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Home My WebLink About193-031David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: PBU 09-35A PTD: 193-031 API: 50-029-21314-01-00 Definitive Directional Survey – 03/25/1993 Main Folder Contents: Please include current contact information if different from above. 193-031 T39725 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.30 13:02:07 -08'00' Drilling Manager 09/06/24 Monty M Myers 324-509 By Grace Christianson at 3:02 pm, Sep 06, 2024 DSR-9/11/24A.Dewhurst 11SEP24 10-407 MGR13SEP24 *BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement with fully cemented liner on upcoming sidetrack and all drilling below the PB oil pool confining zones. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.16 12:32:36 -07'00'09/16/24 RBDMS JSB 091624 To: Alaska Oil & Gas Conservation Commission From:Trevor Hyatt Drilling Engineer Date: September 6, 2024 Re:09-35A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 09-35A wellbore as part of the drilling and completion of the proposed 09-35B CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift/caliper for whipstock and MIT. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2"x7" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See 09-35B PTD request for complete drilling details - 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. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x7" whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 4 and lands in Zone 2. The lateral will continue in Zone 2 to 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 isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in November 2024) x Reference 09-35A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and Caliper 2. E-Line : Set 4-1/2"x7" Whipstock at 9,626’ MD at 150 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 3,000 psi 4. Coil : Mill XN nipple (at 9,433' MD) and Window (if window not possible, mill with rig). Give AOGCC 24hr notice prior to BOPE test. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,420 psi. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,420 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (top of window at 9,631' MD pinch point) - only if not done pre rig. 3. Drill build section: 4.25" OH, ~356' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,125' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner 6. Pump primary cement job: 36.7 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Sundry 324-509 PTD 224-220 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be drilled with a 3.80”OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x DS 09 is an H2S pad. The last H2S reading on 09-35A: 220 ppm on 05/04/2024. x Max H2S recorded on 09-35A: 450 ppm on 02/05/2008. Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,300 psi at 8,800 TVD. (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,420 psi (from estimated reservoir pressure). x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Distances from top of riser Excluding quick-test sub Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 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 3.0" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240419 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 4/5/2024 AK E-Line Perf BRU 242-04 50283201640000 212041 3/20/2024 AK E-Line JB/PProf NCIU A-17 50883201880000 223031 3/27/2024 AK E-Line GPT/Perf PBU 05-02A 50029201440100 201241 4/6/2024 Halliburton PPROF PBU 09-35A 50029213140100 193031 4/9/2024 Halliburton RBT PBU 13-24A 50029207390100 204243 4/5/2024 Halliburton RBT PBU B-14A 50029203490100 209059 4/2/2024 Halliburton RBT PBU D-31B 50029226720200 212168 4/7/2024 Halliburton PERF SRU 222-33 50133207150000 223100 3/27/2024 AK E-Line CIBP/Perf SRU 224-10 50133101380100 222124 3/29/2024 AK E-Line CIBP/Perf SRU 241-33B 50133206960000 221053 4/2/2024 AK E-Line CIBP Please include current contact information if different from above T38718 T38719 T38720 T38721 T38722 T38723 T38724 T38725 T38726 T38727 T38728 PBU 09-35A 50029213140100 193031 4/9/2024 Halliburton RBT Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.19 14:54:13 -08'00' 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Wednesday, October 4, 2023 5:54 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki Subject:OPERABLE: Producer 09-35A (PTD #1930310) TIFL Passed Mr. Regg, Producer 09‐35A (PTD #1930310) gas liŌ valves change out was completed on 09/30/23 and subsequent TIFL passed on 10/03/23. The well is now classiﬁed as OPERABLE. Please call with any quesƟons or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Thursday, September 28, 2023 10:08 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer 09‐35A (PTD #1930310) IA Pressure over NOL Mr. Regg, Producer 09‐35A (PTD #1930310) operaƟons reported IA pressure over NOL 2101 psi on 09/28/23. Despite recent passing TIFLs, the well has persistent IA re‐pressurizaƟon when shut in. The well is now classiﬁed as UNDER EVALUATION and on a 28 day clock to be resolved. Please see aƩached TIO document. Plan Forward: 1. Slickline: Change out OGLV 2. DHD: TIFL / monitor re‐pressurizaƟon 3. Well Integrity: Further acƟon as needed Please call with any quesƟons or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, July 30, 2023 12:17 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer 09‐35A (PTD #1930310) passed TIFL Mr. Regg, Producer 09‐35A (PTD #1930310) passed a TIFL on 07/29/23. The passing TIFL indicates two competent well barriers. The well is now classiﬁed back to OPERABLE. Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, July 11, 2023 1:47 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 09‐35A (PTD #1930310) IA casing pressure above MOASP Mr. Regg, Producer 09‐35A (PTD #1930310) was reported to have sustained IA casing pressure above MOASP on 07/11/23 aŌer it was shut‐in for the FS2 outage. The IA pressure was reported to be 2105 psi. The well will now be classiﬁed as UNDER EVALUATON and is on the 28‐day clock for diagnosƟcs. Plan forward: 1. Ops: POP 2. DHD: TIFL 3. Slickline (pending): replace SO 4. DHD (pending): TIFL 5. Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Thursday, September 28, 2023 10:08 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki Subject:UNDER EVALUATION: Producer 09-35A (PTD #1930310) IA Pressure over NOL Attachments:09-35 TIO.docx Mr. Regg, Producer 09‐35A (PTD #1930310) operaƟons reported IA pressure over NOL 2101 psi on 09/28/23. Despite recent passing TIFLs, the well has persistent IA re‐pressurizaƟon when shut in. The well is now classiﬁed as UNDER EVALUATION and on a 28 day clock to be resolved. Please see aƩached TIO document. Plan Forward: 1.Slickline: Change out OGLV 2.DHD: TIFL / monitor re‐pressurizaƟon 3.Well Integrity: Further acƟon as needed Please call with any quesƟons or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, July 30, 2023 12:17 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer 09‐35A (PTD #1930310) passed TIFL Mr. Regg, Producer 09‐35A (PTD #1930310) passed a TIFL on 07/29/23. The passing TIFL indicates two competent well barriers. The well is now classiﬁed back to OPERABLE. Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe.   PBU 09-35APTD 1930310 2 P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, July 11, 2023 1:47 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 09‐35A (PTD #1930310) IA casing pressure above MOASP Mr. Regg, Producer 09‐35A (PTD #1930310) was reported to have sustained IA casing pressure above MOASP on 07/11/23 aŌer it was shut‐in for the FS2 outage. The IA pressure was reported to be 2105 psi. The well will now be classiﬁed as UNDER EVALUATON and is on the 28‐day clock for diagnosƟcs. Plan forward: 1.Ops: POP 2.DHD: TIFL 3.Slickline (pending): replace SO 4.DHD (pending): TIFL 5.Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer 09-35A (PTD #1930310) passed TIFL Date:Monday, July 31, 2023 10:44:47 AM 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: Sunday, July 30, 2023 12:17 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer 09-35A (PTD #1930310) passed TIFL Mr. Regg, Producer 09-35A (PTD #1930310) passed a TIFL on 07/29/23. The passing TIFL indicates two competent well barriers. The well is now classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, July 11, 2023 1:47 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 09-35A (PTD #1930310) IA casing pressure above MOASP Mr. Regg, Producer 09-35A (PTD #1930310) was reported to have sustained IA casing pressure above MOASP on 07/11/23 after it was shut-in for the FS2 outage. The IA pressure was reported to be 2105 psi. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan forward: 1. Ops: POP 2. DHD: TIFL 3. Slickline (pending): replace SO 4. DHD (pending): TIFL 5. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 09-35A (PTD 193-031) Production Profile 09/11/2021 Report 09/14/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/20/2021 By Abby Bell at 2:35 pm, Oct 20, 2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/06/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 09-35A (PTD 193-031) Production Profile Analysis 09/11/2021 Please include current contact information if different from above. Received By: 10/06/2021 37' (6HW By Abby Bell at 3:45 pm, Oct 06, 2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM )N J U Iii 24 ?ii REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed .()0 a F Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-031 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6 API Number 50-029-21314-01-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-35A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth: measured 11170 feet Plugs measured 10297 feet true vertical 9002 feet Junk measured 11165 feet Effective Depth: measured 10297 feet Packer measured See Attachment feet true vertical 8994 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse* Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7674 9-5/8"47#L-80 30-7704 30-6882 6870 4760 Production 7536 7"26#L-80 28-7564 28-6773 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth' See Attachment feet 4-1/2"12.6#13Cr8 26-9445 26-8536 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED i Li_ 1 7 G15 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 116 2216 10411 1607 345 Subsequent to operation: 98 1072 10153 1586 294 1 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I! Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: ContactCation,Garry R(Wipro) Email Garry Catr n@bp com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature id C ,/'\ . _ Phone +1 907 564 4424 Date 6/15/15 q _ - 1 2015 Form 10-404 Revised 5/2015 J! y Y � � 1 i� ` �1 Submit Onginal Only Packers and SSV's Attachment 193-031 SW Name Type MD TVD Depscription 09-35A PACKER 7566.76 6775.71 7" Baker H Packer 09-35A PACKER 9345.74 8449.78 4-1/2" Baker S-3 Perm Packer 09-35A PACKER 9413.45 8509.16 4-1/2" Baker SABL-3 Packer 09-35A PACKER ' 10306.02 8995.24 4-1/2"TIW SS Horiz Packer • (aac,) 00000000 la r Cn CO �- N N re) CO O II O OCt) N ' CC) N- N- ti C- V 44g O Ff. CO CD M M 7 t7 O) CDN N- CO A- 1" CO CO I,- CO CO CO CO N N M ("Nj CO N 0) CO N- Cn O O CO CC) CO CO N- CO 0 0 1.0 N CO CO CO O) O) CO H CO A- N O) N O CO N- lO O) CO CO CO M M N N- CO 0) N CO CO CO CD N-- •;1- 1.0 N I- N co V 2 I I I I I I I I I (O Q N- 0)(1) 0)MQ M CO M M N N _ I r O Lo, O Co Co co, Y 2, co co co M M 4t 4:k CD N N L CO CO 03 ca 0, 0\0 pO NCV C.) _ O M M N N CV CN M M O) I� L O CO N- N- CC')CO O O O) C CO Act M CD Cn CO N (NI N- I� A- A- C) J W QZ O CD C O W W111U Cau_ u_ Ce0CLCLCLZ Z CC CL W O W W W O D D H c Z Z Z D Ucncn ? aMJJF- m — (O 0) N- O (A (O W- LOo LOC) LOC) MCO +t. N 0 O Lo O Lo aD 0 0 ao m N O O ' N M Ce) N 0 0 0) 0) O 0 03 OD N. N- N- N- N- 0) O O 0) 0) O O OO OD CO OO OD CD 0) OD 00 0) 0. 0 N a) 0) LO CO v v 0) (O 0) r vr N O ti M y N Lo Ln Ln co (1 0) 4 0) U) , 4 '- 0) O O a0 0) 0 0 •- N M CM 0) 0 0 0 0) 0) p (O N. N. N. N. N N CO 0 O O 0) 0) a) a) CO CO CO CO CO CO 0) 0) a) a0 0 0 W 0 w .+ N- NCO 0 0 N N CO N oom W J (n W it LS 0) Lo N aD a0 0) N- 0) Lo O a0 a0 a IL Z N Lo CO CO (O CO CO IN- 0) O O O O 0 J J :� O 0) 0) 0) 0) 0) 0) 0) 0) D CI W W z = a W g g = 0 z uw) z o LLI O o 2 O O w a 0 a Q 0 Q V D D 2 O V O cn (n .n Q $'+ M a Q C I- C: CM wCDCO � CNornrna0 'LUN (N (oo c) m m aCO Ln COOCO (O CO O 0) M 0 Ln OD 00 CI o 0 0 0 0 0 0 0 0 0 0 0 03 V 0 0 2 cc coY U O u) 0. 2 z2Occc,nanti ua) d a 0 C) c 0 IL IL IL IL IL IL IL IL Co u) u) U) u) 0 0 0 ¢ ¢ Q Q W Q m m m m m 0. 0 t a 0 co CO CO CO LO N- N- N- N- N p p � � °) rn °) rn °) - 0) 0) 0) 0) 0) o O coo °) rnr) rn °) o ) 0) 0) 0) 0) wONN z w 10 MM , ONNNN. CCO000 ((0 (OCO W O p N N N N Z a J U W W LL W Cl CCI Oa Lo a 0 J J J J 3 D_ m O 3 W J J a a D. V) LL lL Lai CCi) O 0 E ca Q Q Q Q Q Q Q Q Q Q Q Q Q Z Lo Lo Lo Lo Lo Ln Lo Lo LO U) Lo LO Ln M M M M M M M M M M M M M i i I i I i i I i i D_ V1 LL O LL N �' LL Cl) 00001000000000 a a m m ILL U (II) C O ce • Eo / k C 0)& _1 _ m z- w USB a < � / m En 2 aU & 2o k Lcƒ Tr z nr ■ D 0 p / % C L L O o m o >- 2 : 2 I .. E e >- o 0_ / / / / co 0. 0. 2 2 2 / / w I cc I- 0 cnLD ENz � V \ E 5 - _ Q a o 71 �_ I- 2 O - > 9 2 r, ƒ uj / < 0 �\ o g i s L 5 O1,1 G z I- t _ _j X / < a) w 0 o > ,_ e 2 O % Cl)- ƒ � cc cc iio / CC « 2 -L2 � cc � Z % 2 >. ZO � aogw \ - OL . O 02 - o $ ? > « O Ci Z > U) ZO7a-0 H -J kbc/ 2 ¥ � LL % w ¥ � 7 / 21 % 2 " / / / / a _1c / _jU- Ai_ Jo < - z —1 & - _j _1 _i - o I ® R k ¢ k � � � > � 0_ 0 < D co | E 2 / / ,-= 1"-- I .-- E o_ / < L / b Lu < to in \ A co 5 ƒ %I- da q $ $ < TREE= 4"CNV WEFLFEAD= Mc EVOY S. _fY NOTES: WELL ANGLE>70"@ 10071'"' ACTUATOR= OTIS 09-35A 13-3/8 68#K-55 IN SURFACE CSG,BURST=3450 PSI OIC EL.EV= • 55, " " 'CHROME TBG&LNR" BF ELEV= NA 13-3/8"CSG,684, H 71' A KOP= 2950' K-55,D=12.415' K Max Angle= 91°@ 10737' I i 2095' H4-1/2'HES X NP,D=3.813' Datum MD= 9870' 20 CONDUCTOR 111' Datum ND= 8800'SS 91 5#,11-40, K GAS LFT MANDRELS D=19 124" K ST MD ND DEV TYPE VLV LATCH PORT DATE ia 7 3489 3460 25 KBG-2 DOBK 16 03/20/14 13-3/8"CSG,72#,L-80 BTC, D=12.347' H 2526' ME 6 5321 4991 35 KBG-2 SO BK 24 04/02/14 K 5 6353 5826 38 KBG-2 DMY BK 0 05/03/06 7'LM 26#,L-80 TCI XO TO L-80 BTC-M -I 2992' D K 4 7218 6505 39 KBG-2 DMY BK 0 05/03/06 K 3 7949 7089 25 KBG-2 OMY BK 0 05/03/06 K 2 8559 7684 7 KBG-2 DMY BK 0 05/03/06 Minimum ID = 3.725" @ 9433' k 1 9131 8251 16 KBG-2 DMY BK 0 05/03/06 4-112" HES XN NIPPLE K 7555' H BKR C-2'WHACK SLV,13=7.50" 7"TIEBACK UR,26#,L-80 BTC-M, - 7558' 7565' HT X 4-1/2"BKR TIE3K SEAL ASSY,D=6170' .0383 bpf,D=6.276' .1 7562' H 9-5/8'X 7'BKR H PKR D=6.19' 756T -I 9-5/8"X7"BKR HY FLO HGR D=6.14" 9-5/B'CSG,47#,L-80 BTC,13=8.681' H 7700' I- 9-5/8'CSG&CLOUT WINDOW(09-35A) 7700'-7750' 7'LW,29#,L-80 NSCC XO 13CR NSCC H 9232' —›< X ' ' 1 9326' 1H4-1/2'HES X NP,D=3.813' E z— 9347' -17'X 4-1/2'BKR S-3 PKR D=3.87' ' I r 9370' 4-1/2'Hes X NP,D=3.813' I I 9433' H 4-12'HES XN NP,D=3.725' 4-12"TBG, 12 6#,13CR VAM TOP, - 9446' 0152 bpf,1).3 958' \/ " 9446' 1-14-12'WLEG,D=400'1 7'MARKER JT(20') H 985T —0 H SMD TT NOT LOGGED TOP OF TNV POLISFEBR RISER,D=4.820' - 10291' J 1029T elm H ( 01/16197 10302' -17'X 4-1/2'TM/SS PKR &LN2 HGR D=4.000' . . .� 10308' H4-12"PORTED JT,D=3.96'(43') 7"LNR 29#,13CR NSCC, 0371 bpf,D=6.184' H 10387' J--, I 1 L I PERFORATION SUMMARY REF LOG.CDR ON 03/17/93 ANGLE AT TOP PERF-37'@ 9581' •\ •\ Note:Refer to Roduction DB for historical perf data •\ • SIZE SPF INTERVAL Opn/Sgz DATE • •� HSTRIP 11165' F75H- 15'STGUN(08/1 3/96) • SEE PAGE 2 FOR PERFORATION DATA • • • 4-1/2'LNR 12.6#,13CR FOX,.0152 bpf,D=3.958' -I 11170' DATE .REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 05/16/8ROW 35 IPITIAL COMPLETION 04/16/14 STF/JMD PULL WI-LOON CATCHER(4/2/14) NIL 09-35A 03/27/93 N2ES SIDETRACK(09-35A) 09/02/14 GTW/JMC ADFERFS(08/23/14) PBRIIT No. 1930310 05/04106 D-16 MVO 06/19/15 DLW/JMD ADFERFS(05/27/15) API No: 50-029-21314-01 03/26/14 CJN/JM)GLV C/O(03/20/14) SEC 2,T1ON,R15E 1822 FSL&1048'FB- 0326/14 RCT/JMD SET WHCDON CATCHER(3220/14) 04/09/14 MBMJMD GLV C/O(04/02/14) BP Exploration(Alaska) 09-35A • °. t I i . 1 ►i �4 ►i •� °°.1 c• ! !., .4 D P. .1 ►. •4 ►i ! • �i 4 ► .► x I I ► Z .._ . I I PERFORATION SUMMARY REF LOG:CDR ON 03/17/93 I I ANGLE AT TOP FERE:37'@ 9581' / \ Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT - SOZ 3-3/8" 6 9581 -9597 0 08/23/14' 3-3/8" 6 9649-9657 0 08/23/14 2-1/2 2 9666-9674 0 11/15/96 2-1/2" 4 9674-9682 0 09/20/97 8 2-1/2 6 9682-9688 0 10/21/96 ► Z 2-1/8' 6 9690-9710 0 08/13/96 2-1/2" 4 9694-9710 0 05/26/96 ' ' •2-1/2" 6 9694-9710 0 10/21/96 1 I L 2-7/8" 6 9986-9996 0 05/27/15 I I\ 2-1/8" 2 10520-10526 0 01/16/97 1 • 1 2-1/8" 2 10840-10860 0 01/16/97 •\ ' • 4-1/2" SLTD •10351- 11124 C 01/16/97 '\ •• • • • • DATE REV BY (X)IME'ITS DATE REV BY COMJBJTS PRUDHOE BAY UNIT 05/16/86 ROW 35 INITIAL COMPLETION 04/16/14 STF/JWD RLL WFCDON CATCHER(4/2/14) WELL: 09-35A 03/27/93 N2ES SIDETRACK(09-35A) 09/02/14 GTWMJ/JADPERFS(08/23/14) _ PBRIAT No:'1930310 05104/06 D-16 RWO AFI No: 50-029-21314-01 03/26/14 CJMJWD GLV C/O(03/20/14) SEC 2,T101y R15E 1827 FSL 8 1048'FEL 03/26/14 RCT/JPAiSET WFDDON CATCHER(3/220/14) 04/09/14 €M'JM]GLV C/O(04/02/14) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 j 3 - z 2 / Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 09 - 35 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, fi 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 -09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09-01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09 -03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09-14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09 -27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 02 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA •-"'> 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09 -39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 102 7/17/2010 09-41 1900740 50029220540000 Dust Cover , NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 102 9/16/2010 09-45 1901150 , 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 10.2 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 _ 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 STATE OF ALASKA,IIL- ~S(a. ALASAIL AND GAS CONSERVATION ~MISSION (i.' REPORT OF SUNDRY WELL OPERATIONS' 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028324 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Tieback Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): ~ Repair Well ~ Pull Tubing o Operation Shutdown 52' 11170 9002 10297 8994 111' 2526' 7700' 2832' 888' 7536' o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 4. Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 193-031 6. API Number: 50-029-21314-01-00 9. Well Name and Number: PBU 09-35A 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool feet feet Plugs (measured) 10297 feet Junk (measured) 11165 feet Size MD TVD Burst Collapse 20" 111' 111' 1490 470 13-3/8" 2526' 2526' 3450 1950 9-5/8" 7700' 6879' 6870 4760 7" 7555' - 10387' 6767' - 900 l' 8160 7020 4-1/2" 10282' - 11170' 8992' - 9002' 8430 7500 7" 7565' 6774' 7240 5410 9666' - 11124' 8714' - 9003' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl 4-1/2", 12.6# 13Cr 9446' Tubing Size (size, grade, and measured depth): 9347' 7" x 4-1/2" Baker 'S-3' Packer Packers and SSSV (type and measured depth): RBDMS 8Ft M.Ä Y 1 6 2006 Treatment description including volumes used and final pressure: Pull tubing. Run 7" tieback to surface from 7565'. Cement wI 103 Bbls (258 sx) Class 'G' and 105 (504 sx) Class 'G'. Run new tubing 13. Prior to well operation: Subsequent to operation: 14. Attachments: Re resentative Dail Gas-Met Water-Bbl Tubin Pressure 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my know e ge. Sundry Number or N/A if C.O. Exempt 306-110 o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Printed Name Terrie Hubble Signature ~ Form 10-404 Revised 04/2006 Title Technical Assistant Phone Date OS/]o/O~ Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = .09-35A Complet¡ct, Max Angle = Datum MD = DatumTVD= 4-1/16" CrN McEVOY Otis 53.0' NA 2950' 91 @ 10737' 9871' 8800' SS 2.C'ìS ~ -14-1/2" HES X NIP GAS LIFT MANDRELS TVD OEV TYPE VLV LATCH 3467 25 KBG-2 OCK- BEK 4990 35 KBG-2 Ommy SBK2c 5850 38 KBG-2 Ornmy SBK2c 6495 39 KBG-2 Dmmy SBK2c 7080 25 KBG-2 Dmmy SBK2c 7686 29 KBG-2 Dmmy SBK2c 8245 15 KBG-2 Ommy SBK2c ST MO 7 3489 6 5320 5 6353 7555' 4 7217 3 7948 2 8558 1 9131 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 1 7" TIEBACK, 26#, L-80 H I BKR C--2 TIEBACK SLY, 10 = 7.50" , 19-5/8" X 7" BKR H PKR, 10 = 6.19" , 19-5/8" X 7" BKR HYFLO HGR, 10 = 6.14" I 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 17" L-80 X 7" 13-CR LNR XO I I 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" I 17" MARKER JT (20') I 1 TOP OF TrN POLISHER RISER, 10 = 4.820" I 1 7" LNR, 29#, L-80/13-CR, 10 = 6.184" I PERFORA TION SUMMARY REF LOG: COR ON 03/17/93 ANGLE AT TOP PERF: 43 @ 9666' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA DATE 05/13/86 03/27/93 02/10102 09/29/02 09/27/05 05/04/06 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (09-35A) CHlTP CORRECTIONS BMlTP WAIVER SAFETY NOTE EZLITLH WAVIERSFTY NOTE DELETED D14 RWO 7555' 7562' 7567' 7700' ~ 9232' 944" 9857' 10291' 9370' 9433' 9448 10297' el 10301' 10308' 10351' I I I I , , , , , , , , , , , , , , , I I I , , , , , , , , , , , , "rl 1 0387' 115' STRIP GUN 8-13-96 I 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" DATE REV BY COMMENTS PORT 1" 1" 1" 1" 1" 1" 1" DATE 05/02/06 05/02/06 05/02/06 05/02/06 05/02/06 05/02/06 05/02/06 9-5/8" CSG MILL OUT WINDOW 7700' - 7750' (SECTION MILL) -14-1/2" HES X NIP -17" X 4-112" BAKER S-3 PKR -i 4-1 /2" HES X NIP -i4-1/2" HES XN NIP 41/2" TUBING TAILIWLEG -I BKR IBP (SET 01/16/97) I -17" X 4-1/2" TrN SS PKR, 10 = 4.000" I -14-1/2" PORTED JT, ID = 3.96" (43') I -1 TOP OF 4-1/2" SL TD LNR , 11124' HBTM OF 4-1/2" SLID LNR I PRUDHOE BA Y UNrr WELL: 09-35A PERMrr No: "1930310 API No: 50-029-21314-01 SEC 2, T10N, R15E 1822' FSL & 1048' FEL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = Datum TVO = 4-1/16" CrN McEVOY Otis 53.0' NA 2950' 91 @ 10737' 9871' 8800' SS e PERFORA TION SUMMARY REF LOG: COR ON 03/17/93 ANGLE AT TOP PERF: 43 @ 9666' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 2 9666 - 9674 0 11/15/96 2-1/2" 4 9674 - 9682 0 09/20/97 2-1/2" 6 9682 - 9688 0 10/21/96 2-1/8" 6 9690 - 9710 0 08/13/96 2-1/2" 4 9694 - 9710 0 OS/26/96 2-1/2" 6 9694 - 9710 0 10/21/96 2-1/8" 2 10520 - 10526 C 01/16/97 2-1/8" 2 10840 - 10860 C 01/16/97 4-1/2" SLID 10351 - 11124 C 01/16/97 DATE 05/13/86 03/27/93 02/10/02 09/29/02 09/27/05 05/04/06 REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK (09-35A) CH/TP CORRECTIONS BMlTP WAIVER SAFETY NOTE EZLITLH WAVIER SFTY NOTE DELETED D14 RWO DATE 09-35A e DRlG DRAFT I I I I , , , , , , , , , , , , , , , , , , , , ""~ REV BY COMMENTS PRUDHOE BAY UNrr WELL: 09-35A PERMrr No: "1930310 API No: 50-029-21314-01 SEC 2, T10N, R15E 1822' FSL & 1048' FEL BP Exploration (Alaska) e e 09-35 Rig Workover Prudhoe Bay Unit 50-029-21314-01 193-031 Accept: Spud: Release: Ri: PRE-RIG WORK 04/20/06 JET CUT 3.5" TUBING WITH 2.5" OD SLB POWER CUTTER AT 9378'. 