER 4-1 2" WF , ECLIPSE PACKER FROM 8716' SLM (elements / patch intact). PULL 2 x 4-1/2" WFD SLICK STICKS FROM 8 728' SLM & 8 755' SLM. PULL LOWER 4-1/2" WFD ECLIPSE PACKER FROM 8.783' SLM (recovered all elements and slips). CURRENTLY RIH W/4-1/2" GS. 7/1/2009 PULL 4-1/2" x 2-3/8" NIPPLE REDUCER FROM NIPPLE Q 8972' SLM / 8995' MD, PART WIRE WHILE BUMPING UP IN LUBRICATOR. .FISH COMPLETE TOOLSTRING FROM 227' SLM. FISH NIPPLE REDUCER FROM 253' SLM (reducer intact). RAN 3.625" CENT/TEUS. BAILER, TAG TOC @ 9490' SLM (+23' corr - 9513' md). UNABLE TO LOCATE TBG TAIL, NO SAMPLE RECOVERED. LEFT WELL S/I, TURNED WELL OVER TO DSO. 7/2/2009 Rig up, Layed in 23 bbls of cement from 9490' (across perfs); 5 bb-s neat LARC, 8 bbls LARC cement w/_;. a re ate & 10 bbls neat LARC. S ueezed 3 bbls behind i e. Cleaned out w/ 1.5# biozan to 9340' chase cement and biozan to surface w/ 1% KCL xs. Maintaned 1:1 returns to surface. EST top of cement 9350'. Freeze protect from 2500' with 38 bbls diesel. Job is complete. 7/3/2009 WELL S/I ON ARRIVAL. DRIFf W/3.70" CENT. TEL. 2.50" SB, LOC TT C~ 8.986' SLM (+ 6' TO 8.992' ELM). TAG TOC ~ 9,364' ELM. (no sample) WELL S/I ON DEPARTURE, DSO NOTIFIED. 7/4/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=450/0/600. RU ELINE. LRS PUMP KCL DOWN IA AT 0.6 BPM C~ 2900 PSI, TAKING RETURNS TO FORMATION. LOGGED DYNAMIC PASS FROM TD TO SURFACE AT 120 FPM. CONFIRMED NO LEAKS. BELOW KNOWN TBG HOLES AT 8776' MD. 7/4/2009 LOGGED LDL BY PUMPING 1% KCL DOWN IATAKING RETURNS IN THE FORMATION ~ 0.6 BPM @ 2,900 LBS. CRETACEOUS LEAK INDICATED AT 6.215'. WHILE PUMPING AND PRESSURING UP, RECORDED STOP COUNTS ON BOTTOM AND CONFIRMED CEMENT CAP IS HOLDING WITH -2,180 PSI APPLIED OVER HYDROSTATIC PRESSURE BkiP BEFORE PUMPING = 3980 PSI AND BHP WHILE PUMPING = 6160. NO INDICATION WITH SPINNER OR TEMPERATURE DATA OF ANY LEAK. POOH. RIH WITH HES 3.66" O.D. PLUG AND SET AT 8,924' (MID-ELEMENT), 10' FROM THE TOP OF THE 1ST FULL JT BELOW THE PACKER. POOH. RIH WITH STP TO RUN 2ND LDL WHILE PUMPING DOWN THE TUBING AT 0.5 BPM @ 3,000 PSi . F(~l1Nl~ 1 FAK SIC~NATURFS AT #10 C~I M P(~C;KFT AT R 77F' AND ANOTHER AT --8,388 IN THE iST FULL JOINT ABOVE GLM #7. POOH. RIH WITH 3.65" SLB POWER JET CUTTER AND FIRED CUTTER C~ 8,847'. NO ELECTRICAL CONFIRMATION BUT GOOD TENSION AND SURFACE INDICATION. AFTER FIRING POOH -8' AND TOOL BECOME STUCK. LRS PUMPING DOWN TUBING -1.0 BPM TO ASSIST GETTING TOOL STRING FREE. 7/4/2009 Assist E-line with LDL Pumped 10 bbls 60/40 meth and 118 bbls 1% KCL down the IA while e-line made logging passes. Pumped 6 bbls 60/40 meth, 81 bbls 1% KCL and 37 bbls SW down the TBG while e-line logged. Pumped 14 bbls Seawater down tubing to attempt to free up E-line. 7/5/2009 Assist E-Line. Pumped 6 bbls seawater down tubing to free up E-line Tool. FW HP's= 400/0/0 Valve positions at time of departure; SV open (e-line still on well) WV shut, SSV open, MV open, IA open, OA open. 7/5/2009 PULLED OUT OF WEAKPOINT, ESTIMATED TOP OF TOOL: 8790'. FINAL T/I/0=400/0/0 WELL SHUT IN ON DEPARTURE. 7/6/2009 T/I/0= 340/440/0 (Circulate wellbore TxIA Pre RWO) CMIT TxIA FAILED to 2000 psi. (known PC leakl Pumped 5 bbls neat and 3 bbls 9.8 brine to reach test pressure. TxIA lost 1260/1240 psi. in 10 min. Established a LLR of 0.4 bpm at 2000 psi. for 23 min. Continued with circ out pumping down the tubing taking returns up the IA to well 31 flowline. At 325 bbls away - closed in choke and the IA pressured up quickly to 2000 psi. (rate was at 4 bpm). Established a LLR of 0 2 bpm at 2000 psi for 20 min_ Continued circ down tubing. Pumped a total of 911 bbls of 9.8 brine followed by a 2 bbi neat spacer and 34 bbls of diesel. U-tubed diesel to freeze protect TxIA to 500'. Freeze protected well 31 flowline with 5 bbls neat, 112 bbls crude and 8 bbls diesel. MIT- OA to 2000 psi passed, lost 80 psi in ist 15 min and 20 psi in 2nd 15 min. Bleed pressure to 0, rig down. Swab closed, wing closed, ssv open, master open annulus valves open to gauges. Operator notified of weff status. FWHP=O/0/0 Page 2 of 2 • • BP EXP~ORATION' Pags j~f 10: Operations Summary Repart Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Date: From - To Hours Task Code NPT Phase Deseription of Operations 7/6/2009 i4:00 - 00:00 10.00 MOB P PRE Lower derrick. Move rig off of DS 01-25 and stage rig on pad by DS 01-30. Remove BOP stack from cellar. 7/7/2009 00:00 - 05:00 5.00 MOB N WAIT PRE Wait on prep work on DS 01-30 -Raised Derrick -Bridle Down -Clear Floor -Set BOP Stack in Cellar on Stump 05:00 - 00:00 19.00 MOB N WAIT PRE Continue to Wait on Well Site Prep -Well House and Flow lines have Been Removed -Pad Preparation about 80% Complete 7/8/2009 00:00 - 03:00 3.00 MOB N WAIT PRE Continue to Wait on Well Site Prep 03:00 - 07:30 4.50 MOB P PRE Move Rig over DS 01-30 -Lay out Herculite spill barrier -Lay Rig Mats -Move Over well and shim level -Spot Cutting tank -Set Stairs -Take on 9.8-ppg brine -Acce t ri at 0700-hrs. 07:30 - 09:00 1.50 WHSUR P DECOMP PU DSM lubricator. DSM pump open SSV and drift to ensure full function. MU & PT DSM lubricator to 500-psi. Good test. ~ Pull BPV. 09:00 - 09:30 0.50 KILL P DECOMP RU on tree to circulate out freeze protection. Hold PJSM with Rig Crew and CH2MHill truck drivers. Discuss spill potentials, hazards and positions of people. 09:30 - 10:30 1.00 KILL P DECOMP Pressure test lines to 2500-psi. Good test. Bring pump online and displace well to clean 100-degree 9.8-ppg brine at 5.5-BPM with 490-psi. Troubleshoot #3 Cat issues. Then circulate at 6-BPM with 520-psi. 10:30 - 11:00 0.50 KILL P DECOMP Troubleshoot generator problems 11:00 - 13:00 2.00 KILL P DECOMP Continue to displace well to clean brine at 7-BPM with 740-psi. Monitor well - static. Blow down and rig down lines to tree. Drain stack. 13:00 - 15:30 2.50 WHSUR P DECOMP uhrir.ator ao~L~s~aLe~e~ilo~Q4~~i. _Ciood test_ below to 1000-psi for 10-charted minutes. Keep pump roflina at .085-BPM and hold 1180- si for test interval due to cretaceous leak. RD test equipment. 15:30 - 17:00 1.50 WHSUR P DECOMP Drain tree. ~ameron ren t-bar in test dart. Test K-plua & tesj, dart above to 4000-psi for 10-charted minutes. Good test. RD test equipment and blow down all lines. MU TIW valve and XO to tubing hanger in preparation for ND tree. 17:00 - 19:00 2.00 WHSUR P DECOMP RU sling to blocks. Cameron rep bleed off voids and bleed & plug control lines. ND tree and adapter flange. Barrier for ND on tubing side is tested TWC. Barrier on IA side is tested packoffs. Sinple barrier dispensation in place for ND tree., 19:00 - 20:30 1.50 BOPSU P DECOMP Nipple Up BOP's 20:30 - 21:00 0.50 BOPSU P DECOMP RU to Test BOP's 21:00 - 00:00 3.00 BOPSU P DECOMP Test BOPE. -Test to 250-psi low and 4000-psi high (3500 psi on annular) for 5 minutes. -Chart Record Test Printed: 7/29/2009 3:04:05 PM ~ • BP EXPLORATION Page 2 af 10 Operations Summary Report Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Date Fr4m - To Hours Task Code NPT Phase Description of Operations 7/8/2009 21:00 - 00:00 3.00 BOPSU P DECOMP -Test VBRs with 4" and 4 1/2" test jts. Test annular using 4" test joint. -AOGCC rep John Crisp witness Test. -Test witnessed by BP WSLs (Dave Newlon) and Doyon Toolpushers (Pete Martinusen). 7/9/2009 00:00 - 02:00 2.00 BOPSU P DECOMP Test BOPE. -Test to 250-psi low and 4000-psi high (3500 psi on annular) for 5 minutes. -Chart Record Test -Test VBRs with 4" and 4 1/2" test jts. Test annular using 4" test joint. -AOGCC rep John Crisp witness Test. -Test witnessed by BP WSL (Dave Newlon) and Doyon Toolpusher (Pete Martinusen). will need to repair before finishinq the test . 02:00 - 05:00 3.00 BOPSU N RREP DECOMP PJSM to repair leak on Annular Cap Seals on the BOP stack -Remove the Drilling Riser -Tighten seals with the Potato Masher. -Re-torqueing cap stop leak on cap -Install Drilling Riser 05:00 - 06:00 1.00 BOPSU P DECOMP Resume BOP Testing. P/U 4" test joint and RIH to test bag to 250- si low and 3500- si hi h. Good Test -Perform Accumufatortest -Rig Down Test equipment and Clear Floor 06:00 - 07:30 1.50 WHSUR P DECOMP RU Dutch Riser, 4-1/2" handling equipment and control line spooling unit. 07:30 - 09:00 1.50 WHSUR P DECOMP PU DSM lubricator & test to 500- si. Goo -Drain stack & pull test dart. -MU lubricator. -Pull K-plug. -Well is on a vac. -LD lubricator & K-plug. . 09:00 - 10:30 1.50 PULL P DECOMP Bubbling and rising fluid level in stack observed. Shut well in. Monitor pressure and pressure remains at 0-psi. Notify RWO monitor well while holding meeting with BP D&C HOD, ADW leadership, Doyon Superintendent, BP WSL and Rig Crew. e remained at 0-nsi throuahout meet•~na.- 10:30 - 12:00 1.50 PULL P DECOMP Continue to monitor well. Hold PJSM on plan forward. MU landing joint w/ XO to hanger neck thread in preparation for circulation if needed. Open choke slowly and monitor well. No flow seen. Open blind rams and observe well for flow - static. Discuss plan forvvard with RWO superintendent and RWO engineer. Decide to spear tubing hanger as planned. Not~ ify AOGCC and we will test all well control equipment used when II t in ' w . 12:00 - 12:45 0.75 PULL P DECOMP LD landing jt. MU Itco spear dressed to catch 4-1/2" tubing. 12:45 - 14:00 1.25 PULL P DECOMP RIH. Enqaqe tubinq at 34'. Cameron rep BOLDSs. Pull tubing hanger free. Work up to max pull of 250K-Ibs. Steam wellhead and pull up to 250K-Ibs, chaining brake down for 5-minutes. Hanger breaks free and moves up hole with a PU Printed: 7/29/2009 3:04:05 PM ~ ~ BP EXRLORATION' Page 3 of 1~ Operations Summary Report Legal Well Name: 01-30 Common Well Name: 01-30 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 7/9/2009 12:45 - 14:00 1.25 PULL P 14:00 - 14:30 0.50 PULL P 14:30 - 16:00 1.50 PULL P 16:00 - 16:30 0.50 PULL P 16:30 - 00:00 7.50 PULL P 17/10/2009 100:00 - 03:30 I 3.501 PULL I P 03:30 - 04:00 0.50 PULL P 04:00 - 05:30 1.50 BOPSU P 05:30 - 08:00 I 2.501 FISH I P 08:00 - 16:30 8.50 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 18:30 1.00 FISH P 18:30 - 20:00 I 1.501 FISH I P Spud Date: 6/11 /1986 Start: 7/4/2009 End: 7/16/2009 Rig Release: 7/16/2009 Rig Number: Phase ' Description of Operations DECOMP wt of 145K-Ibs. Pull hanger above the rig floor.eFill back side, takes -6-bbls to et returns. DECOMP Back out & LD Itco Spear. Break out tubing hanger and 5-1/2" handling pup and LD same. Well out of balance. DECOMP MU XO, TIW valve and circulating head to 4-1/2" BTC-M tubing. Pump 10-bbl dye pill and chase at 10-BPM with 1500-psi. See small amount of sand across shakers throughout circulation, with increase at bottoms up. See dye return at calculated surface to surface. DECOMP RD circulating equipment. Monitor well - static. Hold PJSM on Pull & LD tubing. DECOMP Pull & LD 4-1/2" 12.6# L80 BTC-M tubing through pipe shed. Spool dual SS control lines. -Recovered 32 Stainless Steel Bands DECOMP Pull & LD 4-1/2" 12.6# L80 BTC-M tubing through pipe shed -207 jts & 10 GLM's -Cut Joint Flared to 5 1/16", even cut -Cut Joint length = 10.94 DECOMP Lay Down PowerTongs and Tubing Handling Equipment -Clean Rig Floor and ready to pickup Test Plug DECOMP Pick up 4" Test Joint and set Test Plu -Test Blind Rams to 250 si low and 4000 si hi h -Chart Record Test -Test witnessed by BP WSL (Dave Newlon) and Doyon Toolpusher (Pete Martinusen). -Pull Test Plug and Set Wear Bushing DECOMP MU Baker Fishina Dress off BHA. -BHA consists of Dress off Shoe, Overshot Extensions, Inner Dress off Mill, Boot Basket, 9-5/8" Csg Scraper, Bumper Sub, Pump Out Sub, and 9(ea) 4-3/4" DCs. -Overall length = 321.96'. DECOMP RIH from 321' with Dress off BHA, picking up 4" DP 1 x 1. -Work scra~er from 3452' to 3641'. -Continue RIH with Dress off BHA to 8759'. DECOMP Slip and Cut Drilling line -Service Draw Works, Crown and Top Drive DECOMP RIH to 8822', Break Circ and establish Parameters -PUW 180k / SOW 153k / RtWT 165k -6 BPM / 830 psi -40 rpm / 4000 ft-Ibs of torque Wash Down to 8828' md, Tag Stump. Tag Several Time with oositive sian of to~ of stumo. Taa is 19' hiah from Tubina Tallv -60 rpm / 6000k ft-Ibs of torque -3-5k WOB -6 BPM Work over Stub several times without issues DECOMP Pump 20 bbl High Vis Sweep -10 BPM / 2030 psi No Metal on Bottom up Prinied: 7/29/2009 3:04:05 PM • i BP EXP~URATI(~N Pac~e 4 of 1 U Qperations Surnmary Report Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Gode NPT Phase Description of Operatians 7/10/2009 18:30 - 20:00 1.50 FISH P DECOMP Sweep clear hole from residual sand Monitor Well, Static 9.8 ppg In / Out 20:00 - 22:30 2.50 FISH P DECOMP POH to BHA 22:30 - 00:00 1.50 FISH P DECOMP Stand Back DC's and Lay Down BHA -Lay Down Fishing Tools -Clean Junk Baskets, recovering 2 gals of sand and minimal metal shavings 7/11/2009 00:00 - 00:30 0.50 EVAL P DECOMP MU RTTS with Drift Catcher Catcher -Pick up 9 DC's with RTTS -Total length 293' 00:30 - 03:00 2.50 EVAL P DECOMP RIH to 8500 -PJSM with Rig Crew and HES Service Hands on Setting and testing 03:00 - 04:00 1.00 EVAL P DECOMP Set RTTS and Test to 4000 psi for 10 minutes -Set RTTS at 8500' md -PUW 170k / SOW 150k -Turn 2 1/2 turns and slack off to 130k setting 20k on RTTS ~ -Lost 50 psi the first 5 minutes and 20 psi the last 5 minutes -Bleed off and release tool 04:00 - 06:00 2.00 EVAL P DECOMP POH to 4000' md -Set RTTS at 3990' COE. -PU wt = 105K, SO wt= 105K -RU testing equipment. 06:00 - 07:00 1.00 EVAL P DEGOMP Test 9-518" casing above RTTS to 4000-psi for 30-minutes. ' -Good test -Blow down & Rig down test equipment. 07:00 - 07:30 0.50 EVAL P DECOMP Release RTTS. -Drop 2-3/16" DP drift with tail. 07:30 - 09:00 1.50 EVAL P DECOMP POH with HES RTTS standing back DP & DCs in derrick. -LD RTTS. -Recover DP drift (drifted 39-stds DP and 3-stds 4-3/4" DCs) 09:00 - 10:00 1.00 CASE P TIEB1 RU to run 7" 26# L80 BTC-M scab liner. ~ 10:00 - 11:00 1.00 CASE P TIEB1 Wait for 15-jts of 7" casing to arrive. -Csg joints needed due to 9-jts that would not drift. 11:00 - 14:00 3.00 CASE P TIEB1 Load, Drift and Strap 9-jts of 7" 26# L80 BTC-M casing. -WSL complete Casing tally and Running order. -MU 10' pup on top of cement head. 14:00 - 15:00 1.00 CASE P TIEB1 Inspect & double check all 7" scab liner components. 15:00 - 15:30 0.50 CASE P TIE61 Hold PJSM on running 7" Scab liner. -Discuss hazards associated with tongs, centralizers, pipe skate and positions of people. -Discuss running procedures, proper torque, thread compound and centralizer placement. 15:30 - 17:00 1.50 CASE P TIE61 Run 7" 26# L80 BTC-M scab liner with 9-5/8" x 4-1/2" Unique -Bakerlok all connections below insert landing collar. -MU all BTC-M connections to mark. -Use Best-O-Life 2000 thread compound on all BTC-M connections. -Tailpipe assembly / float equipment RIH at 1630-hrs. -Install one free floating centralizer per jt of 7" csg. 17:00 - 00:00 7.00 CASE N RREP TIEB1 Diagnose and Hydraulic System on Top Drive Failure Printed: 7/29/2009 3:04:05 PM • • BP'' EXPLQRAT(O~ Page 5 of 10 Operations Surnrnary Report Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Date Frc~m - To HQUrs Task Code NPT Phase Description Qf Operations 7/11/2009 17:00 - 00:00 7.00 CASE N RREP TIEB1 -PJSM due to change of scope -Remove Top Drive From Torque Tube to access Hydraulic pump -Remove Hyd. Pump 7/12/2009 00:00 - 08:00 8.00 CASE N RREP TfE61 Diagnose issue with Hydraulic System on Top Drive -PJSM with new crew -Trouble shoot problem with Hyd. Pump -Repair coupler between hydraulic motor and pump. -Put Top Drive back together and install on rails. 08:00 - 08:30 0.50 CASE P TIEB1 Hold PJSM on running 7" 26# L80 BTC-M Scab Liner. -Review hazards associated with power tongs, centralizers, pinch points and pipe shed. 08:30 - 14:00 5.50 CASE P TIEBi Continue to run 7" 26# L80 BTC-M Scab liner. -Install one free floating, straight bladed centralizer per jt. -Use Best-O-Life 2000 thread compound on all connections. -62-jts of 7" Csg RIH at 1130-hrs. -100-jts of 7" Csg RIH at 1300-hrs. 14:00 - 14:30 0.50 CASE P TIEB1 MU 9-5/8" x 7" Flexlock liner hanger and ZXP liner top packer assembly. -RIH on 3-stds of 4-3/4" DCs. 14:30 - 15:00 0.50 CASE P TIE61 MU to top drive and circulate one liner volume. -Circulate at 7-BPM with 400-psi. 15:00 - 17:00 2.00 CASE P TIE61 RIH with 7" 26# L80 BTC-M Scab liner on 4" DP from derrick. 17:00 - 17:30 0.50 CASE P TIE61 MU Std #34 and obtain PU wt = 230K-Ibs, SO wt = 200K-Ibs. ', -RIH and see first set of shear ins at 8831'. Shear with ' 10K-Ibs down. -Continue in hole and see second set of shear pins at 8839'. Shear with 10K-Ibs down. -Continue in hole and NoGo at 8842'. Set down 20K-Ibs to confirm. 17:30 - 18:00 0.50 CASE P TIEB1 MU Baker cement head to string. -PU to neutral weight plus 2' and mark pipe. 18:00 - 19:00 1.00 CEMT P TIEB1 Circulate at 5-BPM with 550-psi. - BP WSLs, Doyon Toolpushers, Schlumberger cementers and CH2MHill truck drivers to perform change out. -Hold PJSM with Schlumberger Cementer, CH2MHill Truck Drivers, DDI Rig crew and Toolpusher and BP WSL 19:00 - 19:30 0.50 CEMT P TIEB1 Cement 7" Scab Liner I -Switch over to Schlumberger Cementers i -Pump 5 bbls of fresh water I -Shut lower TIW valve ', -Pressure Test, Lower TIW leak by, work and was able to close completely -Test Fail - Swivel on Cement head leakin 19:30 - 20:30 1.00 CEMT N SFAL TIE61 Change Out Swivel on Baker Cement Head -Swivel seals leaking by , -Replace Swivel and Retest to 4500 psi, Good Test 20:30 - 22:30 2.00 CEMT P TIE61 Cement 7" Scab Liner with Schlumberger Cementing Services -Pump 162 bbls of Class "G" 15.8 ppg Cement Slur (1.16 yield f3/sk), - vTg. pump rate = 62 bpm -Release Dart and Kick Out Plug with 5 bbls of fresh water -Positive Indication of Dart leaving Printed: 7/29/2009 3:04:05 PM ~ • BP EXPLC?RATfUN Page ~ of 10 Qperations Summary Report Legal Well Name: 01-30 Common Well Name: 01-30 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date Frc~m - Tca Hours Task Code NPT 7/12/2009 20:30 - 22:30 2.00 CEMT P 22:30 - 00:00 1.50 CEMT P 7/13/2009 00:00 - 01:00 1.00 CEMT P 01:00 - 02:30 1.50 CASE P 02:30 - 03:00 0.50 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 04:30 1.00 CLEAN P 04:30 - 07:00 2.50 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:30 1.50 BOPSU P Spud Date: 6/11/1986 Start: 7/4/2009 End: 7/16/2009 Rig Release: 7/16/2009 Rig Number: Phase Descriptian of Operations TIE61 -Displace cement with 9.8 brine with cement unit -Displace at 6.8 bpm until catching cement at 111 barrel away, with 160 bbls away slowed displacement to 5.5 bpm / 1700psi, 194 barrels away 4 bpm and 1950 psi, 220 barrels away 3 bpm and 2425 psi, -Bum ed lu at 236 bbls and ressured u to 3200 si CIP 22:30 hrs TIEB1 Set Hanger and Packer With 3200 psi on string slacked off to 50k on hanger -Continued pressuring up to 4200 psi, set packer (pusher actuated at 3475 psi) -Bleed off and check float, Floats holding -Rig Down Cement hose and Install Bull Plug on Cement head outlet -Pressure up to 1000 psi and pull to 85k, rotate 15 turns to the right to release -Pull Up, at 6 ft pressure release increase flow rate to 7.5 bpm 499 psi -After um in 20 bbls, slacked of and set 40 k down ositve indication do sub set down -Increase flow rate to 11 bpm / 960 psi to chase cement out, -100 barrels into chasing cement out stop pumping and close bag, line up to flow back tank -Finish chasing out cement at 11 bpm / 2345 psi -19 barrels of cement back to -Pump additional 50 barrel before return cleaned up -Open up bag and close lines to flow back tank and circulate to verify clean returns -Job Completed at 23:55 hrs TIE61 Rig Down Cement equipment -Flush Lines and Stack TIEB1 POH with Drill Pipe artd stand back 3 stands of 4 3/4" DC's TIE61 Make Service Breaks on Cement head and Lay Down TIEBi Flush Stack -Function Test BOP Rams CLEAN Make U 7" Cleanout BHA -6 1/8" Bit, 7" csg scraper, 2 x junk baskets, bit sub, bumper sub, circ, sub, XO, 9 x 4 3/4" SDC's CLEAN RIH with 7" Cleanout BHA on 86-stds of 4" DP from derrick. CLEAN PU 9-5/8" HES Storm acker and stand # 87. -Set Storm Packer 1-std below ri floor Bit at 8543'). -Stand back std # 87. -Test Storm Packer to 1000-psi for 10-charted minutes. -Good test. CLEAN ND BOP stack. -2 Barriers for ND are 1) tested Storm Packer at 98' and 2) tested FasDril at 8924'. -Pull wear ring. -Drain BOP stack. -Pull Riser. -Stand back BOP stack on pedestal. Printed: ~/29/2009 3:04:05 PM • ~ BP' EXPLQl~ATlC7N Page 7 of 10 Operations Summary Report Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Qate From - Tca Hours Task Gode NPT Phase ' Description of Operatians 7/13/2009 09:30 - 10:00 0.50 WHSUR P CLEAN ND tubing spool. -RU 4-part sling. -Check OA pressure. Pressure is 0-psi. -Back out Lower LDSs -Upper section of packoff came with tubing spool. -Clean bottom section of packoff and API ring groove. 10:00 - 10:30 0.50 WHSUR P CLEAN Attempt to pull lower section of 9-5/8" casinq packoff usinq, liftinp eves. -Unable to pull free. -Apply steam to casing head. -Decide to have rig welder fabricate pulling tool. 10:30 - 13:00 2.50 WHSUR X SFAL CLEAN Rig welder fabricate pulling tool for pulling lower section of 9-5/8" casing packoff. -Continue to steam casing head. 13:00 - 13:30 0.50 WHSUR X SFAL CLEAN Attempt to pull lower packoff section with new pulling tool. -Replace 1/2" all thread. 13:30 - 18:00 4.50 WHSUR X SFAL CLEAN Attempt to pull lower packoff section with pulling tool. -Apply steam. -Fill interior of casing with cold water. -While attempting to pull packoff with pulling tool, periodica_Ily see bubbling and fluid around OD of casing. - o movement seen. ' 18:00 - 21:00 3.00 WHSUR X SFAL CLEAN -NO movement seen. Continue to attempt to pull 9 5/8" pack off unsuccessfully -While developing plan forward we continue to keep pressure on pack off. No movement seen. -Photos taken of lower packoff and send to RWO engineers and Superintendent for review. ~ -Developed plan forward with Anchorage Rig Team; Due to the difficulties removin the 9 5/8" lower ackoff, the decision was made to qo with a McEvoy Casinq Spool and Packoff. 21:00 - 22:30 1.50 WHSUR X WAIT CLEAN Mobilize spool and Packoff -Transport Test Plug and Wear bushing for McEvoy Spool -Q & A Spool upon arrival -Install VR Plug on second OA Port and install blind Flange 22:30 - 00:00 1.50 WHSUR P CLEAN Nipple up spool and Packoff -Test Packoff and void to 3800 psi for 30 mins, good test, zero drop in pressure 7/14/2009 00:00 - 01:00 1.00 BOPSU P CLEAN NU BOP Stack 01:00 - 01:30 0.50 BOPSU P CLEAN Install Test Plug, Fill Stack -Test Break to 250 psi and 4000 high, Good Test -John Crisp with AOGCC waived witness of test. 01:30 - 02:00 0.50 BOPSU P CLEAN Install Wear Bushing 02:00 - 02:30 0.50 ZONISO P CLEAN Retrieve Storm Packer -Make Up HES retrieving tool and RIH with 1 stand -Screw into storm packer and Release -POH and Lay Down Tool 02:30 - 03:30 1.00 CASE P TIEBi i f r min -Rig up head pin and chart -Pressure up and shut in pumps -Lost 40 psi the 1st 15 minutes and zero the 2nd 15 minutes Printed: 7/29/2009 3:04:05 PM • • BP EXPLORATI4N' Pag~ 8 af 14 Operat~ons Summary Repart Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: ~ate Fram - To Hours Task Code NPT Phase Description Q# Operatians 7/14/2009 02:30 - 03:30 1.00 CASE P TIEB1 -Good Test 03:30 - 04:00 0.50 CLEAN P CLEAN RIH to 8550' md -Kelly up and break circulation -Rotate and Reciprocated Scraper several times from 8550' -8620' 04:00 - 05:00 1.00 CLEAN P CLEAN Drill Cement down to Landinq Collar -PUW176k / SOW 150k RtWt 160k -5 bpm / 665 psi -50 rpm 5k ft-Ibs of torque -Firm cement (10k WOB) from 8650 - 8707'md 05:00 - 06:00 1.00 CLEAN P CLEAN Displace 9.8 Brine with seawater while drilling on plug and Landing Collar -6 bpm / 1090 psi -Pump High Vis sweep ahead of seawater 06:00 - 07:30 1.50 CLEAN P CLEAN Continue to Drill cement down to 7" x 4-1/2" XO. -Did not "see" float collar. -Tag XO at 8796'. -PU and RIH to reconfirm tag. -See cement, plug parts, aluminum and metal on magnets at shakers. 07:30 - 09:00 1.50 CLEAN P CLEAN Pump 20-bbl Hi Vis sweep & circulate out of hole. -Pump at 10-BPM with 2290-psi. -Rotate and reciprocate pipe while circulating. -Cement, plug & aluminum returns, cleaned up after sweep returned. -Monitor well - Static. li -Pump dryjob. ' I -Blow down Top Drive. ~ 09:00 - 11:30 2.50 CLEAN P CLEAN POH with 7" drill out BHA. standing back 4" DP in derrick. ' 11:30 - 12:30 1.00 CLEAN P CLEAN LD 7" Drill out BHA. ' -Stand back 3-stds of 4-3/4" DCs. -Recover 1/2-gallon of cement and aluminum shavings from boot baskets. -Clear rig floor. 12:30 - 12:45 0.25 CLEAN P CLEAN RU handling equipment for 3-5/8" Mill Out BHA. -Bring BHA components to rig floor. 12:45 - 14:00 1.25 CLEAN P CLEAN MU 3-5/8" Mill Out BHA. -BHA consists of 3-5/8" Mill, 6(ea) 3-1/8" DCs, 2-jts of 2-7/8" PAC DP, Bumper Sub, Jar, Pump Out Sub, and 3-stds of 4-3/4" DCs. -Total BHA length = 539.1'. -RU head pin and circulate through mill prior to picking up DCs to ensure mill is clear. 14:00 - 17:00 3.00 CLEAN P CLEAN RIH with 3-5/8" Mill Out BHA on 4" DP from derrick to 8880' ' 17:00 - 19:00 2.00 CLEAN P CLEAN Obtain milling parameters & Mill FasDrill. -PU wt = 185K-Ibs, SO wt = 146K-Ibs, Rot wt = 166K-Ibs. -Rotate at 40-rpm with 5K-ftlbs free torque. -Wash down at 4-BPM with 1600-psi. -Rotate through XO and mill ahead. -Ta FasDrill lu at 8901'. - Mill FasDrill lu w/ 4 bpm,1600 psi , 40 rpm 5-7k torque, Broke through and wash down to 9,051' - Saw pressure increase when 2 7/8" X 4 3/4" crossover Printed: 7/29/2009 3:04:05 PM • • Operat Legal Well Name: 01-30 Common Weil Name: 01-30 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 ~ ~ ~ i i 7/14l2009 17:00 - 19:00 2.00 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 00:00 3.50 CLEAN P 7/15/2009 00:00 - 03:00 3.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04;00 - 04:30 0.50 CLEAN I P I 04:30 - 06:30 2.00 RUNCOiviP 06:30 - 12:00 I 5.50 12:00 - 16:30 I 4.501 RUN 16:30 - 17:30 ~ 1.00 ~ RU 17:30 - 18:00 0.50 RUN 18:00 - 18:30 0.50 RUN 18:30 - 22:00 3.50 RUN 22:00 - 23:00 1.00 RU 23:00 - 00:00 1.00 RU Spud Date: 6/11 /1986 Start: 7/4/2009 End: 7/16/2009 Rig Release: 7/16/2009 Rig Number: Phase Description o# Op~eratior~s CLEAN bottomed out on 7"x 4. " CLEAN Drop ball to open cire sub, pump ball down ~ 4 bpm 1040 psi, sheared open w/ 1,450 psi - Pump 20 bbl high vis sweep ~ 5 bpm 680 psi. - Increase rate to 12 bpm, 2630 psi. - Cement, aluminum and small amount of rubber over shakers at bottoms up, hole clean after sweep returned. CLEAN Monitor well-static -Pump dry job. CLEAN POH, Lay down 4" DP CLEAN POH, Lay down 4" DP CLEAN Lay down 9 ea 4 3/4" DCs, cire sub, jars and bumper sub. -Change out handling equipment and lay down 2 jts 2 7/8" DP, 6 ea 3 1/8" DCs and Mill. CLEAN Clear floor of Baker tools. RUNCMP Pull wear ring -R/U to Run 4 1/2" Completion. -Hold PJSM with Rig crew, Doyon Casing tech, Baker Completions rep and BP WSL. Assign people to positions. Discuss general hazards and power tong safety. RUNCMP Run 4-1/2" 12.6# L80 TCII com letion er running order. -BakerLok all connections below packer. -MU all connections to 3850-ftlbs optimum torque using Torque Turn services. -Use Jet Lube Seal Guard thread compound on all connections. -Tailpipe assembly RIH at 0700-hrs. -Run 4 1/2" Completion per running order T/ 3990' 93 jts ran. RUNCMP Continue Running 4 1/2" 12.6# L-80 TC-II Completion per running order F/3990' T/ 8766' MU all connections to 3850-ftlbs optimum torque using Torque Turn services. -Use Jet Lube Seal Guard thread compound on all connections. RUNCMP -UD jt # 209 and makeup hanger and landing joint - Land tubing and RILDS. - WLEG set 5' above ported crossover. RUNCMP R/U Lines to IA and tubing to reverse clean seawater and diesel. RUNCMP Held PJSM with WSL, Toolpusher rig crew, CH2MHILL, Little Red and Baker, for displacement. RUNCMP Test circulating lines T/ 4000 psi -Reverse in 135 bbls clean 120 deg. seawater ~ 3 bpm ICP 50 psi, FCP 120 psi, followed by 170 bbls 120 deg. seawater treated with EC1124-A corrosion inhibitor f~ 3 bpm ICP 120 psi. FCP 200 psi. Followed by 152 bbls diesel C~3 2 bpm ICP 600 psi, FCP 800 psi. RUNCMP Allow Diesel to U-Tube. RUNCMP Droq 1 5/16" Ball and rod. - Backout and lay down landing joint. - R/U to pump down tubing. Printed: 7/29/2009 3:04:05 PM ~ • BP EXPLQRATIC7N Pag~ 1~ af 1a Operations Summary R+eport Legal Well Name: 01-30 Common Well Name: 01-30 Spud Date: 6/11/1986 Event Name: WORKOVER Start: 7/4/2009 End: 7/16/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/16/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hc~urs Task Cade NPT Phase ' Description of Operations 7/15/2009 23:00 - 00:00 1.00 RUNCO RUNCMP - Pressure up on tubinq to 4,000 psi, to set packer and test , tubing record test on chart for 30 min. -Lost 150 psi in first 15 min. Lost 50 psi in final 15 min. -Bled tubing pressure to 1500 psi. 7/16/2009 00:00 - 00:30 0.50 RUNCO P RUNCMP Pressure up to 4,000 psi on IA to test packer, record on chart, for 30 min. -Lost 150 psi in first 15 min -Lost 50 psi in final 15 min. - Bled tubing and IA pressure to zero 00:30 - 01:30 1.00 WHSUR P RUNCMP install TWC, and test from above to 4,000 si for 10 min. ood test. -Blow down circulating lines and drain BOP stack. 01:30 - 03:00 1.50 WHSUR P RUNCMP Held PJSM- Covering N/D BOP and N/U tree - N/D BOP and related equipment. 03:00 - 05:30 2.50 WHSUR P WHDTRE Install tubing head adapter and test seals to 5,000 psi for 30-min. Good Test. - N/U tree fill with diesel and test to 5,000 psi for 10-min. Good test 05:30 - 06:00 0.50 WHSUR P WHDTRE Secure well. -Install all gauges and tree jewelry. -Ensure all pressures are zero. '"Release ri at 0600-hrs on 7/16/200 ". '*TWC left in wellhead per WL & Completions Supervisor." Printed: 7/29/2009 3:04:05 PM 01-30 We I Histor Post Ri Wo~over ~ Y( J ) Date Summary 7l28/2009 W ELL S!I ON ARRIVAL. PULLED BALL AND ROD W/3.6" BELL GUIDE, 2" JDC FROM 8717' SLM. PULLED 4-1/2" RHC PLUG BODY W/ 4-1/2" GS FROM 8722' SLM / 8724' MD. DRIFTED W/ 10' x 3-3/8" DMY GUN, TEL, S. BAILER. TAGGED TD @ 9335' SLM, +11' TO 9346' ELMD. WELL LEFT S/I ON DEPARTURE. 8/26/2009 WELL SHUT-IN ON ARRIVAL FOR E-L1NE 3-3/8" POWER JET PERF, HSD, HMX. SWAB OPEN, LATERALS = OPEN; SSV, MASTER, WING = CLOSED. INITIAL T/I/O = 0/0/0 -- POST RUN 1 T/I/O = 0/0/0. PERFORATED INTERVAL 9315' - 9335' WITH PJ 3-3/8" GUNS. POOH, AT SURFACE READY TO RIH WITH 2ND GUN RUN. 8/27/2009 ELINE 3-3/8" PJ PERFORATING JOB. INITIAL T/I/O = 0/0/0. GUN 2 T/I/O = 0/0/0 PERFORATED INTERVAL 9295' - 9315'. GUN 3 T/I/O = 0/0/0, PERFORATED INTERVAL 9275' - 9295'. GUN 4 T/I/O = 0/0/0, PERFORATED INTERVAL 9255'-9275' GUN 5 TlIfO = 0/0/0, PERFORATED INTERVAL 9235'-9255' GUN 6 T/I/O = 0/0/0, MISS-RUN DUE TO BAD DETONATOR. GUN 6 2ND ATTEMPT, T/I/O = 0/0/0, PERFORATED INTERVAL 9215'-9235'. 8/28/2009 ELINE 3-3/8" PJ PERFORATING JOB. INITIAL T/I/O = 0/0/0. GUN 7 T/I/O = 0/0/0, PERFORATED INTERVAL 9195'-9215' GUN 8 T/I/O = 0/0/0, PERFORATED INTERVAL 9190'-9195' FINAL T/I/O = 0/0/O--WELL ON VACUUM. SSV, MASTER, SWAB, WING = CLOSED. DSO NOTIFIED OF VALVE POSITIONS. WELL LEFT SHUT IN. JOB COMPLETE. Page 1 of 1 TREE _, CNV WELCHEAD = MCEVOY .ACTUATOR = BAKER C KB. ELEV = 70~ BF. ELEV = ? KOP= _ ~ Max Angle = 32° @ 5800' Datum MD = 9342' Datum ND = 8800' SS ~ ~ 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" ~~ 2519~ SAFEI~TES: ***4-1/2" CHROMENIPPLES"`** o~ -30 2025~ ~~4-1/2" HES X NIP (9-CR), ID = 3.813" 3481' ~ 9-5/8" X 7" G2 ZXP BKR lTP w/ FLIX LOCK LNR HGR, ID = 6276" Minimum ID = 3.725"" @ 8995' 4-1/2" OTIS XN NIPPLE 8659~ ~~4-1/2" HES X NIP (9-CR), ID = 3.813" 8690~ ~-~ 7" X 4-1 /2" BKR S-3 PKR, ID = 3.870" 8724~ I~4-1/2" HES X NIP (9-CR), ID = 3.813" 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 1 8791. 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 8796~ 4-1/2" TBG STUB (07/10/09) $$29' 4-1/2" TBG-PC, 12.6#, L-80, 0152 bpf, ID = 3.958" 9007~ PERFORATION SUMMARY REF LOG: BHCS ON 06/23/86 ANGLE AT TOP PERF: 21 °@ 9433' Note: Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 6 9433 - 9453 S 08/ 3-3/8" 9464 - 9474 S 06/12l02 3-3/8" 4 50 S 07/29/94 3-3/8" 4 9 - 51 S 10/31/93 3-3/8" 9518 - 9530 06/25/93 4 9538 - 9554 S 07 3•~8 b q~q°-~3~5 0 °g~u- 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9742~ TD 9750' '-~og 8791 ~ --I4-1/2" WLEG, ID = 3.958" ~ $7gs' 7" X 4-1 /2" PORTED XO, ID = 3.958" gg3g' 9-5/8" X 4-1/2" UNIQUE OVERSHOT 8890~ 9-5/8" X 4-1/2" BKR SB-3 PKR, ID = 3 ggg5' 4-1/2" OTIS XN NIP, ID = 3.725" 9007~ 4-1/2" WLEG, ID = 3.958" 8g92~ ELMD TT LOGGED 02/21/87 ~9350~ FISH: FASDRILL PLUG PUSHED DOWN (07/14/09) ~9350~ ESTIMATED TOP OF CNif (06/28/09) 9520~ TOP OF FILL (06/28/09) 9745~ TE-L20-R SPRING VALVE DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/86 ORIGINAL COMPLETION 01 /10187 LAST WORKOV ER 07/16/09 D16 RWO 07/23/09 MD/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 01-30 PERMff No: 1861110 API No: 50-029-21606-00 SEC 8, T10N, R15E, 1135' FNL & 1533' FWL BP F~cploration (Alaska) o~i2oios Scl~t~ber~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # r~:'.{ ~ ~;~°~.~;=<._.~ ~ ~~~. ~: f ~ :'• t: ~: .__.v . .. _ _. ~~sC~-Ifl o `~ :.~~-3 Log Description Date „ ~~ o , ~;r~o: ~a~s Company: State of Alaska Alaska Oil & Gas Cons Comrri Attn: Christine Mahnken 333 Wes4 7th Ave, Sui4e 100 Anchorage, AK 99501 BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE 06/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 1 G-318 ANHY-00100 LDL ~ 07/07/09 1 1 Z-32BL7 AV1H-00018 SBHP RVEY 07/02/09 1 1 14-10 AY3J-00033 PRODUCTION PROFILE ~'a~ 07/01/09 1 1 A-20 AV1H-00021 SBHP SURVEY -~ '~ 07/07/09 1 1 01-30 AY3J-00034 LDI. (0 07/04/09 1 1 M-26A BOCV-00021 PRODU TION LOG - 07/12/09 1 1 06-23C AXBD-00031 M~MORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PROOUCTION LOG 07/09/09 1 1 ~2-20 AYKP-00031 LDL / 07/10/09 1 1 E-09B 604C-00064 SCMT - 07/01/09 1 1 04-33 AY3J-00036 USIT I 07/07/09 1 1 WGI-0~ BOCV-00020 USIT 07/11/09 1 1 1-31/M-21 B146-00063 PRODUCTION PROFIL~+ - 06/16/09 1 1 L3-02 AZCM-00028 RST 06/15/08 1 1 1-31/M-21 814B-00063 RST ' 06/17/09 1 y 18-18B ANHY-00097 RST a- ~'" ' 06/09/09 1 q ~I CACC Al~Il41A111/1 cn/~C ~L nclt~T nV c~lnul -~A ~ . BP Exploration (Alaska) Inc.------- • - • --~•-••-~ •-~-- .._. _......... ...._ ,. . ~~,,.. , ~. Petrotechnical Data Center LR2-1 J 900 E. Benson Blvd. 'r'.~ ~ ... -~ -.~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 4~0 Anchorage, AK 99503-2838 I~ L_J r 1 L J • f v ~~ ~ J ~ d SARAH rAUN, GOVERNOR CUI~SEB~TIOI~T n ~~ ~ 333 W. 7th AVENUE, SUITE 100 1~ l~oaaa~~-~~~ii~~•~~i1---777 oi` f ANCHORAGE, ALASKA 99501-3539 /~ PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~ ~ . ~~, ~; ~ .y °~ Anchorage AK 99519-6612 ~"`~'J~''` Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-30 Sundry Number: 309-113 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day 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. Sincerely, DATED this day of May, 2009 Encl. Daniel T. Seamount, Jr. Chair f~s~-l(1 ~41 ~ STATE OF ALASKA ~ ~ ~ ~ `/ E V ~"~' 0 ,...~ !~ ~ {~, ~~ALA~ OIL AND GAS CONSERVATIOI~COM ION ~ ~~~~ ~ 7 2009 ~~~a9 ~~'/rt APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 w~iaska Qil & Gas 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensi~pChOt'a~ ® Alter Casing , ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program .® Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Convert to In'ection 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 186-111 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029- 6-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: }\ fv Co property line where ownership or landownership changes: PBU 01-30 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028329 - 70' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12•' PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9750' - 9251' - 9742' 9244' None 9745' C sin L n th Siz MD TVD Bur olla Structural n r 11 1 1 14 47 rf 2 1 1- /" 2519' 251 4 1 In rm diat Pr i n 742' - 1 " 74 ' 44' 7 47 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9433' - 9554' 8955' - 9068' 5-1/2", 17# x 4-1/2", 12.6# L-80 9007' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'SB-3' packer Packers and SSSV MD (ft): 8890' 13. Attachments: 14. Well Class after proposed work: ~~/ ® Description Summary of Proposal ^ BOP Sketch ~ ~+ / ^ Exploratory ® vel ~mbe 'Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 1, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~~2~oh9 Terrie Hubble, 564-x628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ti J ~ ~ ~4~~ S a . ~ . ~, ^ Plug Integrity ~ BOP Test `Mechanical Integrity Test ^ Location Clearance ~~~ ' ~ ~t Other: 10Q~(aS c ~Gl~'~C~ ~~ r ~- ~Q~ ~S~ 't"~w~~~v'~--~ C~r~~~-~C~~ ~~ Subsequent Form Required: t-•~, ~-•~ APPROVED BY ["/Q' A roved B COMMISSIONER THE COMMISSION Date J( Q Form 10-403 a ed 06/200 Submit In Duplicate d ~.