04121/06 PUMPED 5 BBLS NEAT METHANOL SPEAR AND 987 BBLS 2% KCL DOWN TBG TAKING RETURNS UP IA TO FLOW LINE. PUMPED 172 BBLS DIESEL DOWN IA. LET U-TUBE FOR 1 HR. 04/22/06 RUN 3.85" CENT. AND FLAPPER CHECKER TO 2147' SLM. SET HOLD OPEN SLEEVE AT 2147' SLM (OAL 127",3" ID, 3.83" NO-GO). CIRC-OUT (PRE-RWO) CMIT TX IA TO 3500 PSI (PASSED) MIT OA TO 2400 PSI (PASSED) CIRC-OUT- PUMPED 5 BBLS NEAT METHANOL AND 987 BBLS 2% KCL DOWN TBG TAKING RETURNS UP IA TO FLOW LINE. PUMPED 172 BBLS 100° DIESEL DOWN IA TAKING RETURNS UP TBG TO FLOW LINE. LET U-TUBE FOR 1 HR. CMIT TX IA PRESSURED UP TO 3500 PSI WITH 6 BBLS DIESEL. TBG LOST 80 PSI AND IA LOST 80 PSI IN 1ST 15 MINUTES. TBG LOST 40 PSI AND IA LOST 40 PSI IN 2ND 15 MINUTES. TBG LOST X120 PSI AND IA LOST 120 PSI TOTAL IN 30 MINUTES. BLED PRESSURE DOWN. FREEZE PROTECTED FLOW LINE WITH 5 BBLS NEAT METHANOL AND 60 BBLS DIESEL. MIT OA PRESSURED UP TO 2400 PSI WITH 8 BBLS CRUDE. OA LOST 80 PSI IN 1ST 15 MINUTES. OA LOST 40 PSI IN 2ND 15 MINUTES. OA LOST 120 PSI FOR A TOTAL IN 30 MINUTES. BLED PRESSURE DOWN. FINAL WHP'S= 01010. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-35 09-35 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 4/22/2006 Rig Release: Rig Number: Spud Date: 4/27/1985 End: 4/23/2006 22:00 - 23:00 1.00 RIGD P PRE Rig down - Prepare to skid rig floor for move off well 09-06 23:00 - 00:00 1.00 RIGO P PRE Skid rig floor from drlg position to move position - Move rig off well 09-06 4/24/2006 00:00 - 01 :00 1.00 MOB P PRE Move rig from 09-06 to 09-35 01 :00 - 02:30 1.50 MOB P PRE Lay herculite - mats 02:30 - 04:00 1.50 MOB P PRE Move rig over well 09-35 - Shim rig 04:00 - 04:30 0.50 MOB P PRE Skid rig floor from move position to drlg position 04:30 - 05:30 1.00 RIGU P PRE Rig up floor - Set rock-washer - berm same - Prepare to take on seawater - (Accept rig 04:30 hrs) 05:30 - 06:30 1.00 FISH P DECOMP RU lubricator - Pull BPV - RD lubricator - 70 psi on tubing - 0 psi on annulus 06:30 - 07:30 1.00 FISH P OECOMP Install secondary annulus valve - Install 1502 flange on wing valve - MU circulating lines to tree and annulus valves 07:30 - 13:00 5.50 FISH N WAIT DECOMP Wait on DSM to RU containment - Tiger tank - Choke manifold - Run line to rig for displacement 13:00 - 13:30 0.50 FISH P DECOMP Test hardline to 500 psi - Hold 5 mins - Test good 13:30 - 15:00 1.50 FISH P DECOMP Circulate down tubing taking returns thru annulus - 7 bpm @ 1450 psi - (630 bbls) 15:00 - 15:30 0.50 FISH P DECOMP Let diesel mrigate to surface 15:30 - 16:00 0.50 FISH P DECOMP Pump additional 40 bbls to flush remaining diesel 16:00 - 16:30 0.50 FISH P OECOMP Blow down circulating lines - Verify well dead 16:30 - 17:30 1.00 FISH P OECOMP Install TWC - Test to 1000 psi from annulus - Test to 3500 psi for 10 mins - Test good 17:30 - 21 :00 3.50 FISH P OECOMP ND Tree - adapter flange - Check threads on hanger made up 8.5 turns handy - Grind off one lock down screw 21 :00 - 23:00 2.00 FISH DECOMP PJSM - MU spacer spool - NU BOP's 23:00 - 00:00 1.00 FISH DECOMP PJSM - Change out top rams to 2 7/8" X 5" VBR's 4/25/2006 00:00 - 00:30 0.50 FISH DECOMP Cont change out top rams to 2 7/8' X 5" VBR's 00:30 - 01 :30 1.00 BOPSU OECOMP RlU to test BOPE 01 :30 - 08:30 7.00 BOPSU OECOMP Test BOPE - 250 psi low, 3500 psi high, for 5 min each - Tested top VBR's with 3.5",4", & 4.5" test joints - Witness of test waived by AOGCC rep Chuck Scheve 08:30 - 09:00 0.50 BOPSU OECOMP RID test equipment 09:00 - 11 :30 2.50 BOPSU OECOMP RlU lubricator and attempt to pull TWC - Can't get on TWC - Cir on top of TWC with TO and DP - No success getting on TWC - Vacuum stack out attempting to see anything blocking TWC, can't see anything - Attempt to get on TWC with no success again 11 :30 - 13:00 1.50 BOPSU SFAL DECOMP N/D BOP - Clean and re-work threads on TWC 13:00 - 14:00 1.00 BOPSU SFAL OECOMP N/U BOP 14:00 - 14:30 0.50 BOPSU SFAL DECOMP Test BOP stack - 250 psi low, 3500 psi high for 5 min each 14:30 - 15:00 0.50 BOPSU OECOMP RlU lubricator and pull TWC 15:00 - 15:30 0.50 BOPSU DECOMP RID and UD lubricator 15:30 - 16:00 0.50 FISH DECOMP P/U 4.5" landing joint - M/U to hanger and pull to floor - ( PU = 152K) 16:00 - 17:00 1.00 FISH P DECOMP CBU - ( 70 SPM @ 400 psi) 17:00 - 17:30 0.50 FISH P OECOMP UD landing joint and hanger 17:30 - 19:00 1.50 FISH P OECOMP RlU control line spool and 4.5" tbg equipment and compensater 19:00 - 00:00 5.00 FISH P OECOMP PJSM - UD 4.5" 13Cr80 tubing (3700' tbg, recovered 57 ss-bands) 4/26/2006 00:00 - 04:00 4.00 FISH P OECOMP Continue UO 4.5" tbg 04:00 - 04:30 0.50 FISH P OECOMP Change over to 3.5" tubing handling equipment Printed: 5/8/2006 11 :55:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-35 09-35 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 4/22/2006 Rig Release: Rig Number: Spud Date: 4/27/1985 End: 4/26/2006 04:30 - 08:00 3.50 FISH P OECOMP UD 3.5" tubing - Recovered 190 jts 4.5" tbg, 1 4.5" pup jt, 55 jts 3.5" tbg, 8 GLM, 1 SSSV, 1 XN assembly, 1 3.5" cut jt 15.11' 08:00 - 08:30 0.50 FISH P OECOMP UD tubing equipment 08:30 - 10:00 1.50 FISH P OECOMP Mobilize BHA to rig floor 10:00 - 11 :30 1.50 FISH P DECOMP M/U BHA #1 and P/U collars 11 :30 - 12:00 0.50 FISH P DECOMP P/U 4" DP to 860' 12:00 - 13:00 1.00 FISH P DECOMP Mobilize storm packer to floor and set storm packer 97' below wellhead 13:00 - 13:30 0.50 FISH P DECOMP Test storm packer to 1000 psi for 10 min 13:30 - 14:00 0.50 BOPSU P OECOMP Pull wear ring - Blow down choke and kill lines - Drain stack 14:00 - 15:00 1.00 BOPSU P OECOMP N/D BOP - Drop off spacer spool 15:00 - 16:30 1.50 BOPSU P OECOMP N/U BOP - CIO spool on choke line - Send riser to shop to add 2' 16:30 - 17:00 0.50 BOPSU P DECOMP M/U running tool - Pull 9 5/8" packoff - Flush packoff bowl with water 17:00 - 18:00 1.00 BOPSU P DECOMP Set 9 518" packoff and test to 5000 psi for 30 min 18:00 - 19:00 1.00 BOPSU P DECOMP N/U riser and flowline 19:00 - 20:00 1.00 BOPSU P OECOMP RlU and test flange breaks and choke line to 250 psi low, 3500 psi high for 5 min each 20:00 - 20:30 0.50 BOPSU P DECOMP Install wear bushing - RILO's 20:30 - 21 :30 1.00 FISH P OECOMP Retrieve storm packer and UD same 21 :30 - 00:00 2.50 FISH P OECOMP Continue RIH with 4" OP singles from pipeshed to 4750' 4/27/2006 00:00 - 03:00 3.00 FISH P OECOMP Cont RIH to top of fish @ 9378' 03:00 - 08:30 5.50 FISH P DECOMP Mill 3.5" tubing FI 9378' TI 9378.5' - 40/60 RPM @ 5K TO, 56 SPM @ 1100psi, 3-7K WOB 1 after 2 hrs increased WOB TI 10-15K, 5-8K TO, PU 200, SO 160, RW 180 08:30 - 11 :30 3.00 FISH P OECOMP Flow check - Dry job - POOH 11 :30 - 12:00 0.50 FISH P OECOMP Stand back DC and UO BHA #1 12:00 - 13:00 1.00 FISH P DECOMP MIU BHA #2 13:00 - 16:00 3.00 FISH P DECOMP RIH TI 9332' - PU 213, SO 159. RW 183, TO 4K, RPM 20, 25 SPM @ 200 psi 16:00 - 16:30 0.50 FISH P OECOMP Wash TI 9378' - 25 SPM @ 200 psi - Engage fish & set grapples 16:30 - 22:00 5.50 FISH P DECOMP POOH T/416' 22:00 - 23:00 1.00 FISH P DECOMP Stand back DC - UD BHA #2 - UO Fish (cut jt, pup jt, seal stem) 23:00 - 00:00 1.00 FISH P OECOMP M/U BHA #3 4/28/2006 00:00 - 03:00 3.00 FISH P DECOMP RIH with cleanout assembly to 7559' 03:00 - 03:30 0.50 FISH P DECOMP Reverse cir hi-vis sweep to surface, 90 SPM @ 1640 psi 03:30 - 07:00 3.50 FISH P DECOMP Flow check - Dry job - POOH to BHA 07:00 - 08:00 1.00 FISH P DECOMP Stand back collars and UD BHA #3 08:00 - 09:00 1.00 FISH P OECOMP Clear rig floor - M/U BHA #4 09:00 - 11 :30 2.50 FISH P OECOMP RIH to 7510' - Establish PU 170, SO 140, RW 90, RPM 90, TO 4K 11 :30 - 13:00 1.50 FISH P DECOMP Tag tieback sleeve @ 7559' - Polish and dress tieback sleeve @ 5' strokes, 90 RPM, 4K TO, 212 GPM @ 440 psi 13:00 - 14:00 1.00 FISH P DECOMP Reverse circulate bottoms up @ 255 gpm @ 750 psi 14:00 - 14:30 0.50 FISH P DECOMP RID cir lines and blow down kill line 14:30 - 16:00 1.50 FISH P OECOMP PJSM - Cut drilling line - Service top drive 16:00 - 19:00 3.00 FISH P OECOMP Flow check - Dry job - POOH to BHA 19:00 - 19:30 0.50 FISH P DECOMP Stand back collars - UO BHA #4 19:30 - 20:00 0.50 BOPSU P DECOMP Drain stack - Pull wear bushing 20:00 - 21 :00 1.00 BOPSU P OECOMP CIO upper rams to 7" - Test door seals to 1500 psi for 5 min Printed: 5/812006 11 :55:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-35 09-35 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 4/22/2006 Rig Release: Rig Number: Spud Date: 4/27/1985 End: RID test equip - Blowdown kill line RlU 7" casing eqipment PJSM - Run 7" csg - Mobilize & M/U 7" tieback assembly and shoe track - Check float equip 4/29/2006 00:00 - 04:00 4.00 CASE P TIEB1 RIH wIT' 26# L-80 BTC-M csg to 4522' 04:00 - 05:00 1.00 CASE P TIEB1 PJSM - RlU Torque Turn Equipment and compensater for TC-II 7" csg 05:00 - 11 :00 6.00 CASE P TIEB1 PJSM - RIH wI 7" 26# L-80 TC-II csg to 7511' 11 :00 - 12:30 1.50 CASE P TIEB1 Space out tieback seal assembly 12:30 - 13:00 0.50 CASE P TIEB1 RID compensater and RlU cmt head 13:00 - 14:30 1.50 CASE P TIEB1 Test seals to 500 psi - Circulate @ 212 gpm, 210 psi - PJSM - Batch cmt 14:30 - 16:30 2.00 REMCM P TIEB1 CMT per plan - 5 bbl H20, test lines to 4500 psi, 15 bbls H2O, BTM plug, 104.6 bbls 12.5 ppg lead cmt, 104.1 bbl 15.8 ppg tail cmt, Top plug, 20 bbl H20, displace with 268.5 bbls SW @ 6 BPM @ 2400 psi, Bumped plug wI 500 psi over = 2900 psi 16:30 - 17:00 0.50 REMCM P TIEB1 Slack