~ . € `~ ~ _ ~ MAY ~ ~• 2009 • by cr,~ 01-30 Rig Workover • Scope of Work: Pull 4-'/z" L-80 completion. Run new 7" L-80 casing from 8800' to 3500' and cement in place. Change out 9-5/8" casing packoffs. PT new casing to 4000 psi for 30 minutes. Mill out the 7" shoe track. Run 4-'/z" L-80 Baker S-3 packer completion. MASP: 2500 psi Well Type: Ivishak Producer becoming an Ivishak Injector Estimated Start Date: May 1 S', 2009 Production Engineer: James Dean Workover Engineer: Mackie Derrick Pre-rip prep work: S 1 Pull WFD Patch C~ 8739' MD. PULL 2-3/8" X Ni le Reducer C~ 8995' MD. C 2 P & A the erforations in the 01-30 wellbore with cement from PBTD to 9380' MD. ~, E 3 Drift tubing for Jet Cutter and tag TOC. LDL to confirm that cement is a competent barrier and all fluid is exiting out the Cretaceous Leak. Power jet cut tubing ~ 8850' MD. (Reference tubin tall dated 01-10-1987 F 4 CMIT-TxIA to 2000 psi, confirm LLR. Circulate well with 9.8 ppg Brine and diesel thru the cut. MITOA to 3000 si. Bleed WHPs to 0 si W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. O 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/2" x 6" VBR pipe rams. Pressure test to 4000 psi. Circulate out freeze protection fluid and circulate well to clean through the cut. 2. Pull and LD 4-'h" tubing string to the cut. 3. Pressure up to 3500 psi and achieve LLR. 4. Run and cement 7" scab liner from 8800' to 3500' MD. Note: Pipe rams will not be changed to 7" for casing running as the barrier to the reservoir will be KWF and that the perforations have a plugback with TOC ~ 9380' MD. 5. Change out 9-5/8" casing packoffs. 6. Pressure test new casing to 4000 psi for 30 minutes. 7. Mill out shoe track. 8. Run 4-'h" L-80 completion with Baker S-3 packer. Position packer at 8600' MD. 9. Displace the IA to packer fluid and freeze protect fluid and set the packer. 10. Test tubing and IA to 4000 psi. 11. Set BPV. ND BOPE. NU and test tree. RDMO. Post Rig Work crt~ ~~ This well will have 120' of new perforations shot in the Ivishak Z4 prior to the well becoming an Injector. i TREE WELLH b = GRAY ACTUATOR = AXELSO KB.' ELEV - 7 BF. ELEV KOP = Max Angle = 32 @ 5800' Datum MD = 9342' Datum TVD = 8800' SS • 01-30 ~ ~ 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ 30' 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" ~~ 2519' Minimum ID =1.875" @ 8995' 4-1/2" XN X 2-3/8" X NIPPLE REDUCER ~ ~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~--~ 9007' PERFORATION SUMMARY REF LOG: BRCS ON 06/23/86 ANGLE AT TOP PERF: 21 @ 9433' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9433 - 9453 O 08/31/02 3-3/8" 6 9464 - 9474 O 06/12/02 3-3/8" 4 9480 - 9500 O 07/29/94 3-3/8" 4 9498 - 9518 O 10/31/93 3-3/8" 4 9518 - 9530 S 06/25/93 3-3/8" 4 9538 - 9554 O 07/15/93 SAFETY NOTES: 30~~ 5-1/2* X 4-1/2" XO 197' 4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3214 3212 7 FMHO RK 2 5170 5023 28 FMHO RK 3 6277 5988 29 FMHO RK 4 6876 6541 22 FMHO RK 5 7488 7114 20 FMHO RK 6 8326 7905 19 FMHO RK 7 8436 8010 19 FMHO RK 8 8585 8152 19 FMHO RK 9 8665 8228 18 FMHO RK *1 8776 8334 18 FMHO RKP *ST #10 - GLV BEHIND PATCH (XX/XX/XX) 8739' - 8812' WFD ECLIPSE PKR, ID = 2.250' (05/19/06) 8890' - ~ 9-5/8" X 4-112" BAKER SB-3 PKR 8995' 4-1 /2" XN NIP X 2-3l8" X NIP R®UCI ID = 1.875" ~ soOT I-1 4-1/2" TUBING TAIL 8992' ELMD TT LOGGED 02/21 /87 9745' ~-~ TEL20-R SPRING VALVE 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9742' TD 9750' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/28/88 ORIGINAL COMPLETION 06!11/06 TWS/PA XX TTP PULLED @ 8995' 01/10/87 LAST WORKOVER 02/04/03 ATD/TP REMOVEWANERSFTY NOTE 05/29/05 KSB/PJC NIPPLER REDUCER @8995' 05/18/06 RRD/TLH PATCH SET & CORRECTIONS 05/19/06 JGMIPJC WRD ECLIPSE PKR @ 8739' PRUDHOE BAY UNIT WELL: 01-30 PERMff No: 1861110 API No: 50-029-21606-00 SEC 7, T10N, R15E, 222.58' FEL & 2861.66' FNL BP Exploration (Alaska) TREE _ ? WELLH D = GRAY ACTUATOR = AXELSON KBlELEV = 70' BF. ELEV = ? KOP = _? Max Angle = 32 @ 5800' Datum MD = 9342' Datum TVD = 8800' SS • 01-3 0 SA~ N°~. Proposed ~4-1/2" X NIPPLE, ID = 3.813" ~ 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" I Minimum ID =1.875" @ 8995' 4-1 /Z" XN X 2-3/8" X NIPPLE REDUCER Cemented 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" -~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" -~ -3500 1 9-5/8" x 7" G2 ZXP Baker Liner top Packer 4-1/2" X NIPPLE, ID = 3.813" ~~17" X 4-1/2" BAKER S-3 PACKER I 4-1 /2" X NIPPLE ID = 3.813" 4-1/2" OTIS TBG TAIL ID = 3.958" 9-5/8" X4-1/2" Unique Overshot 9-5/8" X 4-1/2" BAKER SB-3 PKR 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 9007' PERFORATION SUMMARY REF LOG: BHCS ON 06/23/86 ANGLE AT TOP PERF: 21 @ 9433' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9433 - 9453 O 08/31/02 3-3/8" 6 9464 - 9474 O 06/12/02 3-3/8" 4 9480 - 9500 O 07/29/94 3-3/8" 4 9498 - 9518 O 10/31 /93 3-318" 4 9518 - 9530 S 06/25/93 3-3/8" 4 9538 - 9554 O 07/15/93 91 007' I~ 4-1/2" TUBING TAIL 8992' ELMD TT LOGG®02/21/87 9745' ~ 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~ I TD I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/86 ORIGINAL COMPLETION 06/11/06 TWS/PA XX TTP PULLED @ 8995' 01/10/87 LAST WORKOVER 02/04/03 ATD/TP REMOVE WANER SFTY NOTE 05/29/05 KSB/PJC NIPPLER REDUCER @8995' 05/18/06 RRDITLH PATCH SET & CORRECTIONS 05/19/06 JGM/PJC WRD ECLIPSE PKR @ 8739' TE-L20-R SPRING VALVE PRUDHOE BAY UNff WELL: 01-30 PERMff No: 1861110 API No: 50-029-21606-00 SEC 7, T10N, R15E, 222.58' FEL 8 2861.66' FNL BP Exploration (Alaska) Page 1 of 2 Maunder, Thomas E (DOA) From: Derrick, George (Mackie) M [derrgm@BP.com] Sent: Thursday, May 07, 2009 9:15 AM To: Maunder, Thomas E (DOA) Subject: FW: DS 01-30 (186-111) Tom, Here is the information related to 01-30. The well is looking pretty good as for isolation. If you need anything else for the sundry please give me a call. Thanks. Mackie Mackie Derrick l'4`or6cover tnaineer BP txp{oration (Alaska) inc. derrgmC~b_p._c_om {9v7} 564 5892 {office (9Q7) 25J 1674 {celll, ~~~\~ y~~~ ~~~ ~ ~k~~~~ ~~~ From: Seltenright, Ana Maria Sent: Thursday, May 07, 2009 9:05 AM To: Derrick, George (Mackie) M Subject: RE: DS 01-30 (186-111) Mackie, There are no wells within %4 mile from 01-30 in the SAG river reservoir. ~~~ The 9-5/8" production casing is fully cemented from TD to ~8694'md, considering that the top of SAG in this well is 9011' md, then the 01-30 provides appropiate isolation passing the top of SAG. Regards, Ana Maria Seltenright E'~~c~c~uctic~>~ ~~;~~~~neer Prtac~ll~oe i3a~ - tai°a~`ity l~raina~e. 13P Ixplc?raiios~ Alaska lr~c. From: Derrick, George (Mackie) M Sent: Friday, April 03, 2009 1:12 PM To: Dean, James A Subject: FW: DS 01-30 (1$6-111) 5/7/2009 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 1:18 PM To: 'Derrick, George (Mackie) M' Subject: RE: DS 01-30 (186-111) Thanks much. Just trying to reduce my "stack". When the information is available, email is fine. From: Derrick, George (Mackie) M [mailto:derrgm@BP.com] Sent: Tuesday, April 14, 2009 1:15 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 01-30 (186-111) Tom, Page 1 of 1 Sorry not to respond. I actually just emailed the engineer to get on this again. One was out of town and now back. The RWO has been pushed back so in that case we are not in a major hurry. But I will light a fire and get the information to you. Thanks. Mackie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 14, 2009 1:10 PM To: Derrick, George (Mackie) M Cc: Reem, David C Subject: RE: DS 01-30 (186-111) Mackie, Is this being worked? I have not had any response to my original message. Thanks, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, March 31, 2009 3:22 PM To: Derrick, George (Mackie) M Cc: Reem, David C Subject: DS 01-30 (186-111) Mackie, I am reviewing the sundry submitted for this well. It is planned to convert the well to an injector. There are several items needed to satisfy the requirements for injection wells. 1. Please provide a listing and assessment of isolation for all wells/penetrations within'/ mile radius of the entry into the Sag. 2. Please provide an assessment of the isolation specifically for DS 01-30. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 4/14/2009 Page 2 of 2 James, Can you please provide me with the information below. I will then get everything to the state. Thanks. Mackie Mackie Derrick Workovcar engineer BP explorntinn {Alnska) Tnc. derrgm~?bp.com <907) 564 5$91 (cffice) {9G7) 25U 16%4 {cel[j From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 31, 2009 3:22 PM To: Derrick, George (Mackie) M Cc: Reem, David C Subject: DS 01-30 (186-111) Mackie, I am reviewing the sundry submitted for this well. It is planned to convert the well to an injector. There are several items needed to satisfy the requirements for injection wells. 1. Please provide a listing and assessment of isolation for all wells/penetrations within %4 mile radius of the entry into the Sag. 2. Please provide an assessment of the isolation specifically for DS 01-30. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 5/7/2009 ¡)JØ/06 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 4 Z006 REPORT OF SUNDRY WELL OPERA TIÐNSI & Gas Cons. Commission . ~~(. RECEIVED . 1. Operations Performed: Repair WellŒ Plu~ PerforationsD Stimulate 0 OtherD Abandon 0 Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ:I ExploratoryD 1RA.1110 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21606-00-00 7. KB Elevation (ft): 9. Well Name and Number: 70.00 01-30 8. Property Designation: 10. Field/Pool(s): ADL-028329 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9750 feet true vertical 9251.4 feet Plugs (measured) None Effective Depth measured 9697 feet Junk (measured) Fish @ 9745' true vertical 9201.9 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 SURFACE 31 13-3/8" 68# K-55 29 - 60 29.0 - 60.0 3450 1950 SURFACE 2459 13-3/8" 72# L-80 60 - 2519 60.0 - 2519.0 4930 2670 PRODUCTION 9716 9-5/8" 47# L-80 26 - 9742 26.0 - 9244.0 6870 4760 ~CANNE~Jì SEP 2 Ð 2D05 Perforation depth: Measured depth: 9433-9453,9464-9474,9480-9490,9490-9498, 9498-9500, 9500-9510, 9510-9515 9515-9518,9538-9546,9546-9554 True vertical depth: 8955-8974,8984-8993,8999-9008,9008-9016, 9016-9018, 9018-9027, 9027-9032 9032-9034,9053-9061,9061-9068 Tubing ( size, grade, and measured depth): 5-1/2" 15.5# L-80 @ 24 - 28 4-1/2" 12.6# L-80 @ 28 - 9007 2-7/8" 6.5# L-80 @ 8739 - 8812 Tubing Patch Packers & SSSV (type & measured depth): 2-7/8" WFD Arrow Pac Patch PH @ 8739 2-7/8" WFD Arrow Pac Patch PH@ 8812 5-1/2" Baker SB-3 Packer @ 8890 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaqe Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 51 0 0 240 SSV Subsequent to operation: 51 0 0 220 860 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr . Title Petroleum Engineer Signature .At ~L . .ø1ê j¿fj ./ Phone 564-5174 Date 9/11/06 , ~ " '1nn¡, Form 10-404 Revised 4/2004 Ul\l\Jii\l/""\L . _ - V~, ,. ~VVV . . 01·30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/11/2006 FIVE RUNS WI 1-1/4" BAILER TO 8963' SLM, SAND BACK WI BAILER BAIL WI 1.5" BAILER @ 8963' SLM PULLED 2-3/8" XX PLUG @ 8968' SLM D&T WI 1.75" CENT., TEL, AND S.BAILER, SAT DOWN @ 9518' SLM 19530' ELMD (12' CORRECTION), SAMPLE BAILER BACK WI FRAC SAND ***WELL TURNED OVER TO DSO ON DEPT.*** 06/10/2006 FOUR 1-1/4" BAILER RUNS TO 8966' SLM, SAND RETURNS RIH WI EQUALIZING PRONG TO 8966' SLM, UNABLE TO EQUALIZE, PRONG STUCK IN FILL, POOH RIH WI 1-1/4" BAILER, STUCK @ 8966' SLM, BLEED DOWN TUBING, COME FREE, APPEARED TO BE PRESSURE LOCKED, BAILER RETURNS OF DRY SOIL LIKE MATERIAL RIH WI 1-1/4" BAILER, CAME BACK FULL OF SAND, SAT DOWN @ 8963' SLM. 06/09/2006 ATTEMPT TO EQUALIZE 2-3/8" XX PLUG, UNABLE TO EQUALIZE TWO RUNS WI 1- 1/4" PUMP BAILER, BACK WI SAND SECOND ATTEMPT TO EQUALIZE, NO PRESSURE CHANGE THREE MORE RUNS WI 1-1/4 BAILER TO 8565' SLM, RETURNS OF SAND. 06/08/2006 ***WELL SHUT IN ON ARRIVAL*** (PRE SAND BACK I CMT CAP) RIGGING UP SLlCKLlNE UNIT TO PULL TTP & DRIFT. 06/05/2006 TIIIO = 870/220/210. Temp = SI. LNFT-IA PASS (Waiver for PC Leak). IA FL @ 260'. Bled lAP to 0 psi in 1 hr, 15 min. Tubing pressure decreased to 790 psi. IA FL rose to 30'. Start LNFT. No fluids returned. SI, monitored for 30 min. lAP increased to 4 psi. Final WHPs = 790/4/210. 05123/2006 TIIIO = 860/220/220. MIT T to 3000 psi (PASSED). AOGCC State Witnessed by John Crisp. Pumped 2 bbls diesel to achieve test pressure. Lost 100 psi in the 1 st 15 min and 40 psi in the 2nd 15 min, for a total loss of 140 psi in 30 min. Bled back to starting pressure. Final WHP's = 600/220/220. 05122/2006 TIO= 850/240/230. SI TBG & IA FL's AOGCC Post Patch. TBG FL @ surface, IA FL @ 258' (12 bbls). 05/19/2006 ****WELL SHUT IN **** (set wft patch---e-fire) SET WEATHERFORD UPPER PACKER PATCH ASSEMBLY @8,725' SLM. (e-fire) RDMO. ****LEFT WELL SHUT-IN**** 05/15/2006 **** WELL SHUT IN **** (set wfd patch assy) SET TWO 30' SLlCKSTICK PATCH ASSEMBLIES @ 8,786' AND 8,754' SLM. ****JOB STILL IN PROGRESS**** 05/14/2006 SET LOWER ECLIPSE PACKER AT 8812' ELM. NO PROBLEMS RIH OR POOH. TIED INTO SENSA TUBE MEMORY LDL DATED 04-DEC-2004. ALSO CONFIRMED DEPTHS WITH PATCH SETTING RECORD DATED 08-NOV-2004. JOB COMPLETE. TURNED 05/03/2006 T/I/O=SSV/240/220. Temp=SI. T, IA & OA FL's for E-line (pre-Patch). IA FL @ 260' (14 bbls). OA FL @ surface. Page 1 . . 01-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/29/2005 MIT OA to 3000 psi (PASSED) (waiver for pc leak) Pumped 2.5 bbls crude to pressure. FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 2 Diesel 2.5 Crude 5.5 TOTAL Page 2 · TREE = WELLHEAD = ACTUA TOR = B. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = ? GRAY AXELSON 70' ? ? 32 @ 5800' 9342' 8800' SS 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 30' 113-3/8" CSG, 72#, L-80/K-S5, ID = 12.347" I Minimum ID = 1.875" @ 8995' 4-1/2" XN X 2-3/8" X NIPPLE REDUCER 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 9007' ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/23/86 ANGLEATTOPÆRF: 21 @ 9433' Note: Refer to Production DB tor historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9433 - 9453 0 08/31/02 3-3/8" 6 9464 - 9474 0 06/12/02 3-3/8" 4 9480 - 9500 0 07/29/94 3-3/8" 4 9498 - 9518 0 10/31/93 3-3/8" 4 9518 - 9530 S 06/25/93 3-3/8" 4 9538 - 9554 0 07/15/93 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9742' ~ 9750' DATE 06/28/86 01/10/87 02/04/03 OS/29/05 05/18/06 05/19/06 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER ATDITP REMOVEWAIVERSFTY NOTE KSB/PJC NIPPLER REDUCER @8995' RRDfTLH PATCH SEr & CORRECTIONS JGM'PJC WRD ECLIPSE PKR @ 8739' 2197' 4-1/2" CAMCO BAL-O SSSV NIP, ID=3.813" ST MD lVD DEV TYPE VLV LATCH PORT DATE 1 3214 3212 7 FMHO RK 2 S170 5023 28 FMHO RK 3 6277 5988 29 FMHO RK 4 6876 6541 22 FMHO RK 5 7488 7114 20 FMHO RK 6 8326 7905 19 FMHO RK 7 8436 8010 19 FMHO RK 8 8S85 8152 19 FMHO RK 9 866S 8228 18 FMHO RK *10 8776 8334 18 FMHO RKP *5T #10 - GL V BEHIND PATCH (XX/XXIXX) 8739' - 8812' -WFD ECLIPSE PKR, ID = 2.250' (05/19/06) 01-30 DA TE REV BY COMMENTS 06/11/06 TWS/PAG XX TIP PULLED @ 8995' NOTES: 30' 5-1/2" X 4-1/2" XO I - 9-5/8" X 4-1/2" BAKER SB-3 PKR I 4-1/2" XN NIP X 2-3/8" X NIP REDUCER ID = 1.87S" 4-1/2" TUBING TAIL I ELMD TT LOGGED 02/21/87 - TE-L20-RSPRINGVALVE I PRUDHOE BA Y UNrT WELL: 01-30 ÆRMrT No: ~861110 API No: 50-029-21606-00 SEC 7, T10N, R15E, 222.58' FEL & 2861.66' FNL BP Exploration (Alaska) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ? 1'....., Pol. Supervisor \ ') DATE: Wednesday, May 24, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-30 PRUDHOE BA Y UNIT 01-30 V \V\ \t6 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: Pol. Suprv SB¡2-- Comm Well Name: PRUDHOE BAY UNIT 01-30 API Well Number 50-029-21606-00-00 Inspector Name: John Crisp Insp Num: mitJCr060524044650 Permit Number: 186-11 1-0 Inspection Date: 5/23/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --, 01-30 ! 0 I I ! Well Type InJ. . N I TVD 8443 I IA 220 220 220 I 220 j I I I I i P.T. 1861110 iTypeTest: SPT I Test psi 2110.75 OA 220 220 220 220 I .-. I T -- Interval REQV AR P/F P Tubing 860 3020 2920 2880 Notes Tubing patch installed. MIT T to 3000 for new waiver. NON-CONFIDENTIAL ,~f':;>'~'. Nt;; 1 ) ~rv::¡ 'w ."..0.: ...;....~- "'; r ,(j Wednesday, May 24,2006 Page I of I ¡?\:,j¡ ..~ :.?i7\ ·l' . ':-'-I~ \ ',," 'I 'I / I··~ '\ ,.11 ,j '\, '\'1; ; \,., ; ~, :=1'\~) i¡:¡ / .¡;W, '\, ,Ii i'J ,.'.Jj "I" ,¡ ',I ':' ,-_' .~ .~~ ~-.c.t W:~ ,.~ - ..,;-- 'I 1-j rw IJJ /7\ 1'"1 :1'\ I ",::;~: ~:7 If-;'\ ;I }~ \ ' , ,- I r I ,~ ;I ]\., i! " " ' '. ", I \ ( " i \ ! '-.I \ Ii' --, ",' ilL , U~"\J L Lt"':..;. ~) J,~ L -'J FRANK H. MURKOWSKI, GOVERNOR AItA.SIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alex Yancey Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: PBV 01-30 305-217 \1Ö(ç--- I I " ,>",- Ù M ' i ,_. í n" A U G II ",' 'ì 0 i"' f: Sli¡j"MtlNE"....J" J "::. .1 I~ UJ Dear Mr. Yancey: 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 . ay or weekend. A person may not appeal a Commission decision to Superior ourt unless rehearing has been requested. DATED this J-vtay of August, 2005 Encl. Alter Casing Change Approved Program Abandon D D D CfJ. B-q·o5 ~'È f/1/2"~OÇ- STATE OF ALASKA ~':J:f( rY / r I s CE/\/ED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 a 2005 APPLICATION FOR SUNDRY APPROV~~aD¡J&GDsc ons. Co . Ant~lJrJge mm/$sio PerforateD Waiver 0 Other [!] StimulateD Time Extension 0 CONVERT TO INJ Re-enter Suspended Well D 5. Permit to Drill Number: 186-1110 / ( 20 AAC 25.280 1. Type of Request: Repair Well Pull Tubing Suspend D D D Operation Shutdown Plug Perforations Perforate New Pool D D D 2. Operator Name: 3. Address: 4. Current Well Class: BP Exploration (Alaska), Inc. Development Œ] / Exploratory D P.O. Box 196612 Anchorage, Ak 99519-6612 11. Presen1 Total Depth MD (ft): 9750 Casing Total Depth TVD (ft): 9251.4 Stratigraphic D Service D 9. Well Name and Number: 01-30 ¡ 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9697 9131.9 Size MD TVD 6. API Number / 50-029-21606-00-00 7. KB Elevation (ft): 70.00 KB 8. Property Designation: ADL-028329 Length Plugs (md): None Burst Junk (md): 9745 Collapse CONDUCTOR SURFACE SURFACE PRODUCTION top bottom top bottom 80 20" 91.5# H-40 28 108 28.0 108.0 31 13-3/8" 68# K-55 29 60 29.0 60.0 2459 13-3/8" 72# L-80 60 2519 60.0 2518.8 9716 9-5/8" 47# L-80 26 9742 26.0 9243.9 1490 3450 4930 6870 470 1950 2670 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9433 - 9453 8955 - 8973.6 5-1/2 " 15.5 # L-80 24 28 9464 - 9474 8984 - 8993.2 4-1/2 " 12.6 # L-80 28 9005 9480 - 9518 8999 - 9034.4 9538 - 9554 9053 - 9068.1 Packers and SSSV Type: 5-112" Baker SB-3 Packer 4-1/2" Cameo BAL-O SSV Nipple Packers and SSSV MD (ft): 8888 2197 12. Attachments: Description Summary of Proposal [!] Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: August 17, 2005 Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasD /' Service 00 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: WAGD GINJD Plugged D Abandoned D / WINJoo WDSPLD Prepared by DeWayne R, Schnorr 564-5174. Alex Yancey Contact Printed Name Signature ~ncey '/ / ~Þ·0,"r/ Com"mission Use Only Conditions of approval: Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-5092 8/3/05 BOP TestD Mechanciallntegrity Test ~ Sundry Number: 3os:. ;J .q- Location Clearance D '.t 'vJ1d, , -II I 0 - 4 L' 4 . RBDMS BFL AUG 15 2005 BY ORDER OF THE COMMISSION Dale: 11 of "- Form 10-403 Revised 11/2004 ORIGINAL SUBMIT IN DUPLICATE \ ' bp ttJ~"..,.;,.. 1 ITI","')' ;, i. ~: .,.., 4C., ....L, ....".".. ;..-p,~ Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RECEIVED AUG 0 3 Z005 August 1 , 2005 AI~s~a Qil & GO! Coos. Cømmi~~jor¡ AnchoragG RE: Sundry Notice for 01-30 --- Conversion from Production to Injection BP Exploration Alaska, Inc. proposes to convert well 01-30 to a Sea Water injection / well. Step Type Procedure E Set lower packer assembly 2 S Run slickstick patch and upper packer assembly 3 0 MIT-T to 3000 psi 4 S Pull Tubing Tail Plug Well 01-30 is currently having its surface facilities converted to water and injection service. / The objective of the conversion is to provide pressure support to current producers, improve volumetric sweep efficiency, and to mobilize and capture remaining oil saturation above the GOC (Updip Zone 4 injection). This program is consistent with a larger regional strategy to manage and develop the GDWFI /" area in a manner that considers the maturity of the waterflood areas, the maturing of the GO process and the possible impact of gas sales on overall recovery. Included is the Cement Bond Log from well 01-30 (06-30-1986). The top of the cement is at 8980 ft outside the 9-5/8 production string, and the top of Zone 4 is at 9190. The nearest offset wells are 01-15A, 01-13, and 01-10 and their bottom hole locations are beyond 1320 ft / from well 01-30. Sincerely, A ß( ~ee, Alex Yancey DS 01 Production Engineer r ¡ I r I r - ~ j _~ ,;/l· ~-; .J ~,_ ~ ¡ , .J ~ _ u _ I ~~ - _ ,L"'T·~.:;;-.~'=~"7,;:~..;:;::,;<, I_~ \ ..,.... - _," ...,...~ '..... '411 ,-.;- __' ,;";;¡;øv.a"¡>!t..-- ~;~: ~ ¡..-................a.-, ·~..».,11 f, ,..~ . ...............' """""'~. ~_,__,____'" ,_ _ U }" .. ,-....--~,~n··' ~.......; . . <:.,'l'".A:'-'\.~'~" ~ . .- , __'.'. ......~. I",. '~':,.I"""""".. .. \.,.¡(,. """.. _,.., ftj, """"""""'¡"'._',,",,:t.,\~~ ..", _..". \'" ',." - -.... r :LT,'-'\¡",4'1' :,jt;....,.-~_ : ..,.._..........._~ ¡"" ,:-'?~'2:S.~1;'~::: - ";;-2 , ,.,' .I'¡"-'-'A,," __" I/I"...~"""~ '~~ !_~~.II~~..:"· '/~ .~-'. ~,..., ~~t--.( .f-.~.L . 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L~. l-. -..-.¡----~, ,--' -f':.:."· "j:1 -;:.' ;':'J ,t.." iI.'1. --. --1"1\ frI--'''- , ¡ , \ I ! j J\ (' \. ¡.1 \: ; \.\ .,1 , 'i . \.. ,I )/:'(-'"""1' J:\~.!, '. ./\/'It \¡ ¡ t ~ I l '.) ~ ~ t \.1 \' i . y...'......../V.í i I¡! \l \./ . :.1 ! . , ,'\ r " ,j : i :1 ¡ v ¡,Ai "'" ü\ III .~ '1\ \~ _ _.._~._ > 1:~ ......~ ¡ -t ¡ .._.._.~_~__~~_l~-.-:...____- \.. l.'·\ , .1-"'--_ i , j ~ . -~.. . _0' , - .. '., f)91Ü(î ,);9 2 (H) A v¡ ~...,¡,,,... -~,~ ~, 'H' ! \ TREE = WELLHEAD = ".. ",... - .. ,.. ....1 ACT¥JAIOR = KB.ElEV = " . BF, aEV = . KÒP~ Max Angle = . öätum MD = . ............ Datum 1VD = ? GRAY AXB....SON ,_. 70' ? ? ) .n.... "".....~. 32 @ 5800' , "" 93·f2', . .m,_._.___. .. 8S00' SS 15-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 30' 13-318" CSG, 72#, L-801K-55, ID = 12.347" l-i 2519' Minimum ID = 3.725" @ 8995' 4-1/2" OTIS XN NIPPLE 14-1/2" TBG-PC, 12.6#, L-SO, .0152 bpf, ID = 3.95S" 1-1 9007' PERFORATION SUMMARY REF LOG: BHCS ON 06123186 ANGLE AT TOP ÆRF: 21 @ 9433' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn1Sqz DATE 3-31S" 6 9433 - 9453 0 08131102 3-3/S" 6 9464 - 9474 0 06/12/02 3-318" 4 9480 - 9500 0 07/29/94 3-3/8".> 4 9498 - 9518 0 10/31193 3-318~", 4 9518 - 9530 S 06125/93 3-318" ". 4 9538 - 9554 0 07115/93 9-5/8" CSG, 47#, L-BO, ID = 8.681" l-f 9742' ŒJ-i 9750' DATE 06/28/86 01/10/87 02/15/01 05/31/02 06/15/02 06/22/02 08/31/02 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER TP CORRECTIONS KAK PERF CORRECTIONS C::WSITP ADD PERF KBfTLH RBv10VE PLUG & PERF CORR. C::WS/TP A DD PERF DATE 10/17/02 02104/03 08/17/03 II{ 11/06/04 ~ 01-30 \ I " r )AFETY NOTES: MWtIA X FORMATION COMM. i LEAK @ 6200' . 6300'. I 30' 1-1 5-1/2" X 4-1/2" XO 1 2197' 1- 4-1/2" CAMCO BAL-O ~ SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3214 3212 7 FMHO RK 2 5170 5023 2S FMHO RK 3 6277 5988 29 FMHO RK 4 6876 6541 22 FMHO RK 5 7488 7114 20 FMHO RK 6 8326 7905 19 FMHO RK 7 8436 8010 19 FMHO RK 8 8585 8152 19 FMHO RK 9 8665 8228 18 FMHO RK 10 8776 8334 18 FMHO RKP r 8763'-8779'1- 4-1/2" WFD ARROW PAC PATCH, 10 = 2.372" SET 11/06/04 8890' 1-1 9-5/8" X 4-112" BAKER SB-3 PKR 1 8995' 1-{4-112" OTIS XN NIP, ID = 3,725" I 9007' 1-1 4-1/2" TUBING TAIL I 8992' 1-1 ELMD 1T LOGGED 02/21187 I I I 9745' l-i T&L20·R SPRING VALVE 1 REV BY COMMENTS JRClKK WANER. SAFETY NOTE A TDfTP REMOVE WAIVER SAFETY NOTE CMOffiP OA TUM MD CORRECTION MDClTLP WFD PATCH ~ ..!. L I I :¿g;: ~ r t 4 -', - PRUDHOE BAY UNIT WELL: 01-30 PERMIT No: 1861110 API No: 50-029-21606-00 SEe 7, T10N, R15E, 222.58' FEL & 2861.66' FNL BP ExPI~r~ti~n (J\las kà) MECHANICAL INTEGRITY REPORT' , :~ ~ G R E ~ .: l-_:: .:: : &(I/Ilq~r;' 0!2~/l1gro OPER & FIELD - ~ p - p ~ LA- \-.:Z:il NUMJ3ER 0 I ~ ~ 0 ::?UD DA:~: :.-::..:1e-:-: Shoe: 11D :"Joi:;g: s- '/2 <1'/. 4~'þ2.~'cke::: 9005""· HI.) '!'VD; :CF: HI) 9/ 5 Z TVD HI) ·Tvu HD ;:"'["0 .;/ 'I Cas ir:.g: q ~ ~ TD: Q150 .HD.. CItes I TVD ~ ?BTD: 9~q7 Shoe: q741 lID 924-4 TVD¡ DV: :~~LL DATA TVu¡ Set ê.t fff~ ::ole Size Il ~ I!~ 1/ a.na Perf.s q4)~ to qÇ54 :-SC?..Þ_NIC;~ INTEGRITY - PART /1 Annulus Press Test: ~p 15 m~n 30 min Co=ents: M IT 'r-f"~ u.Â "-f J . ,...- ~CHÞ_1\lICÞ~ INTEGRITY - PART /2 Cement: Volumes:- þ...mt. Liner ~oO c., Ie.. t Csg ~é>O SIt:. DV ¿\q~o I . Cült -"01 to cover per=.s 2 -3Lp SfL' fo f· (J' +' ';Ot)',@ ~(,?~? Qi.,t'.cç.r:. .-.. , Theoretical Toe 1058 Cement Bond Log (Yes or No) -if ; In AOGCC File ' v -4tÞ 90 :) 0 I L -J q .go' 'J O(.~q lA<:t. lj \ \ ' 1)'I<"'\.(l( I"' (" "", \ 'r ,~,. ¡ if H CIA Cf.!L" r"~ d GBL ~valuation, =one a.Dove perfs Proåu~tion Log: Type Evaluation .. CONC;LUSIONS: ?arf n: ME, 'OuJ~d, ? arc: : 2: C-vti t V DI, ) C<M-+ åWv(, Á{) () v0ll/2 d 8/ q /Z,(}()Ç -., ~J: 6 A,t'~'lÃ- I J I I ,." ·l ) \" ,/ /"."'. -~' /I 1\'(.'1 ¿"'.¿', ' ¡ " µAf ) ¡'"",:IL.., 10 c} "n.., ~,(.,. ~,-"fC. ,,\.... ,'; \.. " ~">,, "d j /..t/ ~ "j¡? (M,.:l? ( I ~, fA",''lJ y.l1.,.d r\., It-fJ 12 " .. -.. -- ) ) Iff, -/(( (Q' ~ FRANK H. MURKOWSKI, GOVERNOR ATJASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alex Yancey Petroleum Engineer BP Exploration (Alaska) Inc. 900 E. Benson Blvd. P.O. Box 196612 Anchorage, AK 99519 Re: Your request to convert PBU Well 01-30 to injection service. Sundry Number: 304-470 Dear Mr. Yancey: AOGCC hereby denies your application to convert PBU Well 01-30 to injection service. This denial is without prejudice. If you wish to resubmit this application, please include with your submittal the following information in support thereof: (1) a copy of the subject well's cement quality log(s), and (2) a list of all well penetrations within a one quarter-mile radius (the Area of Review) of the subject well's proposed injection zone. AOGCC appreciates your attention to this matter. Daniel T. Seamount, Jr. Commissioner DATED thisíday of December, 2004 Ene!. SCANNED DEC 1 3 2004 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 RepairWell D Pull Tubing D Operation Shutdown 0 PerforateD Annular DisposalD Plug Perforations D StimulateD Time Extensi OtherŒJ Perforate New Pool D Re-enter Suspende ellD Convert to Inj 4. Current Well Class: 5 ermit to Drill Number: 186-1110 /' 6. API Number /' 50-029-21606-00-00 BP Exploration (Alaska), Inc. 11. Total Depth MD (ft): 9750 Casing Total Depth TVD (ft): 9251.4 Development [!) Exploratory 0 Stratigraphic 0 Service 0 9. Well Name and N~ber: 01-30 10. Field/Pool(s): Prudhoe Bay Field / Pru oe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Dep 9697 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.00 KB 8. Property Designation: ADL-0028329 Length Size MD Plugs (md): Junk (md): None 9745 Burst Collapse top Conductor 80 20" 91.5# H-40 /1 28 Production 9716 9-5/8" 47# L-80 I ¡ 26 Surface 31 13-3/8" 68# K-55 / 29 Surface 2459 13-3/8" 72# L-80! 60 Perforation Depth MD (ft): Perforation Depth TVD (~t): See (ttachment . K Packers and SSSV Type: ,'~ \ ' 2-7/8" WFD Arrow Pac Patch Packer ('"\ \J \ 2-7/8" WFD Arrow Pac Patch Packer \1) 5-1/2" Baker SB-3 Packer J 12. Attachments: saiD Detailed Operations Program 0 BO Sketch 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Repr " nt iv : botto top bottom 08 28.0 108.0 1490 470 9742 26.0 9243.9 6870 4760 60 29.0 60.0 3450 1950 2519 60.0 2518.8 4930 2670 Tubing Size: Tubing Grade: Tubing MD (ft): 2.875 " 6.5 # L-80 8763 8779 4.5 " 12.6 # L-80 28 9005 5.5 " 15.5 # L-80 24 28 Packers and SSSV MD (ft): 8761 8777 8888 13. Well Class after proposed work: ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil D GasD WAG D GINJD Service ŒI PluggedD AbandonedD WINJ ŒJ WDSPLD Prepared by Garry Catron 564-4657. oing is true and correct to the best of my knowledge. Contact Alex Yancey Printed Name Signature , Yancey {o/ ~ :fL~/ Title Phone Petroleum Engineer 564-5092 11/15/04 Commission Use Only Notify Commission so that a representative may witness Sundry Number: 3oc..f- 41 0 Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D Other: Subsequent Form Required: Approved by: BY ORDER OF THE COMMISSION Date: RBDMS BFL DEC 0 6 2004 ORIGINAL Form 1 0-403 Revised 06/2004 SUBMIT IN DUPLICATE ') ; . Perforation Depth MD (ft): 9433 - 9453 9464 - 9474 9480 - 9490 9490 - 9498 9498 - 9500 9500 - 9510 9510 - 9515 9515 - 9518 9538 - 9546 9546 - 9554 ) Attachment Perforation Depth TVD (ft): 8954.85 - 8973.6 8983.86 - 8993.2 8998.84 - 9008.2 9008.21 - 9015.7 9015.7 - 9017.6 9017.57 - 9026.9 9026.94 - 9031.6 9031.62 - 9034.4 9053.16 - 9060.7 9060.65 - 9068.1 Page 1 _? TREE = - ¿. ~~~~~.r.?~,..... ....u..u~.~X A CTjJA;rOR = AXELSON KB. ELEV = 70' ... ". ........... ,.., m....... .u.." BF. ELEV = ? M'< ........,..,.. "....,.....".".^",....."..'..l>.'.....,.....,,~ KOp,;_m.m . ""'.......... '... . .-.. ... ... ..?.. ." ... ..... ..... ".... .0<'"'" . . , Max Angle = 32 @ 5800' . oatumMÕ';'w,,, ..... ... .... .'.. 9342" "'" uu.~.,. 'U"'h..«UU""U"uuu....,.'"" .... .«.«uu«.",,,,..,..«,,-..,, Datum TVD = 8800' SS ') I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" l-i 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" l-i 25191 Minimum ID = 3.725" @ 8995' 4-1/2" OTIS XN NIPPLE 14-112" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 90071 PERFORA TION SUMrv1ARY REF LOG: BHCS ON 06/23/86 ANGLE AT TOP PERF: 21 @ 9433' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9433 - 9453 0 08/31/02 3-3/8" 6 9464 - 9474 0 06/12/02 3-3/8" 4 9480 - 9500 0 07/29/94 3-3/8"," 4 9498 - 9518 0 10/31/93 3-3/8" 4 9518 - 9530 S 06/25/93 3-3/8" 4 9538 - 9554 0 07/15/93 r 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 97421 œ., 97501 DATE 06/28/86 01/10/87 02/15/01 05/31/02 06/15/02 06/22/02 08/31/02 REV BY DATE 10/17/02 02/04/03 08/17/03 11/06/04 COMMENTS ORIGINAL COM PLETION LAST WORKOVER TP CORRECTIONS KAK PERF CORRECTIONS CWS/TP ADD PERF KBITLH REMOVE PLUG & PERF CORR. CWS/TP ADD PERF 301 01-30 \ / , , . )AFETY NOTES: ***IA X FORMATION COMM. I 'LEAK@ 6200' .6300'. ~ 301 l-i 5-1/2" X 4-1/2" XO 1 21971 1- 4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" ~ ~ ..!. ST MD TVD 1 3214 3212 2 5170 5023 3 6277 5988 4 6876 6541 5 7488 7114 6 8326 7905 7 8436 8010 8 8585 8152 9 8665 8228 10 8776 8334 GAS LIFT rv1ANDRELS DEV TY PE VL V LATCH PORT DA TE 7 FMHO RK 28 FMHO RK 29 FMHO RK 22 FMHO RK 20 FMHO RK 19 FMHO RK 19 FMHO RK 19 FMHO RK 18 FMHO RK 18 FMHO RKP L I I ~ ~ r , ~'. ~ I 87631-877911- 4-1/2" WFD ARROW PAC PATCH, ID = 2.372" SET 11/06/04 88901 l-i 9-5/8" X 4-1/2" BAKER SB-3 PKR 1 89951 1-i4-1/2" OTIS XN NIP, ID = 3.725" 1 9007' l-i 4-1/2" TUBING TAIL 1 89921 I., ELMD TT LOGGED 02/21/87 I I I 97451 l-i TE-L20-R SPRING VALVE 1 REV BY COMMENTS JRClKK WANER SAFETY NOTE ATDITP REMOVE WANER SAFETY NOTE CMOITLP DATUM MD CORRECTION MDClTLP WFD PATCH PRUDHOE BA Y UNIT WELL: 01-30 PERMIT No: 1861110 API No: 50-029-21606-00 SEC 7, T10N, R15E, 222.58' FEL & 2861.66' FNL BP Exploration (Alaska) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reoo::a\ 'R~ II, ~ I ö4 P.I. S.~ l ~ Chuck Scheve .. Petroleum Inspector DATE: Wednesday, November 17, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-30 PRUDHOE BAY UNIT 01-30 \. ~~.- ~.l\ FROM: Src: Inspector Reviewed By: P.I. Suprv :JBI- Comm Well Name: PRUDHOE BAY UNIT 01-30 Insp Num: mitCS041115140311 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21606-00-00 Permit Number: 186-111-0 Inspector Name: Chuck Scheve Inspection Date:' 11/14/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01-30 Type Inj. N TVD 8444 IA 60 180 230 P.T. 1861110 TypeTest Test psi 2111 OA 0 0 0 Interval OTHER P/F F Tubing 100 3000 670 Notes: This test was to be a MITT. A plug had been set in the tubing and a patch set across the known leak in the tubing in an attempt to restore tubing integriy. A leak rate of.3 bbl per min was established on the tubing. During this leak rate test the IA pressure climbed from 60 psi to 1250 psi. The IA of this well also has a substantial leak. SCANNED DEC 1 4: 2004 Wednesday, November 17,2004 Page 1 of 1 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D ') STATE OF ALASKA) ALASKA Oil AND GAS CONSERVATION COMMISSION ~\¡OU REPORT OF SUNDRY WELL OPERATION~~ V 2004 Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K] Stimulate D Other,O WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 186-1110 6. API Number 50-029-21606-00-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.00 8. Property Designation: ADL-0028329 11. Present Well Condition Summary: Total Depth measured 9750 true vertical 9251.4 feet 9745 4. Current Well Class: Development [!] Stratigraphic D 9. Well Name and Number: 01-30 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D feet Plugs (measured) Junk (measured) None Effective Depth measured 9697 feet true vertical 9201.9 feet Casing Conductor Production Surface Surface Length 80 9716 31 2459 Perforation deDth: Size 20" 91.5# H-40 9-5/8" 47# L-80 13-3/8" 68# K-55 13-3/8" 72# L-80 MD TVD Burst Collapse 28 108 28.0 - 108.0 1490 470 26 - 9742 26.0 - 9243.9 6870 4760 29 60 29.0 60.0 3450 1950 60 - 2519 60.0 - 2518.8 4930 2670 Measured depth: 9433 - 9453,9464 - 9474,9480 - 9490,9490 - 9498,9498 - 9500,9500 - 9510,9510 - 9515 9515 - 9518,9538 - 9546,9546 - 9554 True vertical depth: 8954.85 - 8973.56,8983.86 - 8993.22,8998.84 - 9008.21,9008.21 - 9015.7,9015.7 - 9017.57,9017.57 - 9026.94 9026.94 - 9031.62, 9031.62 - 9034.43, 9053.16 - 9060.65, 9060.65 - 9068.14 Tubing ( size, grade, and measured depth): 5-1/2" 15.5# L-80 @ 24 28 4-1/2" 12.6# L-80 @ 28 9005 2-7/8" 6.5# L-80 @ 8763 8779 Packers & SSSV (type & measured depth): 2-7/8" WFD Arrow Pac Patch Pack. 2-7/8" WFD Arrow Pac Patch Pack. 5-1/2" Baker SB-3 Packer @ 8761 SCANNED NO" 1" 4: "2.004 @ 8777 ..- ..- . @ 8888 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ReDresentative Daily AveraQe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 12.1 5140 500 74.2 4026 500 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron #~~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ! Signature Form 10-404 Revised 4/2004 Oil-Bbl 894 891 Tubing Pressure 734 180 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] GasD DevelopmentŒ] ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant Phone 564-4657 Date 11/18/04 ORIGINAL RBDMS 8FL NOV 2 6 2004 ) ) 01-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/31/02 Perforate 94331-94531 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 T,.REE = _? WELLHEAD = GRAY 'A'cruÁ'fó'R' ;"'...... "'ÄXi~LS'Ö'N ",." ,,,~.O'.'.w,.w.~- KB. ELEV = 70' <-BF~'a:Br;,;" ? ^K.~~~~~'~~::~,="..::m'::..~:.,^':-'~^."^,^^] Max Angle = 32 @ 5800' "5ãtum'MÓ;;'"'' """""""'9342' "5ãtum'T\io,n;",.. ""ääóó'U<ss ') I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 30' 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" 1-1 2519' Minimum ID = 3.725" @ 8995' 4-1/2" OTIS XN NIPPLE 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1--1 9007' ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/23/86 ANGLEATTOPÆRF: 21 @ 9433' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9433 - 9453 0 08/31/02 3-3/8" 6 9464 - 9474 0 06/12/02 3-3/8" 4 9480 - 9500 0 07/29/94 3-3/8". 4 9498 - 9518 0 10/31/93 3-3/8" 4 9518 - 9530 S 06/25/93 3-3/8" 4 9538 - 9554 0 07/15/93 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9742' [§]-I 9750' DATE 06/28/86 01/10/87 02/15/01 05/31/02 06/15/02 06/22/02 08/31/02 REV BY DATE 10/17/02 02/04/03 08/17/03 11/06/04 COMMENTS ORIGINAL COM PLETION LAST WORKOVER TP CORRECTIONS KAK ÆRF CORRECTIONS CWS/TP ADD ÆRF KBITLH REMOVE PLUG & ÆRF CORR. CWS/TP ADD ÆRF 01-30 \ I , , }AFETY NOTES: ***IA X FORM A TION COM M. I LEAK @ 6200' - 6300'. ~ 30' 1-1 5-1/2" X 4-1/2" XO 1 2197' 1- 4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" ~ --. ..!. ST MD TVD 1 3214 3212 2 5170 5023 3 6277 5988 4 6876 6541 5 7488 7114 6 8326 7905 7 8436 8010 8 8585 8152 9 8665 8228 10 8776 8334 GAS LIFT MANDRELS DEV TYPE VLV LATCH PORT DATE 7 FMHO RK 28 FMHO RK 29 FMHO RK 22 FMHO RK 20 FMHO RK 19 FMHO RK 19 FMHO RK 19 FMHO RK 18 FMHO RK 18 FMHO RKP L I I :8: ~ j , ~ -, ~ ~ I 8763'-8779'1- 4-1/2" WFD ARROW PA C PATCH, ID = 2.372" SET 11/06/04 8890' 1-1 9-5/8" X 4-1/2" BAKER SB-3 PKR 1 8995' 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 9007' 1--1 4-1/2" TUBING TAIL 1 8992' 1-1 ELMD TT LOGGED 02/21/87 1 I I 9745' 1-1 TE-L20-R SPRING VALVE 1 REV BY COMMENTS JRClKK WANER SAFETY NOTE A TD/TP REMOVE WANER SAFETY NOTE CMOITLP DATUM MD CORRECTION MDClTLP WFD PATCH PRUDHOE BAY UNIT WB..L: 01-30 ÆRMITNo: 1861110 API No: 50-029-21606-00 SEC 7, T10N, R15E, 222.58' FEL & 2861.66' FNL BP Exploration (Alas ka) ._ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other /,/ [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1135' SNL, 1533' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 2755' SNL, 58' WEL, SEC. 07, T10N, R15E, UM At effective depth 2853' SNL, 208' WEL, SEC. 07, T10N, R15E, UM At total depth 2863' SNL, 224' WEL, SEC. 07, T10N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 70' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 01-30 ~"'" 9. Permit Number 186-111 10. APl Number 50-029-20606-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool !2. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 9750 feet 9251 feet 9697 feet 9202 feet Plugs (measured) Junk (measured) See Diagram Length Size Cemented Structural Conductor 110' 20" 150 sx Coldset II Surface 2519' 13-3/8" 2000 sx CS III, 550 sx CS II Intermediate Production 9742' 9-5/8" 950 sx C~ass 'G', 4.50 sx CS ,, 30o sx CS ~ Liner MD TVD 110' 110' 2519' 2519' 9742' 9244' Perforation depth: measured Open: 9464'- 9474', 9480' - 9500', 9498' - 9518', 9538' - 9554' Sqzd: 9518' - 9530' true vertical Open: 8984' - 8993', 8999' - 9018', 9016'- 9034', 9053' - 9068' Sqzd: 9034'- 9046' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 30'; 4-1/2", 12.6#, L-80 to 9007' Packers and SSSV (type and measured depth) Baker 'SB-3' packer at 8890'; Camco 'BaI-O' SSSV at 2197' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operati/on August 8, 2002 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Dave Wesley, 564-5773 15. [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is triqe an.d,,_~co~¢ect to the best of my knowledge i / ~'~.i~,L~'~ ? Title Senior Drilling Engineer Date Signed Brian Robertson ~ %__" ! , ~, - - r- ,, .....r '~ ........ ; ....... , - ~--,~ ........... ,, ...... , .... r']- ' ' Cond,,,o.. o,.pp.ov.,: No, Comm,.,o.. e,re.en,,,ve m w, e. ] pprova, No. Plug integd~ BOP Test ~ LocaUon clearance __ Uechani~llntegri~Test__ Subsequentfo~requiredl0- ~O'Z ~e~ ~;~~ .~ ~ ~ , Commissioner Date Approved by order of the Commission - ~.,,, ~..,~.~=~,.,, ~ , . Camm ~,~ .... ~ Form 10-403 Rev. 06/15/88 Y ' .......... .,~-~' ] Submit bp To: From: Subject: Reference: Winton Aubert - AOGCC Date: July 31, 2002 Dave Wesley - BPXA GPB Rotary Drilling DS 1-30 Application for Sundry Approval - P&A for Sidetrack Operations AP! # 50-029-21606-00 Approval is requested for ~e proposed P&A of PBU well 1-30. The existing 01-30 wellbore is mechanically unsound, and Zone 2 has been hydraulically fractured twice, once in 1993 and again in 1994. Well 01-30 failed an MITIA in 1997, and has remained shut in since that time due to the substantial leak rate observed while pumping down the IA (-9 gpm @ 1700 psi). A leak detection log run in October 1999 identified a probable leak in the 9-5/8" casing over the interval 6200'-6300'. It is possible that multiple holes exist over this interval. The well will remain idle until integrity is restored. / /- Well 01-30 was originally drilled in June 1986 and first produced oil in March, 1987. To date the well has produced over 7 MMBO. This Zone 2 producer contains the original 4-1/2" tubing, and has undergone multiple well interventions throughout its history (two GSO operations, numerous add-perf jobs, acid stimulations, three ROPE stimulations, and 2 hydraulic fracture stimulations). Located south of DS1 in the GDWFI area, well 01-30 was a solid producer until early 1990 when water breakthrough occurred, and the GOR increased sharply coincident with an add perf job in June 1990 (see attached production history plot). The well failed a pre-squeeze TIFL in August 1991, and a GSO was performed in October of that year, but the well was difficult to bring back on line. Perforations were added in December 1991, but the well was still dead. A waiver was secured to flow the well with gas lift (waiver needed due to IA communication), but production rates were less than anticipated. Oil production trends greatly improved after perforations were added in June 1992, and again in January 1993. Unfortunately, the GOR remained quite high. In June 1993 the well appeared to be severely damaged by a GSO operation (cement squeeze). A ROPE treatment and hydraulic fracture stimulation were performed in July 1993 in an attempt to restore oil production, but the response was disappointing. An acid stimulation in April 1994 and additional perforations in July 1994 did not improve productivity. Well 01-30 underwent another ROPE and hydraulic fracture treatment in December 1994, and while oil production improved, the GOR and water cut remained fairly high. The 1-30A sidetrack is currently scheduled for Nabors rig 2ES, beginning around September 1, 2002, after the completion of the H-02A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. 1-30 Application for Sundry Scope Pre-Riq Work: Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slick line. Dummy off any remaining live GLV, with the exception of the lower-most GLV at 8,776' MD. Pull the valve and leave the mandrel open. Drift 4 ~" tubing, and down to the top of fill. Document for upcoming cement P&A and tubing cut. / 2. Rig up CTU. Run in hole to open GLM and attempt to circulate the IA. Attempt to determine whether or not there is substantial fill on the backside of the tubing, from the known cretaceous interval leak in the 9 5/8" casing at-6,200' MD, resting on top of the packer. 3. RIH with slick line and dummy off the open GLM. 4. RIH with CTU. Perform a cement P&A of the Zone 2 perforations with 15.8 ppg class 'G' cement, using aggregate as required to aid in plugging perforations. Use adequate cement volume to fill the 9 5/8" casing from the top of fill (tagged at 9,536' MD on 6/11/02), to a depth of -9,250' MD, plus /,,',~queeze a minimum of 5 bbls into the perforations. Estimated minimum cement volume needed is 6.0 barrels. Do not exceed squeeze pressure of 3500 psi. f . . Rig up slick line and drift the 4 ¼" tubing to the top of cement. The drift run is to verify the tubing is clear to the proposed tubing cut depth of 8,880' MD, and may be run at the discretion of the Wells Group. Rig up E-line. Chemical-Cut the 4¼" L-80 tubing at 8,880' MD. This cut will need to be fished. The packer and the remaining tubing tail will also be removed during de-completion operations. 7. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. 8. Test the Gray 9-5/8" mandrel pack-off and tubing hanger seals to 5000psi for 30 minutes. Function all Lock Down Screws and repair or replace, as needed. 9. Set a BPV in the tubing hanger. Secure well. 10. Remove the well house and flow lines. If necessary, level the pad. Please provide total well preparation cost on the handover form. 1-30 Application for Sundry Ri.q Operations: 1. MI/RU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3500psi. 4. Pull and lay down 4 1/2" tubing from tubing cut and above. 5. P/U Packer Retrieval Assembly and 4" drill pipe. RIH and mill packer free. POOH with remaining tubing tail. 6. M/U a casing scraper assembly. RIH to PBTD and circulate well clean. 7. R/U E-line. RIH with Schlumberger USIT. Log 9 5/8" casing from PBTD to surface to determine OA cement placement and 9 5/8" casing condition. 8. R/U and RIH with a 9 5/8" RTTS. Pressure test the 9 5/8" casing to 3500psi, for 30 minutes, above the known Cretaceous leak at ~6,200' MD. Record test. 9. R/U to run and cement a 7", 26#, L-80 liner to -9,185' MD, placing the landing collar at 9,100' MD. Hang the liner and set packer at ~5,700'MD, or as needed to cover all 9 5/8" casing of poor condition. Displace cement to hanger on the backside. 10. Pressure test the 9 5/8" X 7" casing / liner to 3500psi for 30 minutes. Record test. 11. R/U and RIH with a Gauge Ring / Junk Basket. Drift to and tag the plug at the landing collar. 12. M/U and RIH with a 7" Whip Stock assembly. Set whip stock on plug / landing collar. Displace the well bore to an 8.5ppg QuickDrilN fluid. Mill window in the 7" X 9 5/8" liner / casing at 9,080' MD. Perform FIT to 10.0ppg EMW. POOH. 13. M/U and RIH with a 6 1/8" drilling assembly, including DidGR/Res and recorded Den/Neu. 14. Drill 6 1/8" production section, as per directional plan, to an estimated TD of 10,190'MD (-9,170' TVD). 15. Run and cement a 4 W', 12.6#, 13Cr-80 production liner throughout the 6 1/8" well bore. Displace well to clean seawater above liner top. POOH. 16. Run a 4 ½", 12.6#, 13Cr-80 completion, tying into the 4-1/2" liner top. 17. Drop Ball and Rod to set packer and test the tubing and annulus to 3500 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to ~2200' and secure the well. 20. Rig down and move off. Post-Rig Work: 1. MIRU slick line. Pull the ball and rod / RHC plug from 'X' nipple below the production packer and install gas lift valves. Estimated Pre-rig Start Date: 08/10/02 Estimated Spud Date: 09/01/02 Dave Wesley Operations Drilling Engineer 564-5773 1-30 Application for Sundry ACTUATOR= Axelson i. CB. ELEV: 39.20' I SAFETY NOTES: IA X F°rmati°nJ ,,iKop.__ .......... _3,poo,...md leak at 6,200' - 6,300'. o 0 ' Max Angle = 32.0 @5,8 0 ~1 2197' 1-14 1/2"CAMCOBAL-OSSSV,'D=3.813 1133/8",72#,L-80/K-55BTCCasingld 2519' GAS MANDRF1 S I Minimum I.D. = 3.725" @8,995' I sT I MD TVD DEV 'D~F~ SITE I_TCH COMMENTS 4 1/2" Otis 'XN' Nipple ' , 1I 3214 3212 7° FMHO RK 2 5170 5023 28° FMHO RK 3 6277 5988 29° FMHO RK 4 6876 6541 22° FMHO RK 5 7488 7114 20° FMHO RK 6 8326 7905 19° FMHO RK 7 8436 8010 19° FMHO RK ~ ' 8 8585 8152 19° FMHO RK 9 8665 8228 18° FMHO RK , 10 8776 8334 18° FMHO RKP , Size SPF Interval Open/SqzI Date i I ~ I 8,995' 4 1/2" Otis 'XN' Nipple I.D. = 3.725" ! 3 3/8" 6 9464-9474O ' 06/12/02 '-- ~'19,007'1-141/2", 12.6#, L-80 TBG-PC Tbg Tail 3 3/8" 4 i 9480- 9500 O 07/29/94 3 3/8" 4 9498 - 9518 O 10/31/93 3 3/8" 4 9518 - 9530 S 06/25/93 3 3/8" 4 9538 - 9554 O 07/15/93 I e, 42' I-I TE-L20-R Spring Valve [9 5/8" 47#, L-80, BTCCasing Iff 9,742' I ~ · DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/15/01 TP Corrections WELL: DS01-30 05/31/02 KAK Perf Corrections PERMIT No: 1861110 06/15/02 ' CWS/TP iAdd perf APl No: 50-029-21606-00 06/22/02 KB / tlh Remove plug and perf corr. Sec. 7, T10N, R15E 07/31/02 DEW Recreation of 01-30 Current Condition BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 ST MD TVD DEV TYPE SIZE LTCH COMMENTS 1 3214 3212 7° FMHO RK 2 5170 5023 28° FMHO RK 3 6277 5988 29° FMHO RK 4 6876 6541 22° FMHO RK 5 7488 7114 20° FMHO RK 6 8326 7905 19° FMHO RK 7 8436 8010 19° FMHO RK 8 8585 8152 19° FMHO RK 9 8665 8228 18° FMHO RK 10 8776 8334 18° FMHO RKP Size SPF Interval Open/SqzI Date 3 3/8" 6 9464 - 9474 O 06/12/02 3 3/8" 4 9480 - 9500 O 07/29/94 3 3/8" 4 9498 - 9518 O 10/31/93 3 3/8" 4 9518 - 9530 S 06/25/93 3 3/8" 4 9538 - 9554 O 07/15/93 DATE REV BY COMMENTS 02/15/01 TP corrections 05/31/02 KAK Perf Corrections 06/15/02 CWS / TP iAdd perf 06/22/02 KB / tlh Remove plug and perf corr. 07/31/02 DEW Recreation of 01-30 Current Condition ' -30 Pre-rig Conuition ....... w...EL...L....H.......F.A ._ .D= .......... ~!~a.y........G..e...n.:. ACTUATOR-- Axelson KB. ELEV = 70' i i ---, ISAFETY NOTES: IA X Formationl CB. ELEV = 39.20'illeak at 6,200' - 6,300'. I Max Angle = 32.0°@5,800' ............................ -~':'~'z~, I 30' I-I ~"/~"~g-~, ~', L-~O, ,D:~.~" I Datum TVDss= 8,800' I 30' ~ I 2197' Id4 1/2" CAMCO BAL-O SSSV, ID=3.813 I 1133/a",72#,l-a0/K-55BTCCasingl~ 2519' ]~J i GAS LIFT MANDRELS I Minimum I.D. = 3.725" @8,995' ST MD 'I'VD DEV TYPE SIZE LTCH COMMENTS 4 1/2" Otis 'XN' Nipple 1 3214 3212 7° FMHO RK ~'~ 2 5170 5023 28° FMHO RK 3 6277 5988 29° FMHO RK 6876 6541 22° FMHO RK 7488 711420° FMHO RK 8326 7905 19° FMHO RI< 8436 8010 19° FMHO RK 8585 8152 19° FMHO RK 8665 8228 18° FMHO RK 8776 ! 8334 18° FMHO RKP St MD TVD DEV TYPE SIZE LTCH COMMENTS 1 3214 3212 7° FMHO RK 2 5170 5023 28° FMHO RK 3 6277 5988 29° FMHO RK 4 6876 6541 22° FMHO RK 5 7488 7114 20° FMHO RK 6 8326 7905 19° FMHO RK 7 8436 8010 19° FMHO RK 8 8585 8152 19° FMHO RK 9 8665 8228 18° FMHO RK 10 8776 8334 18° FMHO RKP I Pre-rig chemical cut d ~8,880' I - ~ ~ I 8,890' I--19 5/8"x4 1/2" Baker SB-3 Packer I IT°p °f P&A cement plug Id ~9,250',1! I', .119,007'8'995'._Id41-141/2,,,1/2" otis'XN' Nipple I.D. = 3.725"12.6#, L-80 TBG-PC Tbg Tail II Perforation Summary Size SPF Interval Open/Sqz Date 33/8" 6 9464 - 9474 O 06/12/02 33/8" 4 9480 - 9500 O 07/29/94 33/8" 4 9498 - 9518 O 10/31/93 33/8" 4 9518 - 9530 S 06/25/93 33/8" 4 9538-9554 O 07/15/93, ; ':~: I 9,742' I-t T~-,=0-.Spring Valve I 195/8" 47#,L-80, BTCCasing I-t 9,742' I ~,' DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/02 DEW Proposed Pre-rig operations WELL: DS01-30 PERMIT No: 1861110 AP1 No: 50-029-21606-00 Sec. 7, T10N, R15E BP Exploration (Alaska) ~Ar~v/~s UPDATE: O3/08/01 Size SPF Interval Open/Sqz Date 33/8" 6 9464 - 9474 O 06/12/02 33/8" 4 9480 - 9500 O 07/29/94 33/8" 4 9498 - 9518 O 10/31/93 33/8" 4 9518 - 9530 S 06/25/93 33/8" 4 9538 - 9554 O 07/15/93 TREE = CIW 4" 5K Stainless .......... 1-3hA Proposed Co, npletion ACTUATOR= Axelson KB. ELEV = 67.70' , CB. ELEV = 39.20' KOP = -3,000' md "~'-~'h'~'ie ;""~'7':6;~';~~' DatumMD= 9,883' I I I 2200' I-I 4 l/2"'X'LandingNipple, ID=3.813" Datum TVDss= 8,905' 113 3/8", 72#, b-80/i-55 BTCCasingl--t 2519' I ~ ~ i~ o^s,,~M,~s ST! MD TVD DEV TYPE SIZE LTCH COMMENTS i ~ 1 3600 3592 13° RP I 1/2" 4 1/2" 'X' Landing Nipple 3 6832 !6500 22° ! DV 1" II 4 7900 ~;~ 19° DV 1" 9 5/8" X 7" 'ZXP Liner top packer -- -5,700' ~;;~ ~:.; and 'Flex-Lock' liner hanger. " ~ *~ I-6,200'- 6,300'Id9 5/8"Leak in Cretaceous Interval I 7"X 4 1/2" Baker S-3 Prod. Packer ~ ~ ~ [ 8,900' Id4 1/2" 'X' Nipple I.D.: 3.813" t.:~ ,, , , : ~1 8,9~s, I-I 4 1/2" 'X' Nipple I.D. = 3.813" [7", 12.6#, 13Cr-80, VamAce Tubing Id 8,930' ~ 8,930' 7" X 5" 'ZXP liner top packer with -Re- ~? ~ back sleeve, 'HMC' liner hanger. ~ . ~ I ..... I--{W~ndow ~n both 7" scab liner and 9 5/8" ITop ofWhip Stock Id 9,080' I ~i casing. ST! MD TVD DEV TYPE SIZE LTCH COMMENTS 1 3600 3592 13° RP I 1/2" 2 5500 5310 30° DV 1 1/2" 3 6832 6500 22° DV 1" 4 7900 7500 19° DV 1" 5 8740 8300 16° DV 1" 17" 26#,L-80, BTCLiner Id -9,185' I~ I 9,742' I-I TE-L20- RSpring Valve J I 195'8" 47#,L-80, BTCCasing Id 9,742' I I 10,190' Id4 1/2", 12.6#, 130r-801iner;VamAce I DATE I REV BY COMMENTS PRUDHOE BAY UNIT 07/31/02 DEW Proposed Completion WELL: DS01-30A PERMIT No: AP~ No: 50-029-21606-01 Sec. 7, T10N, R15E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 DATE REV BY COMMENTS 07/31/02 DEW Proposed Completion Memory Multi-Finger Caliper Log Results Summary Company: ARCO Alaska Well: 01-30 Log Date: Oct. 7, 1999 Field: Prudhoe Bay Log No.: 1020 State: Alaska Run No.: 1 APl No.: 50-029-21606-00 Pipe Desc.: 4.5" 12.6~ Buttress Top Log Intvl: Surface Pipe Use: Tubing Bot. Log Intvl: 8,980' Ft. (MD) Inspection Type' Corrosive Damage Inspection COMMENTS · This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that most of the tubing is in fair condition, with most joints showing corrosive damage in the 20% to 40% wall penetration range. 17 Joints in the lower half of the tubing stdng indicate slightly more severe corrosive penetrations between 40% and 52% wall thickness. The damage appears in the forms of general corrosion and line corrosion on the Iow side. The area of most severe wall loss is located in Jt. 40, @ 1642', and measures 18% wall loss. Most of the interval logged shows less than 10% cross-sectional wall loss. No significant deposits or obstructions were recorded. MAXIMUM RECORDED WALL PENETRATIONS · Corrosion (52%) Jt. 198 @ 8317' MD Corrosion (48%) Jt. 206 @ 8745' MD Corrosion (48%) Jt. 201 @ 8471' MD Corrosion (47%) Jt. 154 @ 6423' MD Corrosion (46%) Jt. 130 @ 5414' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · The Area of Maximum Cross-sectional Wall Loss is recorded near the bottom of Jt. 40 @ 1642' and measures 18% wall loss. A Cross-sectional drawing of this area is included in the report. MAXIMUM RECORDED ID RESTRICTIONS · A Minimum ID of 3.80" is recorded in the SSSV assembly @ 2211' MD. No significant deposits or abnormal obstructions are recorded throughout the logged interval. Field Engineer' R. Richey / S. Adcock Analyst: Joey Burton Witness: Jerry Middendorf ProActive Diagnostic Services, ]~Fic. / P.O. Box i369, Stafford, -IX 77d-97 ' ~°~'q'~ ~.x~gu85 F~: t/_ol) ~""' ~a . Phone (28i) or to~,,-./~ ~ - m~ . . ~-~a~,~ E-rnail PDS~merrlolylocj.com Pnon~, (907) 659-2307 Fax: (go7) 65g-23-Lfi Prudhoe Bay Field Office ' - =' Sondex Caliper Overview Body Region Analysis Well: DS 01-30 Survey Date: OCT. 7, 1999 Field: PRUDHOE BAY Tool Type: PDS MFC40 No. 99694 Company: ARCO ALASKA, INC. Tool Size: 2.75 In. Country: USA No. of Fingers: 40 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom.OD Nom.ID Nom. Upset 4.5 ins 12.6 ppf L-80 EUE 4.5 ins 3.958 ins 3.958 ins Penetration and Metal Loss (% wall) penetration body : :: ~ metal loss body 250 200 150 100 50 0 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 233) Pene 0 3 34 179 17 0 Loss 3 221 9 0 0 0 Damage Configuration ( body ) isolated general line dng hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 233) 10 179 44 0 0 Damage Profile (% wall) penetration body , .; metal loss body 0 50 1 O0 GLM 10 GLM 9 GLM 8 GLM 7 GLM 6 GLM 1 Bottom of Survey - 210 Analysis Overview page 2 SONDEX CA . ER JOINT TABULATION ,' ]EET Pipe: 4.5 ins 12.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 penetration bo( metal loss bod, Joint Penetration Metal Pro'ection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche., inches :) 50 lC I 0 .06 24 4 0 .04 3.90 1st Full Length Jt of 4.5" 2 0 .04 15 7 0 .04 3.87 Shallow corrosion. I,. 3 0 .05 2C 2 0 .03 3.91 Shallow corrosion. "= 4 0 .05 1S 4 0 .04 3.88 Shallow corrosion. · ' 5 0 .08 28 6 0 .05 3.89 Corrosion. --- 6 0 .04 13 3 0 .03 3.91 Shallow corrosion. [] 7 0 .06 21 4 0 .05 3.87 Corrosion. i"[] 8 0 .03 11 3 0 .03 3.89 Shallow corrosion. 9 0 .06 24 6 0 .05 3.86 Corrosion. 10 0 .08 30 5 0 .05 3.86 Corrosion. "''' 11 0 .08 29 5 0 .04 3.91 Corrosion. 12 0 .04 14 3 0 .06 3.91 Shallow corrosion. ,. 13 0 .08 28 7 0 .06 3.88 Corrosion. ,.. · 14 0 .07 26 6 0 .04 3.89 Corrosion. -- · 15 0 .05 18 5 0 .05 3.87 Shallow corrosion. 16 0 .05 20 3 0 .03 3.94 Line shallow corrosion. 17 0 .06 22 5 0 .06 3.85 Corrosion. "· 18 0 .06 21 4 0 .04 3.87 Line corrosion. 19 0 .04 16 4 0 .04 3.90 Shallow corrosion. 20 0 .06 23 6 0 .04 3.88 Corrosion. ,~m 21 0 .04 14 3 0 .04 3.93 Shallow corrosion. Il"' 22 0 .05 26 7 0 .06 3.86 Line shallow corrosion. 23 0 .08 28 4 0 .05 3.89 Line corrosion. --- 24 0 .05 20 5 0 .04 3.86 Shallow corrosion. . 25 0 .08 28 6 0 .05 3.87 Corrosion. ~-- 26 0 .07 27 5 0 .08 3.86 Corrosion. --- 27 0 .05 18 6 0 .04 3.85 Shallow corrosion, al· 28 0 .05 18 5 0 .05 3.84 Shallow corrosion, i'[] 29 0 .06 23 6 0 .05 3.88 Line corrosion. I!· 30 0 .04 13 2 0 .02 3.93 Shallow corrosion. 31 0 .08 30 7 0 .05 3.87 Corrosion. ia 32 0 .06 24 5 0 .07 3.86 Line corrosion. 33 0 .06 21 5 0 .06 3.86 Corrosion. Il· 34 0 .06 21 4 0 .05 3.84 Corrosion. ""· 35 0 .08 31 6 0 .05 3.89 Corrosion. ia 36 0 .09 32 12 0 .07 3.84 Corrosion. Ii~/· 37 0 .05 19 5 0 .05 3.87 Shallow corrosion, li 38 0 .06 24 6 0 .06 3.86 Corrosion. 39 0 .06 23 4 0 .04 3.90 Corrosion. 40 0 .09 34 18 0 .05 3.90 Corrosion. 41 0 .09 32 7 0 .06 3.87 Line corrosion, lib · 42 0 .06 21 4 0 .05i 3.86 Corrosion. lam 43 0 .07 24 4 0 .05 3.89 Corrosion. ia· 44 0 .04 15 3 0 .03 3.90 Shallow corrosion, la, 45 0 .10 35 5 0 .04 3.88 Line corrosion. 46 0 .07 25 5 0 .06 3.86 Corrosion. 47 0 .07 25 7 0 .05 3.88 Corrosion. Ii·, 48 0 .06 21 5 0 .06 3.87 Corrosion. 49 0 .06 23 6 0 .06 3.87 Corrosion. 50 0 .05 19 5 0 .04 3.87 Shallow corrosion. 51 0 .08 31 6 0 .07 3.87 Corrosion. I" Pipe Tabulations page 1 SONDEX CAi JOINT TABULATION ',, iEET Pipe: 4.5 ins 12.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 penetration boc metal loss bod, Joint Penetration Metal Pro'ection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche., inches 0 50 1(: 52 0 .09 32 6 0 .05 3.85 Corrosion. -r-- 53 0 .05 20 5 0 .04 3.88 Corrosion. 53.1 0 .04 16 4 0 .04 3.85 PUP Shallow corrosion. 53.2 0 0 0 0 0 0 3.86 SSSV 53.3 0 .06 22 4 0 .06 3.86 PUP Corrosion. ._..-- - 54 0 .06 24 5 0 .05 3.87 Corrosion. - 55 0 .08 28 6 0 .05 3.87 Corrosion. ' 56 0 .06 23 6 0 .05 3.86 Corrosion. -. 57 0 .07 27 5 0 .05 3.86 Line corrosion. -Ira· 58 0 .05 17 4 0 .05 3.89 Line shallow corrosion. 59 0 .08 28 6 0 .06 3.87 Corrosion.-;-- - 60 0 .04 16 4 0 .03 3.90 Shallow corrosion. ~ · 61 0 .06 21 4 0 .04 3.85 Corrosion. ,~- 62 0 .07 25 6 0 .07 3.88 Corrosion. ="= ' 63 0 .05 20 4 0 .05 3.86 Shallow corrosion. 64 0 .06 22 4 0 .04 3.90 Corrosion. 65 0 .08 31 5 0 .041 3.87 Line corrosion. ~'-- 66 0 .05 18 3 0 .04 3.85 Shallow corrosion. = [] 67 0 .08 28 4 0 .071 3.86 Corrosion. - 68 0 .07 2,,. 4 0 .08 3.84 Line corrosion. 69 0 .06 21 2 0 .07 3.86 Corrosion. 70 0 .05 18 3 0 .07 3.86 Shallow corrosion. []· 71 0 .09 34 6 0 .04 3.89 Corrosion. 72 0 .06 22 4 0 .03 3.88 Corrosion. mm 73 0 .09 33 5 0 .05 3.87 Corrosion. 74 0 .08 30 5 0 .04 3.87 Corrosion. 75 0 .08 29 5 0 .07 3.88 Line corrosion. 76 0 .05 18 3 0 .03 3.91 Shallow corrosion. · · 77 0 .08 29 5 0 .05 3.91 Corrosion. · [][] 77.1 0 .06 22 4 0 .05 3.87 PUP Corrosion. ,=' 77.2 0 0 0 0 0 0 3.89 GLM 10 (Ltch. ~ 2:00) 77.31 0 .08 31 4 0 .04 3.89 PUP Corrosion. 78 0 .06 23 4 0 .04 3.87 Corrosion. - - 79 0 .06 21 5 0 .04 3.87 Corrosion. " - 80 0 .09 35 6 0 .04 3.92 Corrosion. ~ --- 81 0 .07 27 6 0 .07 3.89 Corrosion. ~[] 82 0 .07 25 6 0 .07 3.87 Corrosion. ,' ' 83 0 .09 35 7 0 .04 3.91 Corrosion. -.- -- 84 0 .08 29 4 0 .07 3.88 Corrosion. .~. 85 0 .06 21 4 0 .05 3.88 Corrosion. [][] 86 0 .09 32 6 0 .06 3.88 Line corrosion. ![] [] 87 0 .09 34 6 0 .05 3.89 Corrosion. II[] []~ 88 0 .08 31 7 0 .06 3.88 Corrosion. ~" [] 89 0 .06 2zl 4 0 .04 3.85 Corrosion. ~~ 90 0 .07 2,' 3 0 .08 3.88 Corrosion. ·[] 91 0 .07 27 4 0 .05 3.88 Corrosion. ~[]i~ 92 0 .06 2zl 4 0 .05 3.88 Corrosion. [][] 93 0 .07 27 8 0 .05 3.90 Line corrosion, i~! 94 0 .06 2; 4 0 .04 3.87 Corrosion. [][] 95 0 .10 3~ 6 0 .06 3.85 Corrosion. []~~ · 96 0 .11 39 8 0 .05 3.90 Corrosion. ~[]~ · Pipe Tabulations page 2 SONDEX CA', JOINT TABULATION .EET Pipe: 4.5 ins t2.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 penetration boc metal loss bod, Joint i Penetration Metal Pro~ection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche., inches 0 50 10 97 0 .07 27 6 0 .06 3.87 Corrosion. m- · 98 0 .07 27 4 0 .05 3.86 Corrosion. =- · 99 0 .08 30 7 0 .05 3.90 Corrosion. 100 0 .08 31 6 0 .07 3.88 Corrosion. "'' 101 0 .07 27 5 0 .06 3.85 Corrosion. ~,w · 102 0 .06 21 2 0 .08 3.86 Corrosion. 103 0 .10 38 12 0 .06 3.86 Line corrosion. 104 0 .10 37 8 0 .07 3.88 Corrosion. 105 0 .09 33 6 0 .06 3.85 Corrosion. 106 0 .10 36 7 0 .10 3.85 Corrosion. 107 0 .09 32i 10 0 .06 3.86 Corrosion. -- 108 0 .10 38 8 0 .05 3.90 Corrosion. 109 0 .10 35 6 0 .11 3.82 Corrosion. 110 0 .08 31 4 0 .04 3.89 Corrosion. 111 0 .08 31 5 0 .08 3.86 Corrosion. 112 0 .09 34 7 0 .05 3.88 Corrosion. 113 0 .10 38 4 0 .08 3.85 Corrosion. 114 0 .08 30 4 0 .20 3.77 Corrosion. · '' 115 0 .09 35 4 0 .05 3.88 Corrosion. 116 0 .09 35 4 0 .09 3.85 Corrosion. 117 0 .11 42 13 0 .05 3.87 Corrosion. 118 0 .09 33 6 0 .05 3.90 Line corrosion. ~ m., 119 0 .07 27 3 0 .04 3.89 Corrosion. []w• , 120 0 .09 32 6 0 .05 3.83 Corrosion. 121 0 .09 33 6 0 .06 3.88 Corrosion. T-- 122 0 .10 36 7 0 .06 3.85 Corrosion. 123 0 .10 37 6 0 .05 3.88 Corrosion. 124 0 .12 44 12 0 .06 3.91 Corrosion. 124.1 0 .09 33 3 0 .07 3.87 PUP Corrosion. 124.2 0 0 0 0 0 0 3.89 GLM 9 (Ltch. ~.. 9:00) 124.3 0 .08 28 4 0 .05 3.89 PUP Corrosion. []" · 125 0 .06 24 4 0 .05 3.87 Line corrosion. []- 126 0 .08 31 5 0 .06 3.86 Corrosion. li"-[] 127 0 .08 28 4 0 .05 3.89 Corrosion. i,[]· 128 0 .10 35 11 0 .05 3.86 Corrosion. la[]·1 129 0 .10 38 6 0 .05 3.88 Corrosion. B[] · · 130 0 .12 46 16 0 .06 3.88 Corrosion. laB·[]' 131 0 .11 41 8 0 .06 3.86 Corrosion. la[]· · 132 0 .11 42 17 0 .07 3.88 Corrosion. ! B[] · 133 0 .10 37 9 0 .06 3.88 Corrosion. · [][] 134 0 .08 29 4 0 .05 3.90 Line corrosion. II[][] 135 0 .09 34 5 0 .05 3.88 Corrosion. II[][] 136 0 .07 27 3 0 .09 3.86 Corrosion. i,[]· 137 0 .07 27 2 0 .04 3.88 Corrosion. [][]· 138 0 .10 38 3 0 .06 3.88 Corrosion. I" [][]1. 139 0 .08 29 3 0 .05 3.88 Corrosion.I. [][] 140 0 .11 41 3 0 .04 3.89 Corrosion. [][][][] 141 0 .08 28 3 0 .06 3.88 Corrosion. []~· 142 0 .09 32 3 0 .04 3.90 Corrosion. []·[] 143 0 .10 38 4 0 .06 3.87 Corrosion. lam ~- 144 0 .11 40 6 0 .06 3.84 Corrosion. Ii!'" []~ Pipe Tabulations page 3 SONDEX CA: ' ER JOINT TABULATION ," EET Pipe: 4.5 ins 12.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 penetration boc metal loss bod, Joint Penetration Metal Pro'ection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche~ inches 0 50 10 145 0 .09 32 4 0 .05 3.87 Corrosion. ,-- - 146 0 .11 42 8 0 .06 3.87 Corrosion. 147 0 .11 39 5 0 .06 3.87 Corrosion. 148 0 .08 30 3 0 .03 3.90 Line corrosion. 149 0 .10 37 6 0 .18 3.77 Corrosion. 150 0 .11 39 3 0 .11 3.82 Corrosion. 150.1 0 .08 30 4 0 .05 3.86 PUP Corrosion. 150.2 0 0 ¢ 0 0 0 3.86 GLM 8 (Ltch. @ 7:00) 150.3 0 .10 35 3 0 .07 3.86 PUP Corrosion. 151 0 .10 38 6 0 .05 3.86 Corrosion. 152 0 .08 30 3 0 .04 3.89 Line corrosion. 153 0 .10 36 4 0 .06 3.89 Corrosion. 154 0 .13 47 3 0 .04 3.89 Line corrosion. 155 0 .12 43 3 0 .04 3.88 Line corrosion. 156 0 .07 25 2 0 .03 3.90 Line corrosion. --- 157 0 .08 29 3 0 .05 3.88 Corrosion. ,"[][] 158 0 .09 32 4 0 .05 3.88 Line corrosion. 159 0 .07 26 2 0 .05 3.89 Isolated pitting. ~-' 160 0 .10 37 5 0 .05 3.89 Corrosion. 161 0 .10 37 3 0 .06 3.89 Line corrosion. 162 0 .06 23 2 0 .04 3.88 Isolated pitting. 163 0 .11 39 5 0 .20 3.77 Line corrosion. 164 0 .08 28 2 0 .03 3.90 Isolated pitting. - -- 164.1 0 .05 20 3 0 .03 3.87 PUP General shallow corrosion. -- 164.2 0 0 0 0 0 0 3.84 GLM 7 (Ltch. @ 8:00) 164.3 0 .05 20 2 0 .05 3.84 PUP General shallow corrosion. 165 0 .10 36 4 0 .05 3.87 Corrosion. 166 0 .11 41 4 0 .04 3.90 Line corrosion. 167 0 .11 39 6 0 .07 3.86 Corrosion. i![][]. 168 0 .08 28: 3 0 .06 3.88 Corrosion. 169 0 .11 41 3 0 .05 3.92 Line corrosion. ·[]·[] 170 0 .11 41 3 0 .04 3.89 Line corrosion. [][][][] 171 0 .10 38 6 0 .05 3.86 Corrosion. ",[][]· 172 0 .07 27 2 0 .06 3.89 Isolated pitting. ~'[]. 173 0 .11 39 11 0 .06 3.87 Line corrosion. [][][] 174 0 .09 34 2 0 .05 3.89 Corrosion. [][][] 175 0 .10 36 4 0 .05 3.89 Corrosion. [][][] 176 0 .10 38 5 0 .05 3.91 Corrosion. i"[][]· 177 0 .09 33 3 0 .05 3.87 Corrosion. "[][] 178 0 .07 25 2 0 .07 3.86 Corrosion. ·[] 178.1 0 .04 13 2 0 .07 3.87 PUP Line shallow corrosion. 178.2 0 0 0 0 0 0 3.86 GLM 6 (Ltch. ~ 10:00) 178.3 0 .04 14 I 0 .07 3.86 PUP Isolated shallow pittin.q. 179 0 .12 45 3 0 .04 3.87 Isolated pitting.[] [][][]! 180 0 .09 34 3 0 .05 3.87 Corrosion. i.[]-I 181 0 .09 35 2 0 .06 3.87 Line corrosion, i"[][]1 182 0 .08 31 3 0 .04 3.89 Corrosion. []·[] 183 0 .09 33 3 0 .05 3.90 Isolated pitting. ·~ [] 184 0 .08 30 3 0 .04 3.89 Line corrosion. "'[][] 185 0 .09 32 3 0 .04 3.88 Corrosion. ·[] [] 186 0 .08 313 3 0 .05 3.88 Corrosion. [][][] Pipe Tabulations page 4 SONDEX CAi JOINT TABULATION EET Pipe: 4.5 ins 12.6 ppf L-80 .EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 penetration boc metal loss bod, Joint Penetration Metal Pro'ection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche~ inches 0 50 10 187 0 .10 37 4 0 .10 3.83 Corrosion. 188 0 .08 31 3 0 .07 3.88 Line corrosion. 189 0 .08 28 3 0 .07 3.86 Line corrosion. ~'' 190 0 .10 38 3 0 .05 3.89 Line corrosion. 191 0 .11 39 4 0 .05 3.84 Line corrosion. 192 0 .11 40 3 0 .04 3.85 Line corrosion. 193 0 .11 42 6 0 .06 3.88 Corrosion. 194 0 .10 35 4 0 .08 3.84 Corrosion. 195 0 .09 34 3 0 .05 3.87 Corrosion. 196 0 .08 30 6 0 .08 3.86 Corrosion. ..,:. m m 197 0 .10 39 5 0 .07 3.87 Corrosion. 198 0 .14 52 5 0 .06 3.90 General deep corrosion. 198.1 0 .03 13 3 0 .07 3.84 PUP Shallow corrosion. 198.2 0 0 0 0 0 0 3.82 GLM 5 (Ltch. (~ 8:00) 198.3 0 .03 10 2 0 .11 3.82 PUP Shallow corrosion. - 199 0 .08 30 6 0 .08 3.88 Line deep corrosion. 200 0 .08 29 3 0 .04 3.89 Corrosion. 200.1 0 .07 27 2 0 .07 3.88 PUP Isolated pitting. 200.2 0 0 0 0 0 0 3.87 GLM 4 (Ltch. @ 11:00) 200.3 0 .09 33 3 0 .08 3.87 PUP Corrosion. '' ' 201 0 .13 48 5 0 .08 3.88 Line corrosion. 202 0 .09 33 3 0 .08 3.87 Corrosion. 202.1 0 .03 13 I 0 .08 3.85 PUP Shallow corrosion. 202.2 0 0 0 0 0 0 3.85 GLM 3 (Ltch. ~ 9:00) 202.3 0 .04 13 2 0 .07 3.85 PUP Shallow corrosion. []l 203 0 .11 40 6 0 .05 3.89 Line corrosion. 204 0 .09 35 3 0 .06 3.87 Line corrosion. 204.1 0 .09 32 3 0 .07 3.88 PUP Corrosion. 204.2 0 0 0 0 0 0 3.86 GLM 2 (Ltch. ~ 12:00) 204.3 0 .03 10 2 0 .06 3.86 PUP Isolated shallow pitting. [] 205 0 .10 37' 3 0 .06 3.88 Corrosion. 206 0 .13 48! 7 0 .07 3.88 Corrosion. 206.1 0 .03 13 1 0 .09 3.87 PUP Shallow corrosion. 206.2 0 0 (: 0 0 0 3.86 GLM I (Ltch. ~ 10:00) 206.3 0 .03 10 2 0 .07 3.86 PUP Isolated shallow pitting. [] 207 0 .09 32 6 0 .06 3.85 Corrosion. -m m 208 0 .10 38 5 0 .06 3.91 Corrosion. 208.1 0 .07 27 3 0 .07 3.86 PUP Corrosion. -- - 208.2 0 0 ¢ 0 0 0 3.85 PACKER 209 0 .08 28 3 0 .08 3.85 PUP Corrosion. I 210 0 .10 37 .3 0 .08 3.86 Line corrosion. Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 12 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 12 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 20 thou inches deviation in body, 60 thou in upset. Modal line length = 0.200 feet. Pipe Tabulations page 5 Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubin~l: 4.5 ins 12.6 ppf L-80 EUE Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99694 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 198 Tool speed = 50 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 17 ° at depth 8316.74 ft Finger40 Radius: 2.113 ins DEEPEST PENETRATION RECORDED 0.14 In. - 52% Cross-Sections page 1 Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubing: 4.5 ins 12.6 ppf L-80 EUE Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99694 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 40 Tool speed - 50 Nominal ID -- 3.958 Nominal OD -- 4.500 Remaining wall area - 88 % Tool deviation - 4 o at depth 1641.81 ft Finger 1 Radius = 2.07 ins AREA OF MOST CROSS-SECTIONAL WALL LOSS Cross-Sections page 2 Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubing: 4.5 ins 12.6 ppf L-80 EUE Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99694 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 206 Tool speed = 49 Nominal ID - 3.958 Nominal OD - 4.500 Remaining wall area = 98 % Tool deviation - 13 ° at depth 8745.04 ft Finger 40 Radius = 2.14 ins 2nd Deepest Penetration Recorded 0.13 In. -48% Cross-Sections page 3 Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubing: . 4.5 ins 12.6ppf L-80 EUE Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99694 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 154 Tool speed = 50 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 97 % Tool deviation = 18 ° at depth 6422.8 ft 1 Finger 30 Radius = 2.058 ins 3rd Deepest Penetration Recorded 0.13 In. -- 47% Cross-Sections page 4 SONDEX -"\LIPER JOINT TALLY SHE 7 Pipe: 4.5 ins 12.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches I 38.80 42.48 4.000 2 81.28 42.37 3.998 3 123.65 43.52 3.999 4 167.17 41.19 3.989 5 208.36 40.78 3.987 6 249.14 41.50 3.995 7 290.64 39.94 3.954 8 330.58 40.94 3.999 9 371.52 38.45 3.972 10 409.97 39.24 3.979 11 449.21 32.73 3.993 12 481.94 41.88 4.004 13 523.82 40.85 3.988 14 564.67 40.12 3.985 15 604.79 36.61 3.950 16 641.40 39.43 3.999 17 680.83 37.65 nominal 18 718.48 40.56 3.989 19 759.04 40.98 3.995 20 800.02 34.77 3.990 21 834.79 38.82 3.993 22 873.61 40.35 3.973 23 913.96 42.75 3.990 24 956.71 38.64 3.961 25 995.35 38.75 3.959 26 1034.10 41.59 3.955 27 1075.69 36.95 3.984 28 1112.64 40.35 3.956 29 1152.99 41.69 3.963 30 1194.68 43.47 3.984 31 1238.15 39.37 3.962 32 1277.52 42.50 3.955 33 1320.02 40.68 nominal 34 1360.70 41.02 3.952 35 1401.72 41.77 3.981 36 1443.49 40.87 3.960 37 1484.36 41.85 3.965 38 1526.21 35.05 3.961 39 1561.26 41.10 3.981 40 1602.36 40.24 3.987 41 1642.60 41.48 3.974 42 1684.08 42.94 nominal 43 1727.02 41.95 3.990 44 1768.97 40.02 3.996 45 1808.99 42.18 3.978 46 1851.17 42.14 nominal 47 1893.31 43.53 3.960 48 1936.84 41.74 3.985 49 1978.58 43.12 3.959 50 202t .70 42.72 3.954 51 2064.42 42.50 nominal Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 52 2106.92 40.95 3.954 53 2147.87 42.26 3.977 53.1 2190.13 10.07 nominal Pup 53.2 2200.20 16.50 nominal Sssv 53.3 2216.70 10.05 3.924 Pup 54 2226.75 43.75 3.959 55 2270.50 43.15 3.968 56 2313.65 41.50 3.951 57 2355.15 39.77 3.948 58 2394.92 42.53 3.990 59 2437.45 35.64 3.950 60 2473.09 43.36 3.988 61 2516.45 41.84 3.952 62 2558.29 41.05 nominal 63 2599.34 41.19 3.951 64 2640.53 37.80 3.988 65 2678.33 42.10 3.952 66 2720.43 42.24 3.946 67 2762.67 42.98 3.956 68 2805.65 40.14 3.952 69 2845.79 41.19 3.960 70 2886.98 41.12 3.948 71 2928.10 39.15 3.956 72 2967.25 39.24 3.970 73 3006.49 43.72 3.966 74 3050.21 42.79 3.963 75 3093.00 39.98 3.961 76 3132.98 41.42 3.987 77 3174.40 38.03 3.985 77.1 3212.43 8.87 3.942 Pup 77.2 3221.30 9.51 nominal Glml0 77.3 3230.81 9.90 3.965 Pup 78 3240.71 42.16 3.980 79 3282.87 41.48 3.955 80 3324.35 41.79 3.991 81 3366.14 39.28 3.983 82 3405.42 42.01 3.948 83 3447.43 42.71 3.985 84 3490.14 40.94 4.000 85 3531.08 39.95 3.970 86 3571.03 37.60 3.967 87 3608.63 40.92 3.966 88 3649.55 43.36 3.971 89 3692.91 41.21 3.944 90 3734.12 40.68 3.964 91 3774.80 40.15 3.956 92 3814.95 39.88 3.978 93 3854.83 37.51 3.997 94 3892.34 41.04 3.959 95 3933.38 39.63 3.982 96 3973.01 41.93 3.973 Joint Tally page 1 SONDEX' -'ALIPER JOINT TALLY SHE T Pipe: 4.5 ins 12.6ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches 97 4014.94 41.21 3.954 98 4056.15 39.77 3.951 99 4095.92 41.45 3.994 100 4137.37 36.73 3.953 101 4174.10 42.53 3.954 102 4216.63 41.42 3.953 103 4258.05 41.37 3.970 104 4299.42 42.03 3.971 105 4341.45 41.08 3.962 106 4382.53 41.56 3.959 107 4424.09 41.18 3.949 108 4465.27 40.94 3.974 109 4506.21 40.94 3.942 110 4547.15 40.89 3.962 111 4588.04 41.89 3.944 112 4629.93 43.32 3.959 113 4673.25 41.05 3.949 114 4714.30 40.41 3.951 115 4754.71 43.49 3.961 116 4798.20 35.36 3.950 117 4833.56 42.45 3.972 118 4876.01 40.81 3.968 119 4916.82 43.97 3.962 120 4960.79 40.17 3.948 121 5000.96 41.83 3.956 122 5042.79 39.75 3.975 123 5082.54 41.18 3.967 124 5123.72 43.38 3.983 124.1 5167.10 8.51 3.945 Pup 124.2 5175.61 9.74 nominal GIm9 124.3 5185.35 10.10 3.944 Pup 125 5195.45 40.17 3.955 126 5235.62 40.42 3.967 127 5276.04 43.18 3.980 128 5319.22 40.72 3.962 129 5359.94 43.17 3.960 130 5403.11 42.86 3.970 131 5445.97 37.98 3.962 132 5483.95 41.77 3.955 133 5525.72 41.84 3.950 134 5567.56 41.01 3.964 135 5608.57 42.58 3.964 136 5651.15 41.75 3.942 137 5692.90 41.34 3.948 138 5734.24 42.36 3.963 139 5776.60 39.37 3.952 140 5815.97 35.75 nominal 141 5851.72 41.28 3.950 142 5893.00 42.60 3.963 143 5935.60 42.43 3.960 144 5978.03 41.50 3.959 Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 145 6019.53 42.62 3.955 146 6062.15 41.46 3.956 147 6103.61 43.43 nominal 148 6147.04 41.73 3.960 149 6188.77 41.76 3.953 150 6230.53 42.27 3.959 150.1 6272.80 9.83 3.955 Pup 150.2 6282.63 8.44 nominal GIm8 150.3 6291.07 9.85 3.943 Pup 151 6300.92 41.40 3.961 152 6342.32 34.26 3.959 153 6376.58 42.13 3.963 1 54 6418.71 42.46 nominal 155 6461.17 42.33 3.962 156 6503.50 42.88 3.961 157 6546.38 42.07 nominal 158 6588.45 39.65 3.961 159 6628.10 41.46 3.954 160 6669.56 40.62 3.968 161 6710.18 42.37 3.955 162 6752.55 42.04 3.956 163 6794.59 38.50 3.961 164 6833.09 37.91 3.965 164.1 6871.00 8.95 3.940 Pup 164.2 6879.95 9.52 nominal GIm7 164.3 6889.47 9.70 3.937 Pup 165 6899.17 38.77 3.947 166 6937.94 41.05 3.968 167 6978.99 40.79 3.953 168 7019.78 41.75 3.950 169 7061.53 44.08 3.971 170 7105.61 41.85 3.959 171 7147.46 42.17 3.962 172 7189.63 41.42 nominal 173 7231.05 40.80 3.949 174 7271.85 41.85 3.961 175 7313.70 43.01 3.953 176 7356.71 42.76 3.973 177 7399.47 41.35 3.953 178 7440.82 42.00 3.950 178.1 7482.82 8.93 3.950 Pup 178.2 7491.75 9.11 nominal GIm6 178.3 7500.86 9.62 3.939 Pup 179 7510.48 41.57 nominal 180 7552.05 42.38 3.963 181 7594.43 36.55 3.948 182 7630.98 40.72 3.960 183 7671.70 40.80 3.968 184 7712.50 39.88 nominal 185 7752.38 36.76 3.954 186 7789.14 42.71 3.963 Joint Tally page 2 SONDEX \LIPER JOINT TALLY SHE T Pipe: 4.5 ins 12.6 ppf L-80 EUE Wall thickness. Body: 0.271ins Upset = 0.000ins Nominal ID: 3.958 ins Well: DS 01-30 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 187 7831.85 42.21 3.959 188 7874.06 41.38 3.953 189 7915.44 38.52 3.956 190 7953.96 41.85 3.962 191 7995.81 42.26 3.944 192 8038.07 41.14 nominal 193 8079.21 41.76 3.976 94 8120.97 39.79 3.955 195 8160.76 41.01 3.941 196 8201.77 39.00 nominal 197 8240.77 39.95 nominal 198 8280.72 36.97 3.976 198.1 8317.69 6.88 3.945 Pup 198.2 8324.57 11.43 nominal GIm5 198.3 8336.00 10.32 3.949 Pup 199 8346.32 42.53 nominal 200 8388.85 39.08 3.969 200.1 8427.93 11.08 3.940 Pup 200.2 8439.01 7.48 nominal GIm4 200.3 8446.49 11.26 3.946 Pup 201 8457.75 41.26 nominal 202 8499.01 40.75 3.949 202.1 8539.76 9.45 3.939 Pup 202.2 8549.21 8.92 nominal GIm3 202.3 8558.13 9.21 3.939 Pup 203 8567.34 44.20 3.971 204 8611.54 42.72 3.959 204.1 8654.26 9.51 3.944 Pup 204.2 8663.77 9.54 nominal GIm2 204.3 8673.31 9.60 3.942 Pup 205 8682.91 41.31 3.955 206 8724.22 42.17 3.959 206.1 8766.39 7.97 3.951 Pup 206.2 8774.36 9.70 nominal GIm 1 206.3 8784.06 9.44 3.950 Pup 207 8793.50 42.62 3.965 208 8836.12 42.77 3.973 208.1 8878.89 9.58 3.940 Pup 208.2 8888.47 26.58 nominal PAcker 209 8915.05 39.85 3.948 163 8954.90 unknown 3.961 Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 3 - STATE OF ALASKA ALASK, OIL AND GAS CONSERVATION ( 'VlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N, R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9750 feet 9251 feet Plugs(measured) Effective depth: measured 9554 feet true vertical 9068 feet Junk(measured) Casing Length Size Conductor 110' 20" Su dace 2449' 13-3/8" Production 9672' 9-5/8" Perforation depth: Cemented 150 sx CS II 2000 sx CS III, 550 sx CS II 950 sx G, 450 sx CS II, 300 sx CS I measured 9480-9518'; 9538-9554' true vertical 8999-9035'; 9053-9068' Measured depth True verticaldepth 110' 110' 2519' 2519' 9742' 9244' Gas Cons, commis$~or~ Anchor[" Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 30' MD; 4-1/2", 12.6#, L-80, PCT @ 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD; Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 1264 4849 3916 Tubing Pressure 249 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 GSS cc: KZ, JWP. Date SUBMIT IN DUPLICATE~ I -30 DESCRIPTION OF WORK COMPLETED ROPE, HYDRAULIC FRACTURE TREATMENT, & GEL BREAKER STIMULATION I I/1 7/94: MIRU CTU & PT equipment. RIH w/CT to tag PBTD at 9549' MD, then pumped 9 bbls of gelled sand slurry containing 1300 lbs of 20/40 mesh sand, to spot a sand plug across the perforations at: 9538 - 9554' MD (Z2) Made a final top of sand plug tag at 9529' MD. I I/2 0/9 4: Ref. Log: BHCS POOH w/CT. RD. 6/23/86. RIH w/CT to tag sand plug & pumped 33 bbls of Crosslinked Gel on top of sand plug. POOH w/CT. RIH w/shear disk & set in XN Nipple at 8995' MD. N2 lifted well dry above shear disk. RD. 1 1/21/94: MIRU CTU & PT equipment. Pressured backside to 3000 psi & pumped 203 Mscf N2 down tubing to pressure up on shear disk for Wedge ROPE Treatment of the perforations above the sand plug at: 9480 - 9518' MD (Z2) Ref. Log: BHCS 6/23/86. Ruptured the shear disk at 7660 psi. Bled down well. RD. 1 1/22/94: RIH & retrieved ruptured shear disk, then tagged top of sand plug at 9543' MD. I 2/1 0/94: MIRU CTU & PT equipment. RIH w/CT to tag sand at 9545' MD, then pumped 5 bbls of gelled sand slurry containing 1100 lbs of 20/40 mesh sand, to raise the sand plug over the lower perforation interval (listed above). Tagged final sand top at 9524' MD. POOH w/CT. RD. 1 2/1 3/94: MIRU & PT equipment to 8500 psi. Pumped a Hydraulic Fracture Treatment, using 20/40 mesh proppant, through the perforation interval above the sand plug (listed above). Pumped Data Frac consisting of 300 bbls 30# Pre Pad Gel @ 10 - 25 bpm, followed by Shutdown. ISlP @ 1700. Resumed pumping 27 bbls 30# Crosslinked Gel @ 10 bpm, followed by 168 bbls Flush @ 20 bpm, followed by Shutdown. ISlP @ 2080. Resumed pumping Fracture Treatment consisting of 8 bbls 30# Crosslinked Pad @ 15 bpm, followed by 65 bbls Crosslinked Slurry w/proppant stages @ 1 - 12 ppg, followed by 147 bbls 30# Gelled Flush, followed by Shutdown. Placed a total of 7,500 lbs of proppant into the formation. Rigged down. I 2/1 4/94: RIH w/CT & jetted proppant/sand plug down to 9590' MD to uncover lower perforations (above). 2/9/95: Performed a Unbroken Frac Gel Breaker Stimulation as follows: MIRU CTU & PT equipment. RIH w/CT swirl nozzle & reciprocated 95 bbls Hot 1% KCl Water w/Breaker solution across the perforations (above), then Shut In the well & squeezed 85 bbls of fluid into the formation to 550 psi maximum squeeze pressure. POOH w/CT leaving 10 bbls of breaker fluids in casing. Rigged down. RECEIVED Placed the well on production w/gaslift & obtained a valid production test. FEB 2 8 1995 Alaska 0il & Gas Cons. Commission Anchorr. ,- GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk -~. 1-2 ~:) C~ .._ I I.~ CNTD (4-19-94) ~. 1-9A ~ L( DUAL BURST TDT-P (8-7-94) DC. 1-12 ~ 7- ~ ~ DUAL BURST TDT-P (2-7-93) d.~ 1-16 7~-O¢~ CNTH (2-27-93) ~. 1-17 ~ ~ - O O DUAL BUTST TDT-P (4-7-94) ~. 1-19 ~%--I~ CNTH (2-27-93) ~S. 1-23 ~- ~O DUAL BURST TDT-P (11-15-93) ~s. 1-28~- o? 3~ CNTH (3-1-93) ~. 1-30 ~6 -(11 CNTD (8-6-94) ~S. 1-31 ~-I~ ~ CNTH (3-1-93) ~. 1-32 ~ ~-/~7 DUAL BURST TDT-P (3-6-93) 6~-33 ~ ~- I'~ DUAL BURST TDT-P (3-28-94) 5.~-34 ~- I/~ CNTH (2-2~-e3) 3¢. 2-2 7~ ~d3% ~UAL aURST TDT-P (2-2~-93) D.S~-5 ~ O -O ~O CNTD (5-7-94) ~S. 2-12 7 ?-~ 71 CNTH (2-23-93) SIGNED: DATE: ~i;':~.~,'a Oil& Gas Cons. Cornr/l[s~iotl A~chorago Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Page I . STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CO. /IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2524' FSL, 53' FEL, sec. 7, T10N, R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T1 ON, R15E, UM Plugging Perforate X , Repair well Other 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9750 feet 9251 feet Plugs(measured) Fill @ 9553' MD (7/29/94) Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2449' Production 9672' 9553 feet 9068 feet Size 20" 13-3/8" 9-5/8" Junk(measured) Cemented 150 sx CS II 2000 sx CS III, 550 sx CS II 950 sx Class G, 450 sx CS II, 300 sx CS I Measured depth 110' 2519' 9742' True vertical depth 110' 2519' 9244' RECEIVED Perforation depth: measured 9480-9518'; 9538-9554' true vertical 8999-9035'; 9053-9068' Ai_i{; 5 0 /.',l~.~ska 0il & Gas COilS. Ccrnrnission Anchor Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 30' MD; 4-1/2", 12.6#, L-80, PCT @ 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD; Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 164 575 1311 161 149 1394 Tubing Pressure 206 192 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: (::)il x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ' 1209/14 cc: KZ, JWP Title Engineering Supervisor Date ~UBM~ IN DI~PLICATE~¥ I -30 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/28/94: RIH & tagged PBTD at 9546' MD. 7/29/94: MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 9553' MD, then PU & shot 20' of reperforations as follows: Reperforated: 9480 - 9500' MD (Z2) Ref. Log: BHCS 6/23/86. Used a 3-3/8" carrier, & shot 4 spf, at 60/120 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas rift & obtained a valid welltest. RECEIVED _ STATE OF ALASKA ALASKA AND GAS CONSERVATION CC ¢IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing AItercasing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, sec. 8, T10N, R15E, UM At top of productive interval 2524' FSL, 53' FEL, sec. 7, T10N, R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED JUL 2 5 1994 Alaska Oil & 6a$ Cons. Commission Anchorage x 6. Datum of elevation(DF or KB) 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9750 feet true vertical 9251 feet Effective depth: measured 9530 feet true vertical 9046 feet Casing Length Size Conductor 110' 20" Su dace 2449' 13-3/8" Production 9672' 9-5/8" Plugs(measured) Fill @ 9530' MD (4/2/94) Junk(measured) Cemented 150 sx CS II 2000 sx CS III, 400 sx CS II 950 sx Class G, 450 sx CS II, 300 sx CS I Measured depth 110' 2519' 9742' True vertical depth 110' 2519' 9244' Perforation depth: measured 9498-9518'; 9538-9554' true vertical 9016-9035'; 9053-9068' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 30' MD; 4-1/2", 12.6#, L-80, PCT @ 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD; Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 103 115 776 167 ~ 33 1402 Tubing Pressure 213 203 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas .._ Suspended . Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 1148/10 DTK cc: JED, JWP Title Engineering Supervisor Date-~//~¢/~ SUBMIT IN DUPLICATE ~~, I -30 DESCRIPTION OF WORK COMPLETED ROPE TREATMENT & FULLBORE ACID STIMULATION 3/26/94: MIRU CTU & PT equipment. RIH w/CT & pumped gelled sand slurry containing 1300 lbs of 20/40 mesh sand, to place an isolation sand plug over the lower pedoration interval located at: 9538' - 9554' MD (Z2) Ref. Log: BHCS 6/23/86. POOH w/CT leaving estimated top of sand plug at 9526' MD. Rigged down. 3/28/94: RIH & tagged top of sand plug at 9534' MD, then ran & set a 4-1/2" Shear Disk in the XN nipple at 8995' MD, in preparation for a ROPE treatment. Rigged down. 3/29/94: MIRU & PT equipment to 8300 psi. Pumped 5 bbls Diesel, followed by 50 bbls of Meth Water w/0.5# Biozan, & pressured up on the Shear Disk to perform a ROPE Treatment of the upper perforation interval above the sand plug. Shear disk ruptured at 4889 psi. Rigged down. 4/2/94: RIH & retrieved the ruptured Shear Disk, then RIH & tagged top of sand plug at 9530' MD. 4/4/94: A Fullbore Acid Stimulation Treatment was performed as follows: MIRU & PT equipment. Pumped the stimulation fluids through the perforations above the sand plug, to remove cement filtrate damage & initiate interval production at: 9498' - 9518' MD (Z2) Ref. Log: BHCS 6/23/86. Pumped: a) 50 bbls 1% NH4CI Water, followed by b) 22 bbls Xylene @ 5.4 bpm, followed by c) 72 bbls 12% HCI @ 4.7 bpm, followed by d) 31 bbls 9% HCI - 1% HF @ 1.1 - 1.6 bpm, followed by e) 377 bbls 1% NH4CI Water Overflush @ 7 bpm, followed by f) Shutdown. RECEIVED Rigged down. Placed well on production w/gas lift & obtained a valid production welltest. JUL 2 5 1994. Atsska Oil & Gas Cons, Commission Anchoraue ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution P.O. Box 100360, ,....chorage, AK Transmittal #: 94049 99510,~ ~, Well i Number -_qO i 1-05ST ~ i 1-06 '5'q- ! 1-tl Z~5 i 1-25 10'% { 1-29 ~ \ ! 1-30 2_.L~ i 3-02 .q.~. i 3-19 .~ i 4-36 ?o Log Date (M-D-Y) 6-13-94 6-13-94 6-14-94 6-t0-94 Tool Type Dual Burst I 1, 5" Dual Burst i 1, 5" i" Perf Record i 1 5" Sch : Sch ~ Sch ~ Sch : Sch Sch Sch Sch Sch Sch / Perf Record 6-14-94 i~'' Dual Burst 6-08-94 i/ CNL 6-07-94 ix Tubing Cutter 6-05-94 j-/' Perf Record 6-11-94 i~- Perf Record 6-12-94 i'-"Cutter Record 4-41 i 5-11 i Sch Sch 6-11-94 i" Dual Burst 6-13-94 ! / Inj Prof 6-14-94 i / InjProf 6-i4-94 i/ inj Prof 6-11-94 i / Perf Record 6-07-94 i ~' Perf Record 6-09-94 i /'' Perf Record 6-09-94 i/ Perf Record 6-15-94 i .~ Prod Log 6-15-94 i/ Dual Burst 6-13-94 i~'Leak Detection , 6-10-94 ! f Alpha Tubing 6-6-94 if Prod Prof 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" I 5" 1 5" 1 5" I 5" i 5" I 5" I 5" I 5" 1 5" 1 5" 1 5" I 5" 1 5" 9-15 9-18 9-25 1, 1" &5" 6-12-94 i/' Perf Record i 1, 5" 6-12-94 i /' Dual Burst i 1, 5" 6-10-94 i,,-l_eak Detection i 1, 1" & 5" 11-35 11-36 13-31 13-35 14-03 14-03 Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch . Sch 16-23 16-23 17-02 _ 18-02 18-04 18-19 * The correct APl Cf for 1-05ST is 50-029-20076-00 Number of Records: E. DeGrey Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska- ARCO Alaska, inc. Is a Subsldlary of At~a~t~cRIchflelclCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-2-93 REFERENCE: ARCO CASED HOLE FINALS ~_-]b 1-3 10-31-93 '7~.~.~.Z~ 1-4 11-5-93 7~___~~1-16 11-5-93 ~1-22 11-7-93 ~-~?~ I~ 1-24A 10-14-93 ~ 11-6-93 ~_~z-3o ~ 10-31-93 '~-~- 19 10-17-93 -20A 11-9-93 ~~- 11 11-4-93 11-8-93 -21 10-18-93 ~t~tL~ ~-2aa 11-2-9a ' ~--~ff~7o20 11-4-03 _~~9-6 11-1-93 9-7 10-20-03 9-7 10-25-93 --50 11 - 1-93 c~ 1-12 1-9-93 11-9-93 ~I-16ST 11-8-93 ~~j~2-16A 10-26-93 2-16A 11-8-93 ~12-16A 11-8-93 -/~6~ i 14-2 11-7-93 ~~4-4 11-6-93 ~~14-23 11-10-93 18-29A 10-19-93 and return the attached copy. as ,EC IW Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA Peri Record i0~l~ ?~ -]iOoF, Run 1, ~' Sch Peri Record ~ -~'~{ Run 1, 5" Sch ~od ~offie ~o~~e~R~ 1, ~' .o-i0~ Sch ~od ~offie /~}~)e~~R~ 1, ~' ~0~t~O Sch D~ B~t T~P 11~0--il60; R~ 1, ~' Sch Pe~ Record ~9~0 ~lO~Z~ R~ 1, ~' Sch Pe~ Record 5~0-~ - R~ 1, ~' Sch Completion Record ~0~z~ R~ 1, ~' Sch USIT (C~im~m~ Color R~ 1, ~' 5~0~f~0 Sch Peal Record ~S~ ~;~5 R~ 1, ~' Sch TBG Patch Record R~ 1, ~' 'Vv~O-?;~-~ Sch ~od ~offie~a~a~/~a~/~ R~ 1, 1'&5" 0-l~ Sch Collar (Packer ~t) . R~ 1, ~' ~{oq~ Atlas D~ B~st TDTP i;~O~i~aO R~ 1, ~' Sch Peal Record ~O~q~O R~ 1, ~' Sch Pe~ Record {~~{~ R~ 1, ~' Sch ~od ~offie I~t~a i~m~l~i6r~R~ 1, 1"~" ~l~-~ Sch IBP Set ~00~ R~ 1, ~' Sch Pe~ Record ~[ o~Z0 ~~,O R~ 1, ~' Sch CNL I~ 00- I~S t R~ 1, ~' Sch Pe~ Record I [~ a0 ~ I~S0 R~ 2, ~' Sch ~ Detect I~0~[~0 R~ 1, 1"~" Sch USIT (~.aT~~]Color R~ 1, ~' ~0 ~{~ Sch Pe~ Record ~9~ R~ 1, ~' Sch L~er/Jewe~/G~ R~ 1, ~' ~0-~60~ Sch ~ Detect (~]~a~ , _~ 1, ~'~" 0- ~o Sch ~od ~offie l~n ~}~~~ 1, 1"~" o-t~0;~ Sch TBG ~cher Z9~-a95o R~ 1, ~' Sch Pe~ Record ~00~01~ R~ 1, ~' Sch D ~ B ~st ~~5 } ~ R= 1, ~' S c h receipt of data. f...,: ) APPROVED Trans~ 9314~ ~ MOBIL t ill fill iiIii The correct API# for 3-20A is 50-029-20980-01. This log was ran on 4-11 not the sidetrack and the correct API# is 50~)29-20286-00. The correct API# for 9-7 is 50-029-20223-00. This log was ran on 12-16A and the correct API# is 50-029-20899-01. he correct API# for 18-29A is 50-029-22316-01. STATE OF ALASKA ALASKA~ AND GAS CONSERVATION CO fISSION REPORT OF SUNDRY WELL OPEHATIONS Perforate Xother ~ ) ,~i~,Jl 6. Datum of elevation(DF or KB)~ 70 RKB 1. Operations performed: operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well 2. Name of Operator 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, Sec. 8, T1 ON, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N, R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9750 feet 9251 feet Plugs(measured) Fill @ 9547' MD (10/31/93) Effective depth: measured 9547 feet true vertical 9062 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 150 sx CS II 110' 110' Sudace 2519' 13-3/8" 2000 sx CS III, 400 sx CS II 2519' 2519' Production 9742' 9-5/8" 950 sx Class G, 450 sx CS II, 9742' 9244' 300 sx CS I RECEIVED Perforation depth: measured 9498-9518'; 9538-9554' DEC - 7 199 true vertical 9016-9035'; 9053-9068' Alaska. 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 30' MD; 4-1/2", 12.6#, L-80, PCT @ 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD; Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1766 19220 1692 130 202 794 Tubing Pressure 1087 196 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil, x Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~' ~ Form 10-404 8 1071/6 MRM/DTK cc: SW, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE ~:~ I -30 DESCRIPTION OF WORK COMPLETED ROPE TREATMENTS, CTU CEMENT SQUEEZE~ FRACTURE TREATMENT, & ACID STIMULATION 6/14/93: RIH & tagged bottom at 9661' MD. 6/16/93: RIH & set a XXN Shear Plug in the XN Nipple at 8995' MD, in preparation for ROPE treatment. Rigged down. 6/18/93: MIRU & PT equipment, then pumped 46.3 bbls 1% KCI Water w/friction reducer, to pressure up on the shear plug for a ROPE Treatment of the open perforations at: 9480 - 9530' MD (Z2) 9538 - 9554' MD (Z2) Ref. Log: BHCS 6/23/86. Shear disk ruptured at 5360 psi. Rigged down. 6/19/93: RIH & latched the ruptured shear plug. POOH w/plug. Made RIH to tag bottom at 9652' MD. Rigged down. 6/25/93: An Acid Wash & CTU Cement Squeeze for Gas Shutoff were performed as follows: MIRU CT & PT equipment to 4500 psi. Fluid packed the wellbore w/Seawater, then RIH w/CT & reciprocated a presqueeze acid wash across the perforations (listed above). Pumped 48 bbls 12% HCI w/20% Xylene @ 2.2 bpm, followed by 75 bbls of Crude displacement down CT backside, followed by 10 bbls Seawater spacer. Continued pumping 46 bbls of Latex Acid Resistive cement, to squeeze the open perforations (listed above). Placed 10 bbls of cement behind pipe at 3200 psi max squeeze pressure. Had several pressure breaks then held 2700 psi for I hour. Contaminated cement & jetted out contaminated cement from wellbore. POOH w/CT. RD. 6/26/93: RIH & tagged bottom cement at 9644' MD. 6/29/93: Performed an Injection Profile indicating that the top squeezed perforation interval was leaking. 7/5/93: Reperforated: 9538 - 9554' MD (Z2) Ref. Log: BHCS 6/23/86. 7/7/93: RIH & set a XXN Shear Plug in the XN Nipple at 8995' MD, in preparation for a ROPE treatment. Rigged down. 7/10/93: MIRU & PT equipment, then pumped 50 bbls 1% KCl Water w/friction reducer, to pressure up on the shear plug for ROPE Treatment of the open perforations (listed above). Shear disk ruptured at 5100 psi. RIH & retrieved ruptured shear disk. Rigged down. 7/1 I/93: MIRU & performed an Injection Profile that showed the top squeezed perforations (listed above) leaking. PT Frac equipment to 10000 psi, then began pumping a planned Hydraulic Fracture Treatment, through the open perforations (above). Pumped 239 bbls 20# Linear Gel @ 10 bpm/2200 Whp, then shutdown due to a sudden pressure spike up to 4600 Whp (perforations may have plugged off). Rigged down. 7/18/93: PT Frac equipment, then pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the open perforations (above). Pumped 220 bbls 20# Pre Pad Gel @ 12 - 15 bpm, followed by Shutdown. ISIP @ 2100. Resumed pumping 40 bbls 25# Crosslinked Datafrac Pad @ 10 bpm, followed by 107 bbls 20# Linear Flush @ 10 bpm, followed by 30 bbls 20# Linear Flush @ 3 bpm, followed by 35 bbls 20# Linear Flush @ 10 bpm, followed by Shutdown. Resumed pumping 15 bbls 25# Crosslinked Pad @ 10 bpm, followed by 92 bbls Crosslinked Slurry w/proppant stages @1-10 ppg, followed by167 bbis Flush, followed by Shutdown.R F C ~ IV ~ ~) I -30 DESCRIPTION OF WORK COMPLETED ROPE TREATMENTS, CTU CEMENT SQUEEZE, FRACTURE TREATMENT, & ACID STIMULATION 7/21/93: Performed a CT proppant fill cleanout down to 9470' MD. 10/9/93: Performed a CT proppant fill cleanout down to 9600' MD. 10/15/93: MURU & PT equipment to 3000 psi. Pumped a fullbore Emulsion Breaker Stimulation through the perforations (listed above), consisting of 15 bbls Diesel @ 4 bpm, followed by 60 bbls 20% Xylene/80% (1% KCI) Water @ 4.7 bpm, followed by 155 bbls Crude Flush, followed by 15 bbls Diesel, followed by Shutdown. Rigged down. 10131/93: Reperforated: 9498 - 9518' MD (Z2) Ref. Log: BHCS 6/23/86. Returned well to production w/gaslift & obtained a valid welltest. Note: Oil rate decreased by 1636 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1729 BOPD, resulting in a net oil benefit of 93 BOPD. R£CEIV D DEC - 7 1995 Oil & Gas Cons. Commission Anchera~le ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~/z-~'~l 1-24A ~-!~ 1-30 ~-30 ~2-21 ~4-40 9 ?~9-13 ~.~2_~9-26 ~-42 ~~11-12 s ~0-~ * 11-22 ~-1 q z~o~l 4-5A ~4-22t ~ 4-40 ~6-6 - 6-7 ~7-15 7-14-93 Completion Record liun I, 5 Sch 7-5-93 Perf Recordm°~z~ R~_m 1, 5" Sch 7-11-93 ~J ~offie q~ ~-N~ R~m 1, 5" Sch 7-17-93 Pe~ Record~°m~~5 R~ 1, 5" Sch 7-17-93 ~od ~offie~t~-~ R~ 1, 5" Sch 7-10-93 ~ucflon ~g~ ~z~VR~ 1, 5" Sch 7-6-93 P~/~J ~offie~U~~m 1, 5" Sch 7-6-93 ~ucflon ~g~~V~R~n 1, 1"&5" Sch 7-8-93 ~mple~on Record R~ 1, 5"~S55Sch 7-11-93 Pe~ Record ~w~q5 R~ 1, 5" Sch 7-3-93 Pe~ Record )~-I~ ~ R-n 1, 5" ~h 7-3-93 Pe~ Record%~O-~~ R~ 1, 5" Sch 7-9-93 ~ ~tect ~-~ R~n I 5" _ a~Sch ' 7-4-93 ~mpleflou Record R~ 1, 5" 7-4-93 ~ ~tect R-n 1, 2"°- ~v~% Sch 7-8-93 ~ ~ct ~~ R~n 1, 2"&5" Sch 7-2-93 ~ B~t ~P R-n 1, 5"~-%~ch 7-16-93 Pe~Record l~7~-~z~Sl R-n 1, 5" Sch 7-16-93 ~e-~ ~g- ~P ~v~%~o~m 1, 5" Sch 7-5-93 ~ ~tect ~-~o R~n 1, 2" Sch 7-6-93 Pe~Record q~~ R~m 1, 5" Sch 7-9-93 ~j ~~/~ ~c R~m 1, 5'~-~a~ZSch 7-13-93 Pe~ Record ~v~lV~ I R~ 1, 5" Sch 7-12-93 ~ ~tect v_ ~vt~ R~n 1, 2" Sch Please sign and return the attached copy RECEIVED BY Have A Nice Day~. Sonya W~ce ~PPROVED_~___ ~ CENT~ F~S ~ C~~ON ~ CLOT C~~ ~ BPX ~ E~ON ~ STATE OF ~~ ~ MOB~ * The correct top logged interval for 11-22 is 380 feet. ARCO Alaska', Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS * 1_1B~ 1~°~6.20.93 1-22 ~w~? 6-29-93 1-30 i~' ~ ~ 6-29-93 3-25A ~~ 6-27-93 -30 6- 3-93 ?~-~AGI-6 ~ ~-~? 4-25-93 AGI-8 ~ ~- ~ ~ 6-19-93 *** AGI-100q$.$~ 6-18-90 *** AGI- 1 6-18-93 3-31 ~ ~-q ~6-23-93 3-33 ¢~-i/o 6-29-93 3-36 ~3~!~ 6-28-93 4-37 ~/~7 6-20-93 4-40 ~ I~ {}~6-20-93 5-3A ~~ 6-18-93 5-26 ~q ~ 6-25-93 6-4 ?~- ~ z~6-26-93 6-13 ~ -3~ 6-25-93 9-49 ~} ~-~ 6-22-93 9-50 ~-~ 6-26-93 12-26e~ 6-22-93 13-17 ¥~~ 6-27-93 13-14 ?~-~1 6-28-93 13-20 ~ ~? 6-19-93 16-12 ~l~ 6-21-93 17-20 ~-~6-26-93 Prod Profile R~m 1, 5" Sch Perf Record Run 1, 5" Sch Production Log R-n 1, 5" Sch Leak Detect Rim 1, 5" Sch Perf Record R-n 1, 5" Sch Leak Detect Run 1, 2"&5" Sch Bridge Plug Setting Run 1, 5" Sch Completion Record Run 1, 5" Sch Perf Record Run 1, 5" Sch Dual ~urst TDTP (Borax) Run 1, 5" Sch Completion Record R-n 1, 5" Sch SBT/GR/CCL R~_m 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Perf Record Run 1, 5" Sch Production Log R~!n 1, 1"&5" ~ch -Production Log Rim 1, 2"&5" Sch CNL Run 1, 5" Sch Le~k Detect Run 1, 2" Sch Leak Detect Run 1, 2" Sch Plug Depth Record R~_m 1, 5" Sch Prod Profile Run 1, 1"&5" Sch Production Log R.n 1, 5" Sch ~.~i .Acoustic CBT R-n 1, 5" Atlas Perf ReCord R~n 1, 5" Sch GR/(X~ Run 1, 5" Sch Perf Record R.n 1, 5" Sch Please sign and return the attached .c~op~ as receipt of data. RECEIVED B _~_~_~ Have A Nice Day~/ ' / /~, / Sonya Wallace APPROVED_ ATO- 1529 Trans# 93074 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct name for this log is 1-1B. RECEIVED # ~,-m~ ',JUL 3 0 1993 # CLINT CHAPMAN ## 7_,zzO~~o]~IL Alaska 011 & Gas Cons. Com~is~ion Anchorago Tht~ is a revised log, please discard previous copy received. The correct APl# for AGI-10 is 50-029-22353-00. ARCO Alaska. Inc. P.O.Box 100360 Anchorage. Alaska 99510 RECE VED DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-13 2-7-93 .... ~11-24A 2-20-93 -30 1-24-93 ~~- 2-14 7-27-91 ~/~[- 7~7~--' 3-9 12-19-92 ~..~.~_~ 3-24 1-25-93 ~gq~ 7 /3-32 4-25-92 ~_~ 3-32 4-25-92 *'X3-32 2-19-93 ~3-34A 2-19-93 ~l~Sq .4-~ 8-z6-ga ~-31 8-18-92 ~~-4 2-22-os a-2-oo ~ 3-1-92 ~ ~0-27 ~-1-02 - 2-8-93 -- Mz-~ 4-21-o~ 1-18 4-14-92 ~ ~ ~~12-19 2-11-93 ~,~ ~12-29 12-22-92 12-a2 12-20-02 ~: ~l ~14-5A 2-20-93 ~' ~14-12 4-24-92 ~~4-12 4-24-92 4-~ 4-37 4-13-92 6-21 7-23-92 6-21 7-23-92 6-27 8-23-92 ~&~ 16-30 2-12-93 '.Alaska Oil &^.,~...__Gas Cons. COmmleslon Pert' Record "~~' H~ Pe~ Reco~ R~ 1. E' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ T~ R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PGST Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, C' H~ T~ R~ 1, ~' H~ DSN R~ 1, ~' H~ T~ Boron ~Jection R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ ~GT 5 ~/M~ R~ 1, ~' H~ ~GT 10 ~/~ R~ 1, ~' H~ Pe~ Record R~ 1, C' H~ Pe~ Record R~ 1, C' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, C' H~ Pe~ Record R~ 1, C' H~ PSGT Computed Rca~!s H~ 1, ~' HLS PSGT R~ 1, ~' H~ Pe~ Record R~ 1, C' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, C' H~ Pe~ Record R~ 1. C' H~ Pe~ Record R~ 1, C' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, C' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, C' H~ Pe~ Record R~ 1, C' H~ Pe~ Record R~ 1, C' H~ R~ 1, C' H~ ~-~ [~,~ 7-21 12-20-92 Perf Record Please sign and return t~e attached copy as receipt of data' RECEIVED BY ~_~_~~~ APPHOVED ~onya Wallace ATO-1529 Tr~s~ 930 # CENTRAL FILF. S # CHEVRON # LUCILLE JOHNSTON # EXXON PHILLIPS MOBIL BPX STATE OF ALASKA * The correct apl# for 3-32 is 50-029-21141-00. ARCO ~-~n~_n_, Xne. P.O.Box 1OO360 Anchorage, Alnska 99~10 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-31-93 Perf Record Run 1, 1-4-93 Perf Record Run 1, 1-10-93 Perf Record Run 1, 1-11-93 Perf Record Run 1, 11-12-92 Perf Record Run 1, 11-8-92 Perf Record Run 1, 11-26-92 Perf Record Run 1, 1-29-93 Perf Record Run 1, 11-15-92 Perf Record Run 1, 11-19-92 Perf Record Run 1, 11-6-92 Perf Record Run 1, 11-27-92 Perf Record Run 1, 11-18-92 Perf Record Run 1, 1-2-93 Perf Record Run l, 1-1-93 Perf Record Run 1, 2-1-93 Perf Record Run 1, 1-9-93 Perf Record Run 1, 11-18-92 Perf Record Run 1, 11-15-92 Perf Record Run 1, 1-3-93 D/tN Run 1, 1-8-93 Perf Record Run 1, 11-2-92 Collar {Inflatable Packer) Run 1, 11-16-92 Collar (To spot jet cutter) Run 1, 1-8-93 Perf Record Run 1, 11-14-92 Perf Record Run 1, 12-2-92 Perf Record Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, 6-25 11-29-92 Perf Record 6-26 13-31-92 Perf Record ""~** ~ 6-29A ~. ~O~~~_.~6.30 11-29-92 Perf Record 1-5-93 Perf Record ~~~..17-19 11-17-92 Perf Record Have A Nice Dayt Sonya Wallace ATO-1529 HL8 HL8 HL~ HL8 HL8 HIS HL8 HIS HI~ HL~ HL8 HL8 HL8 HL8 HIS HL8 HL8 HL8 HL8 HL~ HL8 HL8 HL8 HL~ HI~ HL8 HL8 HIS HIS HIS HL~ # PHIIJAPS PB~ FILE8 #BPX # STATE OF AI21SKA RECEIVED These logs were mn in 1993 not 1992, The correct API# for 4-14A is 50-029-203104)0. The correct APl# for 16-29A is 504)29-22272-01, Alaska Oil & Gas Cons. Commission Anchorage _ STATE OF ALASKA ALASKi ]LAND GAS CONSERVATION C 'MISSION REPORTOF SUNDRY WELL OP,-RATIONS 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 1135' FNL, 1533' FWL, Sec. 8, T1 ON, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N, R125E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM Development Exploratory Strafigraphic X 6. Datum of elevation(DF or KB) ~ ?,~..." 70 RKB fe~t 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 5. Type of Well 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9750 feet 9251 feet Effective depth: measured 9697 feet true vertical 9201 feet Casing Length Size Conductor 110' 20" Su dace 2519' 13-3/8" Production 9742' 9-5/8" Plugs(measured) Junk(measured) Cemented 150 SX CS II 2000 sx CS III, 400 sx CS II 950 sx Class G, 450 sx CS II, 300 sx CS I Perforation depth: measured 9480-9530'; 9538-9554' true vertical 8999-9046'; 9053-9068' Tubing (size, grade, and measured depth) 4-1/2", 12.6~ @ 9007' Measured depth True vertical depth 110' 110' 2519' 2519' 9742' 9244' Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD, Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Well was pedorated Treatment description including volumes used and final pressure - 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 2177 17945 1790 -- · Subsequent to operation 2162 ~''- 18181 1813 -- Tubing Pressure 1092 1125 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x.~_ Gas ~.. Suspended_._ Service 17. I hereby certify that the fore/ge~ng is true and correct to the best of my knowledge. Signed ~ ~'.~/'~,~v ~ Title Senior Engineer --orm 10-404 Rev 06/15/88// .S. Wallace/DS Engr/MW. Peirce Date ~/o/~.~ SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS DS 1-30 API# 50-029-21606 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows: INTERVAL SPF ZONE COMMENTS DATE 9510-9520' MD 4 2 RePerf 1 / 24/93 9500-9510' MD 4 2 A Perf 1/24/93 9490-9500' MD 4 2 A Perf 1/31/93 Depths referenced to DA BHCS 6/23/86. Oil L;: (~:~ Co:~s. 5o~nn'fissi~,. Anchora[~e ARCO ,~!Ask~; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-2-92 REFERENCE: ARCO CASED HOLE FINALS -3o 9-3.92 _ ~3 2-13 9-1-92 -~r~ ~ ~ 3-27 8-21-92 Temp ~~ InJ Profile Prod Profile (Flexstak} ,~/~z/~ ., 8-24-92 Collar/Baker mP 9-1-92 Prof Profile 9-1-92 Prod Profile . , 8-~ Perf Br~skdow~ Prod Profile Prod Profile Leak Detect ~lexst~k) Prod Profile Prod Profile GR/Colln~ l~m L 5" l~m 1,5" Run 1, 5" Run L 5" Run 1, 5" l~m 1, 5" Run 1,5" l~m 1,5" Run 1, 5" Run 1, 5" Run 1, 5" Run L5" l~m Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1,5" l~m 1, 5" ~L5" ~L5" ~m L~ Please sign and return th~ attac~d copy as receipt of data. RECEIVED B~ Have A Nice Da [ Sonya Wallace OCT 0 5 199l APPROVED ATO-1529 ~Jaska 0ii & Gas Cons. ~0mmi~# 9221~ ' Anc~0mile # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON # MOBIL PtHLLIPS PB WEIZ, FILES R&D BPX STATE OF ALASKA Cnrnco CamcO Camco CamCO Camco CamcO Camco Camco Camco Camco CamcO Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco C--_m co * This is not a field print for 1-11. STATE OF ALASKA ./.~i ALASKA . AND GAS CONSERVATION CC /IISSION ... REPORT SUNDRY WELL OPErtATION il. I G I N 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 1135' FNL, 1533' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N, R125E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T1 ON, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9750 feet Plugs(measured) 9251 feet Effective depth: measured 9697 feet true vertical 9201 feet Junk(measured) Casing Length Size Cemented Conductor 110' 20" 150 sx CS II Sudace 2519' 13-3/8" 2000 sx CS III, 400 sx CS II Production 9742' 9-5/8" 950 sx Class G, 450 sx CS II, 300 sx CS I Measured depth 110' 2519' 9742' True vertical depth 110' 2519' 9244' Perforation depth: measured 9480-9490'; 9520-9530'; 9538-9554' true vertical 8999-9008'; 9036-9046'; 9053-9068' Tubing (size, grade, and measured depth) 4-1/2", 12.6~ @ 9007' RECEIVED ~. Si.:'? ! 0 Ak~ska Oil .~', G-a:s r .... ,¢, Anch0rarj3 Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD, Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Well was perforated Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Productionorlniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 113 2144 1152 -- · 364'~~ 1643 1347 -- Tubing Pressure 193 221 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x.~.. Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~/- ~ Title Form 10-404 Rev 06/15/88// V cc: S. Wallace/DS Engr/J. W. Peirce Senior Engineer Date ~//~ ~ SUBMIT IN DUPLICATE--~' REPORT OF WELL OPERATIONS DS 1-30 APl # 50-029-21606 PERMIT 86-111 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows: INTERVAL TVD ZONE COMMEN'I~ DATE 9480-9490 8999-9008 2 ADPERF 6/25/92 ARCO Alaska, Inc. Post Office Box ,,~d360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 13, 1992 Ms. Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Ms. Miller: RECEIVED AU 6 1 1 199P.. Alaska .0ii & Gas Cons. O0mr01ssl.o.a ~ch0raga Per our phone conversation of 8/12/92: (1) Please find attached copies of the Application and the Report Sundry pertaining to Approval # 90-519. Verbal approval was granted 6/5/90 to perforate Well 1-30, and the work was reported on a 10- 404 on 6/29/90. The Application was sent 7/2/90. Both reference the same approval number. (2) Regarding Approval # 9-692 on Well 16-20, please find enclosed a 10-404 Report Sundry for Bridge Plug Installation and Removal. In this case, the approved Application of 8/14/89 was for a Choke Packer Installation that was never performed. Per your request, the Bridge Plug Installation (11/90) and its removal (3/92) is reported referring to the 9-692 Approval #. (3) Regarding Approval # 91-090 on-Well 3-11i, of approval date 3/15/91, requesting approval for an Annular Communication Evaluation, I have directed your. request for a 10-404 Report submittal to Julie Heusser / James Styler (at 659-5102), who are the Annular Communications Engineers responsible for filing this Report. (4) Regarding recent sidetrack work completed on Well 3-34A, the 10- 407 Completion Report is enclosed for the P&A of the old wellbore ~--(3-34). Per conversation on 8/12/92, with Marion Sloan (564-5127} at BPX, the Completion Report for the new Well 3-34A, was sent 7/6/92. If missing from your files, she will supply another copy. ARCO Alaska, Inc. is a Subsidiary o! Atlantic Richfield Company AR3B-6003-C Ms. Joan Miller August 13, 1992 Page 2 Regarding the 16-9A Rig Workover for Packer Failure, Marion will work on completing the outstanding 10-407 Recompletion Report. Sincerely, /'-John W. Peirce Engineering ~de JWP/002 Attachment cc: ~on Cawvey - (ARCO) - ATO- 1520 ~ Julie Heusser / James Styler- (ARCO) - PRB-24 Marion Sloan - (BPX) - Drilling Dept. Alaska Oil & Gas Cons. Commlsslo~ /~nchorag~l ~_ STATE OF ALASKA ALASKA 'AND GAS CONSERVATION REPORT SUNDRY WELL OPF_.HATIONS 1. Operations performed: Operation shutdown Stimulate .,~ Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, Sec. 8, T1 ON, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N, R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9750 feet Plugs(measured) 9251 feet Effective depth: measured 9660 feet true vertical 9167 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 150 sx CS II 110' 110' Surface 2449' 13-3/8" 2000 sx CS III & 550 sx CS II 2519' 2519' Production 9672' 9-5/8" 950 sx Class G & 450 sx CS II 9742' 9243' & 300 sx CS I Perforation depth: measured 9480-9490'; 9520-9530'; 9538-9554' true vertical 8998-9008'; 9036-9045'; 9053-9068' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 30' MD; 4-1/2", 12.6#, L-80, PCT @ 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD, Camco Bal-0 SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 751 6114 643 '-- Subsequent to operation 413 696 1651 -- Tubing Pressure 1563 214 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date 860/10 DCR/KAS cc: SW, JWP SUBMIT IN DUPLICATE ~ -30 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF & ACID STIMULATION I 0/3/9 I: An Acid Wash & CTU Cement Squeeze were performed for Gas Shutoff as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/seawater & RIH w/CT to reciprocate an acid wash across the open perforations at: 9510 - 9515' MD (Z2) 9515 - 9530' MD (Z2) 9538 - 9546' MD (Z2) 9546 - 9554' MD (Z2) Ref. Log: BHCS 6/23/86. Pumped 35 bbls 15% HCI w/10% Xylene, followed by 37.5 bbls 12% HCI - 3% HF, followed by 46 bbls 3% NH4Cl Water. Pumped 45 bbls of Acid Resistive cement, & placed 7.5 bbls of cement behind pipe at 3500 psi max squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 9662' MD. POOH w/CT. Rigged down. 10/10/91: Reperforated: 9538 - 9554' MD (Z2) Ref. Log: BHCS 6/23~86. 12/16/91: A Mud Acid Stimulation w/Inflatable Packer was performed as follows: MIRU & PT equipment. Ran into fluid packed wellbore w/CT mounted inflatable packer. When setting the packer to isolate the perforated interval (listed above) for stimulation, the packer element failed. Performed the stimulation without a packer seal, pumping: a) 19 bbls 15% HCI w/10% Xylene, followed by b) 38 bbls 15% HCI - 1.5% HF, followed by c) 42 bbls 2% NH4Cl w/5% Musol, followed by d) 15 bbls 2% NH4Cl w/1% Surfactant & Nitrogen @ 550 - 1000 scfm, followed by e) 10 bbls Foam Diverter (2% NH4CI w/1% Surfactant), followed by f) 5000 scf Nitrogen Chaser Slug, followed by g) 15 bbls 2% NH4Cl w/1% Surfactant, followed by h) 19 bbls 15% HCI w/10% Xylene, followed by i) Shutdown for 15 minutes. Resumed pumping j) 38 bbls 15% HCl - 1.5% HF w/Nitrogen @ 750 scf/bbl, followed by k) 57 bbls 2% NH4CI Overflush w/5% Musol & Nitrogen @ 750 scf/bbl, followed by I) 45 bbls Dead Crude w/Nitrogen @ 750 scf/bbl, followed by m) Shutdown. POOH w/inflatable packer, then RIH w/CT & pumped nitrogen to lift well. POOH w/CT. Rigged down. I 2/29/9 1: Added perforations: 9520 - 9530' MD (Z2) 6/25/92: Added perforations: 9480 -9490' MD (Z2) Ref. Log: BHCS 6/23/86. Ref. Log: BHCS Placed the well on production & obtained a valid production test. Oil rate decreased by 338 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 677 BOPD, resulting in a net oil benefit of 339 BOPD. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO CASED HOLE FINALS ? ~ --F'~ 1-5ST 6-26-92 CCL/Perf ??--;-~ 1-12 6-26-92 CCL/Perf ~'""/// 1-30 6-25-92 CCL/Perf ~'.~ ~5'~ 2-22 6-26-92 CCL/Perf 3-32 ~-~ 6-27-92 CCL/Perf 12-14 ~/~/~ 5-26-92 Coll2r/Jet Cut 13-26 ~.~-~/ 5-21-92 Peri/Collar 16-26 ~ ~¢~/6-27-92 CCL/{Perf Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5' Run 1, 5'" Run 1, 5" Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 RECEIVED jUL I ,'5 1992 APPROVED_Y Trans # 9214 ~- Alaska 011 & 6a~ Cons. Com~i.s.sion Anchoraf-je # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # PI-HLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO # MOBIL Atlas Atlas Atlas Atlas Atlas Hls Hls Atlas .- ARCO AL. ASKA., INC~ F' Fi BCi",." i ,':; ¢., 'z 6 6, ,-..., ~ .,.,. ..... : "' ;"C ' ~;~ 9 % ANCHORA(..;.E r.~l..A,., K A . _ i ,3, DATE.' t .... i_5:-92 REFIERENCE ' ,ARCO CASED HOLE FI,,!A.L3' ~ "so c;,i CCI 'F'["F'F'"' ' 13'-' 33 i -' '2 iP F C -' G R t 2-2,&-9i CCL/PER'F- ~ i 2~"26-'c.;~ i C[;L./I"'k:.i".:i" i 2-'2,6-9 i CCL/F:'ERF "' i 2- :...6-'~.' i C:C L..,"PE~'.:~' i 2-'2",'-9i CCL/PERF i "2 - 2 8- 9 t C C I_.. / P E R F' Fi'.IIN i , ";" I;,'IJN i, ~,~" RLJN i , 5" RUN t , .5." RUN t, 'J" RUN i, ~'_~" RUN t, ':;.,.' RUN t, ..,~¢'" F'I._EASF SIGN AND RETURN f'HE A'¥T,.-~,..HED COPY AS RECEIPT OF' I)ATA ATL. A,S' A 'f'l.. A S A l' L. A ~'.;' ATI_AS A'f L.. r:."~ .':.; ~q I' L..A;~';' A'f'I_A;~: ATI..A,.? F..E:.Ut:.]:VED BY ............. HAVIF' A NICE DAY! SON:fA WALl_ACE: A T 0 -' i ':'; o ,.':, i) I.-.¢'TR I BU'F :[ ON CEIVED AP'F'ROVEI)~..~.V. '~ ,i&N 2 l 'I-RANS$ 92-)~r{-'6~- ... 1992 Alaska Oil & Gas Cons. Commission Anchorage CENTRAl_ FILES .11, ~,. C H E V R O N "" EXTE:NSION E:XPLORA'I" I ON '11' 41. · ,. EXXON MARATHON · ,- HOB I L F'FIlL. L I F'S F:'B WELL F:']:L. ES R & D :~: BPX ~.,- STATE OF' ALASKA TE. XACO ARUO ALASKA, INC~ F:',.()~ BOX ~00S60 AHCHORAGE: ALASKA 995i ~ I)ATE · i 2-Si -9i F,'EF'ERENCSE' ARCO MAGNETIC TAPE(S) WITH LISTING(S) JOB:$L66"?54--6 PLEASE SI~,]N AND RETURN THE ATTACHE:.I) COF:'Y AS RECEIPT [iF:' DATA,. RECEIVED BY . ~~_.~._ HAVE A NICE DAY! SONYA WALLACE A T 0 -. i 5 '29 APF'ROVED~ "I"RAN$~ 9 HL. ,S' DISTRIBUi'ION CENTRAL FILES (CH) CHEVRON D & M I)EI)E $CHWAF,'TZ (OH/CC:T) EXXON MARATHON MOBIL · ' PHILLIPS F:'B WELL FILES R & D · .'"' BPX. STAI'E (.)F ALASKA TEXACO RECEIVED JAN 1 0 I992 Alaska Oit & Gas Cons. Commission Anchorage ARCO ALASKA: INC. P.O. BOX i ANCHORAGE, ALASKA 995i DATE' i 2-St-9i REFIERENCE' ARCO CASED HOLE FINALS RUN t, 5' RUN :5, 5' RUN t, 5" RUN i, 5 · RUN i, 5" RUN 2: 5" RUN t,.,.~'" PLEASE SIGN AND RETURN THE ATTACHED COPY ~ ~[~:[B'l' OF DATA, hA'~"t: A Nit..,::. :uAY! AF'F'ROVEI) ~ T R ~ ru, :".. :~- 9t ~ON 'r A ~,,'t~:~i.. ~...~:~UE ATO- i 529 ~ CENTRAL FILES .,-~ CHEVRON ~ EXTENSION EXPLORATION ~ EXXON MARATHON ~ MOBIL PHILLIPS PB WELL FILES R & D BF'X STATE OF ALASKA TE:'XACO * THE CORRECT AF']:~ FOR t-iB IS 50-(.}':29-2i,'.5¢.7-,:)t. ** THE CORRECT AF'I~ FOR 2-2',5S'¥ IS 5(D-(D29'-2()795' THERE IS, NO SUFFrX. A T L A S SCH HLS RTl_AS ATLAS SCH ATLAS RECEIVED JAN 1 0 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALAYKA, iNC P~ O. BOX ANCHOF.:AC.F, ALASKA I:::iFt':I.EI:;,'ENCE: ARCO CASED HULi::. i-'.~-NAL.$ O-i ¢,-9i /28-29/9t -i9-9i .-25-9t -22--9i -26-9i PERF RE:C;ORI) POST F'ERF BREAKDOWN DSN PERI:" RECORD DSN F'ERF RECORD C:CL (TO SPOT AVA POGLN) F'ERF RECORD THD .~CORRECTE THD -28-9t DSN AND RETURN THE ATTACHI.ZD COPY AS RECEIF'T OF' DATA, RUN t , .5' RUNS i &2, RLIN t , 5' F,'UN t , 5 ' RLJN t, .5" RtJN J, 5' RUN t , 5' I;:tJNi, 5' RtJN J, 5" F;.:UNt , 5" ii RECEIVED HAVE A N SONYA WA ATO-t 529 LL..ACE: AF'F'ROVE:D '.~ j~~--------- ~ 'FRAN$:~ 9i SCH HLS HI...S I.~I._S HL.,S' HLS FILS SCH f.li..3;' HL.S HL. 5' DISTRIBUT10N CENTRAL FILES CHEVRON D & H EXTENSION EXPLORATION EXXON MARA 't'FION NOBIL · "' F'HILLIF'$ 'Il' PB WELl. FILES R & D ,."' BPX " STATE OF ALASKA l' E X A C 0 RECEtVED t,lO.V i2 i991 Alaska Oil & Gas Oons. OommiSsio~ Anchorage i.,.~,...F'~'.. ':./L.. } i...-'.....- I .I .... { F:' ¢; !{',:", i::' 'f' r.:' r"-'¥' 'r 8 N .:.. :,.. k...,.: ~ ! N ,J [i~. :'.'3 T i O: i'..! t..: ;.'::: ! F' F,.: .,9 )1)U ("; 'i-ill {1)t".i F:' .r.;: E) D LJ E:: "!." ]: E) N L. iii: ¢~ l{ ii:.:, E'i" ii;;. {.'; '¥' :Il {} H j f::' ..'"., L-" r', Z' 'r ~::' ¢"-'¥' i' f"i i"-.~ ...L..'-""Ji'-. &."i... i L..~,.; i .i. ;,.'J, C; O L. L. ,,q F:: ....'" F:' ii;. l-';..' F: · "' ~. ;-'-..' :- -'.""..'"--" -' '~'": ¢~ .... i".",; L.; F.'..' P'i r"! ¢4 ..--' L.. L.. J......" ,J ~::. ~/...' i::. L.. v,' ,.'" ._. !E ~'.":'~ ?.'