seal assembly into receptacle - Check floats 17:00 - 17:30 0.50 CASE P TIEB1 UD cmt head & TO turn equipment - Flush stack - Void 7" for cut 17:30 - 19:30 2.00 BOPSU P DECOMP N/D BOP - Set Emergency slips @ 230K wt - Cut 7" csg with Wachs cutter 19:30 - 00:00 4.50 BOPSU OECOMP NU 13-5/8" X 13-5/8" Cameron Tubing Head and BOPE. Test 7" casing pack-off to 4500 psi for 30 minutes. Change out spool on choke line. 4/30/2006 00:00 - 01 :00 1.00 BOPSU DECOMP PJSM - N/U riser & flowline - Install test plug 01 :00 - 03:00 2.00 BOPSU DECOMP CIO upper rams to 2 7/8" X 5" VBR - Open, wash and inspect blind and lower rams for cement 03:00 - 04:00 1.00 BOPSU DECOMP RlU to test BOPE 04:00 - 08:00 4.00 BOPSU DECOMP Test BOPE (250 psi low, 3500 psi high for 5 min each) - Witnesing test waived by AOGCC Rep. Lou Grimaldi 08:00 - 08:30 0.50 BOPSU OECOMP RID test equipment - Blowdown TD, choke and kill lines 08:30 - 09:00 0.50 FISH DECOMP Mobilize BHA #5 to rig floor 09:00 - 10:00 1.00 FISH DECOMP M/U BHA #5, clean out assembly 10:00 - 12:30 2.50 FISH DECOMP RIH to 7350' 12:30 - 13:00 0.50 CLEAN DECOMP Wash down F/7350' TI 7499' - Tag cement @ 7499' , 225 GPM @ 730 psi, PU 170, SO 135, RW 150 13:00 - 14:00 1.00 CLEAN P DECOMP RlU and test casing to 3500 psi for 30 min 14:00 - 14:30 0.50 CLEAN P DECOMP RID test equipment and blowdown lines 14:30 - 15:30 1.00 CLEAN P DECOMP Drill cement and float collar - F/7499' T/7631' - 60 RPM, 5 TO, 250 gpm, 890 psi, PU 170, SO 135, RW 150 15:30 - 16:00 0.50 CLEAN P OECOMP CBU - Rot & Rec @ 60 RPM, 5 TO, 425 gpm, 1970 psi 16:00 - 19:00 3.00 CLEAN P OECOMP Flow check - POOH t/ 411 ' 19:00 - 19:30 0.50 CLEAN P DECOMP Stand back collars - UO BHA #5 19:30 - 20:00 0.50 FISH P DECOMP M/U BHA # 6, packer milling assembly 20:00 - 21 :30 1.50 FISH P DECOMP RIH to 4683' 21 :30 - 00:00 2.50 FISH P OECOMP PJSM - Slip and cut new drilling line, 1200' 5/1/2006 00:00 - 01 :00 1.00 FISH P DECOMP PJSM - Finish spooling new drill line on drawworks - Service TD & Blocks 01 :00 - 02:00 1.00 FISH P OECOMP Lubricate rig - Adjust rollers for new drill line 02:00 - 03:30 1.50 FISH P OECOMP RIH FI 4683' TI 9324' - Wash to 9408' and tag packer 03:30 - 05:00 1.50 FISH P DECOMP Mill packer F/9408' T/9412' , (Lost returns) PU 220, SO 150, RW 176, RPM 80, TO 7K, 175 GPM @ 500psi 05:00 - 06:00 1.00 FISH P OECOMP Push packer FI 9412' TI 10090', tail @ 10208' Printed: 5/812006 11 :55:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-35 09-35 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 4/22/2006 Rig Release: Rig Number: Spud Date: 4/27/1985 End: 5/1/2006 06:00 - 07:30 1.50 FISH P OECOMP Monitor hole - Shoot fluid depth levels, Initial 462', Secondary 672' 07:30 - 13:00 5.50 FISH P OECOMP POOH to 408' - Pumping 6 bbls per 5 stands, (Fluid level shots @ 9702' = 672', @ 8284' = 792') 13:00 - 13:30 0.50 FISH P OECOMP Stand back collars and UD BHA #6 13:30 - 14:30 1.00 FISH P OECOMP M/U BHA #7 ( Spear assembly) 14:30 - 19:00 4.50 FISH P DECOMP RIH to 9986' (fill pipe every 10 stands with 10 bbls) 19:00 - 20:00 1.00 FISH P OECOMP Wash down and engage fish @ 10091' - (30 SPM @ 70 psi before fish, 30 SPM @ 240 psi w/fish) PU 245, SO 155, RW 187,20 RPM, TO 8K 20:00 - 21 :00 1.00 FISH P OECOMP POOH F/10091' TI 9137' - Lost 5K drag, check pressure with 30 SPM @ 70 psi 21 :00 - 22:00 1.00 FISH P OECOMP RIH TI 10091', set down 45K, pressured T/140psi with 30 SPM, worked bumper sub, POOH tJ 10031', checked pressure with 30 SPM with 1140 psi 22:00 - 00:00 2.00 FISH P OECOMP POOH FI 10031' T/6582', (pumping 6 bbls every 5 stands) 5/2/2006 00:00 - 05:00 5.00 FISH P OECOMP Cont POOH FI 6582' T/408', (Pipe pulling wet, pump 10 bbls fluid every 5 stands) 05:00 - 06:00 1.00 FISH P OECOMP Stand back collars and UO BHA #7 (spear assembly) 06:00 - 06:30 0.50 FISH P DECOMP RlU 3.5" tubing equipment 06:30 - 07:30 1.00 FISH P DECOMP UD 3.5" tail pipe assembly, (4-10',2-3',1-3' pup jts, 2-nipples) 07:30 - 08:00 0.50 FISH P DECOMP Clear rig floor and mobilize BHA #8 08:00 - 08:30 0.50 FISH P DECOMP M/U BHA #8 (clean out assembly) 08:30 - 13:00 4.50 FISH P OECOMP RIH TI 10113' (fill drill pipe every 10 stands with 10 bbls fluid) 13:00 - 13:30 0.50 FISH P OECOMP Wash hole clean F/10208' TI 10113', 30 SPM @ 70 psi 13:30 - 20:30 7.00 FISH P DECOMP POOH UO DP FI 10208' T/411' 20:30 - 21 :30 1.00 FISH P DECOMP UD drill collars and BHA #8 21 :30 - 22:30 1.00 FISH P OECOMP Clear rig floor, UD all Baker tools 22:30 - 00:00 1.50 RUNCO P RUNCMP Mobilize tubing equipment to floor and RlU for 4 1/2" completion run 5/3/2006 00:00 - 01 :00 1.00 RUNCMP Cont RlU F/4.5" tbg & PJSM 01 :00 - 02:00 1.00 RUNCMP M/U & Run tail pipe assembly & Inspect packer 02:00 - 14:30 12.50 RUNCMP Run 4.5" 13cr 12.6# VAM TOP tubing to 9445'-Filling hole wI 40 bph- No rejected pipe or backouts 14:30 - 15:30 1.00 RUNCMP Establish parameters- PU 170k- SO 130k- PU tubing hanger- Drop ball & rod assembly. 15:30 - 16:30 1.00 RUNCMP Land hanger- Verify landed- RILDS 16:30 - 17:30 1.00 RUNCMP Pump down annulus- 3 bpm 180 psi wI 175 bbls inhibited seawater 17:30 - 19:30 2.00 RUNCMP RU & pump down tubing to set packer- Pressure to 3500 psi for 30 min- Test good- Bleed tubing to 1500 psi- Pressure up on annulus to 3500 psi for 30 min- Test good- Bleed tubing pressure & shear DCK shear valve. 19:30 - 20:30 1.00 RUNCO RUNCMP RID cir lines - UO landing jt - Install TWC & test TI 1000 psi 20:30 - 21 :30 1.00 RUNCO RUNCMP Clear tbg equipment from rig floor 21 :30 - 23:30 2.00 BOPSU P RUNCMP NIO BOPE 23:30 - 00:00 0.50 WHSUR P RUNCMP N/U adapter flange 5/4/2006 00:00 - 00:30 0.50 WHSUR RUNCMP PJSM- Working in cellar- Tools- Pressure 00:30 - 01 :30 1.00 WHSUR RUNCMP NU adapter flange 01 :30 - 02:30 1.00 WHSUR RUNCMP Test flange to 5000 psi f/30 min.- Test Good 02:30 - 03:30 1.00 WHSUR RUNCMP NU tree 03:30 - 04:00 0.50 WHSUR RUNCMP RU & test tree to 5000 psi f/10 min.- Test Good 04:00 - 05:00 1.00 WHSUR RUNCMP RU lubricator- Pull TWC Printed: 5/8/2006 11 :55:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-35 09-35 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 4/22/2006 Rig Release: Rig Number: Spud Date: 4/27/1985 End: 5/412006 05:00 - 06:00 06:00 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 12:00 1.00 WHSUR 1.50 WHSUR 1.50 WHSUR 0.50 WHSUR 0.50 WHSUR 2.00 WHSUR RUNCMP RU Hot oil Truck- PJSM wI all personnel- Test lines to 2000 psi RUNCMP Pump down annulus wI 70 bbls diesel- 2 bpm 600 psi RUNCMP Allow diesel to "U Tube" RUNCMP Install BPV- test same to 1000 psi f/5 min.- OK RUNCMP Suck back all diesel wI Hot Oil truck RUNCMP Install all guages- Clean cellar- Secure well- Release rig at 12:00 hrs Printed: 5/8/2006 11 :55.23 AM e e ~1rL%1rŒ (ID~ L%~~~æL% I AIfASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ,_ ~ ¿ 01Þl., \~?J Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-35A Sundry Number: 306-110 Dear Mr. Chan: Enclosed is the approved Application for Sundry ApprovaJ. relating tOHthe 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 tbi~ay of March, 2006 Encl. lJtß'- \,<.rL ,~ (jV} ~(7A/'ÞÞ3/2!.Ja,.Ilf6 W.4~ 11Vr/wo(, Ij\.)íJ\¡~ ,-~I STATE OF ALASKA · I' RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION \'~,;.. ')006 3 /¿ 0 APPLICATION FOR SUNDRY APPROVAL ili"R 2 3 L .. )(<< 20 AAC 25.280 Alaska Oil & Gas Cons. COO1mlsslon ~ . e 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Other --------------~ o Alter Casing III Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program III Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. a Development o Exploratory 193-031/' 3. Address: o Stratigraphic o Service 6. API Number: ,/ P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21314-01-00 7. KB Elevation (ft): 52' 9. Well Name and Number: PBU 09-35A / 8. Property Designation: 10. Field / Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11170 9002 10297 / 8994 10297 11165 Casinç¡ LenÇJth Size MD / TVD Burst Collapse ~ I 111' 20" 111' 111' 1490 470 ~lIrf~r.A 2526' 13-3/8" 2526' 2526' 3450 1950 7700' 9-5/8" 7700' 6879' 6870 4760 Liner 2832' 7" 7555' - 10387' 6767' - 9001' 8160 7020 Liner 888' 4-1/2" 10282' - 11170' 8992' - 9002' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: I Tubing MD (ft): 9666' - 11124' ./ 8714' - 9003' 4·1/2', 12,6# 13·1/2", 9.2# ./ 13Cr80 9530' Packers and SSSV Type: 7" x 3-1/2" Baker 'SABL' packer; Packers and SSSV MD (ft): 9409'; /' 4-1/2" Camco TRDP-4A TRSSSV 2165' / 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal o BOP Sketch o Exploratory a Development tJ Service o Detailed Operations Program 14. Estimated Date for A~J2006 15. Well Status after proposed work: Commencing Operations: a Oil o Gas o Plugged o Abandoned 16. Verbal Approval: \~~: o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby œr::tißt that the fOregr is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed' N1Yne p"uJ-Çh<y'l) Title Drilling Engineer SiQnatu~.Y ( (.- Phone 564-5254 Date 3123/oc.. Prepared By Name/Number: Terrie Hubble, 564-4628 "- "- Commission Use Only I Sundry Number: ?n lo .... I tn Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: T -e..-c;. t 130 PL= -ro ?>SOO ftA. Subsequent Form Required: \0 - 4(6 ''A~' - ~ ~ i ,. $(¡:OMf:f¡J8!ifÓNER APPROVED BY ~. Date 3·¡f-ob Approved By: THE COMMISSION Form 10-403 Revised 07/2005 o! - RBDMS 8FL MAR 28 2006~. Submit In Duplicate W '-¡;. , \ i-. ") 3. 4. 5. 6. 7. 8. 9. 10. 2. During the pre-rig work, a plug will be set in the XN nipple in the current 4-1/2" completion at 9518' MD, the tubing will be cut at 9378' MD and a BP~ill be placed in the tubing profile. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. Pull and LD tubing string to the cut at 9378' MD. RIH with scraper x tie back polishing mill to TaL at 7555' MD and polish tie back receptacle. Run and cement 7" tieback to surface. Drillout shoe track. /' Mill and retrieve the Baker SABL packer. Run 4-1/2" 13Cr80 completion with Baker S-3 packer. Set packer at -9350' Displace the IA to packer fluid and set the packer. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. Set BPV. ND BOPE. NU and test tree. RDMO. MD / 1 9-35 Workover Procedure e e lREE= WELLHEAD'= ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumìVD= 4-1/16" CrN McEVOY Otis 53.0' NA 2950' 91 @ 10737' 9871' 8800' SS 945 Proposed Com¡!etion 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 7" TIEBACK, 26#, L-80 H 7555' 2100' -14-1/2" HES X NIP GAS LIFT MANDRELS ST MD ìVD DEV 1YÆ VLV LATCH PORT DATE IBKRC-2 TIEBACK SLV,IO= 7,50" I 19-5/8" X 7" BKR H PKR. 10 = 6.19" I 19-5/8" X 7" BKR HYFLO HGR, ID = 6.14" I 19-5/8" CSG, 47#, L-80, ID = 8.681" H 17" L-80 X 7" 13-CR LNR XO I 9-5/8" CSG MILLOUT WINDOW 7700' - 7750' (SECTION MILL) -14-1/2" HES X NIP 9350' -i7" X 4-1/2" BAKER S-3 PKR -14-1/2" HES X NIP -i 4-1/2" HES XN NIP -14~1/2" TUBING TAIL WLEG I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3,958" I I TOP OF TrN POLISHER RISER, 10 = 4,820" I 10291' I I I I , , , , , , , , , , , , , , , I I I , , , , , , , , , , , , ',~ -lBKRIBP(SET01/16/97) I -17" X 4-1/2" TrN SS PKR, ID = 4.000" I -4~1/2" PORTED JT, ID = 3.96" (43') I -TOPOF4-1/2"SLTOLNR I 17" MA RKER JT (20') I 9857' 17" LNR, 29#, L-80/13-CR, 10 = 6.184" I 10387' ÆRFORA TION SUMMARY REF LOG: COR ON 03/17/93 ANGLE AT TOP ÆRF: 43 @ 9666' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 115' STRIP GUN 8-13-96 I 11124' H BTM OF 4-1/2" SL TO LNR I SEE PAGE 2 FOR ÆRFORA TION DATA 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" DATE 05/13/86 03/27/93 02/10/02 09/29/02 09/27/05 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (09-35A) CHlTP CORRECTIONS BrvvTP WAIVER SAFETY NOTE EZLITLH WAVIER SFTY NOTE DELETED DATE REV BY COMMENTS PRUDHOE BA Y UNff WELL: 09-35A ÆRMff No: ~930310 API No: 50-029-21314-01 SEC 2, T10N, R15E 1822' FSL & 1048' FEL BP Exploration (Alaska) IREE = WELLHEAD"= ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CrN McEVOY Otis 53.0' NA 2950' 91 @ 10737' 9871' 8800' SS 13~3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.750" @ 9 3-1/2" PARKER SWN NI 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf,ID= 3.958" I BKR C-2 TIEBACK SLV, ID = 7.50" 9-5/8" X 7" BKR H PKR, ID = 6.19" 19-5/8" X 7" BKR HYFLO HGR, ID = 6.14" 19-5/8" CSG, 47#, L-80, ID = 8.681" 17" L-80 X 7" 13-CR LNR XO 3-1/2"TBG, 9.2#, 13-CR, .0087 bpf,ID=2.992" 17" MA RKER JT (20') I TOP OF TrN POLISHER RISER, ID = 4.820" , 7" LNR, 29#, L-80/13-CR, ID = 6.184" e 09-35A/ Y NOTES: WELL ANGLE> 70° @ 10071' & > 90° @ 10426' . FISH ON BTM. ***CHROMETBG & LNR*** . I 2165' 1-14-1/2" CAMCO TRDP-4A TRSSSV, ID = 3.812" I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1--4 ~ 1 3584 3545 27 MMG DOME RK 16 09/26/97 1 2526' 2 6001 5544 36 MMG SO RK 28 09/26/97 l 3 7267 6543 39 MMG DMY RK 0 03/27/93 518' 4 7900 7046 28 MMG DMY RK 0 09/18/97 5 8427 7554 8 MMG DMY RK 0 03/27/93 PPLE 6 8923 8046 7 MMG DMY RK 0 03/27/93 7 9170 8288 18 MMG DMY RK 0 03/27/93 I 8 9323 8429 26 MMG DMY RK 0 09/18/97 7482' I 1- 7555' ¿ 7486' H4-1/2" x 3-1/2" TBG XO, ID = 2.992" 1 1- 7562' ~ IX 1- 7567' J 9-5/8" CSG MILLOUT WINDOW H 7700' I-- 7700' - 7750' (SECTION MILL) 1 9232' . ~ -----¡;. ¡....-.V I 1-13-1/2" PARKERSWS NIP,ID=2.813" I I I 9352' J 'I 9408' H3-1/2"BKRKBHSEALASSY,ID=3.95" l ~ 9409' 1.,7" x 3-1/2" BKR SABL PKR. 10 = 3.875" 1 I I 9438' H 3-1/2" PARKER SWS NIP, ID = 2.813" 1 I I 9518' 1- 3-1/2" PARKER SWN NIP, 10 = 2.750" I H 9529' I H3-1/2" TUBING TAIL WLEG I 9530' [ I 9530' H ELMD TT LOGGED 11/22/96 I 1 9857' [ 1 10291' 110297' elml-BKRIBP(SEr01/16/97) I ~ :8 2S 10301' H7" x 4-1/2" TrN SS PKR, ID = 4.000" I . . . 10308' 1-14~1/2" PORTED JT, 10 = 3.96" (43') I I I 10351' 1-TOPOF4-1/2"SLTDLNR I I 1 0387' ..; I I ~ I ÆRFORA TION SUMMARY REF LOG: CDR ON 03/17/93 ANGLEAT TOP ÆRF: 43@ 9666' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR ÆRFORA TION DA TA DATE 05/13/86 03/27/93 02/10/02 09/29/02 09/27/05 REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK (09-35A) CHlTP CORRECTIONS BIINTP WArvER SAFETY NOTE EZLlTLH WAVIERSFTY NOTE DELETED I I , , , , , , , , , , , , , , , 11124' H BTM OF 4-1/2" SL TD LNR 1 115' STRIP GUN 8-13-96 1 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 09-35A PERMIT No: '1930310 API No: 50-029-21314-01 SEC 2, T10N, R15E 1822' FSL & 1048' FEL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = -,,,,-,,,-,,,,,,,,.,.,.,,,,-,,,,,,,.,,."-,,,,"-,..."'.' KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 4-1/16" CrN McEVOY Otis 53.0' NA 2950' 91 @ 10737' 9871' 8800'SS e ÆRFORA TION SUMrvtARY REF LOG: CDR ON 03/17/93 ANGLE AT TOP ÆRF: 43 @ 9666' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-1/2" 2 9666 - 9674 0 11/15/96 2-1/2" 4 967 4 ~ 9682 0 09/20/97 2-1/2" 6 9682 ~ 9688 0 10/21/96 2-1/8" 6 9690 ~ 9710 0 08/13/96 2-1/2" 4 9694 - 9710 0 OS/26/96 2-1/2" 6 9694 - 9710 0 10/21/96 2-1/8" 2 1 0520 ~ 10526 C 01/16/97 2-1/8" 2 10840 - 10860 C 01/16/97 4-1/2" SLTD 10351-11124 C 01/16/97 DATE 05/13/86 03/27/93 02/10/02 09/29/02 09/27/05 03/20/06 DATE REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (09-35A) CH/TP CORRECTIONS BrvvTP WArl/m SAFETY NOTE EZLITLH WA vim SFTY NOTE DELETED V VPAG SAFETY NOTE UPDA TE 09-35A e . REV BY I I I , , , , , ' , ' , ' , ' , ' , ' , ' , ' , ' "'~ COMMENTS PRUDHOE BA Y UNrr WELL: 09-35A ÆRMrr No: "1930310 API No: 50-029-21314-01 SEC 2, T10N, R15E 1822' FSL & 1048' FEL BP Exploration (Alaska) 04102/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-rN: Beth NO. 2725 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 400 Anchorage, AK 99504 Field: Prudhoe Bay, Endicott, Milne Pt. Color Well Job # Log Description Date Blueline Prints CD ~'-20_.B c_~--~-c:~ L~ 23081 CH EDIT MGR 12/08102 1 ~?r~. 9-35A \ Ot ~ -~ ~ ~ 23050 RST 01108103 1 ~ /.~ ~ 0.S. 9-28A '~ ~ ,~ -~ ~ 22515 RST ~110102 ~ 1 ~~ ~.18-05 ~-~~ 2241~ MCNL 08119/02 I 1 ~~H ~.S~-44A t~'~ 23100 SCMT 03105103 2 ~-30 ,~-~ .~ ~ 23078 SCMT 02113~03 2 ~IA~ 23087 OH EDIT ARC & IMPULSE (PDC) 11103102 ~ / ~'~ ~31A ~ ,.~ ~ 23087 MD VISION RESISTIVI~ 14103102 ~ ~-31A/ ~ 23087 ~D VISION RESlSTIVI~ ~4103/02 1 ~-31A/ 23087 :MD VISION RESISTIVI~ (BHP) ~1103102 ~ , , .... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~?,~ :~...~ .~ . Date Delivered: ~=' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FFN: Beth '~. .~) Receive -~--, STATE OF ALASKA -~ (A OIL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 55' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1822' NSL, 1048' WEL, Sec 2, T1 ON, R15E, UM. 9-35A At top of productive interval: 9. Permit number/approval number: 2590' NSL, 2658' FWL, Sec 2, T10N, R15E, UM. 93-31 At effective depth: 10. APl number: 50-029-21314-01 At total depth: 11. Field/Pool: 434' NSL, 3357' WEL, Sec 35, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11170 feet Plugs (measured) Bridge Plug @ 10297' MD (set 1/16/97) true vertical 9002 feet0RIGINAL Effective Depth: measured 10297 feet Junk (measured) true vertical 8996 feet Casing Length Size Cemented Measured depth True vedlcal depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2526' 13-3/8" 2500 Sx CS III & 2526' 2526' 400 Sx CS II Production 7700' 9-5/8" 500 Sx Class G & 7700' 6879' 300 Sx PFC Liner 2844' 7" 526 Sx Class G 10387' 9001' SPotted Liner 879' 4-1/2" Uncemented 11170' 9002' Perforation Depth measured 9666 - 9688'; 9690 - 9710'; [Isolated below Bridge Plug: Slotted Liner: 10387 - 11124' w/perfs at 10520 - 10526' & 10840 - 10860'] true vertical 8715 - 8730'; 8731 - 8746'; [Isolated below Bridge Plug: Slotted Liner: 9000 - 9003' w/perfs at 9000 - 9000' & 8999- 8999'] Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 7486' MD; 3-1/2", 9.2#, 13CR Tbg @ 9530' MD. Packers and SSSV (type and measured depth) Baker SABL Packer @ 9409' MD; Camco TRDP-4A SSSV @ 2165' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 865 11932 2531 372 Subsequent to operation 1667 27506 6502 754 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X 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 Date /~ -"7 "' ~' '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-35A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE 3 9/19197: MIRU CTU & PT equipment. RIH w/CT & tagged Inflatable Bridge Plug (set 1/16/97) at 10282' MD. PU & pumped 24 bbls of gelled sand slurry containing 9000 lbs of 20/40 mesh sand to place a sand plug cover on top of the IBP to 9910' MD. POOH w/CT. Rigged down. 9/20/97: RIH & tagged sand plug top at 9934' MD. follows: RU & RIH w/perforating gun & shot 8' of perforations as Added Perforations: 9674- 9682' MD (Z3) Ref. Log: CDR 3-17-93. Used a 2-1/2" carrier & shot the perfs at 4 spf at zero degree phasing at balanced pressure. RD. 9/23/97: MIRU & PT equipment to 8000 psi. Pumped a Hydraulic Fracture Treatment using 20/40 & 16/20 mesh proppants through the open perforation intervals located above the sand plug at: 9666 - 9688' MD (Z3) 9690 - 9710' MD (Z3) Ref. Log: CDR 3-17~93. Pumped Breakdown: a) 200 bbls 20~ Pre Pad Gel @ 20 bpm, followed by b) Shutdown. ISIP@1300. Pumped Data Frac: c) 22 bbls 40# Crosslinked Gel ~ 5 bpm, followed by d) 106 bbls Flush @ 5 bpm, followed by e) 27 bbls Flush @ 25 bpm, followed by f) Shutdown. Pumped Fracture Treatment: g) 15 bbls 50~ Crosslinked Pad @ 20 bpm, followed by h) 83 bbls Crosslinked Slurry in 2 to 10 ppg proppant stages, followed by i) Flush. Screened out w/8 ppg stage on the perfs. Placed a total of 7000 lbs of proppant in the formation. RD. 9/25197: RIH w/CT & jetted a proppant fill cleanout w/biozan to 9750' MD. Returned the well to production & obtained a valid welltest. ....... STATE OF ALASKA ALASKA _ _ AND GAS CONSERVATION CO,v,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing ~ Alter casing ~ Repair well ~ Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1822' NSL, 1048' WEL, Sec 2, T10N, R15E, UM. At top of productive interval 2590' NSL, 2658' FWL, Sec 2, T10N, R15E, UM. At effective depth At total depth 434' NSL, 3357' WEL, Sec 35, T10N, R15E, UM. 5. Type of Well Development Exploratory Slratigraphic Service X 6. Datum of elevation(DF or KB) 55' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit number/approval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 11170 feet 9002 feet Plugs(measured) Bridge Plug @ 10297' MD (Set 1/16/97). Effective depth: measured 10297 feet true vertical 8996 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2526' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2526' 2526' Production 7700' 9-5/8" 500 Sx CIG & 300 Sx PFC 7700' 6879' Liner 2844' 7" 526 Sx CIG 7543 - 10387' 6757 - 9001' Slotted Liner 879' 4-1/2" Uncemented 10291 - 11170' 8993 - 9002' Perforation depth: measured 9666 - 9674'; 9682 - 9688'; 9690 - 9710'; [Isolated below Bridge Plug: Slotted Liner: 10387 - 11124' w/perfs at 10520 - 10526' & 10840 - 10860'] true vertica! 8715 - 8720'; 8726 - 8730'; 8731 - 8746'; [Isolated below Bridge Plug: Slotted Liner: 9000 - 9003' w/perfs at 9000 - 9000' & 8999 - 8999'] Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 7486' MD; 3-1/2", 9.2#, 13CR Tbg @ 9530' MD. Packers and SSSV (type and measured depth)Baker SABL Packer @ 9409' MD; Camco TRDP-,~ ~ ~%3~1',~F~D. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORIGINAL FEB 10 1997 Alaska 0il & Gas Cons Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1131 11112 2090 -- 1425 15308 3167 Tubing Pressure 399 5O9 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~'~M/~ '~. ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-35A DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION TREATMENT 1/16/97: RIH w/Inflatable Bridge Plug & inflated plug to set at 10297' MD (middle of element). 