.': i";, iii: 'i' !:~. E: '}" '{' (:'J i",~ L. iii: ¢',. i-::: Z::." iii: 'i" !ii; C '}.,. ,..'r ."'i N F:'.,.'r '¥' :i':; / l N ,_,~[:',... :;;' T .,.'r (3 i",! 1[ N,.! iii: {} T i O N F:' i:-:.: (} ~l.'-' Li E: 1" ]1 C,' N (l: ()L i._ ¢~ F:' F;.; O .f..'.-'-U .C ".," ];,....r'~ :?"~..: T ii~. id ix` / X F:' :i: i'-,: N ii; F," ,,q T C} -" i ,5:2 "";-:' ;"..':-' .ii g T F.: ! 5-: L. i' .ii 0 f"; f?; ;".'i r'" r"~ (2 ~':':'~ i""'i tl.t ill .......... L.. f.:i P'~ L.: !...' ......, .....,.-...... i .:.'~ F.': ~ ~ : ..... ~ ~ : .....-..., r:':'; 'i" i... ~'-":'~ ;? (11: ;':',. f"i E: {2 r.":'~ ('i C !2 r:':'~ i""~ C (12 ........ ._.; ¢:'~ f':1 !...: !.~.: f.':'~ i'"i (11: O .......... i...: ~'::'~ ~"'I .".. _1 i: ,,'::'~ ¢"i ('2 1-" ............,... J' f...; p'; ~.... l...f :.... r:':',. N ('-: H 0 F::. A Ii. E., A I.. A ;:.;' I{ f.':; F;.'. I? !::' Jiil I:;,' Ii"' N C: E · A F;:. (."; 0 C A ;:.;,' Ii"' D I-'! i'i "' :') I.~' .") .'"~'"J i'~ ............ : ....... · ,:.. -4. f "" ',~ i P I::.'. (.'.1)) o 1'": '¥ ]] 0 ["] I::' I:~' f"l t::' 31 I._ Iii] F.'I I f',l 5 .... i ¥ ..... 'i '?" .... 9 i (."; 0 I... I.. A I::.:/F:' !ii; F:.: I'":' J:;t U ,'J ...... i 9 2 .... 2 8 .... 9 i I N,.J F:' R il)F:' ]; I... E F;.i !..I i"'.! '.:.;.' S': ;'i ..... J 6 .... 9 i C I.] I... I... A I::~/' P E I:;.'. F:' R I..! N '..,.'~' ...... 'i ;~:.:: ¥ .... ':? 9 '1 F:' I:;.: 0 I) LI C '1' .110 N. F:' I:;.: C) I:: '.11 I... liil F;.'. I.J i"'-! '7 .... 'i 6 Z"~, "" 8 ..... ::? 'i ·1·· E./"'i F:' li'E F;,' A'i" I.J R Ii" R U I'J. ':i; ...... :'.-:' ¥ .... "i ..... 9 i I... Iii A 1< i) E ]" I:[ C T ]i 0 i"-,I !:;.: I..J i".! 'i 2 .... 2 :"~ .... /', .... 9 i ]i N..J F::R 0 I::' I I...I'Z i:;~ U lJj.l.~I'.) l l'' ~, i ;;f~ ..... J, .... I:~I ii, F:' R [)D t.J C 'T' ]i O. i'"] I::: I:;..' 0 F' ]i L ['] r.,,'"' I...IN i..,.. '''~ "- ,:. '''> '~, S .... 6 '"' ".-;' i I i'"~,,..I i::l F;.'. 0 F' T. I... E R Lj i",i i 3-.' 2 A 3 ..... i ,?," .... 9 i I... E A i< i) I_:il 'i' E C'i" I 0 N F;.'. t.J i"..! · );: 'J ~ .--'.15 ]3 ..... i :iii ..- 9 i C I"1L L A I";.'. /P [.:' IR I:: I:;: I..! r..i i 4 .... 4 3 .... i ,:'-.;.', .... ".';-:' i F:' R I.] D L.I C "f' ]] 0 N P R C.I F- ;.[ L E R U N t ,:':'. .... i 2 "' i ,"-', ..-':;' i , Iii." W Ii.;. I... iR Y IR [J N i ,:'.I. .... ~ 2 :.¥'; .... i <.>-. 9 iF:' i:;; 0 L:, U C T ]: 0 i'--~ I::' R 0 F' I I... E R I...I N -:,,': ':,f i ,..1. .... 2 S S..- 3 .... :? i I::' IR 0 D U C'¥' I 0 N F'R 0 F' I L E R U N i f.!:: ..... 4 '2 ..... J 9 .... 9 i F:' R I .S' M A N A L Y,S.' .'[ S R U i",l i 6-.-i ~ S..-8..-9i l_E"'fil< DETFB'T'ION i:.,.'r, _ ,,...'::' ~'~.. ....,".: .... '::;', .... ? i I... E'] A K ]() E 'T' E C l' I [1N I:;~ I..I i 8 .... i 6 :.'.~..- 8.... 91 F' R 0 D (J C T I 0 N F'IR 0 I= I I.. 1:"~ I:;,' LJ N i ! i, i, F:' I., E A 3' E ,.S' I E N A N I) R E 'T' lJ R N T H E A l" '1" A C Ft E D C 0 F' Y A,S' R E C [ii .t F:' 'i" 0 I::' D A i' A F:: Er C E I V Ii"' D B'T' ._./~ ....... HAVE A i",I]]C:E DAY! S i..t A R 0 N W I L..,%' 0 N A 'i" 0 '-' i.)':' ,.="; o;, A F:' F' R 0 V E D 'TF;,'AN,~':D 9i 082 -- I) I STR I BUT ]: ON · , :,,- CENTRAl.. FILES ~ PI-ilL~L.I PS :I',: C H E V R 0 N F:' B W E L.I., F:' I I.. Ei. S D & M ~ E X'1' F.:~ i'.l,S' I 0 h~. EXF'LORATiON .,. '"' BF:'X :,t- EL X X 0 N .... :... S T A'1' I:Z. 0 I= A L A S K A M A R A 1' I-.I 0 N '1" E X A C 0 .,.'"' H [] )'J'~ I L F' ~ 0_. B O X ~ ,'5 ,::'3 -Z,5 "3' A i"..! C H O R A G E, A L A 5' K A 995~ 9 DAT~' · 7-- i 2-9(~ R E F E R E i:! C E - ..,':',. F.: C: O -._: A ?:; E D H O L E F I N A L ~.: · -' ' f .... "F' _ F'LEAE:E IGN AND RETURN THE ATTACHED COF'Y A;~ RE,...E~ 'T ril::' DATA RECEIVED BY HAVE A NICL--. DAY! ::TALLY i40FFECKER ,'~, T,"-~'-' i ,='.", o .,.. .j...-' ... ,U~ 15 1990 ~ ,,j .:_. Alaska Oii& Gas Cons. C0mm't, ss]¢ ' APPROVED 'Anchomg~ T F,' A N,? :~ 9 '7 DIf.:-f'RI BUT ION '"- CENTF.:AL f'!l_ES .-,-*F'HIL. LIF',S' · '".,- CH1EVRON. PB hiEL. L.... F' ]: LE3 D & M R *,~ D -,-"~[:'XTEN."7 10i'~ EXPLORATiC)N ~,.""BF'X ~ EXXON -~'"':j]"A'f'E OF. AL_A:_?I< A H A R A i' H O N T E: X A C 0 ~ MOBIL .... , STATE OF ALASKA ALASK, _ AND GAS CONSERVATION C' llSSIOU,,- APPLICA- ION FOR SUNDRY r'ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Re-enter suspended well Time extension Stimulate Vadance Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1135' FNL, 1533' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N,R15E, UM At effective depth 5. Type of Well Development , X Exploratory , Stratigraphic Service At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM Other 6. Datum of elevation(DF or KB) 70 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30 9. Permit number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9750 feet Plugs(measured) 9251 feet Effective depth: measured 9697 feet true vertical 9201 feet Junk(measured) Casing Length Size Cemented 20", 91.5# 110' 30" 150 sx CS II 13-3/8", 68/72# 2519' 17-1/2" 2000 sx CS III 9-5/8", 47# 9742' 12-1/4" 950 sx Class G & 450 sx CS II & 300 sx CS1 Measured depth 110' 2519' 9742' True vertical depth Perforation depth: measured 9515-9530'; 9538-9546' true vertical 9173-9186'; 9193-9200' Tubing (size, grade, and measured depth) 5-1/2", 17#,, L-80 to 30' MD '~"'::,::'., ~lichorapa 4-1/2", 12.6~, L-80, 30' to 9007' MD Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 8890' MD, Camco Bal-O SSSV @ 2197' MD 13. Attachments Description summary of proposal 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Russ Douglas Name of approver 6/5/90 Date approved x Detailed operations program BOP sketch x 15. Status of well classification as: Oil x Gas. Suspended Service 7.1hereby cj~ify~t the fo/~g, ging i.~4'rue and correct to the best of my knowledge. Signed~~~'"'~~// ~/~~Title SeniorAreaEngineer t FOR COMMISSION U~;E ONLY Conditi s of approval' Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Date I Approva, No. ¢~ .-- ,~/,/ Approved by order of the Commissioner Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 WHS/SunVII Commissioner ^pproved Copy ReJ;urnecJ Date q//~O/~O : SUBMIT IN TI~IPLICATE DESCRIPTION SUMMARY OF PROPOSED WORK PRUDHOE BAY UNIT DS1 -30 'APl Ct 50-029-21606-00 PERMIT Ct 86-111 ARCO Alaska, Inc. proposes to perforate within the Sadlerochit sandstone interval in the subject well as follows' Interval Zone MD Comments 951 0-9515 2B 5' Aperfs 9546-9554 2B 8' Aperfs Ref: Log: BHCS 6/23/86 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2.-5000 PSI WIRELINE RAMS (VARIABLE SIZE) ;3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI ¢ 1/6" FLOW TUBE PACK-OFF i 1 ! bi ! REL ! NE BOP EQUIPHENT. St008a006 ~. t . STATE OF ALASKA ALASKA .AND GAS CONSERVATION CC IISSION ~~:'~ !! ~ ~ ~'~'' "~ J'!'! ~!~L~ REPORT= SUNDRY WELL OPEr-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 1135' FNL, 1533' FWL, Sec. 8, T1 ON, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, T10N,R15E, UM At effective depth At total depth 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development X Exploratory · Stratigraphic 6. Datum of elevation(DF or KB) 70 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-30//¢~- .~'/? 9. Permit number/approval number 86-111 10. APl number 50 - 029-21606 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9750 feet 9251 feet Effective depth: measured 9697 feet true vertical 9201 feet Casing Length Size Condu~or 110' 20" Sudace 2519' 13-3/8" Production 9742' 9-5/8" Plugs(measured) Junk(measured) Cemented 150 sx CS II 2000 sx CS III, 400 sx CS II 950 sx Class G, 450 sx CS II, 300 sx CS I Measured depth 110' 2519' 9742' True ve~icaldepth 110' 2519' 9244' Perforation depth: measured 9510-9530'; 9538-9554' true vertical 9168-9186'; 9193-9207' Tubing (size, grade, and measured depth) 4-1/2", 12.6~ @ 9007' Packers and SSSV (type and measured depth) Baker SD-3 Packer @ 8890' MD, Camco BaI-O SSSV @ 2197' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A 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 3537 2451 940 4527 3671 1203 ~ubmg Pressure 253 297 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas,, Suspended Service 17. I hereby certify t~t the foregoing is true and correct to the best of my knowledge. Signed ~~(.,(~~/'//// /~-~/~//.......L~--~~ Title S eniorAreaEngineer Form 10-(4'04 Rev 06/15/88 Date ~'".~~,~~_...~ SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS PRUDHOE BAY UNIT DS1 -30 APl # 50-029-21606-00 ARCO Alaska, Inc. perforated the subject well on June 11, 1990 as follows: Interval MD Zone Comments 951 0-9515 5' 2 B Aperfs 9546-9554 8' 2 B Aperfs All depths referenced to BHCS log dated 6/23/86. ARCO ALA£KA, !NC. I:'~0. BOX i00360 ANCHORAGE, ALASKA 995 i 0 DATE ' -.'~- 26- 8°, R IE F E R E N C E · A R CO HA6NETIC TAPE(S') WITH i -2i 5-1 6-89 CNL _~- i "'~- 8, CNL i -32 5-i ~-89 CNL ~,-z_o, ~R- i 8-8~. , CNL 4-2 ~R-'~9-89~ CNL 4 -.,R ~.~ - .~, o, - 8 ~, C N L 4-7 5-i 9-89 CNL ,~-"~ 6 R-t 8-89 CNL ~-4 5-i i-8~ CNL 6--on ~'-i~ o-8(; CNL 6-'~4~ 5-1 '~-89~ CNL. 7-S 5-t 3-89 CNL 7-34 5-~ 2-89 CNL ~='~-~ ~-~ 3-8~, CNL ~ 4-3 5-~ 4-89 CNL F'LEA~E SIGN A RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 L.,/-ogt ND RETURN THE ATTACHED COPY LI~TING(5') A~ RECEIPT OF DATA. APPROVED ~,~__ TRAN$¢ 89-.--8 T H E DISTRIBUTION CENTRAL F-ILE~ (CH) CHEVRON D & M TAMI~.J-B~O.WN (OH) · . -;, ~;, : ~.:- EXX.ON:~ ~:-,.:" ... . : · . F'HILLIF'~ F'B WELL F'ILE~ R & D BF'X $'¥A]E OF ALASKA TEXACO CORRECTED AF'I$ FOR 6-22 I~' 5t)-029-2-~8~36. Alaska Oil & Gas Cons. Commission Anchorage -. ARCO AI_A.?KA, INC, I::',. O, BOX J (.)(.)56(-) ....... ., 905 ANCHORAGE, ~l..m:,K:-~ ., ~ (~ DATE · 5-i 9-.'89 RIEFE!RENCE' ARCO CA2ED HOLE FINAL.? i -..:5,:::, ~";-t ,q-..8c~ CNL.-GANi'4A I:;,'LIN t .... ' · " '"' '-' '~ I ..~ i -;52 '5-i ':)'-89 CNL-GAMMA RUN i , '..~: v.... :q ~' ..- ~:~ ..- F~ 9 F: N L. R L.I iq? "~" .., ...... ..' ...... ~,.. ?-'=' ~ 5- 8 ..- 8 9 C N L R U N ":~ .5" 5:'4 5-t ~--.8~, CiWL.-[;ANMA RUN. i , (~" '"' "~ : ,=~'_ 5 .... t 2-89 CNL-GAMMA F:UN t , " 6 ?4 ~'"~ 2-"';~9 CNI._-GANMA RUN i '?"";5 5 .... t :$'"'89 CNL'"'GAMMA RUN ~, 5" 7-34 ~'~-i "~-89 C:NL'-GAMMA RUN i S" i ''~ - 5 - " ,~: i 'i ,'5-'89 CNL-GAMMA RUN .,:.= ..... -" i S-"89 CNL RUN ~. · ~,,~ I ...'" F'I...EA,?E 2tGN AND RETURN THE ATTACHED COPY AS RECEiP"F OF I)A'I"A~ , L. ~-f ,.'~ Al'LAS' .~';' C I..I 5' C H A 'r L. A ,?;' ATL A :~' A T I.,.A,t.' A i"LAS A TI... A A 'i' I.. A ;N: ,?CH RECE:IVED BY HAVE A NICE DAY! ,.~ ~'~L.,.. z HOFFECKI~:~R ATO-. ~ 529 DISTRIBUT]:ON CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL F:' H I L L I F'$ F"B WELL. I:"iLES BF:'X ,~TA'I'E OF ALASKA TEXACO THE CORRECTED APt~ FOR /~/aska Anchorage DATE'" Augu~'t REFERENCE: ARC.O.~,F're~ure O,'.~'ta t -29 8-t 7-87 ' '--'.;:"i--'$t a ~ i c' Grad i ent Camco t-30 8-t 7-87 Sfafic Grad ienf Camco t.-.3t 8-i7-87 Static Gradient Camco 3-7 8-i9-87 Memory F're~.s/Temp, (F',F,O,) F,.J-Sch S-27 8-.~7-87 Flowing Gradient Camco 3-3~ 8-~--87 Flowing Gradient Camco 4-~ 8-.t6-87 F'towing Gradient Camco 4-S 8-t 6-87 Flowing ~radien~ Camco 9-t 8't 3-87 F~owing Gradien~ Camco F'lem_~e .sign and 'return ~ a_'U~cl'~apv a.s ~ipf of data,, lED ' Recei red Dy .... HA VE A N I (;E/xD~Y~. aln.~, Oil & Gas Cons. CommissWll ATO- 'l 5,2? TRAN$ ~;8'7443 Ap p r oreo ........... ................................... D I 3'I'R I B U T I 0 N C e I"~ t-. r a L I:-" i L e .s' -,-'"' F'h i L L i p .~ C:hevron F'B Wel.[ F'i [e~: · '~ D & M :~,~. · ,,. R & I) E ::.'. t: e n :~. i c,'n E x p I. o r a t' i o n ~: ;~;' o h i o ~,~: IZ x x o'n '"' '" · .,. ~.:.-rr.,a'['e of ALa.sl,'.a M ~ r ...':) t' h o 'n .,.'"' '1" e x ..'.~ c o :.": H o b i L ARCO Alaxka, Inc. P.O, Box iOOS60 Anchorage, A lam'ka 995~0 ][)ATE' August St, i987_ REFERENCE' ARCO Ca~e~l Hol~ ~'rla~ i-29 8-8-87 -F'rod, F'ro'fi I.e Run i-SO 8-9-87 F'rod, Profi le Run i--~5~ 8-.9-87 Prod. F'rofi te Run t-S2 8-t8-87 Prod. Profile Run i '-SS 8-9-87 F'rod 3-9 8-~6-87 Temp. Log Run S-t~ '~ 8-8-87 In j, Profi [e Run S-~8 8-6-87 Inj. F'rofi [e Run ~.7 8-~6-87 F'rod, F'rofi te Run 3--~ 8-10-87 GR/Temp/F'rod, F'rofi [e Survey Run 4--S 8--~6-87 F'rod, Profi[e R~n 4--6 7/S~.-8/~/87 Leak De'i',/Temp/l=towmeter Run 4 .... 27 8-6-87 4-~'2 8-~6-87 Prod, F'rofi [e Run 5'-.2 8/~-..2/87 Leak Det/Temp, Log Run '7-°S~ 8-~ 2-87 F [owme'ter Run 9-t 8--i'7-87 X-Y CaLiper Ru 9-S 8-i3-87- Prod~ F'rof~ ~e Run 9-8 8-7.-87 Inj. F:'rof~ ~e/Temp~/Ftowme,er Run 9-~8 8-7.-8'7 Inj~ F'rofi ~e/Temp~/F~owme~er Run 9'--St 7-29--87 Prod~ Profi te Run ~ 2-20 R = '" . . _ =--_,--8 ? Inj F'rc, f i t,~ Run I='Lease sign and re Approved . _ .~ turn the at'~:ached copy as rec:eipt of data, C8 fflC 0 C a m c o Ca fflc 0 C a ~nC 0 Ca h~c o Ca mc o Camco C a m c o Camco Ca mc o Camco ~8~co Ca moo C a ~,~ o C a fO C o C~nco ' - ' '-- STATE OFALASKA - ~'~: i:~ '~ ~' ~ ~ ALASKA OIL AND GAS CONSERVATION C,JMMISSION L_~ ~.'~. ~ ~.~ ~ J*J WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-111 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21606 4. Location of well at surface 9. unit or Lease Name 1135' FNL, 1533' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2524' FSL, 53' FEL, Sec. 7, T10N, R15E, UM 1-30 · At Total Depth 11. Field and Pool 2416' FSL, 219' FEL, Sec. 7, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 70' ADL 28329 ALK 2327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/11/86 06/24/86 02/19/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ I-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 9750'MD,9251'TVD 9697 'MD ,9201'TVD YES,~ NO []I 2198' feet MD 1900' (approx.) 22. Type Electric or Other Logs Run D IL/GR/BHCS/SP, CNL/FDC/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT~PULLED 20" 91.5# H-40 ~urf 110' 30" Conductor report not available 13-3/8" 68.0#/72.0# K-55/L-80 ;urf 2519' 17-1/2" 2000 sx CS Ill & 400 sx CS II Top job performed w/150 sx CS II 9-5/8" 47.0# L-80 Surf 9742' 12-1/4" 950 sx Class G & 450 sx CS II & 300 sx CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9007' 8890' 9515'-9530'MD 9173 '-9186 'TVD 9538'-9546'MD 9193'-9200 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED w/4 spf, 60°/120~ phasing N/A Ref: BHCS 6-23-86 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 02/19/87I F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 03/03/87 4.1 TEST PERIOD I~ 488 262 0 40°I 538 Flow Tubing Casing Pressure CALCULATED OIL-BBL GASIMCF WATER-BBL OIL GRAVITY-APl (corr) Press$99 N/A 24-HOUR RATE ~ 2857 15:~6 0 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. * NOTE= Drilled RR 6/28/86, Tubing run 1/12/87, Perforated well 2/19/87, Form 10-407 Rev. 7-1-80 WC268 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~// .... ;' 30. 29. GEOLOGIC MARK[E'FIs FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad]erochit 9188' 8725' N/A G0C : 9269 ' 8801 ' HOT 9561 ' 9074 ' 0WC 9594 ' 9105 31. LIST OF ATTACHMENTS Perforation Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10~,07 DS 1-30 WELL COMPLETION REPORT PERFORATION SUMMARY Began perforating operation 2/19/87. Pressure tested equipment. RIH with gun #1, shot interval 9515'-9530'MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 9538'-9546'MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fi red. RD and secured well. Ref' BHCS 6/23/86 GRU1/68 05 -27 -87 Mr. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 August 4, 1986 DRILLING ANCHORAGE FILE COPY Ai O ALASKt,, INC. Re- Our Boss Gyroscopic Survey Job No. AK-BO-60041 Well: DS 1-30 Field: Prudhoe Bay Alaska Survey Date: July 1, 1986 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Enclosures Sincerely, NL SPERRY-SUN, INC. District Manager NL Sperry-Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARCO ALASKA, INC. Fi8 1-30 FRL[]HUE BAY . ALAoKA ' ,, ........................................... YERTTC~L SECTION CALCULATED ALf]NO F:L. FISLIF~E ..... · .~F: ERR ¥-~:~UN I/ELL._...SUR~E¥ lNG. COMR_~ibI~ .............................................................................................................. ANRHORAC~E ALA.:,K~ DATE OF .:,URMEV ,_IULV 1, 1986 L~L~U.[~,.I.I_~ ._D~.~E ..... ~0~ G~O~I~ SURVEy ._IULY 8, ~'F~86 JOB NUHBER KELLY BLISHING ELEV,:?:=:: : :, 70. 00 FT. .................................. ]"RUE MEASURED VERT I CAE DEPTH DEPTH 0 100 ............................ ~90 . :'::00 40¢) 500 . 600 7C)0 ....... 8(!0 1000 1200 1:300 ...................... ~.~00 1500 1600 ............... 1700 1800 1900 .......................... 2200 ............. 2400 2500 2600 ~ 700 2:BO0 ......... 8,UB~ ~A., ......... .!=~ .~! L__I_R_' T-~,__E_ -'r° Il--' ................................................................................................ ..... (.':'.O..L!B s E DOi_]-~[I_-~ .'['l_-i ~ N ~ 'VERTICAL INCLINATIAN DIRECTION SEVERITY REC:T~NGUL~R C:OORD I ATEa,:: DEPTH DEG M I N I]EL-~REES DEG/1AO NORTH/SOLITH EAST/WEST':.' VERTI; ....... L._,AL. SECT ! 0.00 0.00 100.00 :30.0c) 0 7 S 33. 0 E 0.13 0.10 S 0.06 E 0.02 2(')('). 00 1 :::('). (')(') (') 7 '.=; 41. :~ 9 ~ o 1 ~ C) 27 ~ ('). (')~] E 0. 1 ..... ~..-~ ~,~ ..... _~...~ t ~ ................ ~_.t .................................... ~.~. ~ ...................... ~.,.~ ........... ~ .......................... ~ ..... - ----, ~ ...... 300 O0 2:30 O0 0 ":':~ ' ". . . ._ . . , , ~ .E; J 69 E 0 40 0 77 F: 0 01 E c),53 ~._, I 49 '=' 0 12 W I 13 4':~':~ '~ 9 a-s,,:> ,~,:~ (') -7,,~ ,=. t 6 (') W (') '-' = 9 :::5 ~ 0, ~'9 W 1,86 F199_. . .99. . ~s'c~.~ ... o,:~.... 0 26 S 0 . ~(-)_. W 0 .21 .~,'-'.._,'-*('.) '-'.:, 0 . :31 W 69 .... 9.9 :~: 629 .9. :~:_ 0 ~.-,(-.) ._,c' 26. 0 N 0.20 ._,° .96 ~,c. 0.44 N o'-'. 10 ~ ........... 9_~ ~.1 ...... o ~,~ ....=, 0 ~3 S~.P~ ~0 E 0. ~.6 5.~,=,":'"' S 0.35 " . 999 '- '-' - .... y,=, 929 'y ~ 0 ~ 0 '-' .... ~ i~'~,. 9R . _ - .:,c ~ ,=, ~ = .-, - -~ ................................... ............... l C~.~ ..~ ~.~ ...... ~ ........ ~ ~ ............. ~ ....... ~~ ................... ~.. ~.~ ................. [. '~ ~ ~ 2o ... ~ ....................... _~. ~¢ .... = :34 , , 1199.97 1129.97 0 ._,1 '.E; .30 E 0.69 6 75 S 0.20 E 4 60 I .96 1229.~ 0 48 .S 26. 10 E 0.13 7.99 S 0.9:3 E 4.96 ,- · z,.. ~ . ~._, !.;3~ ................ ! ..... !(') .~ ..... ~,3C) ~ Q~ ';~ © 1:3:3 E 5 .......... ~_ _ ....................... ~_._ ~ ~ ~I I ............................ 1 .=,99 90 1 ='--"'- --m '.3 ...... '~::Y-'.~ n-~ 2~ 21 2.69 E !A'~'~. 87 16.29~ ,3t:, ~ _17 S i1.1~ E 1799.85 172'F¢~, o '.S :30.50 E 1999.80 lz~<__,-=. ~ ~, S 12 69 E )7 ................... 2029 c; - .. ~ ~ . 0 39 W 2299.75 ~27P,~.~ 0 45 S !9, 3~_.E 2:399.74 2:329. ~ 4 0 44 S 23.10 E · . i .--~ ---m ~ m . i 2499 7:3 ~4~.. 7:3 0 42 S 19 69 E 2 ~ 99 72 '-' ~ '-":¢ "'~ '" ='-' '-' · · , .... ~:~_~;, (~ ........... %2 ........ --2_m ......... o 5. :30 W 2699.7~ 2629.71 1 8 S 21.60 W 2799.68 2729.68 2E:'F~'P / ~ 2:z:29,.65. O. 14.0:3 S 1. .__ Cb 1_ ,6_~_4_1...$ ............... 1 · O. 1 :S:. '~5 S 2. 0 '-' ') . .-'L. 17 S 3. ?'.':' 44 S 4 Om O. O. O. 51 E 7. 09 -,= 6._, E 8.72 20 93 E ........ !(2, 1/-:_,_.. 48 6:2: E 11. (:)2 25 54 E 11.66 32 'P/_z~._ E .................... !.2--__". 74_ ~= ._ ,_.:. E 14 03 ._ ,..., 24.57 c; 4.5'-' . 61 26.04 '-' ~,_--': E 14 75 [_7. ........... 27. '-"- S .~ ..................... ~_..~ .............. ~. 64 [ ........ 1.5_,, 14 (')6 ""-' · .',=,.47 S 6.. 11 E 15.65 06 29.65 ~. '=' 6.56: E 16.15 3 ? ............... ............... !,.,.z !... E ................. !.7, 01.. 38 32.70 S 6.27 E 18.51 ................................ SF.,ERR¥=.S.UN..WELL.... ANC:HORA~Z~E ALASKA "-' - ARL. U ALASKA, INC. DATE OF SURVEY JULY 1, 1'-'-' ALASKA CALCULATED ALONG F'_.LUc. LIRE-'-' '- TRI_IE .C;LIB-::;EA I-:l-II IRSE F:FII IR~:;E' DO~-I Eli I"OTAL MEASURED VERT I CAL V:ERT I CAL I NCL I NAT I ON D I RECT I ON .'-:;EVER I TY RECTANGULAR COORD I NAi )ERTI CAL DEPTH [.EFIH '..DEPTH: DEG MIN DEGREES DEO/IO0 NORTH/':"~,UUTH ..EE. TI " :=: 0 o o '29':/9 Pl o 2929 Pl (') 4 32 ':' '-' ~' '-'" ' .... "-' '~'-' ' ........ _-._,. c, L) W :3 F):~ 41.11 .--, 1..: ~. E ~. c,. (~) i' :3100 :'::099 10 :=:0'.-.'9 10 5 40 ':; 31 0 W I 21 48 5A S '-' . ................... o.64 W 36 70 ~-(~ · 3'=' 0 C) :':: 1 ':.) :z: · 46 ::: 12':z:. 4 A 7 15 ,.z; 27 :q 9 W 1, A 4 5 ::: 40 ::; 9 0'-~ W 47.._, =) 3300 :32.97,46 3400 '~'396 '-'-=' ' ' =' ..'Z ................... ........................... .~.=.u(..) .... .=,4 ~4.61 :=:/=,00 :35.9'=:. 4(.") .-, ,-,,=,, .=,.~ ::: 7 (')o .:, 6 c,;. :3 :_=: C) C) ":' 7"" .=, 4:3 ._, -- i_l .~ ,m :::90(3 .:.'-"-"-',:, o C]. .... · ', ,,... 4 C) 00 :=: .9 7 :3 . .9 2 4100 4066, 10 4200 4157.22 4:300 4247·._,~"-'.:, ........................... ~.4.-(~:!!) ...... ~_:~!.i~: 7 ~-. 2'? 4500 4426.71 4600 4515 '- = · .~'/._1 ................ _4. 700 _4(:'05, :_-::6 4 :--: 00 46'? 4 '='.~, · ~_i._ 4~00 47:_::4. 10 5(])()0 4872.84 5100 4S~/=. 1. 16 · _,~.(.)(.) 504'P. :3:=: 530C) 5137.20 40(') .'--;'-"-' . .... ~....' 4 61 5Fi()F) Plo 11 .~/-, C) C) -=' '-' '='~'-' ._ -- . . ._I.,Z, ,': C, . 57(:)(_') · - 't' ,-, ._1. .... :.Ou 5570 4~ 5.900 F,/. ~Pi "' · '"1 ,~, .~) · :,,:~ 7 46 ='(' ":' 8':~ F,'-' c, ..:,.) S ~.7 W 1 70 "F .... · :, 15 59 W 60. :34 '-"='"' ~ :34 17 '-' '-"=~ · :~._~/=,. 1 :~. .9 27 c;.. 36 .80 W 1 . ~ 4 . .:, 24 . I 1 W :_=:424.61 10 P; ~-' '-, /.c~ '-"-' ~" '-' .'~ '~9" g'-' ~ 1 ....... ~.._..~:Z~._~-=_.._W_ .............!.,_4_! ........ --'~_~L_-_~:_&....~ ............. ~-75 · .L ..... ~ ......................... ~...=-~.!_~'~ ........ '-'~""'-' 40 1'-' - - · :,._, ~ ~=. 11 L~ 3'7 0 W 2. :3::: 114 77 '~ · =, . 47.42 W 114 '~"" 3619..._...':'~ 15 6 S :s:7 .1 '.~. W 1 . '~'-".. ~ 134 .27 S 62.17 W 138 .57 :371 ~ · _, 4:=: 17 0 S :_=:7 ~" ~,0 W i .90 1._6~ '-' ~ '-' .~._, o 7.'_=:. '-':~ W 1A5. ..................... ~ · · · · "i I--I · .',,:, 10 --,,=', .. o=, 19 S 36 :d.¥ W :~.4.9 181 20 S ~.., · ~...x . . .97.87 W 1 3.903 .... 92 '~1 ._,:'"'~ ~,'=' 36 . 'R"-"~; W 2 .~,_~q~' 20.9 .43 S 11c~.. . 07 W ~._ql'~"- .87 · -',.~ --, ,-. ~, - o '~' ' ~-' '-' '" '-"- '-' :::9'=:M,. 1(') ...._~._-, ...... ._4_~ ............ .;_--:..._:~Z~_!_1o _W... ................... !_._.E_L4_ .................. ~=._4.L-)-..~_i.--_, ........ _!_.4_~_.~ 4445. 45.3~., 4624. 4714· 4891. 4.97'?~. .95 26 =' ') ¢; '-'~ 3C) W · _~(. ,_ ,_',.. · :~.. ......... '_2_'6 ....... 2_."_2_ .......... :~._~_(2. 80 W ':'.~ 26 :37 '.3 41:30 W I_1 ,_ · 10 27 0 S 41 · 50 W ......... · -i ~ --, .-- - . 84 ...... ___~ ....... .:..' ........... ~. _4__!, R(-) W 16 28 4 S 42. 10 W 3:3 2:=-: 13 '.S 42. :3C) W O. 06 0.81 0.3:-:: O. 40 0. :3:-:: 0 · 24 0.1.9 272..9:3 S 167.51 W :31 C), 98 :::_ (3. 6.31 S 194 .57 W ._,':' ~._,':'. 66 :34 (:). ':' 1'.3 22:2.76 W '-":/ ='"" .,_ .:, .~ 7.,_:,i..:t 374· 77 S 251.20 W 442. 40'.~. 66 S 279.81 W 486. ':.,.:; · -' ~T~-- ,-' '--' ' ~,'-, '-, _4 _4.;,..._...___~,__~ ............ __~ c_) o ,~..._W._ .................... ~ ~z !,_ .~,_4 477.5'P S 3:37. 'F/2 W 576.01 511.4:3 S 367.76 W 621.01 580.76 S 42.9·75 W 713.83 615.71 S 461.44 W 760..94 0,.~..6_' ........... 6~0_._.~'_2__ q_,S__ .......... ..4'_.-:.~:_- ~D ._N ........... !~)_E:_..61 0.60 686.50 :S 526.71 W 857.1 O. 49 7'..='2.44 S 560.52 W .906.43 O,_~_!---J ..... Z~.:=-__:._..':__4'~_..._.'_-~ ............ ~.'~4,_2~L W ............... _'25~.,.68 . 1.84 794.41 S 628·98 W 1005.72 2.02 830.38 S 666.78 W 1057.88 ARCO ALASKA, PRUDHOE BAY ALASKA ANCHORAGE ALASKA INC. DATE OF SURVEY dULY 1, 1786 GO~F'UY~I' I QN... DATE B£!~;;-~ GYRO.$F.~.C[~.' SURVEY " dI_ILY 8, 1986 ,JOB NLIMBE~ AK-BO-600:4!:::.;;;. K~LL Y BLI~HI NG ELE'~:'~:~::::~:~;~::~:.}?:~. 70. 00 ].~ ]: ].~'~:]:~..:.'::: ~E~Y~.~ ~RGE"~ ...................................................................................................................................................... ; ,' ',:: ~ , .................................. SECTION CALCULATED ALONG CLOSLIRE VERT I F:AL .................... TRUE .......... SUB-..$EA MEASURED VERT I CAL VERT I C:AL DEF'TH [ EF ] Fi DEPTH ....... cr'JuB:~JE ......... !::OW.R'.=;E .......... D.O!:i:L E!S ................................. ..T.C!.'[~L ...................................................... i~- ~ i . -i INC:LINATION DIREC:TION .=,EVER I TY REC:TANGLILAR C:OORD I NATES VENTI _.AL DEG M I N DERREES DEG/100 NORTH/SOLITH EAST/WE'S~. SEL':T i 6100 ...................... Z_:.,200 . 6G:00 /=,0C):=:. :3'.-.-~ 6 40 ('D 60. c.;,. ,..-.,.. ..'='; ,=._, 6~00 6191.7~. 6600 6284. :2:2 6700 6376. '=.75 /=,:E:O0 64/-',:F~. 67 /=,?~00 6562. /=,6 7000 6/=,55. 88 7100 6749. 39 7200 684:3. I 3 7:300 69:3/=,. 'F~/_', "=""'-"-' :::9 .:7._,./ :'::8 S 48 :::9 W 0.4'-' ._,,:,.....-.,. _.""; ':'¢ :::'-.? ":"-] ..... 929 1 '-.? '-':, 781 '-"-' . ,:,o W 120:::. :=:6 ~"". '?. ?'-' ,=~;? ._F'._2.'Ti ........... ?.5 '2 '-"_ &. r'= ...... '-:'. S'.__ ':': -_ '=' '_-' '" = '~' ' '-'.=' · _, .~ 1 ,:,...'.:, .J,-,4,:,. ~:.:, ..._, 5,:, .., 4~. 6 ..~ W ~.. 7o .. 6o ._1_ .=,. _.~ ....... ml._.,_..:~.5_' _W_ ........ 1_..~.=-...4 _.. 70 5938 %":.;' '=' 5 ':' _. .... 16 .'=; 47 '") '-' .. - · .. . .:,~W O. 76 989. .. 63 ,=,46. ~:,~'~' W 1297 9::: "'-"? 5.~ '=":' '=' 03 876.93 W 1 ::: 3'~ 00 60.... 15 F; 46 69 W 1017 64.:,'" ./-,1'::'1 7'-=' '::":''::'2 .q 47 80 W (3 'P7 lO4.~ 9,'. '.:; '~0~.40 W ..... .1.:2!77.75 · ~-., ~ - _ ~ ...... _..~.......~_ . ~ ....... ~ =....'~_". ...................... _'-.."__. t .................. 't ....... ~..". t..~...'~'_' ¢~ ........ -" .................................. 6214.32 22 6306. ?5 22 6:=:'?,'?..6 7 ...... ;~ ! 64'.-.-,'2. 6/-_, 21 6585.88 20 6679. :--:'F~ 20 677:3. 12 20 0 .'_=; 47.69 W 0.38 106'?.36 S 933.35 W 1415.48 16 S 47.10 W 0.:35 1094.86 S ':-.,61.0'.~ W 1453.14 4 ~ !-=..; ,.. ~.Z~. ,i !?, _W .................. (2... _~ ............... !_t_~.~).._~...]~ ....................... ~:,%=!.._.._':-];~ ..W_ ................. ! .4_ '_.79..; ~'7. 26 S 46.10 W 0.45 1145.62 S 1015.24 W 1527.34 58 S 46. 0 W 0.47 1170.73 S 1041.29 W :::1 ::; 4A. %'0 ~ O. 47 I 1:T~5 .-'=":',~, S 1066 c:,_4 W ~ ............. ~ ......... __...,_. _~,_ ._.. ............................... _. ................................ _._.~_ i 14 S 46. 0 W 0.30 1219.40 '.=; 1091.'..o6 W 7400 7030.74 A 9 A ('D 74 '.';' 0 ':' :R ::; 45 :::(3 W .......................................... · ~. ~. ~-..-. ? ................. 7500' 7124.51 ~ 7054.51 20 17 S 45.8,'F," W 7600 7218.:--:9 ~ 714~.~y l'y 5':/ S 45.80 W 770,0 7.312.47 ~. 7.~.2..._,~:~ !~ 3".:7,'_ S,._.,...-,.."'fi '"'"') w" ............ -~-~i~) .... 721-(~],';~;'; ')'2 ~ 7:~6. ~ 19' 22 'S ~-'~-,: ~ "~ "';;' - ::¢) W 7900 7501.09 ~= 7~."~1. (~"~._. ;-:: lY 16 S 46.f. '-" ' ' ='-?~' ='= -,- 75~._,. ~ 1:~ i ~E; 46. ,30 W ,:, (.) IJ (j 7 .J .... ~.._' .J 8'=:A0 77A4.7:V '~77~.7~,,~ 1~ 27 S'-'4~.:30 W ................ ::::::O('D7879. 7/=, ~78f~"¢. 7_, 18 8 400 7974. :=:::: ~ ? 04. ;38 17 54 S 5 :=:. 0 1,4 :::.=, 0 (') 8070. (').=, ~:o O( ) 0 P] 17 51 S .;i':, :q 0 W ....... . -- .... 8 60 0 816 5.45 ~80 9 5 _. 4.5 ._ 1_ 7 :~: '._E_; ~.4_. :~ 0 W 8 7 o 0 :'": 2 61 o 9 81 'F.~ 10'F/ 16 71'-' : _. ....... o S ~,6. :~o W 8 8 o o '-"-' ~/- '~ 4 8 2 8 6. ? 4 - _ o .z,.z,-, 1/-, 1 :..~ S :'-' · _ ~.:,. 50 W 6866.96 20 13 S 45.89 W 0.03 1243.45 S 0.16 1267.63 S 0.10 1291.84 S 0.30 1315.82 S 0.33 1339.47 S 1116.82 1141.72 1166.66 11 '..-] 1. :37 1-.~15 ~-,q 1563.52 ........... !.~; .~_~L, Z4_ ...... 16 :=: 3.7'7 W 1668.2:5 W 1703. '" '-, W 1737. W 1772. '-'= W 1806.16 0.34 1362.63 S 1239.76 W 183'F~.57 0.11 1385.48 S 1263.70 W 1872.66 ............. .Q,Z2:.:~ ...... 1408.._(_~.~ .'._---_; ....... ! 28Z.~ !__ W .......... !_~(~ .. ~6.. 0.09 1430.30 S 1311.34 W 1938.05 0.69 1451.93 S 1335.11 W 1970.16 0., !-.=;7 ........... !..zJz2,_26_. ~ ....... !.3~¢_,,_ ~0 W ....... '_2_'(!.~! ,_ :~8. 0.72 14'? 1.31 S 138:3. 16 W 20:32.0:=-: 0.25 150'.-.?. 62 S 14(.')7.81 W 2062.4:-'-: 0.,_,'~ .1_ ........ ! ~7, 2__-';~ _.'.~ ........ 1.4 ;~.. (_;!:.~. _W ........... ~ (_--_)'..'.-< ~ · 07 0.60 1543.84 S 1456.07 W 2120.81 0.92 155'~.20 S 1480.06 W 2148.68 .................................................... SPER~:Y=.SUN.. WELL ... SUR.VE¥-IbiG_COI~IR~ibl¥ ............................................................................................................. ~E ....... A ....... ANCHORAGE ALASKA ARCO ALASKA~ INC. BATE OF SURVEY dULY 1~ 1'~86 ................ O~......1.r,~.~ . C~'U]~ID~ ~E BOR'S; ~::;F:Ap T C ::;I IRVFY ..................................................................................................................................................................... :': "" ~ '7 ', ................................. PRUDHOE BAY dULY 8, 1~786 dOB NUMBER AK-BO-6~04..1.:.:.. aLa.,k..A'= .... KEL. L Y BUSH I NU" "-'"'" ""'ELEM;:;;'::~;:;?~, ~?."..] 70. O0 F T. ........................................................................................................................................... ~,E~~~.~ a~ ag~:~::i:"}?~:::::~.'.:':.- - ~. VERTICAL SECTION CALCULATED ALONG CLOSURE ....................................................... -EE~.k!_.E_": S;UB-'.~._E_~ ....................... MEA;-.,L RED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY REbTAN6 LILAR COORDI DEPTH DEPTH DEPTH BEG MIN BEGREES BEG/10£) NORTH/SOUTH ' E~ ...................... . .-,(- W 91 ,r)O ,.~,/. Zi":, :'::9 ,-,=' --,,.-,, '=,=.,--, ............ o._,72. 20 17 '" · --,.. W 1 .97 1604 '..'74 '-' ;~.~ ._1,_ # ._, .. 9'2 ~') A 8736 15 B666 1.J =- ~.'-'l'.)'.-'..:: ....S 57.._'~'-?.. W A . ._6,':: 1623 .41,.,'--' 1._ , ,_-,= '-"-y . ._-,'-'._-,'" W ........................................... E R T I CA L SECT · 22A5.45 2237.62 2271 5=' ;~300 c. :_-. .-,..-, -- '-'~='~ R_9 20 ":"-' '-" 57 6:-.? W 0 11 164... 10 b 1618 72 W ~,,,,~ ..-. :~:W o/.-, .... ~. ,., . . . .,-.-':._-,U~,. 5~ c~400.. ,.,.],.-, o.-~., ~..,,, ._,'='-'~. ¢,,_-,:_,.~'-"-'='--'...P;'-':',~ 20 46 ...-c; 56 , ,.-, ~"-"- W 0 .5(:) 16,61 · (-~')'-~.'-' 1648 ,2'-~. W ~.~,,~,'-"'~'--'9. . ~'7 ,:,.=,0r) ':?: ..... : ...... ":'? ...... Z ........... '-__'.: __'2_' ......... 5' =:__. ' ......... ' _ '" ="-' ..... '~' ......................................... .~ 017, 10 o~ ~7, 10 . .-'~ ~.~ . ~ ~.,6,, _1_~. _IN_ ......._~J_,_..4~ ............ l_',~t]_~:a~__~ ........ ~:Z_7...,._6Z_JaL .......... _~Z~_~,._4 ..... '.."? 600 '? 110.73 :".-~ 040.73 20 3'.~ S .56.50 W 0 .23 1700.02 S 1706 . ~ 0 W 240'.."?. (:)4 '-?A.=iCJ '-? 1 P: ?~0:_--:7.47 ""¢ . . · _7 47 ,_4 c, __ c,.-. W 0 57 170;u.76, S 1721 7.'_-": W 2426.44 ...... .._._ .) 5 '-' P]/-,. '-"-? 'P7 A A 9'.-.' A 4 1 :--: '.~ 134, 1 S: 20 54 S = Z. :=: c) --, --, ,u,--, .. . . ................................ ._,__~_... .... W ................. 0...O,L:: .............. ~Z.l.'- - ' .... ' ...................................... ~...-._ ..... ~ = -. .'.~, .5_qL.._a ............ {~7_.~, 68 bi_ ......... '.~~.'::~.=~: ......... 975A ':)25o G::?~ ~? 180. ""-? ~-' '-' z. ,:,; 20 54 56.8'P W 0 00 172~'. "-'=- ...... .., . ~., :-'; 1751 . 63 W z4-,1 . 41 ' HORIZONTAL [,ISPLACEMENT = 246.1. _4_~ ..F.__EF=_T.._ .~_]'__.'.~I~_TH_._~.~_. DE-G~ .... 22__FLI~~~__I~_T_~_~. ..,~L ~.~,,_~2 ........................................ THE CALC:LILATION F'ROC:EDLIRES ARE BASED ON THE I_{SE C,F THREE DIMENL--;IONAL RABILIS OF C:LIRVATLIRE METHOD. ARCh ALASKA, PRUDHOE BAY ALASKA I NC:. INTERPOLATED VAI_UEF: FUR EVEN S.PEE~Y-. SUN. WE L L._ S.U.R..V.E.YING_.C.QI~IP~-~ ............................................................................................... E:I~ .......... ._~ ......... ANCHORAGE ALASKA DATE OF SURVEY dULY 1~ 1'P86 Ilr" ::: J'~:~A dOB NLIMBE~ AK-BO-60041::::.::':: ~-~-~ :~ ....'= KELLY BUSHING- ::::::::::::::::::::::::::::::::::::::::::::::::::::::: FT. 7 .. ............... ..................... 1000 FEET OF MEASURED DEPTH MEASLIRED ......... DEPTH . 'I"RUE VERT I CAL I]EE [ H SUB-SEA TOTAL 'VERTICAL RE;_. I ANOLLAR L._~URD I NATES MD-TVD VERTICAL DE.F:.TH .... NOBTH/_.'E;O!.!T.H EgST/L4E.':_:.T_ .... D IF_JFERENCE C:OR.REC;.T..I.O~ 0 ..................... 1 3000 ................. 4000 5000 6000 7.(~00 . .................. ~ ............. ~. ~..~..!. .......................................................................................................................... 1 'F~':?'.-? '-'(' " ,_-,.) 1 'fy 2'~' :~(') .-,.- . . . _. ~ z. 44 S 4.26 E 0 . ~'--'('.> 0.1 ~:: _'..-..' 9'::,C~ f9,¢') ".~- ' :,2~zy 50 41 11 '-' .......... --, 1·Z~:' E 0 . ~, .> O. 2':~. :::' ."? Y ::: '--~2 '-""-~ '"' "' '-"-' '-'""~ :4,..-. ,~..:.:,_ .......~ ~,.:._. ,. 4:3 S 11::). 07 W :26. £)8 25, .=_5!':.'? ~ i.. ?-~ ~°. ......................................................................................................................................................................................................................... 4A72. C.:4 4802.84 54~..,, 87 :--: :::'-:~:::_. _. 3'.-? W 127 .16 101 . (>8 5741 77 =A-' ,-,,.? cps, .-.,.~o .-,.-, · _,_~1 '77 o:? S 745 18 W 1:31 07 6 ...... 6 ._, 55.....-'. :-_-::.-;.,-', ,-, ...... z', ~' 5 ,:, f:5._ ~'. o ::: ,-,::: 117 o : ....... 7.-,:?.....-,:-7 .............. 1 __:< ) .......... 41 . ...'?.:. .......................... W 2..:, ............ 44.1 ..- 2 ...................................... o '_-:.5_ .-, · o '_-:'-_'_,_-, 7.=,,.?= .~:= -z =, .-, =. ._ 5 1408, 04 "' 1287 51 W 404 45 60 '-'~'~ ......... ,~. 10 :=, 15:31 30 W 451.'-::: . ......... ~ ~ ..... 1__7~.1..,_/:,_:'-i,'_~. ............ ~'~_,..1...! ................ __4Z, 1,_, '-~ "' -I -' . m-- -- · THE C:ALCULATION F. RLL. EKILIRE.:, ARE BASED FIN THE LISE OF THREE D IMEN:--;IONAL RADILIS CIF CLIRVATLIRE ME'I"HOD ,~RERRY=.'-_ELUN WELL. _,---, UR tZEY_INti_C~R~.Y ~_'t~GE ANCHORAGE ALASKA ARCO ALASKA, I NR. DATE OF SURVEY JULY 1, 1986 "'" '-'r . C n_C~E'UI~]:.J..OI:L.P..~_ Al-:::-,- 0.6 '. ............. O.~,:...__,$..=.~;.,._.! ~:__, :: :.: '-':': '' I I ,c: ,-,-, FRU[HUE BAY ' ,_IL. LY ,-. 1 .","¢,6 JOB NUMBE.F~ ALASKA ' KELLY BU~;H I NG' EL.E~:"~ii:!![]i:i:iii.~:]]i:: ~]]ii:i~O. 00 FT. ................................................ , INTERPOLATED VALUES FOR EVEN 100 FEEl' OF SUB-SEA DEF'TH 'I=" R'I _lB: ......... ----~'-='--]=':.' ~=,UB-.:,EA ~ FUTAL -'= ........................................... ~ ]':: "'' ................................... MEASURED VERT I CAL :vERT I CAL RECTANGULAR C:OARD I NAI'ES HD-TVD VERT I CAL ............ _.[!_E...F.i ..T.H. DEF.'TH _K. LE_P_ T__ _H_ ................... .N_L-'.!~.T__.H_~.%L!O.~_.T__.H_ ............. _E_A__.'_:_:_T / WE S T D I.?_F. E R E_N__C__E CORRE_~T ! ~ .... ' . 0 C). 00 - 70.00 0.00 0.00 0. (') 0 170 270 .......................... 470 570 670 770 ,=,TL ~. 00 O. O0 O. O0 0 .~00 ............................................................ : .... O. 00 0.01 O. 00 O. 00 O. 00 · '7(..) 970 0(') '.:;,C)() C)C) C)70 1 C)7C). C)0 1000. C)0 170 117 C). C) 0 110C). 0C) 27 C) 1270. C) 0 120C). 0 C) 370 1:370. C) 0 1 :::. C). c).. c). 0 ':? .0:3 ~ 470 1470.0 C) 1400. C) 0 i 1 . 1 ~= ~' ~'' · ~, 7 (') 1570 C) 0 1: (') C). 0 C) 13 '"'" '" _ . ........ : .......... -_ _-..-_ ............................... ~.~ 167C). 00 1600.00 15.73 S 1770.00 1700. C) C) 17.87 S 1670 1770 · _,:'. 4'.-? :_3 0 .30 W 0 .02 g. OC) 5.79 S 0.19 W 6.._"~'=',_, .'_--; 0 .06 W 7. ,"-'.-'_,... S 0 .74 E 0.02 0.0:3 C). 04 0.05 O. 07 0. 1'-',- 0.15 1.27 E 1.46 E 1.80 E 2.34 E O. O0 O. 00 0. O1 0.01 0.02 0.03 C). 03 ARCO ALASKA, DS 1=30 PRUDHOE BAY ALASKA MEASURED .. ~ DEF'TH I NC:. ANL. HURAL E ALA.=,KA DATE OF oLIRVEY ,JLILY 1 ....... L.uI~EU]. AYI U~_~AIE dULY 8. 1986 ,_lOB NUMBER AK-BO-60~]41 KELLY BUSHING ELEV~,''~:,=',~. "ZO. 00 FT. . I-' .... -'1 INTERPOLATED VALLE.:, FOR EVEN 100 FEET OF .:,LB-.:,EA DEF'TH ................ · ,, . ,, , SUB-SEA TOTAL ' " I-' * -']' '' VERT I CAL REL. TAN_d_ILAR L.L URD I NATES; MD-TVD VERT I CAL TRLIE VERT I CAL DEPTH 1870 !770 :2 070 2170 .......................... ~70 2:2:70 2470 ..................... 2:570 2670 2770 2:370 ......... 2:.~70 :3070 :2:171 .............. :2:27:2 :B37:2: 3474 :B576 367'.-} 1870 '00 1800.00 19.5'7 'S :3.28 E 0.17 0.02 1 '770. ("DO 1 9('DO. ('DO '..? 1 · 7('D S 4 · ¢')9 E 0. 19 ('D. (")::: t. ~ .... ~. ,_- , .~ -, ,.-, ...... ~.,~ ........................ .-. .......... '* ............................... ~.-~' ......... -" ............................... · ........................................... ' ....... -"--,~ 2070. O0 2170· O0 :.-.'~:.'_, ~ :C · .-. ~. 7 (,.). ':-? :2:70.00 2470.00 25.7 (L-... 2670.00 2770.00 2870.00 2'~70.00 :3070.00 :3170.00 . 3270.00 3370.00 3470.00 :B570.00 3670.00 2600.00 · 2700.00 2:.-:.:0o ._ 00.__ 2900. O0 3000.00 3 ! 0o_.. O0 :32 00.0 0 :2:2:00. O0 3400. O0 3500.00 3600.00 ....................................................................94.47 S 31.91 W _4____?.~. ........................ .. 110.58 S 44.'26, W 7.00 1 :--:0.10S ='-. _ ..:,~ 01 W 9.96 S E~E R R Y..r-SLIN WEE L .=, UR ~EY.INLi._CI]L~. A N ¥_ F:AI~E ................... ANUHUI:',,AL E ALASKA A~L.L ~LASi<.'~ liNC.:, n~TE OF F:;URVEY JULY I 1S.,'86 ............. ' "ii' i .... -i' ": Y 7~-'--'~"7' "111L~' ~,"'1~=]:~' , lOB NIIMBER AF-BI]I-6004::J:'':' PR. [ HL E BA : -- ,- .... :, - '. ALASKA KELLY BUSH I NG ELEV:~.:.::.i!i:.::.:~::::.~:::'::.:..';:':::70, 00 FT. _ ............................................................. : ............ ,..U A R e E R :':i! :ii .i:!:: !il :i:i ::!:i !i?: i:: ::; ..i ! i'? !: i':: :i: i}. :i -- INTERPOLATED VALUES FOR EVEN 1C)0 FEET OF: F;UB-SEA DEPTH 'I"RI_IE MEASLIRED VERT I F:AL_ ........ _[,g?T.H !]EF'TH .. SUB-SEA TOTAL VERT I CAL REc.] ANuL LAR L. uUR£ I NATE._-, MD-TVD VERT I CAL DEPTH NCIRTH/SCIUI"H EAST/WEST [iIFFERENCE _._L.:LJ~E_L_:_T_I_L_..N_-" ,, -' -i ............................................... .'. ' .... · ],-,],.-, , .~,":.' ,=- · ', 7 ,-,.-,:377 (]. 00 3 '700 00 1 ._ ...._, 1 S 76, 08 W 13. :=: 6 :':: · '- ' ."',,-',.-,,-', --,.-, - .... ,,-,' ..... '-' '-'/- 1 :--:. '~'~ ~" '-' · -, o ,-,,:,,-, o 7 ( ). ( ) ~ ) . -, o (.) 0.00 17 ,:,..,:. :, :--; 'P 5.67 W ...~. 1 .:, _ ........... ................... · .'_' ...... .--. .......... " ......... ~ ..... .?...T .................. ~ ................................................................................................................... -% -..--. :_--:'P 9.~ ':: 97 F) 00 :'::'P (')(') 00.."-'("., ~'-'. 17 tS- 118. 1 .."~ W .~.-,"~: . 78 6.79 · %'1 i-, · -- -- · 4104 4070.00 4000.00 ,.41.73 .=, 143:42 W 3:4, Z6 8 48 ...................... ~ 2 .! _4 4. ! 7P ,...P ~.-'.!~ ............... ~ .1.!.:! !;b.~ (! (2 .......................... 2_ ZZ,_6~i.._;~ ............... !. Z!_,. !._7._..E ................ _4.~.,. ~{~ ............................ )~.-.~ 4:324 427o. 00 42¢)0.00 314.68 S '201.5'..~ W 54. ,.~.9 10.90 · _1 11 52 44:36 4 :'::'70.00 4:300.0 F~ '-' 5'-' 72 '=' '-"-"-' o 8 W 66 ~ · _'~ ._ .,'~ · ._, ~ ..", ..D. . . .-,,- ,.--. .-., =' - ,'-, - ,-, I~_(-) ..~,..& 4 R4'=' 4470.00 4400.00 .:, :.-' 1.67 ..................... ~_/'-_:.=,_...~!.,-_,_..__W._ ............ 7~ ....,. 11. S .-.'; ................... f L- .. '- '--.'. ' ' 4660 45. 7 ('}., 00 4 .~_ <'~. (')., F~ 0 4:30.67 '::.. 2'P 7. 16 N 'P 0. ..,..-, ~ '-' 12 ,0:3 . , ,:: -' "/. 70 N 102 "' '~ ._. .,~¢ 11 /=_,7 4772 4670 00 4/_-,F)0.00 4/_-,8 24 "- ..... - ~-, . 4:_=:84 4770.00 4700.00 ~,n, 6 F).~ S ......... ;A~:..]...'?_C].___W ...................... 11_4__._.~ .......................... JL1-.:2'--:E;_ .................... .................................................... ?~._.~r ..... B _..-... ~ ............. ' ....................................... 4996 4870.00 4800.00, 544.75 S 3'P7.3'.:'.,' W 5110 4'P70, 00 4700.00 584.26 S 4:'::2. 'P 1 W ...................... ..'5.~;.-.--! ..... ~(.!7(! :. !P.(! ~(.~._(?0_ :. (~_(! ............... 6'_2.'~!._ f{1.._~i. ................. _4_~,.:~1 W 5:_=::37 5170.00 5100 · 00 664. 1.9 S 505.85 W 5452 5270.00 5200.00 705.12 S 544.21 W 5567 . 537~!, 00__ 5:.--_-_:_~)0.._0~ ......... .7.4_~,._~6_~_.?,~L .......... ~,30 5682 5470.00 5400.00 7:3:--:. 00 S 622.59 W 57'P'P 5570.00 5500, 00 ,'_--:3C). 19 S 666.57 W 126.7.9 12.61 140.02 13.23 153 ..~ 6 ............................... 1.~.~,..&4__ .................................................... 167.43 182.08 177,22._ 212.34 229, 47 13.97 14.65 ;L~.,._i.~-_ ................................................. 15.12 17. 1:-_-: SPE.RR Y.=,_,LIN...WELL ...... UR.VE ¥_I N Li..__L;£1ME.AN_Y ................................................................................................. R ~ ............... ANCHORAGE ALASKA ARbu ALASKA~ INC DATE OF SURVEY dULY 1 DS.. 1.:-30 CO~'U TAT I.ON_....D~IE -,, ! :.'~:--" ~.. F RLDHOE BAV ,JULY E:, 1.986 ,JOB NUMBER AK-BO-600~.I ..... ::::::: ALASKA ... K~L~Y BL~SHI N'S" ::::::::::::::::::::::::::::::::::::::::::::::::::::::., FT, - ........................ : ............ ORE.R~ZO~-D, ~ INTERPOLATED VALLIES FOR EVEN 100 FEET OF oI_B-SEA DEPTH T'RUE ':SUB-SEA TOTAL ~ · ~-: MEASURED VERT I CAL VERTICAL RECTANGI.IL. AR COORD I NATES HD-TVD VERT I CAL ........ DEPTH. DEPTH ..... DEE:TH ....... NORTH/S~.TH E~;T/.~;~.T D.I EE~R.~CE ............. C:~B~II.~ ................ 5'F~ 17 ............................. 6146 6257 /_-,476 ~z .... z, 4 5/-,70.00 5600.00 870.50 S 713.53 W 247.08 17.61 ~;~ZZQ.. O0 .......... ~7¢.!0.,..(.L0 :~_OZ.,..6&.._.':~ ....................... Z.~6.,..<.27.__ .N .................. ~./._.'~,..~_Z 1_~_. 1 ~ 5870. O0 5800. O0 .943.64 S 7.97.44 W 276. O0 13.73 5.970.00 5.900.00 977.32 S 833.55 W 287.54 11.54 .6_<.-'_~ 70_.._ .09 ..4-E.~ ~_) 0 (~ .................... !!:.! Q.~ ~_ ? ~.. ~; .................. :~_/.-::Z, '~ .....~ ......................... _'~:~.Z :_ ~.~ ...................................... !._C_~ ~._.'~9.. 6170. O0 6100.00 107:7..95 S 8.98.77 W 30/.,. 51 8.67 6270.00 /.,200.00 1065.46 S .92.9.08 W 314.56 8.05 6800 6470.00 6400. 6.907 5 '. . _ 6.. 7o 00 A50O ........................ Z~) 1_ ~ 6.670 ,.00 ......... 6699 71~' 7228 .......................7 <,':'.2 ~:-=,-- . 7441 7548 ......................7~.~ 4 ~ 7Y61 7867 00 O0 /_-.770.00 6700.00 /-,870.00 6800. O0 707£). 00 7000.00 7170.00 7100.00 '7 2 7 0: 0 0 7 2 0_0_b_ 0 c_j. 7370.00 7300.00 7470.00 7400.00 1200.61 S 1072.42 W 1 .- ..' :,. ~:.-:: S 1 O'P'P. 08 W ............. 1.~D_i.~. ~_.~: .......... 11~%_56 W 1277.80 S 1152.18 W 1303.53 S 1178.72 W .......... 1,;,~-_~.._.~ ......... ~."'04.7.9 W 1._,':' ._~ ._,':'. 73~,'-" 1 ~'-' <,'-' C.) . 40 W 1:377..97 S- 1255. :34 W 1120.44 S 988.62 W 330.36 7.86 1147.62 L--; 1017.32 W 337.89 7.53 . 1..1..7__4.~ ~?. __~ ........... 10.4. 5:~1~)___W ....................... .3..4~F~_2 ................................ _7._. 23 ................................................................... :--:52. O0 6.8.9 358.63 6.63 _36~._'21 .......................... 6.~.~-~ ............................................................. 371.88 6.67 378.4.9 6.61 _384. 'PO __6_._45L ............................................... 391.07 6.18 3.97.07 5.99 ARCO ALASI<A, IhlC:. PRU_nHOE BAY ALASKA ~EF_.F(~Y=.~_.~WELL_~.~VEY~_I~LCi_COHPAI~I_~ _ _ PAGE ANCHORAGE ALASKA DATE OF' SURVEY dULY 1, 1.986 dULY 8, 1.986 dOB NUMBER A KELLY BUSHING El .00 FT. INTERPOLATED VAL. UE8 FOR EVEN 100 FEET OF SUB-SEA DEPTH MEA._ _IRED VERT I CAL VERTICAL RECTANGLILAR COORDINATES MD-TVD VERT I CAL ..: ............ _[_EF] ']...~!' DEPTH_ DEPTH NORTH/SOLITH EAST/WEST K! I FFERENCE CORRECT I ON 7'..772 '7570.00 7500.00 1402.00 S 1281.09 W 402· .97 5..90 :-':1:34 7770· 00 7700·00 1448.64 S 1:_::31.42 W 414.41 5.67 828.9 7870.00 7800.00 1470.25 S 1356.44 W 41'~.74 5.32 84.9'.-? 8070. O0 :--:000.00 150'.-?. 61 :--; 1407.7.9 W 42'~..95 5.07 8604 8170.00 8100.00 1528.04 S 1433.21 W 434.77 4.82 870.9 8270.00 8200.00 1545.34 S 1458.32 W 43.9.31 4.55 :_~,_, 1 :~ _,.=,70.00 o..~00'-'~' ' '. 00 158,1.18 S 1483 .30 W 443 .60 '-' '"~ ~'~?] 92 c. 150~ '~c'W 447 ~8 ,_,c,,~.. 17 8470.00 ~40~ .00 1 ~ ...... . ~,~ , ' '"':' ~ 5 '~ ~0~._, '"~ ' ' ' ""m .... ~ - "' '~ " o..,70. ~)0 ~-,.~0~ ~, ~ ~¢ ~ 1. ,V 1.6 ~ o 1537 6~ W '.-.?12.9 8670.00 8600.00 1610.2.9 S 1568.58 W 45.9.44 '.:~236 8770.00 8700. O0 1630.1.9 S 15.9.9. ?3 W 466.11 S/342 ,'_:::--:70.00 8800.00 1650.07 S 16:} 1.31 W 472.7.9 8.970. O0 8.900.00 .9070. O0 .9000. O0 .9170.00 '~ 100.00 ',-.7250. :_::.9 '.-."'.' 180.8.9 172.9.25 S '?449 1670.72 S 166:3.03 W 479.71 '.:~556 16.91.55 S 16.94 · 10 W 486.48 .9663_ _. 171'-~ ~_o -. 4,93.41 '--"..--~, ~ ! 725.74 _~ '7750 1751 · 63 W 4.9.9 · 1 1 4.2':-~ 4.38 5.14 ..... 6.32 6.67 6.67 6..92 6.77 6..93 5.70 THE C:ALE:ULATION ' 'l ..... -' FR_u_.EDURE._-, I_I:--;E A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATLIRE) POINTS ANL. HuRAL E AL. ASI<A ARC:O ALASKA, INC: DATE OF .:,LIRVEY ,_iLILY 1 PRLIDHOE BAY ,JULY 8, 1'~86 dub NLMBER ............................................................................. INTERPOLATED VALUES FOR SPECIAL SLIRVEY F'OINTS I R..IE: SUB-SEA TOTAL MEASURED VERT I CALVERT I C:AL RECTANC~I ILAR COORD I NATES ....... DE P.T_H D ELF'. T H . O E FL'IH N.QB T.H/.~; OUT H ................ E A;-;.]'ZNE~.T. ................... H~'t~_' ~E( ........................ ""'~ '-"-' 'q '-'=.=,'-' 6:2: 1601 '--' ,_-, :,..-._-,. 6._ ,.-_,._,._ ._-,. .._, 1 S 15..~~ . '~8 W TOF' .'_=;AG R I VER ,z,/. ~.-:, 7'O ;E!~i;~!2.,..7.0 ......................... I,~,(!~,~;~.~.~._S ................. I_~.~.,.~;..,..I..;J:;_..N .................. ~_Q.EL._.'~.;HUBLI I< !,,d...!.r~-,. ~ ~ ........... _ ,=,'~' /'=, ._.=; '"-,. . '.~(~ 1621 . 16 ._'=; 1585 .81 W TOP SADLEROCH I T ,=,7,:,0 '-"-' . .. . o.-', 16~6 "-"':' ....... o 1/-,09.60 W GAS/OIL CONTACT ,~/(:)(:)~ .-,.-, · . '.-.-,(')?~.-.: ~:... .................. ~.1 :~/-',.'- ,-- ?':.-.'. ..... i~.' 2.=, ............ 17~.)._,. 1._-,.:~_ ..... :Z .......... ~ nJ:L/WATEr2_ ................ : ...-:...-_L.U~TAL. T '.--,'():~7 ~7 17(:)'.-.-/ 76..:, '-'172'1 73 W ;_-,L R~EY []E~TH .... ~ . '-' I' '?~ 80_, :~? ~._7~':~: :~.~ ;~ .......... ~.Z~_!,...~_~_~ ............... .T.~TAL._..~E:_~.T_H._[j_Bi~I..E~ ARCO ALASKA, INC. DS 1-30 ~=:.. [.~ ~).T I ~.BCJ~H_I;J_ .=, U MI~...IBY. ................................................................................................... DERIVED I I'S;ING.._ DIL DEPTHc, AND .:,FERRY SI_IN ol...IRVEY DATA -MARKER- MEASURED BEPI'H -TVD THICKNESS WITH REF, TO WELLHEAD BKB BKB SLIB-SEA VERT I CAL ( OR I G I N- 11 ;~SFNL 1533FWL TOP '.--;AG R I VER 9F)8(-) '-' '-'":' 'a'='=":'- 63 1601 ": 1 ~-'='-' '--" ' ' · . . o 6 ~.._,. 6:3 c ._,._, ....... ,.,..:,..~ , .... TOF' SHI_IBL I K ,~) 111 8/-,~'> 7¢) :::~82 7(') ........................... ;L6.()._6.,_:~/..4_~... ........ ' ~'/. '-' T 0 P S A n L E R 0 C: H 'f. T 9. 1 ,:,"",=,'-' 872 ~, '.-.-/0 ~"-~_/-,_ Pi_ 4, 'P (-) ! 621, ! z-_, '='._, 1 ._ c, ._,, 81 W i--o _~A.:,/0 ! L CONTACT '.-:~2Z_-,'P '-'"" -) '"" '-'F ,:,,:,(.)(. 83 ,:,7._-, .) '-"-' _ . . . ,_-,._", 1/-,3A --,.-,o ..... .-,._-,._, 1A09 60W TOP ZF~NE :3 '.~411 ':"-'~":"~' :.--:0 :~,.....~..._-.:-:.-.L, TOP Z ONE~'-' 94"?'.~. . ,-,c~¢~-/ 0-,,_~.-, ~.. ,=, :. .... 43 o....-7.43 1676.43S 1671 ...., ZW HOT 9~A 1 9074. '- '" . 16 .-]~.. 43S 16'~.~ 42W .... '..'._-, ?004 23 -' '-' . .. OIL/WATER CON'I"ACT "P5'P4 c~_10~ ! 1 '.-]0:--:~. 11 PLUG BACK TD 'P6'P7 S¢201. '-'.:,,=:"' 91:31 . 3::: 1718 . ¢.~2:~. _ 1 7.=,'-'~._,. 78W TOTAL DEPTH [ R I LLER 9'?.~C~ ............... '-'.~'.~'F,F~ :=:9 91 :=:¢-). 89 1729 ~._'-'R'-'.=, 1751 63W EXTRAFLLATION BELOW DEEPEST '.:;TATION. '2) COMPLITER PROGRAM - F;PERRY SLIN THREE DIMENSIONAL RADIUS F~F CLIRVATLIRE. DA TA CALI-_J__I_L_A..T ! 0N_ A_._N[_I _I _N_.T_E_. R_'..F.'.I__-,!_L_A_ .T.!_..L-!~ ..._By._ _R_~_EJ.I__I___!.L_:i... CIF C:LIRVATLIRE .......................................................... D-!8_T_~_ OF SURVEY. J_ll~y ._1~ ..... 1_;~.~ .......................................................... COMPUTATION DATE JULY 8, 1786 JOB NUMBER AK-BO-60041 ~.-'~E:.~_LY BUSHI~..ELEV..=__ .70..~20._..E.'[. ................................... SCALE ;- 1 INCH 78 SOO. Q0 / SO0, O PRUOHBE 8AY ARCO ALASKA, OS 1-~O JULY l, 1986 AK-80-60041 !NC. TRUE NORTH 9750 /./ ---5OO. O0 --lO00. O0 --1SOO. CO l_2000.00 MOB ~ ZSNTAL ~8OJECT ~ O~',~ 0.00 5CRLE PRUOHOE ORY 05 t-80 qK-SO-6004t :- l INCH TO 2000.00 / 2000.0 qRCO RLRSKR, JULY t, [986 2000.00 4000.00 6000.00 8000. oo CO00. rjo! 9250. ~9750 I 2000. CO YERTT_CflL PROJECTION I 6000. O0 RE[EIVED Alaska Oil & Gas Cons. Oommissio:-, Anchorage TE£ECL2 Teleco Oilfield S,*--~-es of Alaska Inc. 6116 Nielson Wa Anchorage, AK 99502 (907) 562-2646 July 1, 1986 JOB # 508 TAK ARCO ALASKA WELL: DS 1-30 PRUDHOE BAY PARKER 141 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to ARCO. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures I ECEIVED J U L 2 8 1986 0ti & Ga~ C~s. C~mmi~i0~, A ,~gNJ~T COMPANY TELECO OILFIELD SEVICES JOB 508 SURVEY CALCULATIONS Date Page 06/20/86 Company-. Well: Location: Rig: ARCO ALASKA DS 1-30 PRUDHOE BAY PARKER 141 TELECO Job # 508 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.30 degrees 31.30 degrees 227.00 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** ASSUME VERTICAL AT TIE-IN 2950.00 0.0 209.9 S 29 54 W 2950.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD SURVEYS 3124.00 6.3 209.9 S 29 54 W 3123.65 9.13 8.28S 4.76W 9.55 S 29.910W 3.621 3312.00 9.2 206.4 S 26 24 W 3309.91 33.12 30.63S 16.72W 34.89 S 28.636W 1.562 3502.00 11.2 216.9 S 36 54 W 3496.90 65.52 59.23S 34.35W 68.47 S 30.114W 1.433 SINGLE SHOT SURVEYS 3690.00 16.0 218.3 S 38 18 W 3679.57 109.12 94.24S 61.31W 112.43 S 33.050W 2.559 TELECO Job # 508 TAK 06/20/86' Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG~ DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 3957.00 20.5 219.3 S 39 18 W 3933.08 191.85 159.39S 113.69W 195.78 S 35.501W 1.689 TELECO MWD SURVEYS 4434.00 26.4 218.7 S 38 42 W 4367.85 385.65 310.86S 237.42W 391.16 S 37.372W 0.322 4952.00 26.8 218.7 S 38 42 W 4831.02 615.18 491.80S 382.54W 623.06 S 37.877W 0.077 4748.00 26.8 220.1 S 40 06 W 4648.93 524.01 420.72S 324.16W 531.12 S 37.614W 0.000 4905.00 27.0 221.1 S 41 06 W 4788.94 594.60 474.66S 370.39W 602.07 S 37.966W 0.316 5092.00 28.0 221.8 S 41 48 W 4954.81 680.54 539.37S 427.54W 688.27 S 38.403W 0.562 5280.00 28.7 221.8 S 41 48 W 5120.26 769.45 605.89S 487.08W 777.40 S 38.796W 0.372 5438.00 29.7 222.6 S 42 36 W 5258.18 846.26 662.99S 538.86W 854.36 S 39.103W 0.680 5416.00 29.3 222.6 S 42 36 W 5239.03 835.45 655.02S 531.52W 843.55 S 39.058W 0.000 5707.00 31.3 225.0 S 45 00 W 5490.27 982.02 760.98S 633.12W 989.92 S 39.760W 0.803 5803.00 31.8 226.8 S 46 48 W 5572.08 1032.24 795.93S 669.20W 1039.87 S 40.056W 1.110 5834.00 32.7 229.9 S 49 54 W 5598.30 1048.78 806.92S 681.55W 1056.24 S 40.186W 6.075 5887.00 31.8 230.3 S 50 18 W 5643.12 1077.02 825.06S 703.25W 1084.11 S 40.443W 1.746 5919.00 31.0 229.9 S 49 54 W 5670.43 1093.67 835.76S 716.04W 1100.55 S 40.589W 2.585 5964.00 29.4 228.9 S 48 54 W 5709.32 1116.28 850.49S 733.23W 1122.92 S 40.765W 3.727 4277.00 26.0 219.4 S 39 24 W 4226.98 317.00 257.03S 193.75W 321.88 S 37.010W 1.719 TELECO Job # 508 TAK MEAS DIRECTION TRUE VERTICAL DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION feet deg deg deg/min feet feet 06/20/86 Page 3 COORDINATES CLOSURE DOG LEG N/S E/W DIST ANGLE SEVERITY feet feet feet deg deg/100 ' 6013.00 29.0 228.2 S 48 12 W 5752.10 1140.18 866.31S 751.15W 1146.61 S 40.927W 1.074 6045.00 29.0 228.2 S 48 12 W 5780.09 1155.69 876.65S 762.72W 1162.00 S 41.024W 0.000 6077.00 28.8 228.5 S 48 30 W 5808.10 1171.15 886.93S 774.27W 1177.34 S 41.120W 0.772 6108.00 28.2 226.8 S 46 48 W 5835.34 1185.94 896.89S 785.20W 1192.04 S 41.201W 3.256 6139.00 27.6 227.1 S 47 06 W 5862.74 1200.45 906.79S 795.80W 1206.47 S 41.270W 1.990 6234.00 25.7 226.1 S 46 06 W 5947.64 1243.05 936.07S 826.76W 1248.90 S 41.452W 2.055 6265.00 25.4 226.1 S 46 06 W 5975.61 1256.42 945.33S 836.40W 1262.23 S 41.501W 0.972 6327.00 25.4 226.1 S 46 06 W 6031.62 1283.01 963.76S 855.57W 1288.74 S 41.597W 0.000 6420.00 23.2 226.1 S 46 06 W 6116.37 1321.27 990.28S 883.16W 1326.89 S 41.728W 2.366 6555.00 22.3 227.5 S 47 30 W 6240.87 1373.48 1026.02S 921.21W 1378.89 S 41.919W 0.778 6711.00 22.0 226.8 S 46 48 W 6385.36 1432.29 1066.01S 964.33W 1437.47 S 42.133W 0.256 7025.00 20.9 225.7 S 45 42 W 6677.60 1547.10 1145.41S 1047.28W 1552.02 S 42.437W 0.373 7120.00 20.5 225.0 S 45 00 W 6766.47 1580.67 1169.01S 1071.17W 1585.56 S 42.499W 0.495 7350.00 20.2 225.0 S 45 00 W 6982.12 1660.61 1225.54S 1127.75W 1665.47 S 42.620W 0.131 7663.00 19.7 225.7 S 45 42 W 7276.33 1767.36 1300.60S 1203.73W 1772.15 S 42.785W 0.177 7975.00 19.1 226.4 S 46 24 W 7570.62 1870.97 1372.52S 1278.34W 1875.62 S 42.965W 0.206 8147.00 18.6 226.8 S 46 48 W 7733.39 1926.54 1410.70S 1318.71W 1931.08 S 43.070W 0.300 TELECO Job # 508 TAK 06/20/86 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG' DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 8286.00 18.0 231.0 S 51 00 W 7865.36 1970.16 1439.39S 1351.59W 1974.50 S 43.198W 1.042 8600.00 17.1 234.5 S 54 30 W 8164.74 2064.35 1496.69S 1426.95W 2067.91 S 43.634W 0.442 8861.00 16.5 239.4 S 59 24 W 8414.60 2138.62 1537.82S 1490.16W 2141.37 S 44.098W 0.589 TL_ECO 0 i 1 ~ i ~ 1 d S~rv i c~ VERTICAL PROJECTION A 0 2000 9000 ~000 SO00 6DOD 7OOO 8000 9000 1DODO 1 1 ODD 1000 2000 :9000 4000 5000 BOOO -.-,--~ 'P-l--l- - . ~",' t-T-', ....... , -~'~' ,- FT~T- ,'-j- '3'~"~-'~"~ ~'-r-'~'-r-r'~ Z' ht!--'~ ..... i-.--H-~¢ ' ' ' -' !--, .... ~'~-'~' 4-" l-'~zq:~ ...... r'T'i .... t'~'~ ~ r-~'-w~--~,~' w~.~-'~'~ .... f'"'+ ........ 1 ' ' i , I :' [ ~ t I . ~ I ~ I ', ,, I I ~ . c. ~...~ .... ' ' 1, I i .'~ ~ !Ii -,.,., , ~ : , I I . ...... -"t ...... i .... ; .... ; ...... F ~% lissio: VERTICAL. SECTION TL,_ECO Oil~imld Smrvicms PLAN VIEW 24.00 2000 1800 1200 800 4.00 0 7/~0~ .:~o .,, ~ .. i t.. :-~-- WEST 400 800 12O0 -r 2001~ 2400 2800 S2OO LOCATED IN THE APPENDIX [21 WFL UI IPR LOG [21 CALIPER SURVEY [21VOLAN ffi CURVE DATA [21 STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: ARCO Al. aska, Inc,. P.O. Box t0e360" Anchor-age, ALa.s;ka 99510 DATE' Ha~-ch 2, t o, 8,-, REFERENCE' ARCO Cased Hole Final I---5¢ ,._'-'--t 9'-87. , F'e~-f., Record Run t -71,.., ~°--t9'-87. F'erf, Reco~"d Run I , ....._.,'z°.- ,"~-i 9--87 F'e~- f ,, Rer-o~- d_ F;..' u n t --~',_,,_, ~'~-'~ t.,:. -'87 Pe'rf , Reco'rd F;.fu'n t --S4 2--t 9-87 F'e~~f_. Reco'rd Ru.n -~-'~18-9 8-tt-86 6CT Di'rec±io'na[ ~u'r'vey RtiFI --],_, [;R in Ca sing . 8--9 8-i t ~: '~ F;.'un 8-9 8-t I -86 ~,,:Lueeze Reco'rd Run t , 8--9 8--t ~-86 r'.ET Ru.n ~'c h ,~,:: h :~' r: h ,? c h ,?,:: h .'~'c h ,.";' c h ~-,ch F'Lea~e sign and 'ret:.u'rn The a'.l:t:ached copy as 'rece ip'.l: of' Rec'~ i vect 8y .................... :-' ' ""'- I,I'~ ~... A T,'.'3- i ''~ '~' o ~ ,-':~ : . . ,---- ---- TRAN¢.~, ~87~40 i~ Ap p '.," c:;./e d ..................................................... D 15,' T F;,' .T,. ~L.IT I ON d a 't' a, · ~ Cent~-aL Fi Les: ~ E:hevl-on F'B WeI. L F'i I. es D & M F;.'. & ][) '"'.,.E x 1- erts- i o n E x p L o 'r :'~ *,. i o n :~: ,:,'" o h i;-~._ :~ [--xxon :~ ~£taf. e of Alaska M a 'r a t:. h o n .I',: T e x a c o .... Mob i L 'I1' STATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMbs. 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other Stimulate [] Plugging [] Perforate ~. Pull tubing [] COHPLETE 2. N a,r~e~,o~ ,O p.e rato. r 5. P. KL, U A1 asKa ~ I nc. 3. Address P.O. Box 100360 Anchorage~ AK 99510-0360 Datum elevation (DF or KB) RKB 70 ' 4. Location of well at surface 1135' FNL,1533' FWL, Sec. 8, TION, R15E, UM At top of productive interval 2524' FSL, 53' FEL, Sec. 7, TION, R15E, UM At effective depth 2426' FSL, 203' FEL, Sec. 7, TION, R15E, UM At total depth 2416' FSL, 219' FEL, Sec. 7, TION, R15E, UM n it,,or PEoper,ty. name ruonoe Bay unit 7. Well number 1-30 8. Approval number 280 9. APl number 50-- 029-21606 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 9750'MD 9251 'TVD Effective depth: measured 9697 'MD true vertical 9201 'TVD Casing Length Size Conductor 80' 20" Surface 2490 ' 13-3/8" Producti on 9716' 9-5/8" Perforation depth: measured None feet feet feet feet Plugs (measured) EZSV ~ 9697' Junk (measured) None Cemented Measured depth Conductor rpt not rec'd 1lO'MD 2000 sx CS III & 2519'MD 400 sx CS II 950 sx Class G 9742'MD 450 sx CS II, & 300 sx CS I True Vertical depth 110 'TVD 2519'TVD 9243'TVD 12. true vertical None RECEIVED Tubing (size, grade and measured depth) 4-1/2" L-80 tbg w/tail (~ 9007' , , Packers and SSSV (type and measured depth) Stimulation or cement squeeze summary N/A Intervals treated (measured) 0 6 1987 Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Iniection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Wel 1 Hi story w/Addendum, dated 08/06/86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ,~ GYRO 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (DANI) SW0/165 Date -~L)~7 Submit in Duplicato~ · ARCO Oil and Gas Company Daily Welm History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District 1County or Parish I Alaska IL .... Field or Unit Prudhoe Bay Auth. or W.O. no. Title AS0855 North Slope Borough ADL #28329 Completion Accounting cost center code State Alaska IWell no. 1-30 WWS #1 API 50-029-21606 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete AR.Co. W.I. 21.66% Date 1/10/87 I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0230 Hrs. Date and depth as of 8:00 a.m. 1/10/87 thru 1/11/87 Complete record for each day reported 9-5/8" @ 9742' 9697' PBTD, RR Diesel Accept rig @ 0230 hrs, 1/10/87. ND tree, NU & tst BOPE. Tst csg to 3000 psi. RU Schl, make GR/JB rn, RD Schl. RU & rn 271 its, 4½", 12.6#, L-80 BTC AB Mod tbg w/SSSV @ 2198', SB-3 Pkr @ 8890', Shear Out Sub @ 9007'. Displ well w/diesel. ND BOPE, NU & tst tree. RR @ 0700 hrs, 1/12/87. Wait on weather to move rig. FE 6 1987 Alaska 0il & Gas Cons. Oommissio~ Anchorage Old TD Released rig 0700 Hrs. Classifications (oil, gas, etc,) Oil Producing method Flowing INew TD PB Depth Date 1/12/87 K nd of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit 9697' Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time :Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % ~OR Gravity Allowable Effective date corrected The a,,,._,,,~bove,is correct gnat t~ IDate { Title 1/30/87 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 1-30 7/1/86 RU DA, rn CBL f/9684'-7800' w/o press and w/1000 psi f/9000'-7800'. Repeat log f/9000'-8600'. Log DV ti f/4979'-4600', POOH, LD CBL. Rn gyro f/9650'-surf. RD DA. 8/03/86 Arctic Pak w/300 sx CS I, followed by 125 bbls Arctic Pak. Drilling Supervisor ARCO A/mska, In~6.. ~.:': .~ F',,O. Box 'i 00360':.j-- .. .-.; Anchorage, ALa.s:k'a:" 995¢~~ DATE · September REFERENCE' ARCO 8, t986 Cased Hole Final *~,,-'i--:30 6-30-86 ,ii~ 4-t 7-~ 0-86 4-9 7-9-86 'J 'i -'~ 7 6-29-86 '~ t -.J 8 6-29-86 ACBL/¥DL/SIN/GR Run Gamma Ray Log Run CNL/GR MuLti-Space Run ~, 5' ACBL/VDL/SIN/GR Run ACBL/VDL/$IN/GR Run ~, 5' Dre~s Dre~-s Dre~s Dress Dress Please sign and Received By HAVE A NICE DAY L Jnda Hu [ce ATO-J 529 TRAN$ reCurn the attached copy as receip¢ of data. DISTRIBUTION Central Fi [e~ Chevron D & M Extension ExpLoration Ex xon Marathon Hob i L ..-'"- F'hi L [ i p~ F:'B We L L R & D -,-'"' ~'oh i o ~ 5:'t'ate of ~ Texsco F:'i Les A Lasl<a ARCO Ala~'ka, Inc F:', O. Box Anchorage, A l a.s'ka 995 ~ ~ DATE' Augum't 20., i9'86 REFERENCE' ARCO Magnet i c Tapes' w/lib'ting 6-23-86 DIF'L, AC, CN/CDL 5-20-86 CN/CDL, DIFL, AC 6-9-86 DIF'L, AC, CN/CDL 6-23-86 DIF'L, AC, CN/CDL PLease sign and return the attached copy as receipt ot' data. Received By_ HAVE A NICE Linda HuLce ATO-~529F TRAN3 $86523 DAY~ DISTRIBUTION Central Fi Les Chevron D & M Extension Exp Loration Ex xon Marathon Mob i [ Phi I L ip.~ F'B WeLL Fi Le.~ R & D Sohio Texaco ARCO Ata.'.~ka, Inc, I::'~[..I, Box ~ Anchorage, ALaska DAI'E' J:.,.I.y 2 -4, t 986 F;.: E I-- E R E i".~ C E · ARCO Directio'nml- Data ..:- Z / - 86 i"l W D D i r e c .1~ i c, n a I. T e I. e c o ~ 'l .... ,..'P 9 ,.,:- -. t 7 - 86 H I,,! ....... 'l) i') i r e c t i c. n a L T e I. e c o '~'~t-.-.30 '? .... I..-86 HUD I) ir.~..~ctionaL "f'eLeco ~ 'i.- ,3 -i '~', -- .,.. '~ ,_ ''~ - ,...° ,..~- ~'t W I~. D i r e c t i o n a L 'r~. .... !. c,. ~.. o ~ i E~;-'Jl 7-9.-.86 i'tl4I) !l i r ec ~ i ona I. l'e I. eco ti-~? 6-t0-86 HWO D irer..tionaE Tel. eco ~'lt-t8 ?-i -86 HWI) !)irec'~ionml. Tel. eco ' tt "~ .... . · - -.,..4 '? '? 86 ~'iWD Directional. l'~'~l, eco ~'!..,° -' q'.., .5 -- "~ ': -- 8 6... ..; . HWD D ir ec t' i o'na I. Te t. ~co... F'i. ea.'._,-e .~ign and l"F..,'l'tir'n 'l'he a'l-'.l:a(:hed copy a.s i"eceip'i' of dat'a, D I ."';' T I:;.'. ]: B LJ T I 0 N C e'n -I: r a [ F" i I.e.-.:;' (.E.' t"~ evr o'n :()&Pi E x t:. e n.s i o'n [.': x p I. c,'r a t.- i o n Ex Harm t:. h or~ i'-tc',l.~ i L AJaska Oil & Gas Cons. Commission Anchoraoe STATE OF ALASKA ALA~,.,A OIL AND GAS CONSERVATION CON,,,,.,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend .'~ Operation Shutdown~ Re-enter suspended well -- Alter casing _-~- Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order - Perforate - Other '- 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 70'RKB -- 3. Address P. 0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1135'FNL, 1533'FWL, Sec.8, TION, R15E, UN At top of productive interval 2640'FNL, 80'FEL, Sec.7, TION, R15E, UM (approx.) At effective depth 2471'FSL, 176' FEL, Sec.7, TION, R15E, UN (approx.) At total ,dc~st:)tLh' 246:3 189'FEL, Sec.7, TION, R15E, UH (approx.) p6 Unit or Property name 'rudhoe Bay Unit 7. Well number I -30 8. Permit number 86-111 9. APl number 50-- 029-21 606 10. Pool PrOdhoe Bay Oil Pool feet~// 11. Present well condition summary Total depth: measured 9750 true vertical 9263 Effective depth: measured 9697 true vertical 9212 Casing Length Conductor 80' feet feet feet feet Size 20" Surface 2490' 13-3/8" Producti on 971 6 ' 9-5/8" Perforation depth: measured Non e true vertical N o ne Plugs (measured) EZSV ~) 9697 ' Junk (measured) None Cemented Measured depth Conductor report 110'MD not available. 2000 sx CS Ill & 2519'MD 400 sx CS II 950 sx Class G & 9742'MD 450 sx CS II ~ue Verticaldepth 110'TVD 2519'TVD 9255'TVD Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12.A~:ea~l~ ml~ ~tsSt o r ¥ Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation February, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only ( DAM ) SA/076 Date Conditions of approval Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. [] Plug integrity I-I~BO.B,Test-...,~,; Location clearancel by order of Commissioner the commission Date Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE AS0855 Parker #141 Count, parish or borough North Slope Borough Lease or Unit ADL #28329 ITitle I Drill API 50-029-21606 Operator ARCO Alaska, Inc. IState Alaska ARCO W.,. 21 · 66% IPr or status if a W.O. Spudded OrspudW.O. begun IDate 6/11/86 IHOur Date and depth as of 8:00 a.m. 6/11/86 6/12/86 6/13/86 6/14/86 thru 6/16/86 6/17/86 6/18/86 :Complete record for each day reported 0900 Hrs. 20" @ 110' Accep= rig @ 0430 hfs, 6/11/86. 20" @ 110' 1639', (1529'), Drl Wt. 9.3, PV 12, YP 51, PH 8.5, WL --, Sol 7 Spud well @ 0900 hfs, 6/11/86. Drl 17½" hole to 1639' 13-3/8" @ 2519' 2525', (886'), NU BOPE Wt. 9.4+, PV 15, YP 48, PH 8.0, WL --, Sol 7 Drl 17½" hole to 2511', 10 std short trip. TIH, hit bridge @ 2313', wsh & rm to 2511'. Drl to 2525', CBU, POOH. RU & rn 59 its, 13-3/8", 72#, L-80 BTC csg + 1 jr, 13-3/8", 68# K-55 w/ FS @ 2519', FC @ 2428'. Cmt w/2000 sx CS III, followed by 400 sx CS II. Displ using rig pmps, bump plug. Perform 150 sx CS II top job. NU BOPE. 13-3/8" @ 2519' 5660', (3135'), Drlg Wt. 9.5+, PV 7, YP 4, Instl tbg spool, NU & Conduct formation tst to 13.2 ppg EMW. Drl & surv 12¼" hole to 5660' 3124', 6.3°, $29.9W, 3123.74 TVD, 7.98 VS, 9.08S, 2.43W 3690' 16°, S38.3W, 3679.64 TVD, 108.50 VS, 95.45S 59.33W 3957'[ 20.5°, S39.3W, 3932.35 TVD, 192.35 VS, 161.47Si 112.42W 4592', 26.8°, S38.7W, 4509.11TVD, 456.03 VS, 367.57S, 280.76W 5092', 28°, S41.8W, 4953.76 TVD, 683.19 VS, 541.40S, 429.26W 5438', 29.7°, S42.6W, 5256.96 TVD, 849.29 VS, 664.88S, 541.22W PH 8.5, WL --, Sol 9 tst BOPE. TIH, DO cmt, flt equip & 15' new hole. 13-3/8" @ 2519' 6310', (650'), Navi-Drl Wt. 9.6, PV 10, YP 10, PH 8.5, WL 17.6, Sol 9 Drl & surv 12¼" hole to 6310'. 5803', 30.8°, N46.SW, 5570.48 TVD, 1036.03 VS, 797.72S, 672.68W 6234', 27.2°, N46.1W, 5949.63 TVD, 1240.67 VS, 937.76S, 821.91W 13-3/8" @ 2519' 7075', (765'), Drlg Wt. 9.7, PV 10, YP 9, PH 8.5, WL 10.8, Sol 10 Drl & surv 12~" hole to 7075'. 6414', 23°, S46.1W, 6113.68 TVD, 1314.73 VS, 989.12S, 825.28W 6711', 22°, S46.8W, 6388.39 TVD, 1427.60 VS, 1066.16S, 957.77W see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate 7/18/86 ITM Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska I County or Parish State North Slope Borough ILease ADL #28329 or Unit Alaska Prudhoe Bay Well no. 1-30 Date and deptl~ as of 8:00 a.m. 6/19/86 6/20/86 6/21/86 thru' 6/23/86 6/24/86 6/25/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 2519' 8090', (1015'), Drlg Wt. 9.7, PV 16, YP 11, PH 8.5, WL 6.1, Sol I1 Drl & surv 12¼" hole to 8090'. 7025', 20.9°, S45.7W, 6681TVD, 1542 VS, 1145S, 1041W 7663', 19.7°, S45.7W, 7280 TVD, 1762 VS, 1300S, 1198W 7975', 19.1°, S46.4W, 7574 TVD, 1866 VS, 1372S, 1272W 13-3/8" @ 2519' 8380', (290'), RIH Wt. 9.7, PV 12, YP 8, PH 8.5, WL 5.9, Sol 10 Drl & surv 12¼" hole to 8380'. 8286', 18°, S51W, 7869 TVD, 1965 VS, 1437S, 1347W 13-3/8" @ 2519' 9722', (1342'), Logging Wt. 10, PV 15, YP 12, PH 8.5, WL 6.1, Sol 12 RIH, wsh & rm f/8195'-8380', drl & surv 12¼" hole to 9722', 15 std short trip, C&C, TOH. RU DA, RIH w/DIL/GR/BHCS/SP, tag bridge @ 9430' WLM, TOH, RD DA. RIH, rm 9389'-9722', circ out gas cut mud, POOH. RU DA, log DIL/BHCS/GR/SP f/9715'. 8600', 17.1°, 854.5W, 8168 TVD, 2060 VS, 14958, 1422W 8861', 16.5°, 859.4W, 8418 TVD, 2134 VS, 1535S, 1486W 9722', 20°, S57.3W, 9236 TVD, 2398 VS, 1677S, 1715W 13-3/8" @ 2519' 9750', (28'), POOH Wt. 10+, PV 14, YP 11, PH 8.5, WL 6.2, Sol 12 Rn DIL/BHCS/GR/SP f/9715'-2518'. Rn CNL/FDC/GR/CAL f/9700'-6700' strip log f/4970'-4700', RD DA. RIH to 5000', circ out gas cut mud. Fin RIH to 9722', drl to 9750', C&C, circ out gas cut mud f/10+ ppg to 6.9 ppg, POOH f/9-5/8" csg. . Rn 9-5/8" @ 9742' 9750', 9701' PBTD, WOC Wt. 10, PV 15, YP 12, PH 8.5, WL 6, Sol 12 Chg out & tst rams. RU & rn 246 jts, 9-5/8", 47#, L-80 BTC & NS-CC tbg to 9742'. Cmt in 2 stages. Stage 1 w/300 sx C1 "G" w/8% gel, 3% KCL, 2.2% FL-28 & 1 gal/lO0 sx FPS-L, followed by 300 sx C1 "G" w/3% KC1, 1.12% FL-28, .3% CD-31, 2% A-2 & 1 gal/100 sx FP-SL. Stage 2 w/450 sx CS II. Bump plugs. WOC. FS @ 9742', FC @ 9701', By-pass Baffle @ 9701', Shutoff Baffle @ 9664', Stage Colr @ 4980' The above is correct For form preparation and distrib'~"~on see Procedures Manual Section 10, Drilling, Pages 8§ and 87 IDate ITitle 7/18/86 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough J Alaska Field Lease or Unit I Well no. Prudhoe Bay ADL #28329 I 1-30 Auth. or W.O. no. ~Tit e AFE A80855 I Drill Parker #141 API 50-029-21606 Operator ARCO Alaska, Inc. Spudded or W.O. begun A.R.Co. W.I. 21.66% Date 6/11/86 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0900 Hrs. Spud Date and depth as of 8:00 a.m. 6/26/86 6/27/86 6/28/86 Complete record for each day reported 9-5/8" @ 9742' 9750' TD, 9701' PBTD, PU RTTS Wt. 9.8, PV 15, YP 14, PH 8.5, WL 6, Sol 11 WOC. ND BOPE. Instl & tst pack-off to 2000 psi. NU & tst BOPE. TIH to 4979', tst csg to 3000 psi. DO DV & plug, tst csg to 2850 psi; bled back to 1000 psi. TIH to 9664', drl baffle & CO to FC @ 9701'; no cmt, CBU, POOH to PU RTTS. 9-5/8" @ 9742' 9750' TD, 9697' EZSV, Filter brine 9.3+ ppg NaC1 PU RTTS, TIH to DV colt @ 4979', tst to 3000 psi; OK, POOH, LD RTTS. PU EZSV, TIH, set @ 9697'. Perform sqz w/350 sx lead slurry. Rev out. TIH w/HWDP, circ& displ w/9.4..ppg brine. Filter brine. 9-5/8" @ 9742' 9750' TD, 9697' PBTD, RR 9.3+ ppg NaC1 Fin circ & filter brine, tst 9-5/8" csg to 3000 psi; OK. ND BOPE, instl tbg hgr, N~ & tst tree. Left 400' diesel freeze protection in 9-5/8" csg. RR @ 0600 hfs, 6/28/86. Old TD New TD PB Depth 9750' 9697' Released rig Date Kind of r g 0600 Hrs. 6/28/86 Rotary Classifications (oil, gas, etc.) 0'11 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct IDate ITitle 7/18/86 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Ala:~ka, Inc F'. O. Box Anchorage, Alaska 99~ DATE' July ~ 7,~986 REFERENCE - ARCO Open Hole F'ina 6-23-86 BHCAc:ous't i log/GR Ru'n 6_,')-z_ o., CDL/CNL/GF( R un 6-23--86 C DI.../C;,R R u'n 6-23-86 D I F'L.o g/Gl;; R un 6-":'-;~- 86 (..; I:;~ R u 'n 6-23-86 Pro Lc,.g Run Receivecl By ........................... ~! _ HAVE A NICE [':AY! / L i r. da HuLce / '~/ R T6.-.15'2o 'T'I:;'.A N ~' ~:86440 '~ D r e .-.'.':.? Dr e:'-~: s' Dr e Dr es'_'~ .f.)r e .':-; .':;' D I .':';.' T F;,'. ]: B t.I "f' ]: 0 ARCO Alaska, Inc. Post Office b~ 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 June 16, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS 1 ~tWells 30 - 34) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU1/16 Enclosure If ARCO Ataska, Inc. is a Subsidiary of AtlanticRichlieldCompany /,Icc 0 ~?0 N 0 ~?. 0 0 '/.~ 0 0 '/.~0 r. I0 w., t~. 1SE. u.M. /10 VICINITY /VOTES ALL COORDINATS SHOWN ARE A.S.P, ZONE 4. I~I~SIS OF LOCATION IS III: "I-A" AND "1 'B" PER H.V, LOUNSBURY & &$$. -- LOCATED WITHIN PROTRACTED SEC. 8, T. 10N., R. 15E., U.M. 31 32 34 Y: 5~$~,7~lL 5 X = 6~,8'~.5 CELLAR BOX Y: 5,939,?$4.5 X: 698,889.5 CELLAR BOX Y: 5,940,536.5 X= 697,999. 5 CELLAR BOX LAT.: TO° 14'22.45' 1535' F.W.L. I..ONB. = 148° 23' ~.00" 1135' F N. L. ELEV. = 39.2' LAT.= T0°14' 21. 87'' 1544' F.W.L. LON~.:I4~O25'$T. 66" 1194' F.N.L. ELEV. = Sg.;~' LAT.: 70°Hl'~:"~. 99" 67~' F.W.L. LONG. = 148°E:4'0:~.9'~" 34t' F.N.L E:I. EV. = 3~J. 2' Y: 5,940,419.5 LAT. :?0°14'~l.15" 700' F.W.L. X: 698,025.0 LONG.:I4~eZ4'O~.~'7" 486' FN.L. CELLAR BOX ELEV. = 39.5' Y: 5,939,617. 0 LAT. = 70° 14' 20.71' 15~' F.W.L. X: 69~,915.0 LONG.:t48°25'37.OZ" 1312' F.N.L. CELLAR BOX ELEV. = $9.2' O- EXSIST. WELL t- CONDUCTOR A~- BUILT JUN 1 9 !986 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASK.~ AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY REVIEWED BY hiE, AND THAT ALL Alaska 0il & Gas Cons. Commis:-:!oDIMENSIONS AND OTHER DETAILS i Anchnmn~. ARE CORRECT. AS OF; ":'~ #.J. ~/~ ' D.S.-I, CO/VD. IVo's. 30-$4 ,ZL~- BUILT June 5, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, tnc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-754,.o, Re: Prudhoe Bay Unit DS 1-30 . ~RCO Alaska, Inc. Permit No. 86-111 Sur. Lot. t135'FNL, 1533'~.~, Sec. 8, T!0N, R15E, UM. Btmhole Loc. 2723'F~, 169'FEL, Sec. 7, T10N, R15E, UMw. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you frOm the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. ~teYtOn Chairman of/ Alaska Oil and Gas Conservation Commission BY O~J)ER OF THE COF~MISSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. ......... Department of~Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA L.._ AND GAS CONSERVATION CC..,MISSION PERMIT TO BI:tILL 20 AAC 25.005 I la. Type of work Drill ,~ Redrill []1 lb. Type of well. Exploratory ~ Stratigraphic Test [] Development Oil Re-Entry ~ Deepen[]1 Service I~ Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 70', PAD 39.5'feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 28329/ALK2327 4. Location of well at surface (Approximatel y) 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1135'FNL, 1533'FWL, Sec.8, T10N, R15E, UN Prudhoe Bay Unit Statewide At top of productive interval 8. Well nu .mber Number 2640'FNL, 80'FEL, Sec.7, T10N, R15E, UM 1-30 #8088-26-27 At total depth 9. Approximate spud date Amount 723'FNL~ 169'FEL~ Sec.7~ T10N, R15E¢ UN 06/13/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(Mo and TVD) property line 1-8 is 58' (~ 9244' TVD 75~7 feet ,s~rf~¢,¢, feet ?.~60 9683, Mr) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth3000 feet Maximum hole angle22 0 Maximum surface 2783 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5¢ H-40 Weld 80' 30' 30' 110' 110' 2000# Poleset 17-1/2" 13-3/8" 68# K-55 BTC 2470' 30' 30' 2500' 2500' 1500 sx CS I I I & 72# L-80 400 sx CS II 12-1/4" 9-5/8" 47# L-80 BTC 9654' 29' 29' 9683' 9244' 800 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor R,~C'~IVED Surface Intermediate J~lx~ 0 3 Production Liner Alaska 0ii & Gas Cons. u0m~,¢ .... Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee tN Property plat [] BOP Sketch ,~ Diverter Sketch I~ Drilling program ~ Drilling fluid program .'~ Timevs depth plot [] Refraction analysis I~ Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,* ' TitleRegional Drilling Engineer Date Commission Use Only Pp/PD?74 J APl number I Approval date See cover letter Permit Number .~,¢/// 50-- ©'Z,,~- ~'/¢c*G~ 06/0_5/86 forother requirements Conditions of approval Samples required [] Yes '~ No Mud Icg required _~ Yes ,~, No Hydrogen sulfide me~asures ~Yes ~No Directional.survey required ,~ Yes F~ No Required work~8'"~~~/~~'~ 5M; ~ 10M; ,~,'15M Other: by order of Approved by ~ '-,// · Commissioner the commission Date Form 10-401 Rev. 12-1-85 triplicate DS 1-30 DRILLING PROGRAM 1. Set 20" conductor and poleset in place. 2. MIRU drilling rig. NU 20" bell nipple and flow line. (NOTE: No shallow gas was encountered on surface interval of well 1-28.) 3. Drill 17-1/2" hole to 2500' MD. 4. Set 13-3/8" casing and cement. Perform cement top job if no cement returns. Test casing to 2000 psi. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi. Test BOP stack weekly. Drill'lO' new hole then perform leakoff test. 6. Drill to 3000' (KOP). Build 2.5°/100' oriented ~ 46°59'W to 21~52'. Drill directional hole to 9683' MD (9244' TVD). 7. Run open hole logs. 8. Run and cement 9-5/8" casing. Displace cement with 9.4 ppg brine. 9. Test casing to 3000 psi. 10. Secure well and release rig. 11. Run cased hole logs. 12. MIRU completion rig. 13. Run 5-1/2", 17.0#, L-80, AB-MOD x 4-1/2", 12.6#, L-80 BTC tubing string with packer and provisions for subsurface safety equipment. Set packer above Sadlerochit. 14. NU tree and test to 5000 psi. 17. Secure well and release completion rig. 18. Perforate and stimulate well. Install subsurface safety valve. NOTES: a . b . c . d . Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during / any extended interruption in the disposal process. The annulus will/ be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. Maximum surface pressure is based upon recent BHP surveys and a full column gas to TD (0.11 psi/ft). Well 1-30 will cross 124' from well 1-11 at 4442' MD (4380' TVD). Wells 1-29 and 1-9 will be situated 120' from well 1-30 at the surface. The closest well to 1-30 will be 1-8. This will occur at the surface and will be ~8'. PD/PD274:sw 05/30/86 DS 1-30 DRILLING FLUID PROGRAM Plas Yield Density Visc. Point Initial 1OM FL % % pH and ,Depth (TVD) #/gal (CP) #/100 ft2 Gel Gel CC/30M Oil Solids Type of Mud Surf 8.8 Funnel Gel-Benex to to 100- 40-60 30+ 50+ 25 0 8 Spud Mud 13-3/8" 9.2 250 Csg Point 13-3/8" Csg Shoe 8.8 Minimum 2 2 5 25 3.5 Low Solids to to Possible to to to to 0 to Non-dispersed K-lO 9.4 4 4 10 10 6.5 K-lO 9.2 10 to to to TD(9-5/8" 9.8 20 Csg.Pt.) 6 4 8 15 4 pH 9-10 to to to to 0 to Low Sol ids/ 10 8 12 10 8 Non-dispersed EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual 4. Drilling fluid fl ow sensor 5. Trip tank 6. Agitators 7. Mud cleaner (desilter) PD/PD274:$w 5/30/86 and audio warning devices) RECEIVED jUNO 3 Aiaska Oil & Gas ConS. Anchorage TYPICAL MUD PiT SCHEMATIC TRIP TANKS SANDTRAP (3;0 BBLS) · DEGASSER ( 83 BBLS) DESlLTER (97 BBLS) I,51"IAKER J !,51'"U~KER ! PILL PIT ( 36 BBLS) DESANDER (97 BBLS) (36 BBLS) NOTE' SUCTION PIT ( 4,4,8 BBLS) RECE \!ED J U N 0 ~ lg8~ Alaska Oil & G~s Cons, Anchor~oe HIX PIT (122BBLS) DI~AWIN6 IS NOT TO SCALE SYSTEPI IS EOUIPPED WITH A DRILLIN6 FLUID PIT LEVEL INDICATOR WITH BOTH VISUAL AND AUDIO WARNIN6 DEVICES AND A FLUID FLOW SENSOR LOCATED IN THE IPIHEDIATE AREA OF THE DRILLER'S CONSOLE. J6 5116/86 BLINI) RI=IriS SPOOL ~-S/8" ~p STAtiC D~ Accumaator Capacit7 Test I. ~k ~ fill ac~lator ~se~oir to p~r level ~h ~l~c ~d. Z. ~5~e ~ ~~ator P~s~e i~ ~000 p~i wi~ 1SO0 ~i ~t~ of t~ reda:or. ~. ~e t~, t~n clo~ all ~ts ~. ~o~ on ~ re~. ~ acce~le is ~5 ~~ clos~g t~ ~ lg00 psi p~ess~. ~-S/S" ~P St~ Test ~ck t~t all ~1~ ~ s~ws a~ ~ly ~rk ~g jolt ~ p~te~ pl~ seat~g ~. ~ test plug o~ ~ill pi~ ~ seat ~. Close ~~ p~entet ~ ~st~e~ valves. ~. ~i~ly test ~s. · 5..