1/19/97: A Fullbore Mud Acid Stimulation Treatment was performed as follows: MIRU & PT equipment to 4500 psi. Pumped the treatment fluids through the open perforations located above the IBP at: 9666 - 9674' MD (Z3) 9682 - 9688' MD (Z3) 9690 - 9710' MD (Z3) Ref. Log: CDR 3/17/93. Pumped: a) 25 bbls 2% NH4CI Water @ 5 bpm, followed by b) 25 bbls 50% Diesel / 50% Xylene @ 5 bpm, followed by c) 25 bbls 12% HCl w/10% Xylene, followed by d) 10 bbls Brine w/BAF Diverter, followed by e) 75 bbls 12% HCl w/10% Xylene @ 5 bpm, followed by f) 20 bbls 9% HCI - 1% HF @ 5 bpm, followed by g) 50 bbls 12% HCl w/10% Xylene @ 5 bpm, followed by h) 200 bbls 2% NH4Cl Water @ 5 bpm, followed by i) 120 bbls Crude displacement, followed by j) 10 bbls Diesel, followed by k) Shutdown. Rigged down. 1/26/97: Pumped Scale Inhibition treatment. Returned well to production & obtained a valid production test. FE[5 10 199'? Alaska 0il & ..-,: ~r~,,-; (;onm'~ission STATE OF ALASKA --. ALA?'~'"~"~"LAND GAS CONSERVATIO, ,( ~ISSION REPOh ,' SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1822' NSL, 1048' WEL, Sec 2, T10N, R15E, UM. At top of productive interval 2590' NSL, 2658' FWL, Sec 2, T10N, R15E, UM. At effective depth At total depth 434' NSL, 3357' WEL, Sec 35, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 55' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit number/approval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11170 feet Plugs(measured) true vertical 9002 feet Effective depth: measured 11129 feet true vertical 9002 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2526' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2526' 2526' Production 7700' 9-5/8" 500 Sx CIG & 300 Sx PFC 7700' 6879' Liner 2844' 7" 526 Sx CIG 7543 - 10387' 6757 - 9001' Slotted Liner 879' 4-1/2" Uncemented 10291 - 11170' 8993 - 9002' Perforation depth: measured 9666 - 9674'; 9682 - 9688'; 9690 - 9710'; and Slotted Liner: 10387 - 11124' w/perfs at 10520 - 10526' and 10840 - 10860' true vertical 8715 - 8720'; 8726 - 8730'; 8732 - 8746'; and Slotted Liner: 9000 - 9003' w/perfs at 9000 - 9000' and 8999 - 8999' Tubing (size, grade, and measured depth) 4-1/2", 12.64¢, 13-CR Tbg @ 7486' MD; 3-1/2", 9.2#, 13-CR Tbg @ 9530' MD. Packers and SSSV (type and measured depth) Baker SABL Packer @ 9409' MD; Camco TRDP-4A SSSV @ 2165' MD. 13. Stimulation or cement squeeze summary ~'~,,~[,,,~ Intervals treated(measured) See Attached ,J/~,~ 0'7 description including volumes used and final pressure&l~,~ ~ & GaS Co,s; P-,otlllllissi0t~J ''~- -- Treatment 14. Representative Daily A~}age Prod~lf:l~i~9~niection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 617 2518 2449 -- 328 Subsequent to operation 1117 8361 2954 -- 367 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 ~'~~ ~lq, ~.,../' Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date //.2-/2-'~f~ , SUBMIT IN DUPLICATE 9-35A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED i 0/2 1/9 6: MIRU & PT equipment. Reperforated: 9694 - 9710' MD (Z3) Added perforations: 9682 - 9688' MD (Z3) RIH w/perforating gun & shot 22' of perforations as follows: Ref. Log: CDR 3/17/93. Ref. Log: CDR 3/17/93. Used a 2-1/2" carrier & shot 6 spf at 60 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. I I/1 5/96- MIRU & PT equipment. RIH w/perforating gun & shot 8' of add perforations as follows: Added perforations: 9666 - 9674' MD (Z3) Ref. Log: CDR 3/17/93. Used a 2-1/2" carrier & shot 2 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. STATE OF ALASKA ALASKA ._ ,L AND GAS CONSERVATION CO,~,,~vIISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1822' NSL, 1048' WEL, Sec2, T10N, R15E, UM. At top of productive interval 2590' NSL, 2658' FWL, Sec2, T10N, R15E, UM. At effective depth At total depth 434' NSL, 3357' WEL, Sec 35, T10N, R15E, UM. 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 55' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit number/approval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe.~_~_ 61~oV E D 12. Present well condition summary Total depth: measured true vertical 11170 feet Plugs(measured) 9002 feet AUG 1 G 1996 Effective depth: measured 11129 feet Alaska 0il & Gas Cons. C0mmissi0D true vertical 9002 feet Junk(measured) Anchorage Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2526' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2526' 2526' Production 7700' 9-5/8" 500 Sx CIG & 300 Sx PFC 7700' 6879' Liner 2844' 7" 526 Sx CIG 7543 - 10387' 6757 - 9001' Slotted Liner 879' 4-1/2" Uncemented 10291 - 11170' 8993 - 9002' Perforation depth: measured 9690 - 9710'; Slotted Liner: 10387 - 11124' w/perfs at 10520 - 10526' & 10840 - 10860' true vertical 8731 - 8746'; Slotted Liner: 9000 - 9003' w/perfs at 9000 - 9000' & 8999 - 8999' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 7486' MD; 3-1/2", 9.2#, 13CR Tbg @ 9530' MD. Packers and SSSV (type and measured depth) Baker SABL Packer @ 9409' MD; Camco TRDP-4A SSSV @ 2165' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 319 1320 103 1408 17039 124 Tubing Pressure 245 532 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 Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-35A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/1 3/96' MIRU & PT equipment. Added perforations: 9690 - 9694' MD (Z3) Reperforated: RIH w/perforating gun & shot 16' of perforations as follows: Ref. Log: CDR 3/17/93. 9694 - 9706' MD (Z3) Ref. Log: CDR 3/17/93. Used a 2-1/8" carrier & shot 6 spf at 90 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. .... * .... STATE OF ALASKA .... '-': ALASKA _ .L AND GAS CONSERVATION CO~,,,wiSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing ~ Alter casing ~ Repair well~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1822' NSL, 1048' WEL, Sec2, T10N, R15E, UM. At top of productive interval 2590' NSL' 2658' FWL' Sec 2' T10N' R15E' UM' 0 R I G I J"~A LAt effective depth At total depth 434' NSL, 3357' WEL, Sec 35, T10N, R15E, UM. 6. Datum of elevation(DF or KB) 55' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit numbedapproval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11170 feet Plugs(measured) 9002 feet Effective depth: measured 11129 feet true vertical 9002 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2526' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2526' 2526' Production 7700' 9-5/8" 500 Sx CIG & 300 Sx PFC 7700' 6879' Liner 2844' 7" 526 Sx Cl G 7543 - 10387' 6757 - 9001' Slotted Liner 879' 4-1/2" Uncemented 10291 - 11170' 8993 - 9002' Perforation depth: measured 9694 - 9710'; Slotted Liner: 10387 - 11124' w/perfs at 10520 - 10526' & 10840 - 10860' true vertical 8734 - 8746'; Slotted Liner: 9000 - 9003' w/perfs at 9000 - 9000' & 8999 - 8999' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 7486' MD; 3-1/2", 9.2#, 13CR Tbg @ 9530' MD. Packers and SSSV (type and measured depth)Baker SABL Packer @ 9409' MD; Camco TRD~Z~ ~S¢¥¢/~',., ,., . , 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-Mcf Water-Bbl Casing Pressure 221 541 59 -- 239 522 31 Tubing Pressure 233 234 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢',/c4,,L, '~. ~ Title Engineering Supervisor Date S Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ 9-35A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/26/96: MIRU & PT equipment. RIH w/perforating gun & shot 16' of add perforations as follows: Added Perforations: 9694 - 9710' MD (Z3) Ref. Log: CDR 3/17/93. Used a 2-1/2" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED JUN ~ ~ 1996 Alaska 0ii & Ga~ ConS. commissioo Anch0rage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 AT-I'N: Sherrie NO. 1 O246 Company: Alaska Oil & Gas Cons Corem Attn: Howard Oakland 3001 Porct, pine Drive Anchorage, 6/18/96 Field: Prudhoe Bay Ar~adrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Progr~,~m Disk Calc;tllatic~n D.s. 4-30 ST 96;i'50 " cNT-[) .~ 7/~(~ 960510 1 D...S. 5-25 96137 TDT-P __-.~ '~ ! '~'~ 96..0.425 ................... 1 D.S. 1-9A '/ PERFORATION RECORD 960529 1 1 D.S. 1-22A -/ PRODUCI-ION & GAS ENTRY LOG 960529 I 1 D.S. 2-18A ¢ TDT-P BORAX 960603 1 1 D.S. 7-13A ~ PERFORATION RECORD 960602 I 1 D.S. 9-10 '/ PERFORATION RECORD 960523 1 1 ID.S. 9-35 f~ .) ~ PERFORATION RECORD 960526 I 1 D.S. 11-30 ~ PERFORATION RECORD 960509 1 1 D.S. 12-31 -/ INJECTION PROFILE 960525 I 1 D.S. 13-16 '/ INJECTION PROFILE 960527 1 1 D.S. 14-13 ,// INJECTION PROFILE 960527 I 1 D.S. 14-16 '/ LEAK DETECTION LOG 960523 1 1 ., D.S. 14-27 '/' INJECTION PROFILE 960527 1 1 · , ... SIGNED: :' DATE: Alaska Oit & Gas Cons. ~mmissi0n Please sign and return one copy of tills transmittal to Sherrie at the above address. Thank you. Anch0~age .;chlumberq_e_r__J GeoQue..;t 500 W. International ,Airport }3oad A~)chorage, Al,( 99515-1199 A'II"TN: She~"rie NO. 10025 Company: Alaska Oil & Gas Cons Corem Attn: Larr~r Grant 3001 Porcupine Drive Anchorage, AK '99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk I,' · D.S. 4-30 S'rl ,i~'-<~ ~ PROD. PROFILE ,, 9,6010'~, ,,1 , 1 ........ :D:~S. 5-25 ~',~ -- /,_ ~ ,/ PROD. PROFILE 960101 1 _ 1 .... D.S. 6-17 .(~_~£:c~ O _FR..OD. PROFILE 960117 1 1 , D.S. 6-17 __~ ',, ? O DIG.ENTRY & FLuID IMAGING TOOL 'i 960117 1 , 1 ..... D.S. 7-6A -~-~" / ~ '7 TDT-P 9601 06 I 1 ~Si:::7~15 .. ~)~ -, _/ __~_.~ _.L E__AK DETECTION I'~)G _'96011.5 I ..... I ..i '... "" D.S. 9-35A.. c~,.~ _.,~ ! STATIC BHP SURVEY 9601 0...2 1 .... 1 D.S. (.)-45 _~_(,~"_~./',_5"~oTATI.C BHP SURVEY .. 9601 0.4 . I __ _ 1 D.S. 9-46 ~ ~ PROD. PROFILE 960105 I 1 ,D.S. 11-16 sT1 ,~-:~' LEAK DETECTION LOG 960111 1 1 .... D.S. '11-18 ,,, ,'~ ~_/_L_~.-COMP. NEUTRON LOG 9601 17 1 .... 1 .... D.S. 15-1 ~,~ - (~ TDT-P BORAX 960116 I 1 '~'.S. '15-3'i~" ' ~-I/...~ LEAK DETECTION I'0G' ,.960112 1 I .... -_-__ ~' , ~. . ,. SIGNED: _~ DATE: ,, ,, FEB 0 9 1996 · Please sign and return one copy of this transmlttal to Sherrle at the above address. Thank you. _- Alaska Oil & Gas C0~,-,,~. Commission Anchor,-',, ,~, ....... :', PERMIT 93-031 93-031 93-031 93-031 93-031 93-031 93-031 93-03'1 93-031 93-031 93-0~1~ 93-031 93-031 93-031 93-031 DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 5993J 407~/ D~OP~// SHRVEY~ SHRVEY ~ CDN FLD PRN,~./ CDN FLD PRN~'/ T 9550-10387 CDR/CDN R COMP DATE:03/27/93 R 03/03-03/28/93 R 7700-11109 ANADRILL R 7700-11109 ANADRILL L 9550-10387 MAD PASS L 9587-10387 DRILLING PASS CDN FLD PRN TVD//L 8600-9000 MAD PASS CDN FLD PRN TVD'~/L 8600-9000 DRILLING PASS CDN N/F FLD PRN/L 9500-10300 MAD PASS CDN N/F FLD PRN~ L 9587-10300 DRILLING PASS CDR FLD PRN/ L 9587-10387 DRILLING PASS CDR FLD PRN TVD/"L 8600-9000 MAD PASS CDR FLD PRN TVD.w/L 8600-9000 DRILLIN PASS CDR MAD PASS~/ 93-031 PERF 93-031 PERF 93-031 L 9550-10385 MAD PASS p/L 9416-11078 ~/~ 9416-11078 PROD/SPIN/TEMP/v/L 1350-11070 STAT PRESS ~'~ L 9250-10130 93-031 Page- 1 Date: 01/10/95 RUN DATE_RECVD COMP 02/17/94 05/05/93 05/05/93 08/31/93 05/05/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 COMP 05/06/93 1 12/01/93 1 12/01/93 I 12/01/93 1 04/27/93 Are dry ditch samples required? Was the well cored? yes ~ Analysis & description '~~-~d? Are well tests required[~ yes ~ Received? yes no Well is in compliance In%[rial COMMENTS yes ~ And received? _~~no yes no ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, A, .... orage. AK Feb 10, 1994 Transmittal #: ARCO Open hole Magnetic tape(s) John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94O2O 99510,j~ ~ i Well iLog Datei Tape Type i Run, Number. (M-D-Y) Footage i.1_0-28-93 MWD:GR i 11933- 2' 161¢r ~cl0 iO\'(, i~3.