~ e~ of ~ ~11~ tesM, fi:st ~1~ a 250 psi I~ ~s~e test for a ~ of ~ ~es, test at t~ ~ ~~ 6. ~~ p~ss~ t~~~ ~1~ fo~ a of ~ ~es. BI~ ~es~ ~o :e~. 7. ~n ~a: p~et ~ c~~ set ~ ~I~ ~o~ at ~ose valves ~ly ~st~m of ~s ~$. I~Me ~s~ to S000 psi ~ ho18 ~o~ ~n top set of pi~ ~ t~ clo~ ~t:~ set pz~ t~. I~e p~s~e to 5000 psi ~1~ ~t:~ ~t of pipe r~ ~ ~1~ f~ at le~: ~:e$. Test ~e~ ~test~ ~old valves (if wi~ SO00 psi ~s:~em of valve ~ :e~ press~e ~ off ~g jolt ~~1 o~ of ~le. Close bl~ ~ ~ test to S000 psi for at ~e~t 3 ~tes. Bled ~ess~ of~ all ~~. ~n bl~ r~. ~:~g li~ ~ all v~ves ~e ~t ~ ~siti~. Test s:~i~ valves :o SOO0 psi. Test ~lly c~ ~ ~i~ ~P to 5000 psi wi~ ~y ~. ~cor~ test i~o~tion ~ bl~ p~venter test Pe~o~ c~lete ~ test once a ~ek ~ tio~ly o~rate ~ ~ily. 10. 11. lZ. IS. 14. 15, 16. 17. 18. Revised 2121184 D81-30 . 0 0 1000 20CC 3OOO 4000 SO00 6000 70CC 8000 90CC 10000 11000 -1000 2000 3000 4000 5000 6000 ARC 3 AL/ ,SKA, INC. IICALI= I IN = 1000 FT. SHI.: 1135' ;NL, 1533' EVIL, 3-3/8' CASIN 3 TVD-2600 SEC 8, TION, R15E, Ulvl THL: 264(' FNL, 80' FE L, I~G~) TVn ,- ,~flfti] RFI~ 7_ T ION RlfiF_ Iii A 7.5 .. EOC Tvo- ,e84 Mo- 3e:18 0£. - S4.6 DfC 59 MINW 2206 F"(TO TARGET) AVERAGE ANGLE K-lO T~B='7105 MD' 7378 DEP=l,$70 K-6 TVD - 7840 I~ID - 6170 DEP - 1768 ,CU TVD-8315 MD--8757 :)EP--1983 SAG RIVER T~ID - 8815 MD - 9006 DEP -' 2076 SHUBLIK TVCI-- 8646 MD '- 9037 OEP i 2()88 TOP SADLER ::)CHIT TVD - (~ 720 MD i 911! DEl= - 2118 == G_/_O CONTA(:T TVD -' 878(; MDI 9183 DI:P - 2142 O/W CONTACT TVD '-91 )S MD "9639 DEP - 2272 TD TVD- 8244 MD - 9! 88 DEP - 232 ! BASE sAr~LEflOCHIT TVE - 8280 MD- 8722 DEP - Alaska (Ii1 & Gas Cons, Commi:;'7.'-' Ap, chor3oo 7000 0 1000 20CC 3000 4000 50OO 6OOO 7000 8000 9000 43 10000 0 1000 2000 SO00 4000 5000 6000 VERT I ClRL SECT I ON 11000 7000 Z CL C3 _] E - N COORO[NPITES -5000 -4000 -3000 -2000 - 1.000 0 1000 2000 RHI. 11R1,' FNI. 1Ra~' Fw~ SEC 8, ;1ON, R15E, LiM THL: 28~ ;0' FNL. 80' SEC 7, "1ON, R1fE, L.M DS1- 1 VD = ~ 940' ~ ~D ~ 9355' ~ EP = 2 [Off i Alaska i i i i i i i 1 i i i i i 1 i , i i i i i I , i 1 i 1 1 i i , ~ , i i i i z~ -5000 -4000 -3000 -2000 - 1000 0 1000 2000 E - Ia COORDINRTES E - kl COOREIINIRTES JO00 -4000 -JO00 -2000 - 1000 0 tO00 2000 mo_ Z 051-2~ · 0 1- ,, 7AR1 '802 ~ OS 1-11 , , Alaska O' & Cas 6ohs, 6o Anchors08 -5000 -4000 -3000 -2000 -1000 0 1000 2000 E - N COOROINRTES Z -200 -lO0 0 -200 E - N COOROINBTES 100 200 300 ~00 500 389_ - 1 O0 0 1 O0 200 300 400 500 E - gl COOROINBTES 0 o o w Q~ I E - N COOROINRTES -500 0 -300 -200 ~'-- ~lO0 0 100 z I I I I I i i ] I I t i i i · i i i i i i I ! I i I I I I i i i i i i i i I I ! I I I I t i ~ I I I t ! ! i i . - ',%1035 . ~0 //3689 619~ ~msk~ 0i~ & Gas Cons. I [ [ I I [ ] I I I I [ I I I [ I I [ I I I } [ I I I Il I 1 [ I I I I I 1 I I I I ] I I I [ I I 1 [ I I [ I -600 -500 -400 -300 -200 -100 0 lO0 E - N COOROINR~ES .... '" :??:CHECK LIST FOR NEW WELL pERMITS ., ITEM APPROVE DATE · '(1) Fe~ '. '~/~'"--" ' ;-' 3 ""'~ ,/-7 ¢-3-~ (2) n__0__~ (2 ~hru 8) (3) Admtn (~<-': ~"3-~'~ (10 ahd 13)' (1,4 thru 22)~ (5) BOPE (23 thru 28) ComPany 1. Is the permit fee attached .......................................... 2. Is well to 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 ten-day wait .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is tile lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 ............................ Lease & Well No. YES NO Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of d'_--~k-_ 2n~ BOPE attached. Does BOPE have sufficient pressure rating - Test to..~p~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. -, ii ii i 1. i RE~RKS ii (6) OTHER /~,~. , (29'thru, 31) (6) Add: , Geolog~ Engil%ger~ng: ' WVA'~ MTM~~'J4~ / rev: 04/03/86 6.011 For 29. ·30. 31. 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 .............................................. POOL INITIAL CLASS STATUS Oz.,/ /,.0 GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks:. ,'/.~L¢ t.,;~//~,o,~,~- I-Ct. ~_ .~,~ - ;..x,~t, 'x,~e .I o HO r~ ~.] Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history .file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX: .. No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * * ****************************** * ............................ * * ....... SCHLUMBERGER ....... * * ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAlVlE : D.S. 1-30 FIELD NAFIE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUFiBER : 500292160600 REFERENCE NO : 98025 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: **** REEL HEADER **** SERVICE NAFIE : EDIT DATE : 98/01/20 ORIGIN : FLIC REEL NAM~ : 98025 CONTINUATION # : PREVIOUS REEL : COMFiENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-30, API# 50-029-21606-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/20 ORIGIN : FLIC TAPE NA~E : 98025 CONTINUATION # : 1 PREVIOUS TAPE : COM~IE~Ff : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-30, API# 50-029-21606-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S. 1-30 API AK]FiBER: 500292160600 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES TAPE CREATION DATE: 20-JAN-98 JOB ~ER: 98025 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: J. JULIAN SURFACE LOCATION SEC TI ON: 8 TOWNSHIP: 1 ON RANGE: 15E FNL: 1135 FSL: FEL: FWL : 80 ELEVATION (FT FROM MSL O) KELLY BUSHING: 70. O0 DERRICK FLOOR: 69. O0 GROUND LEVEL: 40. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 675 9742.0 47. O0 2ND STRING 5.500 30.0 17.00 3RD STRING 4. 500 9007.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUIVlBER: PASS NUM~ER: DATE LOGGED: 23-JUN-86 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG ............................ 88888.0 88888.5 88888.5 9505.0 9505.5 9505.5 9478.0 9477.5 9463.5 9464.5 9464.5 9454.5 9455.0 9455.0 9448.0 9448.0 9448.0 9444.0 9443.5 9443.5 9431.0 9431.5 9431.5 9419.5 9419.5 9419.5 9407.0 9407.5 9407.5 9404.5 9404.5 9404.5 9401.0 9401.5 9401.5 9397.5 9397.5 9397.5 9387.5 9388,0 9388.0 9385.5 9385.5 9385.0 9385.0 9381.5 9381.0 9381.0 9377.5 9377.0 9377.0 9376.0 9375.5 9375.5 9370.5 9370.5 9370.5 9366.5 9366.5 9366.5 9364.0 9364.0 9364.0 9361.0 9361.0 9360.5 9361.0 9336.5 9336.0 9336.0 9333.0 9333.5 9333.5 9331.0 9330.5 9330.5 9328.0 9328.5 9328.5 9322.0 9322.5 9322.5 9316.0 9318.5 9318.5 9314.0 9316.0 9316.0 9311.5 9312.5 9312.5 9309.5 9310.0 9310.0 9306.0 9308.0 9308.0 9304.5 9303.5 9303.5 9300.5 9302.0 9302.0 9297.5 9298.0 9298.0 9292.0 9293.0 9293.0 9290.5 9291.5 9291.5 9287.5 9289.0 9289.0 9283.5 9285.0 9285.0 9277.5 9277.5 9277.5 9271.0 9272.5 9272.5 9268.0 9269.0 9269.0 9262.5 9264.0 9264.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 9258.5 9259.5 9259.5 9254.0 9255.0 9255.0 9249.5 9251.0 9251.0 9243.0 9243.0 9243.0 9239.5 9241.0 9239.0 9241.0 9237.5 9238.5 9238.5 9229.0 9231.5 9231.5 9225.5 9227.5 9227.5 9224.0 9224.5 9223.5 9224.5 9218.5 9218.5 9218.5 9214.0 9215.0 9215.0 9212.0 9213.5 9213.5 9206.0 9207.0 9205.5 9207.0 9201.5 9203.0 9201.0 9202.5 9199 . 0 9201 . 5 92 O1 . 5 9196.0 9197.0 9195.5 9197.0 9192.5 9195.0 9195.0 9188.5 9190.0 9190.0 9185.0 9186.5 9186.5 100.0 101.5 101.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 1-30 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~A RAY, ALSO NPHI PASS #1 AND THE BCS GAMMA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~VARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9514.5 9185.5 CNTG 9526.5 9185.5 $ CURVE SHIFT DATA - PASS TO PASS (f4EAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) DEPT FT 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTG 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CRATCNTG 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CNTCCNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1065832 O0 000 O0 0 1 1 I 4 68 0000000000 CCL CNTG V 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1065832 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9625.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FClFT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 45.626 DEPT. 9100.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL. CNTG GR . BCS 59 . 173 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUf4~ER : 2 DEPTH INCREFiFJTT: 0.5000 FILE SU~V~Ry LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9514 . 5 9186.0 CNTG 9526.5 9184.5 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFIBER : 1 BASELINE DEPTH .............. 88888.0 9522.0 9517.5 9514.0 9512.5 9511.5 9509.5 9505.0 9502.0 9496.5 9492.0 9491.0 9489.0 9488.5 9486.5 9486.0 9484.5 9483.0 9478.0 9477.5 9472.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88888.5 88888.5 9513.0 9510.5 9505.5 9496.5 9492.5 9490.0 9487.0 9485.0 9478.5 9522.5 9516.5 9514.0 9512.0 9505.5 9502.0 9490.5 9488.0 9486.0 9484.0 9480.5 9477,5 9472.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 9472.0 9473.0 9469.5 9470.0 9468.5 9470.0 9468.0 9467.0 9466.0 9464.0 9464.0 9463.5 9464.5 9457.5 9458.0 9454.0 9455.0 9452.0 9452.0 9453.0 9450.0 9450.0 9448.5 9448.0 9447.0 9446.5 9446.5 9446.5 9443.5 9443.5 9442.0 9443.5 9440.5 9440.0 9437.5 9437.5 9434.0 9434.5 9433.0 9433.0 9431.0 9431.5 9430.0 9430.0 9428.5 9427.0 9427.5 9424.0 9424.0 9422.5 9422.5 9422.0 9422.5 9417.5 9419.5 9416.5 9416.5 9414.0 9415.0 9413.5 9415.0 9410.0 9411.5 9409.5 9409.5 9407.0 9407.0 9403.5 9404.0 9401.5 9401.5 9396.0 9395.5 9391.5 9392.5 9387.0 9388.5 9385.5 9385.5 9385.0 9385.5 9383.0 9382.5 9381.5 9381.0 9381.0 9381.0 9377.0 9377.0 9375.5 9375.5 9375.5 9373.5 9374.0 9372.0 9370.5 9371.0 9370.5 9367.0 9366.5 9366.5 9366.5 9364.5 9363.5 9361.5 9362.5 9359.0 9359.0 9350.5 9350.0 9347.5 9346.5 9340.0 9339.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 9339.5 9339.0 9335.0 9335.0 9333.0 9333.5 9331.0 9330.5 9329.0 9329.0 9328.0 9328.5 9326.5 9326.5 9326.0 9326.5 9322.5 9323.5 9320.5 9321.5 9316.5 9317.5 9308.5 9308.5 9307.5 9308.0 9302.5 9303.0 9301.0 9302.0 9299.5 9300.0 9297.5 9298.0 9298.0 9295.0 9294.0 9292.0 9293.0 9288.5 9290.0 9288.0 9289.0 9281.0 9282.0 9280.0 9279.5 9278.0 9277.5 9273.5 9274.0 9272.0 9274.0 9268.5 9269.0 9268.0 9269.0 9265.0 9264.0 9264.5 9266.5 9261.0 9263.0 9253.0 9253.5 9252.5 9254.0 9245.5 9246.5 9242.5 9243.0 9241.5 9243.0 9238.0 9238.5 923 7.5 9238.5 9233.5 9235.5 9232.5 9233.5 9231.0 9231.5 9229.0 9233.5 9226.0 9227.5 9228.0 9223.5 9224.5 9224.5 9221.0 9220.5 922 O. 5 922 O. 5 9218.5 9218.5 9217.0 9217.5 9215.5 9216.5 9214 . 0 9215.0 9209.5 9211.0 9207.0 9207.5 9203.5 9205.0 9203 . 0 9204.5 9201.0 9202.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 9198.0 9196.5 9195.5 9193.5 9188.5 9188.0 9185.5 100.0 9197.0 9195.0 9190.0 102.0 9200.0 9197.0 9188.0 9186.0 100.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL ClVTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 64 66 1 66 0.5 FT 16 0 FT 68 1 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELI~4 CODE (HEX) DEPT FT 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1065832 O0 000 O0 0 2 I 1 4 68 0000000000 ENPH CNTG PU-S 1065832 O0 000 00 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 NRATCNTG 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 10 NA~iE SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... CRAT CNTG 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 GRCHCNTG GAPI 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1065832 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9526.500 NPHI. CNTG 38.199 ENPH. CNTG NRAT. CNTG 3.680 CRAT. CNTG 3.498 ENRA.CNTG FCNT. CNTG 442.938 CNTC. CNTG 1530.102 CFTC. CNTG CFEC. CNTG 436.865 GRCH. CNTG -999.250 TENS. CNTG DEPT. 9184.500 NPHI. CNTG 44.158 ENPH. CNTG NRAT. CNTG 3.981 CRAT. CNTG 3.825 ENRA.CNTG FCNT. CNTG 417.807 CNTC. CNTG 1664.355 CFTC. CNTG CFEC. CNTG 508.051 GRCH. CNTG -999.250 TENS.CNTG 65.350 CPHI.CNTG 7.529 NCNT. CNTG 449.605 CNEC. CNTG 3725.000 CCL.CNTG 50.009 CPHI.CNTG 6.448 NCNT. CNTG 436.635 CNEC. CNTG 3610.000 CCL.CNTG 34.945 1647.977 3288.998 0.001 41.671 1623.671 3276.148 0.082 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 11 FILE HEADER FILE NUFiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9514.0 9185.0 CNTG 9525.5 9184 . 5 $ CURVE SHIFT DATA - PASS TO PASS (FiEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.0 88887.5 9525.5 9525.0 9523.5 9522.5 9515.0 9516.5 9510.5 9510.0 9505.5 9505.5 9502.0 9502.0 9500.0 9500.0 9491.5 9491.0 9490.0 9490.0 9487.0 9487.0 9486.0 9485.5 9485.5 9483.5 9484.0 9481.5 9480.5 9481.0 9481.0 9478.5 9479.0 9478.0 9477.0 9475.5 9474.5 9473.0 9472.0 9472.5 9473.0 9470.0 9470.0 9469.0 9469.5 9465.5 9466.0 9464.0 9464.0 9463.5 9464.0 9458.0 9458.0 9454.5 9455.0 9453.0 9452.5 9453.5 9451.5 9449.5 9451.0 9449.5 9448.5 9448.0 9447.0 9446.5 9443.0 9443.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 12 9440 0 9439 0 9438 0 9437 0 9434 5 9432 5 9427.5 9426.0 9424.5 9419.5 9417.0 9415.0 9414.5 9412.5 9410.5 9408.5 9408.0 9406.0 9405.0 9402.0 9400.5 9396.0 9393.0 9391.0 9388.5 9387.5 9386.0 9382.0 9376.5 9376.0 9374.5 9374.0 9371.5 9371.0 9367.0 93 65.0 93 61.5 9360.0 9356.0 9347.0 9342.0 9340.5 9339.0 9337.0 9333.5 9331.0 9328.5 9328.0 9326.5 9323.5 9322.0 9315.5 9311.0 9310.0 9308.5 9437.5 9434.5 9431.5 9427.5 9414.5 9408.0 9404.0 9401.5 9388.0 9385.5 9381.0 9375.5 9373.0 9370.5 9366.5 9363.5 9361.0 9341.5 9339.0 9330.5 9328.0 9326.5 9322.5 9310.5 9440.0 9438.0 9436.5 9425.5 9424.0 9419.0 9416.5 9415.0 9411.5 9410.0 9408.5 9405.5 9399.5 9396.0 9392.0 9390.5 9388.5 9385.0 9381.0 9375.5 9374.0 9370.5 9366.5 9359.0 9357.0 9346.5 9339.5 9337.0 9335.5 9333.5 9328.0 9323.5 9317.0 9310.0 9308.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 13 9308.0 9306.0 9304.0 9300.5 9298.5 9298.0 9296.0 9293.0 9290.5 9288.5 9283.0 9278.0 9274.5 9272.5 9271.0 9269.0 9268.5 9266.0 92 65.5 9264.0 9262.5 9258.0 9256.0 9254 5 9253 5 9251 5 9245 5 9245 0 9240 5 9235.0 9231.5 9229.5 9227.0 9226.5 9224.0 9221.5 9221.0 9219.5 9217.0 9215.5 9211.5 9208.5 9208.0 9204.5 9203.5 9203.0 9202.0 9197.5 9196.5 9194.0 9193.0 9189.5 9187.5 9185.5 100.0 9308.0 9307.5 9304.0 9297.5 9293.0 9289.5 9275.0 9273.0 9269.0 9266.5 9264.0 9255.0 9254.0 9246.5 9238.5 9231.5 9228.0 9224.5 9221.5 9218.5 9216.5 9213.0 9209.0 9204.5 9201.5 9197.0 9194.5 9190.5 9186.5 101.0 9300.0 9298.0 9294.0 9292.0 9289.5 9283.5 9278.5 9272.5 9269.5 9266.5 92 62.5 9258.0 9253.5 9251.5 9245.5 9242.5 9235.5 9233.0 9228.0 9221.0 9216.5 9207.5 9205.0 9203.0 9197.5 9194.5 9188.0 100.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 14 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND74~ SAMP ELEM CODE (HEX) DEPT FT 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1065832 .00 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CRATCNTG 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1065832 O0 000 O0 0 3 I 1 4 68 0000000000 CFEC CNTG CPS 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 15 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GRCH CNTG GAPI 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1065832 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9525.500 NPHI.CNTG 42.928 ENPH. CNTG 50.982 CPHI.CNTG NRAT. CNTG 3.918 CRAT. CNTG 3.757 ENRA.CNTG 6.523 NCNT. CNTG FCNT. CNTG 402.463 CNTC. CNTG 1464.985 CFTC. CNTG 393.493 CNEC. CNTG CFEC. CNTG 440.140 GRCH. CNTG -999.250 TENS. CNTG 3745.000 CCL.CNTG 40.181 1481. 452 2871.191 O. 003 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREFiENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFIBERS CNTG 1, 2, 3 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN~1998 09:32 PAGE: 16 REMARKS: THIS FILE CONTAINS THE ARITH~IETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAlViE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CRATCNAV 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1065832 O0 000 O0 0 4 1 1 4 68 0000000000 GRCHCNTG GAPI 1065832 O0 000 O0 0 4 1 1 4 68 O000OO0000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 17 ** DATA ** DEPT. 9526.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999 . 250 ENPH. CNAV -999. 250 ENRA. CNAV -999. 250 NCNT. CNAV -999. 250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999. 250 GRCH. CNTG - 999. 250 DEPT. 9185. 500 NPHI. CNAV 39. 859 NRAT. CNAV CRAT. CNAV 3. 589 ENPH. CNAV 48. 281 ENRA. CNAV FCNT. CNAV 445. 055 CNTC. CNAV 1700. 282 CFTC. CNAV CFEC. CNAV 539. 659 GRCH. CNTG 96. 375 3. 727 6.3O2 478. 927 CPHI.CNAV NCNT. CNAV CNEC. CNAV 37.932 1652.602 3391.608 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUPIBER : 1 DEPTH INCREMENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH ........................... CNTG 9545.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH .......... 9177.5 09-0CT-97 CP 44.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 18 TIf4E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (PT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 837 09-0CT-97 9527.0 9534.0 9194.0 9528.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER ........... SGC-SA-27 CNC- GA- 63 BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (PT): 9742.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE Ti~4PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 ~ COUNT RATE LOW SCALE (CPS).: 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REM_ARKS: TIED INTO BHCS DATED 6/23/86 NO PUMPING REQUIRED PRIOR TO LOGGING GOC AT 9426' RA SCALE AT PERFSAFFECTINGREADINGS THIS FILE CONTAINS RAW PASS #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 19 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1065832 O0 000 O0 O. 5 1 1 4 68 0000000000 RCENPS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1065832 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 20 ** DATA ** DEPT. 9545.500 NPHI.PS1 20.172 ENPH. PS1 32.191 TNPH. PS1 TNRA.PS1 2.494 RTNR.PS1 2.643 ENRA.PS1 4.883 CFEC. PS1 CNEC. PS1 3398.669 RCEF. PS1 656.218 RCEN. PS1 2862.503 RCNT. PS1 RCFT. PS1 761.309 CNTC. PS1 2013.724 CFTC. PSI 814.931 NPOR.PS1 GR.PS1 18.266 TENS.PSi 3660.000 CCL.PS1 -0.161 DEPT. 9177.500 NPHI.PS1 33.278 ENPH. PS1 39.852 TNPH. PS1 TNRA.PS1 3.228 RTNR.PS1 3.774 ENRA.PS1 5.605 CFEC. PS1 CNEC. PS1 3771.407 RCEF. PS1 651.516 RCEN. PS1 3108.202 RCNT. PS1 RCFT. PS1 702.836 CNTC. PS1 1937.949 CFTC. PSi 679.332 NPOR.PS1 GR.PS1 69.188 TENS.PSi 3670.000 CCL.PS1 0.013 20. 836 696. 008 2026.108 21. 029 26.412 672.857 2153.011 23.302 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAPiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 ~ RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 2 DEPTH INC~: 0.5000 FILE SUM~La~Y VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... CNTG 9541.0 9176.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 21 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOCKING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) 09-0CT-97 CP 44.2 837 09-0CT-97 9527.0 9534.0 9194.0 9528.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~ RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER SGC-SA-27 CNC-GA-63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 9742.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): ~S: TIED INTO BHCS DATED 6/23/86 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 22 NO PUMPING REQUIRED PRIOR TO LOGGING GOC AT 9426' RA SCALE AT PERFS AFFECTING READINGS THIS FILE CONTAINS RAW PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAFIE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 ClVEC PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 23 NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... CFTC PS2 CPS 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1065832 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9541.000 NPHI.PS2 43.217 ENPH. PS2 51.440 TNPH.PS2 TNRA.PS2 3.773 RTNR.PS2 3.892 ENRA.PS2 6.558 CFEC. PS2 CNEC. PS2 2531.268 RCEF. PS2 362.577 RCEN. PS2 2158.895 RCNT. PS2 RCFT. PS2 372.697 CNTC. PS2 1450.402 CFTC. PS2 393.610 NPOR.PS2 GR.PS2 92.625 TENS.PS2 3185.000 CCL.PS2 0.001 DEPT. 9176.500 NPHI.PS2 25.917 ENPH. PS2 24.185 TNPH. PS2 TNRA.PS2 2.824 RTNR.PS2 2.760 ENRA.PS2 4.035 CFEC.PS2 CNEC. PS2 3259.313 RCEF. PS2 717.101 RCEN. PS2 2784.585 RCNT. PS2 RCFT. PS2 701.548 CNTC. PS2 2128.263 CFTC. PS2 774.340 NPOR.PS2 GR.PS2 54.531 TENS. PS2 3540.000 CCL.PS2 0.012 39.545 385.970 1468.626 39.545 24.862 807.844 2167.419 24.670 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 24 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUM~D%RY VENDOR TOOL CODE START DEPTH ........................... CNTG 9539.0 $ LOG HEADER DATA STOP DEPTH .......... 9178.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) ~OR TOOL CODE TOOL TYPE ......................... GR GAF~4A RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-0CT-97 CP 44.2 837 09-0CT-97 9527.0 9534.0 9194.0 9528.0 1800.O TOOL NU~ER ........... SGC-SA-27 CNC-GA- 63 9742.0 PRODUCED FLUIDS 20.0 EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 25 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 6/23/86 NO PUMPING REQUIRED PRIOR TO LOGGING GOC AT 9426' RA SCALE AT PERFSAFFECTING READINGS THIS FILE CONTAINS RAW PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE ~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 26 NAFIE SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RTNR PS3 1065832 O0 000 O0 0 7 1 1 4 ENRA PS3 1065832 O0 000 O0 0 7 1 1 4 CFEC'PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 CNEC PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 RCEF PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 RCENPS3 CPS 1065832 O0 000 O0 0 7 1 1 4 RCNTPS3 CPS 1065832 O0 000 O0 0 7 1 1 4 RCFT PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 CNTC PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 CFTC PS3 CPS 1065832 O0 000 O0 0 7 1 1 4 NPOR PS3 PU 1065832 O0 000 O0 0 7 1 1 4 GR PS3 GAPI 1065832 O0 000 O0 0 7 1 1 4 TENS PS3 LB 1065832 O0 000 O0 0 7 1 1 4 CCL PS3 V 1065832 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9539.000 NPHI.PS3 42.919 ENPH. PS3 TNRA.PS3 3.757 RTNR.PS3 3.875 ENRA.PS3 CNEC. PS3 2937.022 RCEF. PS3 352.017 RCEN. PS3 RCFT. PS3 402.564 CNTC. PS3 1561.273 CFTC. PS3 GR.PS3 93.438 T~NS.PS3 3075.000 CCL. PS3 DEPT. 9178.000 NPHI.PS3 28.974 ENPH. PS3 TNRA. PS3 2.992 RTNR.PS3 3.066 ENRA.PS3 CNEC. PS3 3605.024 RCEF. PS3 653.420 RCEN. PS3 RCFT. PS3 734.848 CNTC.PS3 1981.174 CFTC. PS3 GR.PS3 64.938 TENS.PS3 3670.000 CCL.PS3 70.305 TNPH. PS3 7.838 CFEC. PS3 2504.958 RCNT. PS3 425.154 NPOR.PS3 0.003 33.746 TNPH. PS3 5.036 CFEC. PS3 3261.746 RCNT. PS3 705.867 NPOR.PS3 0.174 39.335 374.728 1580.891 39.335 25.726 715.816 2259.988 21.836 ** END OF DATA ** **** FILE TRAILER **** FILE NAlVlE : EDIT .007 SERVICE : FLIC VF~SION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 09:32 PAGE: 27 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/20 ORIGIN : FLIC TAPE NAFIE : 98025 CONTINUATION # : 1 PREVIOUS TAPE : COMFiS~ : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-30, API# 50-029-21606-00 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 98/01/20 ORIGIN : FLIC REEL NAME : 98025 CONTINUATION # : PREVIOUS REEL : COf~TT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-30, API# 50-029-21606-00 ~¢hlu~berq~r AtasKa Co~putfnq Center 26,-~CT- J~ 994 J5:33 PRUDHOE BAY, DS 1-30, 500292{,60600 ~LIC 94P26 ARCO ALASKA PPUDHOE # OPEPATO LoGCI~G SURFACE $~C ~b FWL ET.,E OhM wi~g[~I ME] R: COHDA~Y t I, OC ~TION S,glP: E~,LY BUSHING: gOUt30 bEVFL~ # W ~'Lt, CAblinG bOGS INC., PRUDHO?. '8, A,Y, DS 1-30, 5002921.60600 DS 1-30 500292~ 6060{) ,t~RCO ALASKA, SCHLI, IMBEPG~R 6-0CT-94 94~26 · . W~ST S . HARDEN 1135 70.00 69.00 40.00 OPEq HOLE CASING DPlLLERS BIT STZF (IN) STZ~ (IN) DMPTH (MT) .......................... 5.500 30.0 4.500 9007.0 CASING WEiTGMT (LB/F'T) 17.00 !2.60 - !%LC, mASSFS TO STANDARD(MEASUPED DEPTH) RECEIVED Alaska Oil & ~as Cons. Comrni,~c,~on ~¢horage ~cblu~berqer Alss;~a C0mputtn~ Center BASELINE DEPT}~ 9460,5 941~,5 939~,~ 93~,5 9380,5 9~76,5 9~7~'5 9364,5 9360,5 9340,5 9336,5 9332,5 932~,5 9796,5 9~97,5 928~,5 99~0,~ 9~60,5 9~5~,5 9P52,5 972~,5 S 26-~CT-1994 15133 ~RC}~ CNTD 946~,5 9412,5 941,~,5 9396,5 9396,5 939~.0 9393.0 93~,5 9389,0 9~7a,~ 938~,0 937&,0 9377,0 937~,5 9373,~ 9~65,5 9369,0 934.0,5 9337,0 933~,~ 933~.5 912~,0 9~98,5 9~94,5 9~90 9~82,5 975~.0 9954,5 9~4~.0 924~.0 1,0o,5 103.~ :IHE I~'FmNUATION PFP. TATNT,~G TI3 THE O~E~: .N0;,F, bOG SUCH IS LaG~I~G D~TE, L~GCI~.~G CO~.:PA~.~Y, o~gS ~.~I~EP ~aD RU~,~ ~,~I~EP '~S ~0w ~VTDFD k. lTw Th~ ~APE SI-IPP~TEDRY TwE PAGE: ,,IS Ia. ye Verlflcatiom l,.~ist:~nq ~cblumberq'er A,],,,a~K,a Comp,ltino Center F~Lr NA~E t EDIT ,001 $~RvICE : ~b!C V~R$ION : 001C01 D~T~ : 94/1,0/ 6 ~.X R~C StZ~ : 1024 FTLF TYPE: : LO L.~ST FILE ~ 126-OCT-1994 15:33 PAGE: EDITED CURVM$ Oe~th shifted and el~,pOed curves ~of each ~ass inser~arateftles, 0.5000 DFP~H IMC~E~ENT: ~,DWG TOOL CODE START DEPT~{ ,.535,0 954~.0 ~SE!,,IME CURVE FOR SHI~TS .......... EL~UiVALE.:M%' liNS'HIFT~D D~PTH-.--- ..... ~,ASELIME DEPTH ~E"A~KS: TP, IS F[.[.,E COt',]TAINS PASS #1 r~.F I~WE CNTD. Nr]~ PASS TO PASS SMIFTS ~E',PE APP[,IFD TO THIS DAT~. I..,T'S F~AT ~AT.A T ,~ BT..,E TYPE T~ ~,,., T V A !., U DEF! C.~' AF~CO Al ASKA INC ('omDal%v ~.~ame F~' PoUD~OE~ BaY Field Name ~w DS 1-30 We].l Name AP!~ 50-02~-~1606=00 A~I Seriml Number F't 1135' FND & 80' FWh field ~,ocation S~CT 8 Section TO~ 1 ON Tow~sh iD .,IS Tare v~r~.f~cation L!sti. no ;chlumberqer Alaska Comput:tno center 26-OCT-~994 ~5~33 T U N 71[ . V ~ L U ..... D E F I , $~N 4~8289 PDAT MSL E~ D r T 0, L ~ F R K B APl) FT 70, EwB FT 70, E~F rT 6g, ECL WT 40 T ~ D w T 9 6 6 0. TDL WT 9540. B~,I ~T 9537, TLI rT 9~0o. DWT PUMP-IN 8EAWATE~ TT,,A~ 10: 15 08-~3[]N-94 Cot:l:~eV State or Provi:t ce Nation Witness ~ame Service Order ~umber ~e~manent ~at~m ~levatioD of Permanent Datu~ bog ~easured FrOm Above Permanent Datum Eleva Elev~tio~ of Ground Level Total.. De~th:- Drill. er Total DeDth - Bottom :boq Interval ?o~ t,o~ Interval Dr~,lll~o FlUid TYpe Time LoG~er at Bottom Tt~BL;i: TV.PM : CUPV DFP~ Denth . NPHT Compensated ~ieutron Porosity, SS ~iatrIx, cal,J,, & dead ti~e corr, N~ Meutron Ration Mon-i)ead time Corr'ecte¢~ (N/F) C~A? ueutron gatio, Dead Time Corrected (~N/R?) ~CNw ~aw ~ear Detector Count ~ate, Dead Time Corrected FC~· ~aw War netector Count rate, Dead Ti~e Corrected CwTC Corrected ~ar netector Count Rate C~TC Correcte~ wear Detecto~ Count Pate G~CW camma ~av ~n CasIna T~N~ ~urface Tension CCL CCL AmDl!tude Gm ~pT-Corrected Gamma ~av ** DA?A Fr)R~AT SPP, CTFTC~TI(.)N RECOPD ** ** SKT ~YPC - 64KB ** mmmmmmmmmmmmmmmmm~mmmmmmmmm~mm I 66 n 2 66 3 73 48 4 66 1 5 66 ,IS Tame Veri~ficati~on Listino ,cl~lumberger AlasKa ComDut~.ng CeDter 26-0CT-! 994 PAGE: TYPE ~P~ CODE 7 65 8 68 9 65 11 66 1~ 68 1~ 66 0 1,4 65 15 66 68 16 66 0 66 0 D~pw FT 488289 O0 000 O0 0 1 I 1 4, 68 0000000000 N~HT CNTD PU-S 4,8~299 O0 go0 OO 0 i ~ ! 4 68 O000OO0000 NrtA? CN'~D 488299 O0 OOO O0 0 1 I ~ 4 68 0000000000 C~~' CNTD 4802~9 O0 000 O0 0 I ~. I 4 68 O00000OO00 NCi~i~ CNT9 CPS 488289 OO 000 O0 0 I ! 1 4 68 O000OO0000 FC~W CX~D CPS a$~289 OO 000 O0 0 I 1 ~, 4 68 0000000000 C~T¢ CN~D CPS 488289 O0 000 O0 0 I ) ~ 4 68 oOnO000000 GPC!,~ C~wO G~P! 48~2~9 00 000 O~ 0 1 I ! a 68 0000000000 TWNS C~TD LB 480~9 00 00~ 00 0 I ~ ~ 4 68 CCL CNTD V 48~209 00 000 00 0 :1 ! i ~ 68 0000O00000 G~ O~i GaP! 4882~9 00 000 00 0 I ! ! 4 68 o0o0O00000 m.m.{mMmmmmmmmmmmmmlmmImmmmm--mmmmm.mmmmmmmmmmmMmmmmmmmmmmmmmmmmmImmm-- D~Dw qlgo,0n0 NP;!I.Cg'TD -999,250 NRaT,CNTO -q90.250 HCi'~C~i~D -999,~50 mC~T.CNTD -999.750 CFTCoCNT~ -999.~5a G~C~.C~,TD -9q9o250 TEwS.C~JT9 -q99,~50 CCL.CNTD -999.950 C~AT.CNTD C~TC. CNT!) G~. OH CPA. m.CNTD C~TC.CNTD GP .OH -999.250 -9~9,250 26,748 -999.250 -999.250 59.173 Tare Ver~:f~,catfon Listing chlumberq~rA.,!asK:a Comouti~o Center' 26-OCT-~994 15':~33 PAGE: SF~RVICE : ~,[, I C DAT~: : 94/10/ 6 ~,~X BEC S!Z~ : ~,024 F~L~ ~'YPE : bO F!LF NA,~E ." ~DIT ,002 SFRVICE : FLIC VFRMIO~ D~T~ ~ 94/10/ 6 ~X R~C SiZ~ : 1024 FYLF TYPE : LO b~$~ FILE Deuth ~hlfted and c,li. pDed ct]ryes for each pass ~n separate files. 2 0.5000 DFP?H I~{C~EgENT; # FTLW S U'5~'~q,A R Y LDWG TOOT,, CODE C~TD START DEPTM 9535.0 STOP DEPT8 9200.0 9~00.0 C!~RVE SUIVT DATA - PASS TO DAgS(~EASUgED DEPTH) ~ASELINE CtlRV~ FO~ SHIW~q P.:S~ MUuB~R: 1 PASELINE DEPTF~ 953~.5 9534.5 9530.5 9529.5 g52~.5 9514.5 9K10.5 9501.5 9497oK .......... ~(~I~IVA[,EN3' iJMSWIFTE[~ f]KPTH .......... GRC~ C?~TD 9530.0 9534.5 9530.5 9530.0 9527.n 9519.0 9515.0 9497.5 ,IS Ta~e Ver~fIcsti~on ;c~,lt]m~erqer .fi!asKa Comput!~ Center 26-0CT-1994 15:33 949fi.5 Q~90.5 9480 5 9485,5 947~,5 9470.5 944~.5 9445.5 9417,5 941~,5 9~98 5 9394 5 9~90 5 9386 5 938~ 5 9~7~.5 9~7a. ~ 366,5 9358.5 935~.5 9353.5 9350.5 93.~ 5 9345.5 9341.5 9337.5 9334.5 9330.5 9326.5 932?.5 932~.5 9~.5 9317.S 9313.5 9310.5 930~.5 9?90,5 9489.5 9450.0 9445.5 9429.5 9425.0 9417,0 9414.0 9349,5 9345.5 934~.0 9337.5 9321..5 931~.n 931t.5 9985.5 9495.0 9490,5 9487,0 9482.5 947~,5 9475.0 9470.5 9466.5 9463.0 9399 939~. ~ 9386,5 938~,0 937~,5 937~.5 937..,5 9366,5 9~.63 0 9~5~5 935~,.$ 9351.0 9346,5 9334.5 9330.0 9326.5 9323.0 931e.5 9307.5 9303.0 9~99.0 929a..5 977o,5 ~I,c Tane Vertf~.cat~..on List],ng ;cblt!mberqer AlasKa Computln~ Center 26-0CT-1.9~4 15:33 9?77.5 9P7~,5 9274.5 9~7~.5 9~73,5 9974.0 9~70.5 9~7~.0 9~5~.5 9~59.Q 9~54.5 9~54.5 9~53,.5 9~5,4.0 9.~:50 5 9~51,n 9~3n.~ 9~30,5 9 26,5 9~27.0 9~29 5 9~2~ 5 PEqAPKS: THIS FILE CONTAINS PA, SS ~2 OF THE CMTD. THE DEPTH CORPCCTIQ~$ S~'!OWN APOVE ~EFLECT PASS #2 GPCH TO PASS GPC~ aMD PASS ~ ~P~I TO PASS CURVES WErE CARgIED ~!TH THE NP'HI SHIFTS, $ LTS F'OR~AT DATA PA~E: 8 TaRI,E TVP~ : C0~$ C~ ARCh ALASKA, INC. F~.' P~UDHO£ W~:' D~ 1-30 API~~ 50-029-21606-00 ~'t, 1~35' F~h g BO' S~CT 8 C~I.I~ NnRTH SLOPE ~aTT I]$A Sn~ 8280 p~T EmD WT O. ADD ~T 7n. EW~ ~'r 7n. EnF ~T 6o. ECL FT 40, TmD m~ 9600, T~L mT 9540. n~,i ~T 9537. TLI ~T 9200. D~T P!~/~o-IN ~EAWATE~ Field Wmme Well ~ame ,~P! Serial Number ~ield ~,ocation Sect,.on TowD~hiD Rano~ County State or Provl.ce ~ation witness ~a~e Servlce Order ~umber Permanent ~atum El-vat,on of Permanent DatUm Lo~ ~eas,~red Fro~ a~ove Permanent mat~m ~levation of K~llV BoshimG Elevation of Derric~ F]oor ~l~v~tio- of Ground Level Total DeDth - Driller Total Deotb - LoGger ~ottom Log Imterva! TOD bo~ Interval Pr~,lli.G Fluid Type ;chlumb. erqer Alaska Co~,pHt:In~ Cent. er 26-~CT-1994 15:33 PACE: 9 TI~a~ 10:~50~.JUN-O4 Time,Logger at Bottom T~SLE', TYP~ : CUDV D~FI DEpw Oeoth N~H! Compensated ~e~jt;ron Porositv, SS ~atri~, call & dead time corr. N~A~ "~eutron Pat, ion NoD-Dead time Corrected C~A.~ ~e~)tro~ ~atio, Dead Time Corrected NCNT ~aw Nest Detector Count ~ate, Dead T~me Corrected FCN~ 9aw war Detector Count r~te, Dead Time Corrected CWTC Corrected Far Detector Co~3nt Rate C~TC Corrected ~ear Detector Count ~ate G~C%~ ~am~ R'~V ~D Ca$~nq CCI,, ~Dl~tt)de ** SET ~YPE - 64E'~ ** PE RE, ~ E ~L,,.,, I 66 0 , 2 66 0 3 73 44 .4 66 5 66 6 73 7 65 9 65 ~':i' 11 66 ~3 1~ 68 l! 66 0 ~4 65 ~T 15 66 ~6 66 0 66 .,IS Ta~e Verlf!cet].on Listi. n~. ~chlumberqer Alaska Com~utln. g Center 26-0CT-1994 15:33 PA~E: ** SET TYPE - CNAW ** ID OR~E~ ~ LOG TYPE CLASS ~[)D ~,IU~B Sa~P EL~ CODE FT 4882~9 O0 000 00 0 2 I. 1 4 6~ 0000000000 P[,]-$ 4B~2~9 0(,) 000 00 0 ~ 1 I 4 6~ 0000000000 48~2~9 O0 OOO O0 0 ~ I '1 4 68 0000000000 48~289 O0 000 O0 0 ~ 1 1 4 69 0000000000 CPS 48~2~9 00 000 O0 O ? 1 I 4 68 0000000000 CPS 48~289 00 000 O0 O ~ !, 1 4 68 0000000000 C~8 ~88289 00 000 00 0 ~ 1 1 4 6~ 0000000000 CPS 489289 00 000 00 0 ~ 1, 1 4 6~ O0000000OO GAPI 48~2~9 00 000 O0 0 2 1 1 4 68 0000000000 L[~ 4882~9 O0 000 00 0 ~ 1 1 4 6~ 0000000000 V .488289 00 000 O0 0 ~ 1 1 4 68 0000000000 DFP~'. 9548. 000 :~t.P 141 . t~'~TD 38. 648 N:R,~ T . CNTD . . , . ' ,. "T' CNT~ NCNw CNTD 1992 376 ~CNT CNT~ 345 616 C~'.,..C. GPCW.CaTD -909'250 T:~;~IS. CM"rD 1185.000 CCL.CNTD ** ENO []w DATa ** 5.765 347.~77 0.000 57 .732 0.000 (',I~AT.CNTD CNTC.CNTD CRATeCNTD CWTC.CNTD 6 045 2099~267 5.302 2859.582 FILE' NA~C : EDTT .002 SFavlCE ~ wi, lC DaTE ~ 94110/ 6 ~× REC S!Z~ : !.0~4 FTLV TyD~] : LaSW FII.,5~ Fibr ~A~] : ~DIT .003 SCRvlC~ : wLTC V~RSI~N : O01CO1 0aT~ : q4/ln/ 6 ~X REC STZE : !024 FTL~ TYPE L~S· WI~,E IS ra~e yerf.,flcation I.,istf. n~ Chlum~eraer A.l, asKa eOm~utinc Center 26-mCT-19g4 i5:33 EDITE~ CURVES De~t~ ~fted and CURVE S~IWT mASELINE # 0.5000 CuFves for each Pass START DEPTN 9200.0 9PO0.O D&TA - PAgS TO PASS(MFASUPE~ DEPTW) CIIRVE FOR SWIFTS CU~V~ C[]~E: GRCH 9527 0526 9511 9KO? 9506 9502 9491 947~ 9467 9~6~ 9a59 9455 9a5o 9n27 9426 9422 9a15 940~ 9~0~ 939~. 9390 93~7 9383 9370 937~ 9375 5 .5 .5 .5 .5 .5 5 .5 5 5 ,5 im senarate fi, les. ----------~QUIVALENT UNSHIFT~D DEPTH' ~RCH CNTD ~8.88. 8 9536.0 953~..5 952n.o 9527.0 9517,o 951~.0 9507.5 9507.0 9502.5 949~.0 948~.5 947o.0 946~.0 9463.5 a59.0 ~45S.0 945~0 944~.5 9427.5 9426.5 9423.0 9415.5 940~.0 9403.5 9395.0 939~,5 9387,5 938.4,0 938~,5 937a,F 9376.0 PAGE: IS ~an_e Verif~.cation Li~tlno chlumbercer A!a~K.a ComP,lt,.no Center 26-0C~-1904 PAGE: 1.2 9374,5 9371,5 9367.5 9362,5 935~.~ 935~.5 9346,5 934~,5 9323,5 9~19,5 931~ 5 9~14.5 9~1~.~ ]10 A ,, 9~()6 5 930~,5 9~9~,5 9~9~ 5 9~95i$ 9~3 5 9?78 5 9~75!5 9~74 5 9~70 5 9~6~,5 9~59,5 924~,5 9~4~,5 ~3t-,5 9227,5 9~2~,5 9375.0 9363.0 9359.5 9355.0 9350.0 9346.0 934,~.5 9318.5 9315.0 9311.0 930~.5 g303.0 9?98.5 9'2'7 ~. 5 9~75.0 9~70.5 9~6~.5 9~5~,0 9~43.0 9?38.5 100.0 9371.5 936~.n 33! 5 932~.n g320.0 9315,5 9311.5 9308.0 9300,0 9~95,5 9~83,5 9~76,0 9~64,,0 9250,5 925!.5 9247,0 9~43.5 9~31,5 9223,5 ~00,0 # PE~ARKS: T~IS FILE CONTAINS mASS ~3 OF THE CMTO. THE DEPTH CORPECTIO~8 $~{OWb A~OVE. REFLECT P~SS ~3 G~C~ TO PASS GRC~ ~ND PASS ~3 NPHI TO mASS ~1 NPHI, ~b!., OT~EP CNTD CURVES WEPE C.~RPIED WIT~ THE NPHi ~IFTS, $ [~TS FO}~AT DATA IS Vane Verificatlon [.,ist~n~ ChlUmberq~r ~la~Ka ComPuting Center 26-nCT-19o4 15:33 TaST.,F, TYPE : COrnS T !~ ,q ! V A L. U O ~F T ARCO AL~,$~, INC. CompanV ~a,~e ~'~ P~U~HOE B~Y Flel~ '~; DS !-30 Well Name A~I~," 50-02°-~1606-O0 ~PI Serial ~umber F~ ~35' F~L & ~O' F~G Field Location SFCT 8 Section To~:~,~ 1 ON TOW~ Raq, G 1SE ~an~e C~ Ij~T NORTH SLOPE County 8~A~ ALASK~ ~tate or Province ~ ~T! USA 5~at ion w T T~,t S HA~D~N Witnes~ ~,~ame Sm~ 4~82~g Service ~rder Number PDA~ ~]SL Permanent datum ~I') WT 0 Elevat~oP Oi Permanent Datum L, mF R.~.6 Loo ~easured From A~i'.) wT 70, ,~bove Permanent Datum EDF FT 69. Elevatt. on o~ Derrie~ Floor EC, L WT 40 Elevatio~ of Grotlnd Level TDD ~T 9660. Tota,l Depth - Dr~tler T~L FT 95~0 Total Deoth TSI ?T 9~00. Top LoO Interval DWT Pt,,IMP-!l~:~; SEAWATER Drilling FlU.id TI, Ag I0115'"08-JU~,~'-94 Time Loaoer at Bottom T~BI~E TYP~ ~ C!J~¥ O~FI D~PT De~th . ~)? Compensated ~eutron ~oros~tv~ SS.~tr~o cai! & dead t~me ¢orr, ~PA? ).]eutron ~t.~on !ion-Dead time Corrected.(N/P) C~A· ~eutron ~at. io~ Dead Time Corrected (P~IyRF) ~N~ Waw ~eer Detector Count Wate~ ~ead T~me Corrected Fc~T qaw Far Detector Count rate, Dead Time Corrected CP'TC Corrected Far Detector Count Rate C~!TC Correcte~ 5{ear Detector Count ~ate GPCu gam~a ~av in,Casing T~$ $urface Tension CCL CCL Amm.litt~de I~ ~ane Yerification !.,isting Chlumberoer ?,!asKa Com;)lltinq Center 26-OCT-19gg 15:]3 PA~E~ 1,4 44 nhT~ F~.AT SPFCIFTC.STIO~ ~ECOPD $4 1 ~6 2 66 3 73 ~4 4 ~6 5 66 ? 65 8 68 0,5 9 65 l! 66 1~ 68 13 66 !4 65 FT 1~ 66 68 16 66 0 66 t. ** SET TYPE - CgAM,** . · ~M; .... SE UNIT SERVICE AP1 .AP1 API ~.P'I FILE MU~ Nt..i)'~B ~ REPR ,,ESS . .. . ~ ~L,', ~' i ID ORgE~ ~ b, G TYPE ChArS ~IOD Mt.I~B SA~P ),.LE~~, CCDE ('HEX) ..................,.......,.............. ..... .......-..-......,-...--.....,,.,,,,,..-- r)~PT F~ 8~2~9 0 000 O0 0 3 I 1 6~ 0 . On NP~4T C)~TD ;Pt,)-$ 48'82~9 00 000 00 0 ] 1, 1 ,4 6~ ()0000O0000 t~AT CAT[) 4892~9 00 000 00 C~AT CNTD ,48~289 00 000 00 NCf,,I? CM?O CPS .48~2~9 00 000 00 FCNT CNTD CPS ~88289 00 000 00 CWTC CN~D CPS 4882~9 O0 000 00 C~TC CM~D CPS 48~299 O0 000 00 GPC~4 CNT'D GAPt' 48~299 00 000 00 0 3 1 1 4 68 0000000000 0 3 I I 4 68 0000000000 0 3 1 1 4 69 0000000000 0 ) 1 I 4 68 0000000000 0 t 1 1 4 6~ 0000000000 0 3 I I 4 68 0000000000 0 3 I 1. 4 69 0000000000 v oo ooo oo o ! ! oooooooooo , * D ~ T ~ ,4 D F p T, G~Cu C~TD 548 000 -999.2~0 ~ C N T. C *? T }3 TC~'S 44.419 ~;RaT.CMTD 325.286 CFTC,CMTr> q40.000 CC[,oCMTD 6.3~5 CRAT.CNTD 326.8 9 C~TC.CNTD 0.000 6.685 2184.952 IS Tane VerJ. f$.cation t, isti. nO chl,~mberqer AlasKa Comp,~t.ino Center 26-0CT-1994 15:~3 PAGE !.5 FTL~ ~A~E : EDIT .On3 SVRVICE ~ wLIC VF~gInt'~ : O0~CO1 D~T~ ~ q4!~O/ 6 ~aX R~C SIZ~ : ~0~4 **** FIL~ MEADER FTL~ NAuE : MDIT V~RglON ~ O0~CO1 D~T~ : o4110/ ~aX REC STZ~ : 10~4 FIL~ TYPE : LO Compensated Neutron: Arit5metic average oi edited ~asses ~o~ all curves. ~u],sed Neutron{.UnaveraqeO edited Pass 1 Gamma RaY and backrouDd count~; a~ithmetic averaqe ~ edited static ~aseline passes for all other curves. DEPTH I~CRE~ENT 0.5000 P~:SSES INCbUDED IM A'VERAG~ LDWG TOOL CODE ~SS NUMBERS rNTO 1, ~, 3, PE~A~KS: TNIS VILE CONT,.INS THE ARITHMETIC AVERAGE OF THE THREE 'r~E AVERAGE W~S COMPUTED, LIS FORMAT DATA C~! A.CO ,aLASKA., ~NC. Company ~ame F~? PRUOHOg B~Y Field Na~e Ww DS ~,-30 Well Name API~? 50'029~}.606 09 &PI Serial Nut~ber F! 1135' ~gb & ;0 FWL ~ield Lo~atl. on S~C~ 8 Section TOW~ lOa Township IS Tare Verification Listing Cblt'mber(~er AlasKa Computing Center 26-OCT-~.994 15:]3 T !~ ~ ~ V A. T, kl DEF I ..................... . ............ ....... . ....... . ................................ ....... ...... ORT~.I SLOPE Cou~tv. SmA? ALASKA ,N'3 TI USA W~ 'r~ S H AP DE~,~' APD ~T 70, Ewb ~'r 70, E:DF ~T 6g, TDL ~'T 9540, Et I mT 9537. TLI WT D~T TL AB State or Province ~ation witness ~]ame Service Order ~]umber Permanent datum Elevation of Permanent Datum ~,oq ~easured Fro~ Above Permanent Datum Elevation of Kelly ~usbin~ Elevation of [)err c Floor ~levat~on of G~ou~d Level Total Demth - Dr~ller ?oral Deoth - Lo~qer Bottom LOg Interval ToD ~,oG Interval Dr.llllng Flu~.d Tvpe 101).50~-Jl.J~l-94 ?ime. Loooer at Bottom , , TA.B!,,E~ TYPE : CURV DFPT Depth 5!V~T Compensated Neutron Porosity, S$ MatriX, Cali& dead tlme'corr, NPA~' Weutron Ration Non-Dead time Corrected C~A~ ~:leutron ~atio, Dead TimeCorrected ~CMT ~aw Meat DeteCtor Count Rate, Dead Time Corrected f,c~ ~aw War Detector Count rate, Dead Time Corrected CwTC Corrected Far netector CouDt Rate C~3T~ Corrected Near Detector Count ~ate G~C~ Gamma ~av In Cas~nt~ T~$ Surface Tensl, on ** DATA FORMAT SPECIF!C,ATION RECOPD ** ** 'SET TYPE - 6aE~ ** , TYPE ~P~ CODE V~bUE ! a6 0 2 66 ~ 73 ~ 66 5 66 6 7:3 7 65 IS Ta~e Ver~.ftcation T.,istlr~o Chl'.)mherqer AlasKa Comp,.!ti~o Center 2&-OCT-~994 15:]3 PA~E: 1.7 8 68 0'5 9 ~5 1! 66 1.? 68 ~ 66 0 ~ 65 15 66 16 66 0 66 ** SET TyPE - CgAN ** V UN 9' ,q C. P.. AP.. PI t,E M[JM.8 M[.IS~B gIZE ~EPR PPOCESS ID ORDE~ ~ bog TYPE CheSS MOD ~U~B SA~P FbEM COOE (HFX) D~pT FT 488289 00 000 00 0 4 I 1 4 68 N~HI CN~V ~U-$ 488289 00 000 00 0 4 1 1 4 68 ~PAT CNA'V 4882~9 O0 000 O0 0 4 1 1 4 6~ C~AT CNA,¥ 48~2~9 O0 000 O0 0 4 1 t 4 6~ ~CN~ C~g~V CPS 48~2~9 O0 000 O0 0 4 1 1 4 68 CWTC CMIV CmS 48~2~9 00 000 O0 0 4 1 I 4 65 C~{TC CM~V CPS 48~2~9 O0 0o0 00 0 4 1 1 4 69 G~C~.~ CNA.'V GIPI .4892~9 00 000 00 0 ~ ~ ! 4 68 T~S c:N~V b~ 488289 00 000 00 0 a 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00O0000000 ~PT o548.000 NPHI. C~,IA.V CNT',CNAV 205'9.938 FCNT. C'~AV 338 ~06 GP C,W. C~',~', r, V 34,0.4)3 TE~S.CNAV * * E ~',,! D 0 F D A T A ** NRAT.CMAV CFTC,C'NAV 6.085 CRAT.CNAV 340..433 C'3TC.CNAV 6.381 ~170.454 $~RVICE : FblC V~R~ION' : O0~,COI D~T~ : 94/la/ 6 M~X REC SIZE ~ I0~,t FTt.,F ~YPE : LO IS ~a~e Verif.~cation Li, st:~nq chlumherqer /~la~ka Computlno Center 26=0CT-1.994 15:33 PAGE: 1 ~ ~'A',~E : ~DIT .On5 $~RVICE : ~LIC V~R~IO~,~ : O0~.CO1 ~ q4/lO/ 6 RFC $IZF : 10~4 FTL? NUWBFR 5 'RA'~ CURVES Curves and loq header data for each pass in separate pASS ~U~B~R~ I D~P~H I~CPE,ENT: 0.5090 FID~ SU~M,aRY VE~OOR TOO1, CODE START OEDTN STOP DEPTH ........ ...... . .... . ............. . 9550.0 9!90.5 gOW~WA~E 'VERS'Ir!Nt ,. B TTO.: · I~ LOGCEP ON n TD D~ILi,~R 'rD LOG~EP(~T)~ ~OP [,,0~ YNTERV~ CFT): ~O'TTO~ LOG INTERVAL fFT)~ LO~GIN~ SPEEO DEPTB CONTROL USED tiles: raw baeKmround mass in last fi TOOL ST~I~,G (TOP TO BOTTOm) V~ND[]~ TOOL COD~ TOOL ?YPE CN'TD , CMTO COb[,~ LOCATOP 8-JUN-94 ~8 2 9600.0 9540.0 9200 0 9537:o 1800.0 NO OR'JUN-g4 C~:TD $ AND CASING DATA DRILLERS C~SIN~ DEDTM ~,O~GERS CA:SING D.~PTH 9742,0 'PU~,~P-iN SEA~A.T~R IS Tame V.rlf~catlon I, istin.~ Chlumb, erqer AlasKa Computino Center 26-nCT-1994 15:.~.] FLtTIn LEVEL eFT): KLUTD R~T~ AT ~ELT,HKAD ~ATKR CIJT~ (PCT): GAS/O~L R.~TIO: ~ Fi U'Y ~ 0 ~I TOOL T[IOL ~YPE (EPITHEe~AL OR THKRNA1.,,): THFR~A;, ~',~ 5T~IX: SANDSTONE ~IAT~IX DE~S~TY: ~.65 ~LE CORRFCTION (IN~: BT.,U~LTNE COUNT ~ATE NOR~A[..,IZ~TIO~ iN ~%, ZONE TOP ~TOR~I~LIZ~N~ WINDOW gA~E NOR',~AT.IZI~tG WINDOW fFT) Pb[!ELINE COUNT RATE SC.~LES S~T BY FIELD FNG',I~EER ~A~ COUNT PATE LOW SCALE ~Au COUNT WA~E HIG~ .gCA4E %~E,~R COUNT RAT~ LOW SCA5E TOOL STA~DOF~ (IN): # . RF~aR~S: TIE-IN DA B~CS DATED 6-~3-86. PU~IDED INTO WELL WITH 350 BBLS SEA, W~T~R AT 5BPOe, TgEN ,~T 1 BP~ ~HILE LOGGING, PU~mE~ ~ TOTAL OF 5~4 BRLS CRUDE. LIS F~R~AT DATA PAGE: 1 9 TIB!..,E TYPM : CONS . T U N ~ V A !., U D E FI CN .A~CO aLaSKA, INC. F~ PRUDHOE B,~Y ,API~'! 50-02o-~1,606-0.0 FL 1.1.3~' FNL & 80' FWb 8~CT 8 COU~' N ORT.~'~ NS,~T ~JSA E~D F'r 0, l.~ ~ F R K ,B ~P9 FT 70, Companv Name Field ~ame Well Name ~pl Serial Number Field Location Section Township Range Coqnty State or P~ovi~ce Nation Witness Name Service Order NumDer ~e~mane~t datum EleVation of Permanent Dat~m LO~ ~easured From A~ove Permanent Datum I$ Ta~e VerifY. cation LlStJ. no chl,mberqer AlasKa Comput~no Center 26-0CT-~994 15:33 TT~NT V~6U DEFI ~w~ WT7~" ~levat~.o~ of Kelly EPF mT 69, E~h mT 4~. TPD mT 9600. TDL ~'r 9540. B[,I ~T 9537. T~'I FT 9200. D~T PUkeD-IN SEAWAT£~ TLAm 10:15 OR-JU~-94 ~levattoD of Derric~ Floor Elevation of Ground Level Total DeDth - Driller Total. DePth - Loo~er Bottom LDO Interval TOD 500 Interval Or~llino Fluid TVpe Time Loooer at BOttom DFPT ~)eDth ~i~H! ComDensate~ ~eut. ron Porosity, SS Matri~, cal!& dead t~me corr. ~TNP ~aw Thermal Wet~tron. Patio T~IR~ Thermal Neutro~ w~tio Calibrated RCF? P~w FAP CNT COUNTS C~TC Corrected Near Detector Count Pate CVTC Corrected ~a? Detector Count Rate G~ ~PT~Corrected ~amma PaY TF~ ~urface Tense. on CCL CCL ~m~l~tude. SET TYPE T~E R~PR CLiDE V A.L .,,IE ! 66 0 2 66 0 3 73 44 4 66 ~ 5 66 6 ~ 7 65 9 65 ~ 1~ 66 0 ia 65 ~T lB 66 68 I~ Tare verlffcat~om List!mo cblV~her~r AlasKa romDut!n~ Ceuter 26-~CT-1994 15:33 PAGE: 21 RT~ PS! a8~2~9 O0 T~!R~ PS! ~.88~89 O0 RC~,~ ~S!, CPS ~$~289 O0 ~CF~ ~S1. C~S 48~9 O0 C~!TC ~S1 CPS 4892~9 O0 CWTC DS~. CmS 4882~9 G~ mS1 GiPI .48~299 O0 TwN$ PS1 LB a8~2~9 O0 COL PSi V 48~289 O0 ** SEm TYPE - CHAN ** mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm FT 408289 00 000 00 0 5 ! 1 4 6~ 0000000000 PSI PI! ~8~2~9 00 000 00 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 6~ 0000000000 000 00 0 5 I 1 4 68 00000P0000 000 00 0 5 I 1 4 6~ 0000000000 000 O0 0 5 ! I 4 68 0000000000 000 O0 0 5 i 1 4 68 0000000000 000 O0 0 5 1 1 4 6~ 0000000000 0~0 O0 n 5 1 I 4 68 O0000OO000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 6~ 0000000000 * * 0 A T ~ * * DKPT. 9550.000 GD.DS) 89.1~8 DEPT. 9100.5A0 RCN~.DS1 ~853.707 GD.DS! 20.219 ** END []DF DATA ** 'NPHi*PS1 42.052 RTNR.PS! 6.1.18 rNR.,.PS!' 'A nCFT.PS1 :]45.616 CNTC,P$1 2227.794 CFTC.PS1 TENS.PSI 1705.000 CCS,PSI 0.000 ~C~T:,PSI 621:-~,,~ CNTC,P~I 3082.477 C~TC,DS1 T*"'' · ENS,PSI 1315.000 CCL PS1 0 000 6 415 4.8Pl 642. 740 **** FILE ~RAILEP **** F!LF., NA~,~E : EDIT ,on5 VER:~I~N : 001C01 D~T~ : 94/10/ 6 ~,X R~C SlZ~ : I 0~4 F:TL~ TYPE ~ LO LAS~ FILE Verification ListJno chlumberqer Alaska eomp,.lti~o Center 26-OCT-1994 15:33 FT[,~ ~A~E : EDIT .00~ $~RVICE : WL,~C ~AX R~C STZW : {0~4 FIL~ TYD~ : LO Curves and loq header data for each pass iD semarate P~S$ ~U~B~: FTL? SU~ARY v£NOOR TnOL CODE START DEPT~ STOP DEPTH '~ 547.5 9194,0 LOG HEADE~ OATA ~ATE files; raw back,round pass in last f~ SOFTWARE TI~:E LOGGER ON BOTTO~: · D D~ILL~R (FT): TD LOG~ER{FT): TOm LOG INTErVaL ~OTTO~ Lr~G 'INTERVAL fFT)~ t~OGGING 8PFED fFPH~): OEOTN CONTROL U~Q (YES/NO): TOO% SrP,I~G(TOP Tq BOTTOm) V~NDO~ TOOb CODE TOOL TYPE C~TD COLLA~ [,OCATOR C TD ' C~TD CWT~ 8-JU~g-94 1015 O~'JUN'94 9600.0 9540.0 9~00.0 9537,0 1800.0 NO BOPE}~OI,,,E AWD CASING DAT,g O~E~ ~OLE BlT SIZE (IN): , DRILLE~$ CA'SI. NG DEPTN (FT): I..,O~GER$ CASING D~PTH (PT): ~O~EMO~,E cONDITIONS E?,UID TYPE: SUR~CE T~PE~ATURE (DEGF): BOTTO~ ~OLE TE~DEqATtJRE (DEGF): 97,42.0 PtlMP-I~I SEAWATFR chlumberoer AlasKa Compt~t~no Center 26-0CT-~.994 ]5:33 PAGe;: 23 FT,UTO S/~[.,TNT'IY fPPM3: FLUID LEVEl, (FT): ~.~TRR CUTS CPCT): GaS/OIL CROWE (DEC) ~tEU T~O~ TOOL TOOl., TYPE (~PI~N~]~M~L L)9 THERMAL): THERMAL P'. ~T~IX: ~,~AT~IW DENSITY: ~.~5 BT.,tJ~LIHF COUNT RATE NOR~4AI.,IZATION IN OIL ZONE TOP NG~'~aL!ZTN~ WlNiJ)nW <CPS): ff~OOL S~A~'DOFF R~7~.~,~RK8: TIE,-IN DA BMCS DATED 6-23-86. PU'~PED INTO WELt, WITH. 350 BRLS SEAWATER AT 5BP~q, T~E~ ~T 1 BP~ WNILE L~Gd',ING. PUMPED A TOTAL OF 524 J3~h8 CRUD~. TaB~,E TYPE : CONS T U ,N I V A l, U O E F I , CN APCO AhASKA, !NC. Comoanv Name ~T FT P~UDHOE BAY DS t-30 50-029-21606-00 1~,35' FNL, & 80' FWb 15E: i~ O~T}'i AI.,ASK ~ [.s SA MA~DEN O. 70. Ftel~'Name Wel, 1 Name ~I: Serial Number Field Loeation Section Township ~an~e County :State or Province NatioD Witness Name Service Order Number Permanent datum ~.levat~. m of ermanent Datum Lon ~easured From Above Permanent Datum I,~ Tame 'Veri. flca%~on [,1. stJ. po chluff..~ero.~r AlasKa Computin~ Center 26-pCT-1.9o4 15:]3 PAC~: 24 EnF rT 69. E~L ~T 40. T~L ~'~ 954~. B~,I ~T 9537. Tt,I FT 9~00. o~'r PUMP-IN SEAWATER T!.:A~ 10:~,5 08iJ[JM.94 Elevatlo~ of Derrick Floor ~levation of GrouDd Level Tota~ Demth - Dr,.l/er Total DePth - boqqer Bottom boq Interval Tom [,o~ Interval Dr~llinq F].~.~d TYDe Time Loo~er at Bottom TYPE : CU~V DEF% · !~mHI Compensated Neutron Porosity, SS ~atriX, cal!& dead t~me Corr, R~.~P Raw Thermal Ne%]tron Ratio TN.Ra Thermal Neutron ~atlo Ca].lbrated ~CNT ~Aw NEAR C~T COUgTS RCFT 9AW FA~ CNT COUNTS CWTC Corrected gear Detector Count Rate CfTC Corrected ~ar Detector Count Rate G~ ~PI-Corrected Gam~a Ray TFNS Surface TeDs~on CCL CCL AmDl~tude ** ~ATA FnRMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 1 66 2 66. 0 4 66 5 66 5 73 7 65 8 68 0,5 9 65 12 68 1~ 66 0 15 66 68 IS Ta~e Ver~.ficatlon Listin~ C~hlu~berqet AlasKa Com~'~]tfn~ Center 26-OCT-!994 15:33 PAGe: 25 ** SET TYPE - CWAM ** ?D oRDER # LOG TYPE CLASS ~(]D ~UUB SA~P ~,b~ CO~E (HEX) DFP* F? 48~289 00 000 00 0 6 1 1 6~ 0 0~.. PII aSg2g9 ~0 000 00 O 6 1 1 4 6g 0000000000 CNTC C~TC G~ T~S COb ps~ 4882e9 00 000 00 4,8~299 90 000 O0 CPS 488289 00 000 00 CPS 48~289 O0 000 O0 CPS 488289 O0 000 O0 CmS 45P2~9 O0 000 O0 GAPT 488289 O0 000 O0 [,~ 48~299 O0 000 O0 V 48~2~9 O0 000 O 6 1 1 4 6~ 0000000000 0 6 ! 1 4 6R 0000000000 ~ 6 1 1 4 6~ 000000000o 0 6 1 1 4 6~ 000~000000 0 6 1 1 4 6~ 0000000000 0 6 I I 4 68 0000000000 0 6 1 I 4 6~ O0000OO00~ 0 6 1 1 4 6g OOO0000000 0 6 I 1 4 68 0000000000 D~PT. 75,47.500 NPHI-PS2 38.64~ RTN~.~:PS2 R. Ci~{'~ . PS~ .992.376 PCYT.PS2 345.616 CNT 'PS2 GP.PS'2 R4 938 TE $ PS2 I18~..000 CfI,.~*PS2 DEFT 91q4 000 NP~I.P$2 RCi~:PSP 3043:043 ~C~T.-P$2 G~.'P$~ ~4. 375 ** E'*![? OF 'OATA ** 62~ 824 ~TNR.P$2 1]:56g CNTC.PS2 1255.000 CCL'PS2 5.765 TNRA.PS~ 2099.~67 CFTC.PS2 0.000 4,7 · PS2 o.oo0 . 6.045 347.277 4,900 6~7,.682 **** FILM ~RAI'[,ER **** FIb? NA~E : EDIT .0~6 SERVICE : FLIC V~R~!ON : O01CO1 D,,~TF : 94:/10/ 6 M~X R~C SIZE : 10~4 FIL~ TYPE ~ 1~0 IS ?e~:e Ver!ficstton Listtn.n ChlUmberqor A.~.aska Comptltin,~ Center 26-oCT-J994 15:33 PAGE. 9.6 **** FIL~ HEADTR **** FTL~ ~A~E : MDIT .007 ~X ~EC SIZ? : 1024 FIL? ~'YPE : LO FIb~ ~UuSER 7 R~W C~'RvES Curves and loq header data for each DaMS in separate P~SS ~OU~R: DWPWH INCREmEnT: 0.5000 FTLV VENDOR T~OL COD~: ST~.RT DE~TH STOP DEPTH " .... '"'"'"' CNT[> a 91 O. DATE LOG~ED: SOFTWARE V~RSION: · IME bn~E~ 0{~ .B~'TO~: TO LOG~ER(WT): ~[)P LOG INTERV~,L (ET): POT:TO~ bOG INTERVAL (FT){ LOGGING SPEED DENT},{ CONTROL ~*$ED (YES/MO): ~i, les~ raw back~round pass in last a-JUN-94 38.2 10~.5 9~¢0'0 1800.0 O~-JU~J-94 TOOL STRING (TOP TO BOTTOm) V~N~O~ TO0b CODE TOOB.TYPE TOOL NUMBER CNTn ~ l CNTD ~OLLAR LOCATOR CAL CNTD AUXtLLI~RY ME~.SURE~ENT$ ATC CB 1199 C~tTD COMPENSATMD NMUTRON CNC ~A S AMD CASING DATA [,O~G~RS CA. SI ~TC K ¢ O PTH (F'T): 9742.0 FLUID TYPE: FLUID DENSITY (LB/G): S[IRWACE TT~iPE~ATURE CDEGF): ' })OTTO~ :~O!,,E TKM~K~ATU~E I,~ Tame Verification l,.,istln~ cblumberqer AlasKa COmpUtino Center 26-0CT-1994 15:33 THERWAL SANDSTONE ~.65 BLU~LINF COU~T RATE NOR~AblZATIO~, I~ OIL ZONE mOP nLUE!.,,Iag COUNT RATE SCALES SET BY FIELO ~NGIMEFR rAP CDI!NT mATE LOi~ SCAI,E (CPS)~ ~A~ COUNT PAT~ HIG~ SCALE fCPS): ~E.~R COUNT R~TM LOW $CAG~ (CPS): ~'EaR COU~T ~ATE MI~& SCALE (CPS): TOOl, STAr, DOFF # RF~LR~S: TIE-I~ DA BgC$ DATED P~!~'PED INTO WELL WITH 350 f~BLS SEAWATER AT 5BP~, T~EM AT I BP~ W~,{I!,,E bOGGING. PU~PEo ~ TO?AL OF 5~4 BBLS CR!~DE. $ bis F~R~,AT OATA T.IBLE TYP~ : CONS T'!N! VALU OEFI C~i a~CO ALASKA, INC. F~ PRODHOE BAY AP!W 50'029'21.606'00 FI, 1135' F"NL & BO' FWb S~CT 8 COUM NORTH 5bOPE STAT AI,.,ASKA N~Ti USA P~h~ ~'Sb E P D F T 0 AP~ wT 70. Company Name Well Name API Serial Number · Field bocatlon Section Township Range. County State or Province Nation Witness Name Service ~rder Mumber Permanent. datum Elevation of Permanent Datt~ [,o~ ~easured Fro~ ~ove Permanent ~atum IS Ta~e ver.ff.~.cati, on c~lumberqer .AlasKa Comput.!no Center 26-0CT-1994 TUN! VALU DEMI 7 '0 .W_.levat!o~ of Kellv '.BUshido C~F ~'T 69. ECL rT 40. T~D =T 9600. T~L ~T 9540. BLI rT 9537, TLI rT 9~00. b~T PUMP-IN T~,A: 10:I5 O8-JUN-~4 Fl~v~tto~ of O~rric~ Floor Elevatio~ o~ Ground Level Total De~th - Dr~ller Total DeDth - Y.,o~qer TOD LOO Intervs1 Dr11~in~ Fluid Type Time bo~oer at Bottom TA~!.,E TYP? : CUmV · ne~th N~H~ Compensated Neutrom Porosity, SS ~atri×, call & ~e~d time corr, RTNP waw Thermal Neutron ~atio TW~ Thermal Ne~tron ~atio Calibrated RCNT ~AW NEAR CgT COUgTS RCF~ gAW ~A~ CNT COUNTS CNT~ Cor'~ected Near Detector Count ~ate CFTC Co~r,cted Far Detector Count Rate G9 ~I-Corrected ~amma ~av TmN:~ Surface Tension ** DATA FORMAT SP~CIFIC.~TIQM ~ECOP,!) ** ** SET TYPE - 64MB ** TYPE R~P~ CODE V,~LUE ! 66 0 2 66 0 ] 73 44 4 66 ~. 5 66 6 73 7 65 8 68 0,5 9 65 FT 11, 66 ~3 12 68 13 66 O 1,~ 65 ~T 15 66 68 16 66 ~ IS wa~.e 'ver~.ftcat~on Listlno chl~)n~berger ,%!asKa Comput~.no Center 26-.~CT-~ 904 15:33 PAGE= 29 ** ~ET TYPE - C.qaN ** ..... ...... . ........... . ............... ............... .......... ....................... ~D OR~ ~ LaG TYPE Cbt. SS ~OD ~U~D S~P ELFM CODE fHFX) Dw~w ~m 488289 00 000 O0 0 7 1 1 4680000000000 N~H~ DS3 pl~ 4892~9 00 000 O0 0 7 1 1 4 68 000000000O RTI~R DS~ 489289 nO 000 00 0 7 1 1 4 T~Ra D$3 8882~9 00 000 00 0 7 1 I 4 kC~'r DS3 CPS 48~2o9 O0 000 00 0 7 1 ! 4 ~CF~ ~83 C~S a. 88289 0() 000 00 0 7 l. 1 4 C~TC ~83 CPS 488289 O0 000 O0 0 7 1 1 4 CFTC P$3 CpS a8~2q9 00 000 O0 0 7 ! 1 4 GD ~S~ G~P! 48~289 00 000 00 0 7 1 ~ 4 T~iNS D$3 LB 48~289 00 000 00 0 7 ! 1 4 CCL ~S3 ¥ 48~289 O0 000 00 0 7 1 1 4 68 0000000000 000o000000 0000000000 68 0000000000 0000000000 6~ 68 O00000000O 0000000000 68 0000000000 mmmm~m~mmmmmm~m#m~mmm~mmmmmmmmmmmmmmmm~m~m~mmmmmmm~m~m#~mmm~mmmmmm~m~m#~~##~ 'DFPT. DVPT G 0190'5n0 NPHI.PS3 3017.682 ~CFT'PS3 ~5.4q,4 TENS.PS3 ** END OF DATA 44,, 419 P, TNR.PM3 325: 286 060.000 cc/,.ps3 30005 WTNR.PS] 625:25o C~Tc. Ps3 3:132~03., CFTC.PS3 0. 000 6.6ft5 326.849 s, s,4 6i4.777 **** FILE TRAILER **** FILE ~A~B : EDIT .007 SERvIcE ~ ~hlC V~RSION ~ O()~C01 DaT~ : 94/~0/ 6 ~.X REC SIZ~ : ~02,4 F!L~ TYPE ~ L0 IS Ta~e Verifl. cat!on Listin~ chlt~mher,~er Alaska Computfn.~ Center 26-OCT-!9~.~ 15:33 PAGE: 30 SrRVICE N~iMM : FDTT D~T,:' ~ g4/lO/ ~ O~ I~I'~] : ~LYC P~E~IOUS ~E~L : COMMENT ~ ARCO AI.,ASK~, INC., PRUDNUE BAY, [)S 1-30, 500292160600 * HHHH HHHH * * HI{HH HHHH H H A LL LL II BBBB U U RRRR TTTTT O N N * * HHHH HI-IHH H H AA LL LL II B B U U R R T O O NN N * * HHHH~ HHHH A A LL LL II BBBB U U RRRR T O O N N N * * HHI-tHt-II'It-II-t~ H H ~ LL LL II B B U U R R T O O N 1~ * * HHHH HHH/~ H H A ALL LL II BBBB U R R T O N N * * HHHH HHIqH * *HHHH HHHH L O G G I N G S E R V I C E S , I N C · * * LIS TAPE VERIFICATION LISTING * * 3d:t. CO AI.~SF~ INC. * * DS 01-30 * * PRUDHOE BAY * * NORTH SLOPE * * ALASKA * * (DU~J.~ SPACED N~UTRON LO~) * RECEIVED JAN 1 0 t992 Alaska Oil & (3~s Cons. Commission Anchorage Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 91/12/17 --- ANCH --- 667546 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 91/12/17 --- ANCH COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: 01-30 API NUMBER: 500292160600 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 17-DEC-91 JOB NUMBER: L66754-6 LOGGING ENGINEER: RANDELL OPERATOR WITNESS: HORST SURFACE LOCATION SECTION: 08 TOWNSHIP: i0N RANGE: 15E FNL: 1135 FSL: FEL: FWL: 80 ELEVATION(FT FROM MSL 0) KELLY BUSHING: 70.00 DERRICK FLOOR: 69.00 GROUND LEVEL: 40.00 Page 2 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2519.0 72.00 2ND STRING 12.250 9.625 9742.0 47.00 3RD STRING 12.250 5.500 30.0 17.00 PRODUCTION STRING 12.250 4.500 9007.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: BCS RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: N/A EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG 9133.0 9133.0 9198.5 9198.5 9225.5 9225.5 9270.5 9270.5 9297.0 9297.0 9367.5 9368.0 9402.5 9403.0 9469.5 9470.0 9513.5 9514.0 9581.5 9582.0 9631.0 9632.0 9669.5 9670.5 $ REMARKS: TIED INTO DRESSER ATLAS CNL DATED 10-MAY-89. $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 91/12/17 --- 1024 --- LO COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: EDITED CURVES 01 Page- 3 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9669.0 9133.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000# PUMPED 325 BBLS AT 600 PSI AT 1.6 BBLS/MIN. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH CNSG 667546 GAPI FUCT CNSG 667546 CPS API CODE FILE~ 00000000 0 00000000 0 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 4 1 68 Page 4 NUCT CNSG 667546 CPS 00000000 0 4 1 68 CPHI CNSG 667546 PU-S 00000000 0 4 1 68 NRAT CNSG 667546 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9669.000 GRCH = 86.800 FUCT = 183.300 NUCT = 226.800 CPHI = 25.110 NRAT = 1.255 DEPT = 9569.000 GRCH = 80.700 FUCT = 231.800 NUCT = 276.000 CPHI = 23.310 NRAT = 1.215 DEPT = 9469.000 GRCH = 76.800 FUCT = 235.600 NUCT = 307.300 CPHI = 33.880 NRAT = 1.333 DEPT = 9369.000 GRCH = 46.700 FUCT = 368.700 NUCT = 401.800 CPHI = 19.244 NRAT = 1.118 DEPT = 9269.000 GRCH = 40.900 FUCT = 308.900 NUCT = 360.900 CPHI = 23.730 NRAT = 1.198 DEPT = 9169.000 GRCH = 58.000 FUCT = 384.400 NUCT = 426.200 CPHI = 17.770 NRAT = 1.119 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 91/12/17 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 --- 91/12/17 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 Page 5 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0. 5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9669.0 9143.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000# PUMPED 375 BBLS AT 650 PSI AT 1.5 BBLS/MIN. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 6 MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH CNSG 667546 GAPI 00000000 0 4 1 68 FUCT CNSG 667546 CPS 00000000 0 4 1 68 NUCT CNSG 667546 CPS 00000000 0 4 1 68 CPHI CNSG 667546 PU-S 00000000 0 4 1 68 NRAT CNSG 667546 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9669.000 GRCH = 78.300 FUCT = 171.900 NUCT = 228.400 CPHI = 32.630 NRAT = 1.358 DEPT = 9569.000 GRCH = 70.700 FUCT = 233.200 NUCT = 277.100 CPHI = 24.230 NRAT = 1.216 DEPT = 9469.000 GRCH = 77.100 FUCT = 239.200 NUCT = 308.500 CPHI = 29.190 NRAT = 1.313 DEPT = 9369.000 GRCH = 41.700 FUCT = 365.200 NUCT = 412.700 CPHI = 21.090 NRAT = 1.156 DEPT = 9269.000 GRCH = 36.200 FUCT = 306.500 NUCT = 353.100 CPHI = 22.790 NRAT = 1.175 DEPT = 9169.000 GRCH = 68.400 FUCT = 378.600 NUCT = 427.400 CPHI = 19.015 NRAT = 1.145 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN. 002 --- 91/12/17 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.003 --- 91/12/17 --- 1024 --- LO Page 7 OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9669.5 9141.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH CNSG 9141.5 9140.5 9198.5 9197.5 9225.5 9224.5 9270.5 9269.5 9297.0 9296.0 9368.0 9367.5 9403.0 9402.5 9470.0 9469.5 9514.0 9513.5 9582.0 9581.5 9632.0 9631.5 9670.5 9670.0 $ REMARKS: NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000~ PUMPED 415 BBLS AT 675 PSI AT 1.4 BBLS/MIN. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: Page 8 TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT GRCH FUCT NUCT CPHI NRAT SERVID SERVICE~ UNITS API CODE FILE# SIZE #SAMP REPR. F 00000000 0 4 1 68 CNSG 667546 GAPI 00310010 0 4 1 68 CNSG 667546 CPS 00334300 0 4 1 68 CNSG 667546 CPS 00334300 0 4 1 68 CNSG 667546 PU-S 00000000 0 4 1 68 CNSG 667546 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9669.500 GRCH = 79.100 FUCT = 179.400 NUCT = 229.100 CPHI = 26.540 NRAT = 1.294 DEPT = 9569.500 GRCH = 64.000 FUCT = 228.000 NUCT = 275.100 CPHI = 24.230 NRAT = 1.232 DEPT = 9469.500 GRCH = 75.700 FUCT = 241.900 NUCT = 310.200 CPHI = 28.060 NRAT = 1.306 DEPT = 9369.500 GRCH = 37.300 FUCT = 379.200 NUCT = 416.600 CPHI = 18.712 NRAT = 1.122 DEPT = 9269.500 GRCH = 43.000 FUCT = 318.000 NUCT = 359.700 CPHI = 23.960 NRAT = 1.176 DEPT = 9169.500 GRCH = 68.100 FUCT = 373.200 NUCT = 422.500 CPHI = 21.150 NRAT = 1.157 FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.003 Page 9 SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------0 --- 91/12/17 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 91/12/17 --- 1024 --- LO --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS CNSG $ REMARKS: 01,02,03 NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000~ $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 Page 10 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH CNAV 667546 GAPI 00000000 0 4 1 68 FUCT CNAV 667546 CPS 00000000 0 4 1 68 NUCT CNAV 667546 CPS 00000000 0 4 1 68 CPHI CNAV 667546 PU-S 00000000 0 4 1 68 NRAT CNAV 667546 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9669.000 GRCH = 81.267 FUCT = 179.033 NUCT = 228.033 CPHI = 27.933 NRAT = 1.299 DEPT = 9569.000 GRCH = 74.400 FUCT = 231.600 NUCT = 276.767 CPHI = 24.087 NRAT = 1.223 DEPT = 9469.000 GRCH = 75.867 FUCT = 237.667 NUCT = 306.600 CPHI = 30.150 NRAT = 1.316 DEPT = 9369.000 GRCH = 43.633 FUCT = 368.800 NUCT = 406.700 CPHI = 19.637 NRAT = 1.129 DEPT = 9269.000 GRCH = 37.900 FUCT = 302.267 NUCT = 357.200 CPHI = 24.550 NRAT = 1.207 DEPT = 9169.000 GRCH = 64.133 FUCT = 377.467 NUCT = 425.700 CPHI = 19.382 NRAT = 1.145 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 004 --- 91/12/17 Page 11 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 1024 --- LO --- COMCEN. 005 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 --- 91/12/17 --- 1024 --- LO --- COMCEN.004 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9675.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9133.0 02-AUG-91 DDL1 0092-49 1045 02-AUG-91 9662.0 9670.0 9150.0 9668.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNS COMP. NEUTRON (G) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 11014 27003 12.250 9742.0 9670.0 Page 12 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): CRUDE 7.396 70.0 156.0 0.300 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 12.250 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: 9500.0 9450.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN): 0.0 REMARKS: NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000~ PUMPED 325 BBLS AT 600 PSI AT 1.6 BBLS/MIN. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 Page 13 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GR CNT 667546 GAPI 00310010 0 4 1 68 MCCL CNT 667546 IN 00150010 0 2 1 79 RCCL CNT 667546 MV 00150010 0 2 1 79 FCNL CNT 667546 CPS 00334300 0 4 1 68 NCNL CNT 667546 CPS 00334300 0 4 1 68 NPHI CNT 667546 % SS 00000000 0 4 1 68 NRAT CNT 667546 C/C 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9675.000 GR = .000 MCCL = 0 RCCL = 0 FCNL = 411.400 NCNL = 230.000 NPHI = 8.412 NRAT = .811 DEPT = 9575.000 GR = 55.900 MCCL = 77 RCCL = -28 FCNL = 223.300 NCNL = 255.200 NPHI = 21.520 NRAT = 1.176 DEPT = 9475.000 GR = 60.800 MCCL = 27 RCCL = -19 FCNL = 262.300 NCNL = 341.000 NPHI = 31.350 NRAT = 1.324 DEPT = 9375.000 GR = 41.800 MCCL = 51 RCCL = -29 FCNL = 307.300 NCNL = 379.400 NPHI = 24.810 NRAT = 1.257 DEPT = 9275.000 GR = 31.300 MCCL = 45 RCCL = 28 FCNL = 382.800 NCNL = 413.100 NPHI = 18.074 NRAT = 1.106 DEPT = 9175.000 GR = 70.700 MCCL = 46 RCCL = 77 FCNL = '397.100 NCNL = 467.200 NPHI = 20.820 NRAT = 1.197 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 91/12/17 --- 1024 --- LO --- COMCEN.006 Page 14 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 ------ 0 --- 91/12/17 --- 1024 --- LO --- COMCEN.005 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9675.0 9143.0 02-AUG-91 DDL1 0092-49 1045 02-AUG-91 9662.0 9670.0 9150.0 9668.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMP. NEUTRON (G) $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): 11014 27003 12.250 9742.0 9670.0 CRUDE 7.396 Page 15 SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 70.0 156.0 0.300 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 12.250 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: 9500.0 9450.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN): 0.0 REMARKS: NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 12.250" CASING SIZE: 9.625" CASING WT.: 47.000# PUMPED 375 BBLS AT 650 PSI AT 1.5 BBLS/MIN. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE #SAMP REPR. Page 16 DEPT F 00000000 0 4 1 68 GR CNT 667546 GAPI 00310010 0 4 1 68 MCCL CNT 667546 IN 00150010 0 2 1 79 RCCL CNT 667546 MV 00150010 0 2 1 79 FCNL CNT 667546 CPS 00334300 0 4 1 68 NCNL CNT 667546 CPS 00334300 0 4 1 68 NPHI CNT 667546 % SS 00000000 0 4 1 68 NRAT CNT 667546 C/C 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9675.000 GR = 59.100 MCCL = 0 RCCL = 0 FCNL = 183.100 NCNL = 231.700 NPHI = 26.620 NRAT = 1.292 DEPT = 9575.000 GR = 46.900 MCCL = 45 RCCL = -57 FCNL = 205.200 NCNL = 263.200 NPHI = 26.040 NRAT = 1.296 DEPT = 9475.000 GR = 59.200 MCCL = 30 RCCL = -9 FCNL = 262.400 NCNL = 334.400 NPHI = 27.960 NRAT = 1.296 DEPT = 9375.000 GR = 38.700 MCCL = 29 RCCL = 28 FCNL = 302.000 NCNL = 375.400 NPHI = 25.390 NRAT = 1.264 DEPT = 9275.000 GR = 31.800 MCCL = 29 RCCL = -38 FCNL = 376.400 NCNL = 412.900 NPHI = 19.223 NRAT = 1.124 DEPT = 9175.000 GR = 63.400 MCCL = 37 RCCL = 38 FCNL = 406.500 NCNL = 429.400 NPHI = 17.107 NRAT = 1.094 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 91/12/17 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 Page 17 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 ------ 0 --- 91/12/17 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9674.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9140.5 02-AUG-91 DDL1 0092-49 1045 02-AUG-91 9662.0 9670.0 9150.0 9668.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY CNT COMP. NEUTRON (G) $ 11014 27003 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 9742.0 9670.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): CRUDE 7.396 70.0 156.0 Page 18 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.300 THERMAL SANDSTONE 2.65 12.250 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: 9500.0 9450.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN): 0.0 REMARKS: NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE:. 12.250" CASING SIZE: 9.625" CASING WT.: 47.000S PUMPED 415 BBLS AT 675 PSI AT 1.4 BBLS/MIN. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS DEPT F GR CNT 667546 GAPI MCCL CNT 667546 IN RCCL CNT 667546 MV API CODE FILES 00000000 0 00310010 0 00150010 0 00150010 0 SIZE 4 4 2 2 SSAMP REPR. 1 68 1 68 1 79 1 79 Page 19 FCNL CNT 667546 CPS 00334300 0 4 1 68 NCNL CNT 667546 CPS 00334300 0 4 1 68 NPHI CNT 667546 % SS 00000000 0 4 1 68 NRAT CNT 667546 C/C 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9674.500 GR = .000 MCCL = 0 RCCL = 0 FCNL = 407.100 NCNL = 229.500 NPHI = 9.359 NRAT = .808 DEPT = 9574.500 GR = 44.000 MCCL = 54 RCCL = 9 FCNL = 211.900 NCNL = 259.000 NPHI = 24.310 NRAT = 1.248 DEPT = 9474.500 GR = 56.700 MCCL = 26 RCCL = -28 FCNL = 265.600 NCNL = 331.300 NPHI = 27.280 NRAT = 1.279 DEPT = 9374.500 GR = 36.600 MCCL = 37 RCCL = 38 FCNL = 299.400 NCNL = 370.200 NPHI = 25.080 NRAT = 1.256 DEPT = 9274.500 GR = 32.000 MCCL = 31 RCCL = 0 FCNL = 366.500 NCNL = 403.400 NPHI = 18.983 NRAT = 1.123 DEPT = 9174.500 GR = 66.000 MCCL = 48 RCCL = 8 FCNL = 410.200 NCNL = 444.100 NPHI = 17.350 NRAT = 1.110 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN. 007 --- 91/12/17 --- 1024 --- LO TAPE TRAILER RECORD TYPE 131 SERVICE NAME --- COMCEN DATE --- 91/12/17 ORIGIN OF DATA --- ANCH TAPE NAME --- 0 Page 20 TAPE CONTINUATION NUMBER --- 1 NEXT TAPE NAME --- COMMENTS= ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 91/12/17 --- ANCH --- 667546 ****************************************************************************** END OF TAPE ENCOUNTERED Page 21 ~ROGR~M: LISCAN 2EViSION: 5.1 PART NUMBE2: W5790-PE32 .Start o~ e~ecutiom: TUe 16 MAY 89 9:4ga **** RE=L LIS 89110105 H=AOER~ ATLAS 01 'LIS CUSTOMSR FORMAT TAPE' **** TAPE L*S $9/10/05 HEADER **** 3814 0t 'THREE PASS CN/MS' FILE # 1 PASS !.00t .. t024 CN NN FN COUN STAT FORMAT RECORD ONE DEPTH PER TAPE DEmTH 13 CURVES : NAME 1 GR 2 TTEN : ARCO ALASKA, INC. : PRUDHOE BAY D.S. 1-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA (TYPE¢ 64) ~:RAME -UN*T~ : ~T CODE SAMPLm~, ~= U~'TT.,~ 68 1 ~PI 68 1 LB EYTES ! rCL1 5 CCL ? SSN 8 CSSN 9 LSN CLSN t CN 2 CNC CNRA _ _ 68 I VOLT ~$ 1 VOLT 68 1 CTS 6S I CTS 68 1 CTS 6; I CTS 68 1 PCT 68 ! PCT 68 I C/C ~ D6TA R~CORD (TYPE" ~ ~ , ~ O) 1014 ~-YT'S * D:PTH GR TTEN T~N CCL1 CCL SSN CSSN CLSN CN CNC CNRA 9690.000 1 50.000'"' 0.0000000 0,0000000~ 0,0000000. . 150.0000 50.OuuuO O.OOO0000 0.0000000 96&0.000 26.94905 1050,218 0,0000000 0,0000000 113.7863 6.392100 4~,92520 48,92520 .,u. O00 5n~.~n411~ 1030-~. 901 O.O0000GO 0.0000000 121.6851 6,498651 49,20792 53,20792 9540. u.,~no ..P6. 56660 1091 .877 O O000OO0 0 GO00~ .. . . uvO 1~=,t0~ 12.68642 34,84154 38.84154 9490. 000 t 8. 04909 1 075 . 267 O. go00000 O. 0000000 20~+. 4579 I 5 · 39020 2_9,87393 33. 37393 9440,000 21,87982 1083,238 0.000000~ O.OOuuO00 ?An ?523 20,97903 22,87216 26,87216 9390.000 19. 54263 1045.257 O O00000O 0 ~ ' ~ - ..... .... - ,uOuOOuO ?~2.~6 21,3659~ 21,2641 9 25.26419 9340. 000 24./40356 1071. 555 1· 00000m u I . 000000 243 .1 559 22,3.2523 21 , 64397 25,6/4397 9290.000 25.89265 1069,30¢ 0,0000000 O.OOO0000 193,3969 12,~0950 37,29164 41,29t64 9240.000 22.78357 1055.232 O.O0000OO 0.0000000 223.8998 19.00536 24,53122 28,53t22 9t 90. 000 28. 49915 1 052. 543 O, O0000OO O. 0000000 229. 3269 1 7.48836 28.7091 ,i, 32. 70914 107.4906 1052.432 -lOO,OOCO 50,00000 O,COOO000 -Z6.05280 114.0170 0.5606269E-01 -16.4050z, 122.8459 3.5290053E-01 8,469851 193.9235 0,6541973E-01 -4,180028 20&,0374 0,75/47247E-01 -4.03881Z 2/40,5076 0,8722818E-01 -15,07951 232,2874 0.9193052E-01 -3,091177 246,22~3 0.9066880E-01 0.6990604 193,1372 0.647700/43-01 -6,053946 225.7877 0,8/417356E-01 -o.741723 230.6129 0.7533427E-01 -3,225375 SPD LSN 0,0000000 O,O0000OO 26.03310 25.96513 25,997/41 E6.45451 26,99141 51,333/44 26.03310 60.14789 26,03310 84,6294/4 26.99730 85.61475 26.99730 88.59192 26,09730 40.24385 ?6,96161 75,15~$1 2b,961Ol 69,43829 26.99730 9090.000 I 50. 0000 0.00000OO 44.98669 150.2000,, 0.0000000 0.0000000 50.00000 0.0000000 -100.0000 50.00000 O.O000000 0.0000000 0.0000000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = ~ILE TqhiLER **** 68 9~90.00 ENDING TAPE DEPTH = ¢O82.00 FILF_ ~ 2 P~SS 2,002 **** ~ZL:E HEADER **** 1024 FORMAT ONE DEP RECORD (TYPE~ 64) TH PER FRAME TAPE DEPTH UNIT : FT 13 CUPVES : NAME t GR 2 TT;N 3 TEN 4 SPD 5 CCL1 6 CCL 7 SSN ... uSiNg, 9 LSN 10 CLSN 11 CN 12 CNC t q C~ A CODE SAMPLE# UNiT 68 1 APZ 68 I LB 68 1 LB 58 I F/MM 68 1 VOLT 6~ I VOLT 68 1 CTS 68 I CTS 68 ! CTS 68 I CT$ 68 ! PCT 68 I PCT 88 I C/C BYTES 4 '4 4 * DCTA RECORD DEPTH COL1 CLSN 9593.000 1 ~0 0.0000000 9643,000 1.000000 7,073351 9593,000 0 go0~n (TYPEff 0) 101~ BYTES * GR CC CN 0,0 15 0.0 23 1. 4.5 21 0.0 OOOO00 0.0000 O000OO .95473 OOnOOOv .7g765 .39967 000000 TTEN SSN CNC .O00OOOO 50. OOOnO~ O.O00000O 1141.360 123 2~15 49.79765 1127.!61 133,5063 ,' -'".,. ",] ,~1., .,,i .,"l T E N C SSN CNRA -100.0030 5~.00000 0.0000000 31 .o0410 123.1298 0.5744629F--01 -0.7~47581 135.1209 SPD LSN O. 0u00OO,_: 0.0000000 28.99710 27.82611 9e71'-' 43031 ~543.000 28.02133 0.0000000 0.0000000 13.42458 34.65642 9493.000 21.03757 0.0000000 0.0000000 14.49097 32.33209 9443.000 17,65753 O,~nO~O00~v ~ O, 0000000 Z0.73t95 23.90428 93Q3,000 Z3,06.339 0.0000000 0.0000000 20.34468 23,88777 9343.000 25.89967 O. 0000000 0. 0000000 21 .58252 20.85985 0253,000 39,14532 0,0000000 0.0000000 lZ.75033 35.17830 924~_ ,050~ 25,78408 0,0000000 0.0000000 19.73283 23.00505 ~1 93,000 30,74823 0.0000000 0,0000000 17,58612 27,82590 9t43,000 67.92570 0.0000000 0.0000000 23.23512 21.72684 9093.000 38,52306 1 50. 0000 150,0000 O. O00nO00,~ O, 0000000_ 1150-175 1.6'7.5865 38.65642 1154.646 210.0557 36.33209 1!52.341 245.1651 Z7.90~28 1145.158 238.8091 77.88777 1159,432 23!,7187 24,$5~88 1149.481 195.0810 39.17830 1141.270 223.1993 27,00505 1136.1~6 226.9553 31.82590 1128.264 252.8382 25.72~64 0.0000000 50.00000 0 ~ .uO00000 10.08422 198.4400 0.6765205E-01 -0.2921886 210.3814 0.6887954E-01 -11.37925 245.3~92 0.84503175-01 3.030481 239.102~ 0,8508754E-01 -9.836557 231.2834 0.9331632E-01 -1.403610 194,5579 0.6558114~-01 -17.42587 223.15~7 0.8842510E-01 -11 .67814 227.4884 0.7730550E-01 -5.20329B 254.925R 0.9114486E-01 -100.0000 55.00000 0.0000000 28.23300 52.73520 25.9~710 5~.62352 83.71 730 25.99710 8t .=84~6,¢ 28.9 '~71 0 ,$6.~4472 28.99710 51.53928 30.99690 78.16240 30.99~90 70.02504 30.99690 91.89355 O.OOO0000 O.OOO0000 TOTAL DATA R:CORDS= : STARTING TAPE DEPTH = FILE TRAILER **** 9693.00 ENDING TAPE DEPTH = ~085.00 ~iLE # 3 PASS 3.003 **** FILE HEADER **** 1024 FORHAT RECORD (TYPE# ONE DEPTH PER ~RAME TaPE DEPTH UNiT : FT 64) GR TTEN TEN SP9 CCL1 CCL S SN CSSN LSN CLSN CNC CNRA 68 I API 58 1 LB 68 1 LB 6,- ~ 1 =INM 68 I VOLT 68 1 VOLT 65 t CTS 68 1 CTS 68 I CTS 68 1 CTS o,~: 1 PCT 68 ! PCT _, ,..,lC DATA RECORD Dr-PTH CCL1 CLSN (TYPE'~,,.,, 0), 1014 5YTF--S * GR TTEN TEN CCL SSN CSSN CN CNC CNRA e6o1.000. ~ O.OOO00CO ~.~ 0000000 150.0000 150.0000 50.00000 O.O0000uu 0.0000000 0 nO00000 9641.000 0.0000000 6,475225 9591.000 0,0000000 7.802475 9541.000 0 oonono~ 13.16775 9491.000 0.0000000 14.53728 9441.000 0.0000000 2!.08708 9391.000 0.0000000 22.09268 9341.000 0.0000000 27.48~38~ . 9291.000 O.O00OO00 11.89108 9241.000 0.0000000 18.12000 9191.000 22.69708 1120.325 0.0000000 112.6054 44.98730 48.98730 39.6~446 I 078. 508 O. OOOO000 I 24. 841 2 39.73058 43.73058 27.25575 1104.550 0.0000000 195.8330 34.77910 38.77910 26.03735 1102.991 00uuO00O 206 ,31 91 32.01419 36.01~19 22.2=127 1093.696 O.OOCO000 242.0067 22. 87640 26. 87640 2e. 2489 2 I I 20. 471 uuuuuu~ 238.5407 21.1~t89 ~,1~189 21.50743 1119.2.o7 0 000000n 241 088~ 21.06996 25.06996 23.49023 1121.250 O.O0000OO 19~.6073 38.63268 42.632~8 23, 96901 1149. 270 .O000,.vO 2~6 7420 26.0893~ 30.08934 3!. 51076 I ! 39. 393 -100.0000 55.00000 0.0000003 21.92310 113.3213 0.5714040E-C1 -9.225948 125.8545 0.6199599=-01 -0.4968449 194.9865 0.6753159E-01 2.176175 205.8340 0.71 I 1 ? 04 r'-O 1 -5.010540 242.0852 0.8710605E-01 1C.68599 237.9145 0.92~5975E-01 I .363839 240.6409 O. 93431 23E-01 -3.710327 193.9427 0.6131231E-01 24.81908 226.9619 0.7983714E-01 0.9558697 SPD LSN 0.0000000 O.O000000 27.99721 25.67610 27.99721 30.57845 27.99721 ~2.11865 27.99721 57.378:39 ?7.99721 85.06006 27.79721 83.20329 27.9~721 89.36700 27.99721 48.48317 27.99721 73.04977 27.99721 o~1 41. 000 0.0000000 t4.85335 9091.000 150.0000 0· go00 CO""-.. I 03.6461 0.0000000 30.6,~313 39.44783 I 50. 0000 0 · uvO00 1130.062 208.9789 34.69313 O.OOO0000 50 0000'" 0.0000000 -12.21373 207.1633 0.7109878E-31 -100.0000 55.00000 O.CO0000O ~7.997~1 60.37655 O.OOO0000 O.O00OO00 TOTAL DaTA RECORDS : STARTING TAPE DEPTH : FILE TgAZLER **** 9691.00 ENDING TAPE OE~TH = 9083.00 **** TAPE LIS 89110105 3814 01 TRAILER **** TOTAL RECORDS IN THiS LOGICAL TAPE : 217 **** REEL LiS 89110105 ATL&S 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL REEL : 218 TOTAL RECORDS IN THIS PHYSICAL REEL: 218 End of e×:ecution: Tue 16 MAY 8.~ 9:51a . Elapsed execution time : I m±nute , 52.0 SYSTEM RETURN COD: : 0 · . 009 '."-' _. ? -:.' S "; 7 . ":"' t :' 4 :.~ 7 ] ,, .3 (}. ] ~"-'-5 03] I .17~ C/ .x "'z e,." , ._ . , :; ~?:5,30 -: I · /,:-I0. 33.) I T/ '; > . '? '> ;: :: :h ? i '? :', ':[ . 3': D - ,, i ! -S ;',11 '-: i.:. 7- - o >..L .:, )3 '-, 5" 0 ~ .} :] ] . o '3 ?' (l !j :S , ? -': ? ",335 ,-', * ? 5 ! " ¢'" ? 9 '.:.-. 0 1 3 .75 · -.:' ?' '2 ' . ' I .. '! ,, 9 "7 _ ! , a :-' C ' ' ! i- : ",!i: ' , :_';' '} 5 I '3, nglO -"~4. C:,t ! -- -,477 :7.: ! , 3,09° '!, "I ..(, / ? C: -! ~ 3,3 'i I" o7'? I '} ~. :'} 9-} 1 , 0 3.4 T ::~: E, 3 9 } 7 :, 1 7,3 .: :3 S, ,? 0 3 / ;: > '/:. , O 3,) t.. , :? i, '? , 1 c, {. ! ?, OOS 9,0'?,: LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. Well D.S. 1'30' Field Prudhoe Bay County, State North Slope, Alaska Date 6/23/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC Resistivity Focussed. DIFL .2 - 2,000 RILD Resistivity Medium Ind. " ,: RILD Resistivity Deep " " ,, GR Gamma Ray ,: 0-100, 100-200 AC Acoustic Log AC 150 - 50 SP GR1 CAL CN CORR DEN PORD Self Potentifil Gamma Ray Caliper Compensated Neutron Correction Bulk Density Denisty Porosity DIFL CN/CDL -100 - 100 0-100, 100-200 0-16 60 - 0 -.25 - .25 2- 3 60 - 0 ~RCO Ai ~,SKA PRUDHO~ 5AY~N.SLOPE~K, !q~SN P~ SS ~rN P !]. ,:' O C;,~ :2 2532 ~509. 25~0. 25t~ . ~2512. ~5!4. ~)t~. 2516. 25!8. 2520. 2521 · 2522. 25~3~. ~5 4 ~5~5 ~ 252&. 2527. 753C. 2532. 2533. 2535. ~5~ 2539. 2541. 1,m_~ 1.0 3.1~*~**~ , · ~ ~ · 5''~*''~ 1.! 2.1'***** !.! 1.1 1.1 ] >'~ 16' ,, : , .'~q ,". ;.,~. · C·3O 0.30 16~..":·~,. ,-' n r: v· O.'"a 1/,~ C "'- ~ 30 15:3 .-": :,., · 03 ", · On ,150 . '~ '...~ · ~ ;~' ',,../ ~, ,..,,' '.j '_3 · ~ ~ ~ 33 I 5 ~' '~"' $ '~',3 153 ~ n-: ?, nC 160,~ ,.~, ,~. O'":,, 'u. I 60. ~ '3.0~ 0..~..~ l~,.J.,~, ~,. O Lc O. 0 "',.,I 6 ,.J. 6 "' '-'"' '3 '"" I ~ n O.C-O O., .... u 3 '"'0 ,16n ":' 3 I,-? 9.4 0.09 3.00 0.00 0.00 O.OO C-.SO 9.03 3. 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