- 11357 2-16_~.., 9-18-93i MWD: GR i ~' 11307- 9400 · ~ ~r4q3 .C¢ p.- c~¢,~! 955o i '15-8A I 10-29-93I MWD:GR IO, 10725- -~ ~r, Pf~ 8 '~-~ p., \ 7450 Contractor Sch Sch Atlas Sch Sch Number of Records:5 · DeGrey PBOE Document Control Distribution:. Bob Ocanas BPX State of Alaska Phillips Exxon Please acknowledge receipt by signing and returning a copy of transmittal. By: _, ~/ .... " Date: ,~L_L. LC/V~...L) Alas'~a 0,_'1 & Oas Cons. Cemr~iSsion ARCO Alarm, Inc. Is · 8ubskEary of A~n~cRlct~eldCom¢~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 REFERENCE: /2-16A ~q-?¢ 3-29 70-qz 4-1 '7 I-a 4-4 7s-'v"7 4-7ST 7a-t o 4-8 DEC 0 ? I79~ Alaska Oil & Gas Cons. Commission AnChorage ARCO CASED I.-IOI~ FINALS 9-25-93 9-26-93 9-19-93 9-23-93 9-17-93 SBT/GR/CCL I~aa-i 11~ v Collar (c-rc.~ ~os~o-lo~l 0 Production ~foo -qq5 q Perf Record ~o-I;~so Run Run Run Run Run 9-19-93 Perf Record ~0-qzz~ Run 9-23-93 Inj ~q~ 4-16 9-13-93 ~ ~tect/~-~'~i ~.~/~ ~ Rim 9-5A 9-16-93 ~oducflon/sa~e/,~ R~ 9-29 9-15-93 ~k Detect~];~/~,,~ R~ /9-35A 9-17-93 Pe~Record '%l~{{cT~ R~ ~9-35A 9-18-93 Pe~ Record flq~a-~io~g R~ 1, XO-35A 9- ! 9-93 ~od ~offie J s~ ~),~3 R~ 1, 9-42 9-14-93 ~od ~offie ]f~.i~/~ R~ 1, ~0~O 9-44 9-15-93 ~od ~offie{F~7~ R~ 1, /12-22 9-25-93 Jewe l al a R~ 1, k12-22 9-26-93 Pe~Record ~%00-~t0 R~ 1, 12-30 9-22-93 POG~~t/~G~ch R~ 1, 7~-~3 14-4 9-24-93 Pe~Record {~0~5~ R~ 1, 14-31 9-20-93 ~oducflon 2~-q~o R~ 1, 15-2 9-14-93 ~od ~offie[~J~{ea R~ 1, ~-~ 15-18 9-21-93 B~er ~~ble Packer R~ 1, ?Z-~a 16-29A 9-24-93 ~oducflonl~.a{~/~}~ R~ 1, ~-g~ 17-12 9-22-93 ~oducflon]9~{~{~~~ 1, ~-~5.18-25 9-20-93 ~od ~offie ~o~tzu~o R~ 1, 1, 5" Arias 1, 5" Atlas 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" ~c~0~0s~Sch 1, 2" ~-lo~ Sch 1, l"&5" Sch ~-/ 1, l"&5" Sch 1, 5" Sch 5" Sch 1',&5" .Sch 5" ~ ~s-,~-~ Sch 5" I~-Illq~\ Sch 5,~0-qT~Z Sch 5" Sch 5" ,z~;~o - -~ Sch 5" Sch 5" Sch 5" l~0vdo~ Sch 5" l ~k~-.~-~ azso Sch 5" ~ ~- lzz~z Sch 5" 2I~,~5 Sch 5" Sch Have A Nice Day{ Sonya Wallace ATO- 1529 Please sign and return the attached copy as receipt of data. RECEIVED BY / Trans# 93118 # CENTRAL FILES # CHEVRON # BPX # STATE OF .~t.~KA # PHILLIPS # LILLIAN TIULANA # EXXON # MOBIL STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC' -'~IISSION REPORT (JF SUNDRY WELL OPEriATIONS 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 1822' NSL, 1048' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 2590' NSL, 2658' WEL, Sec. 2, T10N, R15E, UM At effective depth At total depth 434' NSL, 3357' WEL, Sec. 35, T11N, R15E, UM Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB)"*' ':.:,' , 55' RKB f~et 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit number/approval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe Bay Oil Pool 5. Type of Well 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 111' Surface 2526' Production 7700' Liner 2844' Slotted Liner 879' 11170 feet Plugs(measured) 9002 feet 11129 feet 9002 feet Junk(measured) RECEIVED ~40V 1 6 ~93.~ Alaska 0il & Gas Cons. Commission Size Cemented Measured/~g~rue vertical depth 20" 1810# Poleset 111' 111' 13-3/8" 2500 sx CS III 8, 400 sx CS II 2526' 2526' 9-5/8" 500 sx CL 'G'/300 sx PF 'C' 7700' 6879' 7" 526 sx CL 'G' 7543-10387' 6757-9001' 4-1/2 .... 10291-11170' 8993-9002' Perforation depth: measured 10520-10526';10840-10860' true vertical 9000-9000';8999-8999' Tubing (size, grade, and measured depth) 4-1/2",12.6~,13CR @ 7486' MD;3-1/2",9.2#,13CR w/tail @ 9530' MD Packers and SSSV (type and measured depth) Baker SABL pkr @ 9409, Camco TRDP-4A SSSV @ 2165' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) 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-Md Water-Bbl Casing Pressure 276 563 5 357 264 124 Tubing Pressure 259 256 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 Q~ ~ Title FS-2 Senior Engineer Form 10-404 R~v 06/15/88 Date J~[ d~ ~ SUBMIT IN DUPLICATE REPORT OF WELL OPER, .ONS DS 9-35A Perforating Operations: ARCO Alaska, Inc. perforated DS 9-35A at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/17/93. The intervals perforated were the following: 10520' - 10526' 10840' - 10860' MD (Reference Log: Anadrill-CDR dated 3/13-18/93). 'Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 9/17/93. RU CTE perforating unit, pressure tested BOP's and lubricator to 1000 psi, okay. S.I. well, RIH and perforated 10520'-10526' MD at 2 SPF, POOH, all shots fired. RIH and attempted to perforated 10840'-10860' MD at 2 SPF, POOH, shots not fired. (ref: Anadrill-CDR of 3/13-18/93) Rigged down for the night. Began perforating operations on 9/18/93. RU CTE perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 10840'-10860' MD at 2 SPF, POOH, all shots fired, (ref: Anadrill-CDR of 3/13-18/93). Rigged down and secured well. Oil & Gas Gons. Gommisslort Armhorag~ RDC: 11/4/93 ARCO ,nl_~ska__, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MIIrD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Job#AKEl30010 Sperry Job#1209 BHI Aha Aha Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEl30009 Sperry Job # 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Ana Aha Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Tele¢o Job#AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job# 1168 Teleco Job# 1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Tele co Job# 1190 Tele ¢o Job# 1195-450 Teleco Job#1205 BHI Please sign and return the attached copy as RECEIVED BY_~~ Have A Nice Day! Sonya Wallace ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL receipt of data. APPROVED .~ ~..e~ ¢o,~- ~ s ~ 93059 ' ~'~0c~' g PB ~LL F~ES g BPX ~ ST. OF ~. (2 COP~) ~ LUC~LE JO~STON P~E NO, ~ANY PRUI)HOP. BAY I)F:ILLING ~LL NA~ DS 9-35A LE~TIO~ 1 ~E ~¥ LO~TI~'4 2 N(]~,~H SLOP. E BO~:QUGH MAGNETIC D~LINATION 30.~1 07-MAR-93 krELL HEAD LI~TIOH,: L~T(N/-$) ~I~'FI4 F~t'I ROTARY ?~L£ '1~ ?~d~-ET IS; TIE IN F1]INT(?IP) : ~J~ DI~:'TH TRUE gI~,1' DEF~H INCLINATION ~ZIMUTH LA?IllJI)I~(N/-~) DEPA~,~I~(E/-W) 770,0.00 ~79,00 3?.27 329.70 2102.00 -1585,00 D~:'(£/-~) 333,9'2 RECEIVED AUG 5 1 1995 Alaska Oil & Gas Cons. Commission Anchorage PAG~ NO, 2 ~ ?-35A EEASLG!Eb lkTI~.$AL V~TICAL DEFTH DEF~ ft ft 7700,00 O,O 79"34,84 234,9 7076, f5 7966,43 21,6 7105,69' 7~8,59 ~,2 71~,~ ~28,99 30,4 7163,75 *~***~***~.~ ANADRILL ****+**~**** E~BJEY CALCULA?IO~ er***** MINIM~ CL~:VA~]R~'. ~E~D ~**~ TAE~E? STATIC~ AZIMUTH LA?IIYPE SEC~IOq INCLN. N/-S ft deg deo ft 2564,78 39,27 329,% 2102,~ 2710,00 25,45 335.17 2212,53 2722,04 23,42 ~7, ~ 22'2a, 48 2735,21 21,21 339.70 2235,83 2745,4.9 19,43 341,~ 2245,79': D~'AR%RE DISPLAC .E~P~7 at E/-W ft ft -1585,00 2632,61 -1643.99 27~,45 -1649,27 2769,J8 -1653,76 :,-1657,24 2791,06 AZim_qH de.," 323 323,~5 323,51 3Z3,58 dec,,' iCOft 6,01 6.97 7,4,f, 6,38 8000,78 6092,67 8123,41 8154,76 8185,35' 3t,8 7194,07 21,9 7224,~ ~,7 7254,16 :-1,3 7284,60 30,6 7314,~, 2'55,72 17,81 343.49 22b"5,48 ~'.~.91 16,43 347,78 22~,57 2772,81 14,69 ~3,76 2272,69 27'/9,60 13,08 358.0'4. 22~,18 2785,49 10,~, 2,58 2284,53 -1660. ,26 2800,65 -1662,60 28~,36 3~,71 -1643,98 2816,72 ~3,79 -1664,56 2823,12 3~,87 -1~,55 2828,24 5,86 7,40 7,85 8217,20 8279,91 8311,~ 6342,24 31,8 7345,89 31,7 7377,19 ~l,O 7407,94 31,4 7439,05 30,9 7.469,72 2790,10 9,19 12,74 2292,00 2793,5~ 8,18 21,77 22%,56 ~v96.t5 7,70 32,44 2300,~ 2796,~ 7,54 30,42 2303,92 2600,5~ 7,58 32.3~ 2307.3~ -1660,85 2832,24. 324,02 -1662,~, 2635,13 324,10 -16~,53 2837,08 324,L8 -165~,36 2838,69 -14.56,34 2840.28 324,33 7,63 5,35 4,98 0,82 8374,02 8405,04 84~,,63 8468,07 84?8.4-4 31,8 7501,22 51,0 ~31,97 31,6 7563,28 31,4 ~94,44 30,4 7624.5.4 2602,N, 7.60 29.63 2310,99 2~05,12 7,66 31,~ 2314,53 2807,38 7.&~ 31,17 2318,12 2~9,67 7,58 29.7~ 2321,70 2811,89 7,26 28.~9 2325,12 -16~,0~, 2~11 ,~4 ~4,41 -1651,98 2843,60 324,48 -1649,79 2A45,25 324 -1647,6~ 2845,95 324,64 -1~5,~ 2848,~ ~4.71 1,12 0,89 0 """ 0.4.I 1,11 8529,89 8592,69 8623,5~ 8655.28 ~1,4 7655,76 31,5 7~7,0.'5 ~1,3 7'718,10 30,9 77~,77 31,7 7-/80,2.2 2814,15 7,00 28,~ 2328,~ 2816,35, 7,00 29,14. 2331,91 2818,56 7,00 28,25._- 2335,26 2820,79 6.9'9 26,87 ~36,59 2823,12 6,~ 26,27 2342,03 -1643,88 2850,34 324,78 -1M2,03 2852,03 324,35 -1640,20 2853.71 32.4.92 -1638,46 2855,45 324,98 -1636,75 2857,28 325,05 0,~ 0,~ 0.37 0,55 0,~ 8666.,71 8719,58 8751,04 8782,52 8~]4.14 31,4 7811.43 ~,9 7644,07 31,5 7875,33 ~'1,5 7906 31,6 7997,~9 2825,35' 6,6~ 27.93 2345,39 2627.58 6,52 30,3"; 2348,74 2829,52 6,54 31,51 ~51,81 2831.42 6,75 33,5~ 2354.68 2633,28 7,07 35,58 235~,01 0,69 1,40 0,41 1,02 1,27 8,845,46 88T"/,~ 8906,32 8940,92 8971,78 31,3 7969,C7 31,9 8000,76 28,9 6029,47 34,6 8063.83 ~0,9 8094,47 2835,08 7,02 36,51 2361,12 28~,92 7.00 ~,87 2364,28 28.38.6~ 6,91 33,45 236.7,18 2840,71 6,60 ~.59 2370,60 2~42.48 7,13 36,&C 2373,~ 0.3':/ 0,63 0,66 0,50 9003,55 9034,33 9066,13 9096,33 9127,71 31,8 ~'0,8 8156,~ 31,8 8187,51 ~0,2 8216,~ 31,4 8247,37 2844,50 8,71 ~,,21 2377,16 2846,77 10,13 37,81 2381,18 2849,40 li,~ 36.17 2385,92 2852,30 13,55 37,6'~ 2~'1,12 2855,94 15,46 35,05 2397,45 -1613,61 2873,06, 325,83 -14.10,57 2874,71 3~,93 -1606,87 2876,56 ~6,.M -1602,81 2878,62 326,17 -1598,16 2881,~ ~6.31 4,98 4,.~ 4,89 6,20 6,42 **********.*~* ANAPRILL *~************ S~JRVEY CALCL~A?IEHS ***~* MIHIMUN CL~.,q~ATUR~ ~I~T~OD ~******** T~,~;E'r STATION AZI~JI~ LATITUDE SErlOH INCLN, N/-S ft deo dea ft 2860,53 17,48 93,73 24C~4.72 28&5.,28 19,03 26,92 2413,67 2873.~ ~,77 ]9.78 24~,60 2~1,~ ~,44 i4,41 2434.73 2891,65 ~,95 7.3~ 2446,79 DS 9-35A D~F'~,~UR~ DISF'L~SL~ at D'-W ft ft -1573,~ -I5~.b"5 2889,52 -1584.29 22.75.~.~ -15~.89 2902.95 -1578,59 2911,83 AT.'F~IJTW 326.47 326, 32.7,00 ,5'27,17 DLS dea/ 10Oft 6.09 9.47 8.14 10,13 9316.06 9346.79 9379.08 9410.09 9441.32 ~0,5 8423.38 30,7 8450.93 S2,3 8479,46 31,0 850&47 Sl,2 8533,37 29C,2,53 25,60 3,7~: 2459,50 2914 ,.(.3 27,07 356.95 2473,12 2~8,51 28,~ ~5,52. 24~,21 2942,86 30,12 351,58 2503,34 295~,18 30,99 346,55 2518,92 -1577,38 2921,86 327,33 -1577,07 2933.17 327.47 -1577,81 2946,30 327,62 -157'9,54 2960,01 ~7,75 -1582,56 2974,80 327,86 7.~. 8.38 7,20 7.65 9472,37 9503,84 9523,47 95'54,21 31,1 855.,9.90 2'1,5 8586.49 ]9,6 8602,~ EO,7 8628,12 F~.l 8652,32 2974.04 31,62 342,13 2534.44 2990.76 33.03 338, :~ ~5'50,25 3001,58 34.00 336,16 2560,24 3019,~ 35.50 3:~J.7C ~6,24 .'3037,01 37,~ 334,~.9 25~2,51 -1586.92 2990.27 ~7,'.]'5 -1592,64 3006,71 328,02 -1596,85 3017,41 -1604,00 3034.77 328,09 -1611,53 3052.~ 328,13 7.66 8,14 7,42 4.95 7,07 9615.53 9646.68 9678.55 9708.96 9742,16 31,2 8.676.69 31,2 8700,20 31,9 8723,49 30,4 8745,14 ~,2 8768,29 3056,49 39,75 334,~ 2610,09 3076,92 42.21 333.~5 262~.45 3098,68 43,92 334,~~ 2646,02 3120,02 45,26 335,~2 2667,36 3143,81 46.32 335.!2 268%00 -1619,92 3071,92 328,17 -1628.&6 3092.24 328.21 -16~.38 3113,89 328.25 -1647,42 3135,09 328.~ -I657,33 3158,71 328.35 7.12 7.96 5.43 5.38 3.~ 9~3,~ 9818,69 9881,~ 9913,33 31,2 8789,6O 45,4 8.819,82 31,8 8640,26 30,8 6859,05 32,1 8877,39 31~.,54 47,40 335:.,E0 2709,67 3200,37 49,07 333,~' 2740,19 3224,69 50,85 333,50 2761,94 :3249.07 53,89 333,65 278.3,7'7 3275.39 56..38 33'2,~4 2807,28 -16.%,79 3181,27 -1681,40 3214,92 326.47 -1692.29 3239,16 32~.50 -1703.14 3263.44 328.54 -1714.97 3289.&7 328,58 3,59 5,28 5,62 9.68 7.97 ~44.65 9975.54 100O4.72 100~.01 10070,64 ~1.3 8894,12 ~,9 8909,~ ~.2 8922,47 ~,3 8936,32 31,6 8947,60 3301,&6 5%06 332,45 2830,80 3328,72 61,87 331,63 2854,54 3354.75 64,69 330.0~ 2877.30 3386.05 67.66. 330,7] 2904,57 3415..%6 70,55 331,4~ 2930,44 -17Z7,12 3316,08 328,6~ -17~,73 3342.91 328,~ -1752,42 3368,95 328,66 -1767,91 3400,~ 328.^7 -1782,20 3429,82 328,69 8.67 9.37 10,75 8.84 9,40 10101.05_ 10132,92 10164,46 10196.03 10227,39' ~,4 8957,06 51,9 8965,58 31,5 8972,67 31,6 8978,82 31,4 8984,29 3444,41 73.16 330,59 295'5,71 3475,09 75,83 331,0~ 2982,54 3505,77 78,17 330.79 3009,99 3536.68 79,37 330.,~ 3036.4C ~.,67,51 60.57 32'?.07 3063.22 -1796,19 3458,69 328,71 -I811,15 3489,38 326,73 -1826,08 35_20,0~ 328.~ -184:,22 3551,03 328,77 -1856,54 3581.90 32E.78 9,02 8,51 7.48 3,80 4.55 10259,17 1025'1.26 10319,74 10425.90 10~78,50 21.8 32.1 28,5 8996,80 106,2 90D1,49 52,6 9001,13 3598,82 81,5i 3L'IO.~ 30?0,43 · .'.'.'~,55 ~,59 3~-59 3118,10 :3658,80 84,~ 330,24 3142,71 3764.65 90.10 331.00 32',_.5.09 3817,23 90,70 334,5~ 3281.92 -1872,17 3613.28 32~,79 -1&87,83 3645.~. 328.61 -190!,80 3673,34 328,~2 -1953,82 3779.31 328.87 -1977,73 3~31.77 328,93 3.3..~ 3.41 7,97 5,02 7.50 ****.*~*~*** ANA. D~ILL Stg%:~' CALCU~?I~ ****** MINIMUtl CL~.~ATURE ML~HOD ******** TAF, q2~ ~ATIC~i AZIMUTH LATITUDE S~TIC~ IhCLN, N/-S ft deo des ft 36.56,&0 90,20 ~0,~ 3~18,&3 3.889,04 90,~ 330. ~.C ~45, I2 3'-728,24. 90,4.0 ~0,7C · ~79,31 3960,10 ~0, ~ 3~, 40 3407,0~, 3991 ,M 90,30 ~O,:C 343~,52 ft ft -1995,90 3873,27 -2011,% -2031,34 3942,85 -~47,03 ~74,74 -2062,71 4006,33 ~IM_m.H de.," 3-,..,, 79 3Z.~,0! DLS de.~/ 1CKWt 1, 1,37 ,~.." 10.464,20 10714,80 10737,2C., 1074.8,30 10810,70 31,0 ~0,6 8998,59 22,4 87i/8,04 ~1.1 8997,47 42,4 ~22,57 9t,10 330.20 3461,40 4~3,11 91,40 ~1,2~ 348&,08 4.075,48 91,40 330.90 3507,68 41~,~ 90,70 331,.c/C.. 414&,90 ~,30 ~1,10 3572,23 -2078,14 4037,32 -2093,11 4067,90 -2!03,~ -2118,83 4121,35 -2139',06 4163,71 ~?,02 3~' ~03 329,06 2,J.0 3,,41 1 5,97 10832,20 1~95,70 !07Z7,70 1(7.~'58,50 21,5 8~8 34,0 29,5 EO,8 9~X)I,77 4170,3&. 88,00 3130,&C 3591,00 4204,30 87,90 332,00 13620,80 4233,74 68,70 329,.~.; 4265,70 &8,90 332,80 42~'~,45 88,60 329,53 3701,62 -2147,'~ ~. 4185,18 -2165,&4 4219,14 -2180,14. 4248,61 -21~,~ 4280,57. -~10,35 4311,3J 3~, tO ~9,14 3~,16 2,71 4,!2 7,61 10,76 I0~0,20 11028,80 11109,2O 31,7 31,6 9003,4.9 ~3,6 9003,34 15,2 9003,13 4~8,10 ~,40 332,~0 3729,39 4..-"~,65 89,20 329,76 37~,Z3 4~&,2'2 90, .5C, 333,50 3791,02 4431,81 90,70 3134,~ ~21,18 4447,01 90,90 331,00 -2225,&2 4~3,01 ~9,17 10,74 -22~, 15 4551,56 ~', t9 8,54 -2259,I8 4413,13 ~,21 12,71 -~73,98 4446,62 3~,24 2,17 ANAD~RILL 2401 C. ,NABAR LOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 Prudhoe Bay Unit P.O. Box 196612 · Anchorage, AK 99519-6612 March 25, 1993 Attention: Nabors 2ES Drilling Engineer I have compiled a summary of Anadrill's performance on DS 9-35A SERVICES PROVIDED Directional Survey Service with DWOB and DTOR (DSW) was picked up on 07-MAR-93 to begin the kickoff at 7702'. CDR recorded and realtime along with CDN recorded only were picked up on 13-MAR-93 at 9587'. Due to problems sliding, CDN was laid down at 9843' and after 7" casing depth was reached at 10387' CDN was picked up with CDR in record mode only and a MAD pass was made from 9520' to T.D. In the 6" hole, SLIM 1 directional and gamma ray were run to T.D. at 11170'. OPERATING STATISTICS Total MWD footage for the well was 3468' and was accomplished over 9 bit runs in 219.4 total hours operating. There were three standby days and eleven operating days on this well. Four failures occurred during the well. One MWD, one CDR realtime, two SLIM 1. On 3/8 the MWD tool began modulating at 12.7 Hz instead of the proper 12.0 Hz. This problem was caused by a motor control circuit failure and consequently caused a trip for a new MWD tool. This type of MWD failure is not an inherent problem. The insulation on the power line was chaffed which drew down part of the power. On 3/13 after checking out on the surface and the shallow hole test, the realtime CDR (Gamma Ray and Resistivity) latched at 1023 counts. The recorded data was good. Realtime CDR failures were problematic throughout the Anadrill organization one vear ago. At that time, Anadrill Engineering compiled a database consisting of all failures, on a worl'd-wide basis, so they could be analyzed and design changes could be made. The design changes were presented in the Realtime Triple Combo Reliability Improvements Plan - Phase 1. The Alaska District executed each of the 25 design changes within a 3 month period. Upon 100% compliance with the Plan, we began to see immediate reliability improvements with this service. Both SLIM 1 failures were caused by the pulser shorting out downhole. A modification had been made to the pulsers to prevent voltage spikes when making up or breaking the tool apart. It was discovered that this mod could short out downhole but by that time we were already running tools in the hole. Parts to fix the problem were shipped to Anchorage and a pulser fixed and flown special charter to the slope but we had already had two failures. On the third SLIM 1 run, the tool had been modified with the new parts and worked with no problems through the entire bit run. Each failure has been identified and action items have been executed. Additional insulation will be used to prevent wire chaffing which caused the first MWD failure. A modification has been made available by LWD Engineering to prevent the connector problem on failure number two. The SLIM 1 modification, which was implemented and successfully run on the last bit run, will prevent a reoccurrence of that failure type. ,lOB PERFORMANCE Evaluation of data in the window indicates new formation being drilled at approximately 7734', which came .,. feet after beginning the kickoff. This is seen in the formation strenath (!kORS) and penetration rate (ROP) variables of the M£L log. ~ Hole conditions throughout the 8 1/2" hole were aenerallv o~ood as seen ora the St2//V log. Some difficulty during sliding, intervals was encountere~ and atiri~0uted primarily to the CDN stabilizer' hanging up above the ~.'iVvT) tool. This was determined with downhole ,,,,:eight on bit. The CD.",' tool was laid down and the welt was drilled to T.D. The gamma ray tool proved ,,'er,,,, valuable in deternzinina the basal SAD and confirming the Kavik when we drilled into it. A slower data rate was used i~itially to ensure quality, but due to some sticking problems on the last trip in the hole we used the faster rate to decrease survey time. Of the 130 surveys taken, 77 were taken in the 8 1/2 hole and the rest in the 6" hole with SLIM 1. the final survey calculated a TVD of 9003.13, a NORTH of 3834.67, a WEST of 2280.98 with a vertical section of 4447.01. The final angle was 90.9 with an azimuth of 331.0 Torque and Drag Analysis The high dog legs necessitated by getting behind on angle and direction on the second kickoff did not make a significant difference between predicted torque and drag and the actual torque and drag seen on the well. The following table compares the values for predicted and actual torque at the given depths. Depth Predicted Torque A¢I~al Torque 834O 9.0 9.4 8860 9.9 9.6 9600 11.8 11.0 10300 13.4 13.0 The predicted torque values were very close to the actual torque values which were measured on the rig. The average error for the abo~,e depths was 4.3%., this is within the predicted accuracy of the TORSTAR program. For your convenience, I have included a hardcopy of the surveys. I have also inclt~ded a cop>' of the sticking pipe indicator (SP/N) and the SLIM 1 aamma ray log was transferred to the same format as CDR/CDN logs and were distributed b,,TSchlumberger Wireline Services per the standard channels.Anadrill appreciates the opportunity to supply services on your ,,','ell and we look forxvard to continuing a healthy business relationship. Thank you, Dan Bordelon Manager- Alaska Field SeD/ice Manager ! ANADRILL .... ,. STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC ~IISSlON REPORT SUNDRY WELL OPEriATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Peri'orate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stradgraphic Service 4. Location of well at surface 1822' NSL, 1048' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 2590' NSL, 2658' WEL, Sec. 2, TION, R15E, UM At effective depth At total depth 434' NSL, 3357' WEL, Sec. 35, T11N, R15E, UM 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-35A 9. Permit number/approval number 93-31 10. APl number 50 - 029-21314-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11170 feet Plugs(measured) 9002 feet Effective depth: measured 11129 feet true vertical 9002 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1810# Poleset 111' 111' Surface 2474' 13-3/8" 2500 sx CS III & 400 sx CS II 2526' 2526' Production 7648' 9-5/8" 500 sx G & 300 sx PFC 7700' Liner 2844' 7" 526 sx G 10387' 8915' Slotted Liner 879' 4-1/2" 11170' 9002' Perforation depth: measured 10387-11124' (slotted liner) true vertical 8915-9002' (slotted liner) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr, Tubing @ 7486' MD; 3-1/2", 9.2#, 13 Cr, Tubing @ 9530' MD Packers and SSSV (type and measured depth) Baker SABL Packer @ 9409' MD; TIW Packer @ 10301' MD; Camco TRDP-4A @ 2165' MD 13. Stimulation or cement squeeze summary ~, [~ I~, [~ I V Intervals treated(measured) See attached. JUN 0 1993 Treatment description including volumes used and final pressure Alaska O~l & u~s Cons. 14. Representative Daily Averaqe Production or Injection Data Anchorage Prior to well operation Subsequent to operation OiI-Bbl Gas-M~ Water-Bbl Casing Pressure Tubing Pressure 413 ~ 664 47 254 387 1568 39 259 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. ! 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 SUBMIT IN DUPLICATE 1010/3 DAC cc:SW, JWP 9-35A DESCRIPTION OF WORK COMPLETED NITRIFIED MUD ACID STIMULATION TREATMENT 5~24/93: A CTU Nitrified Acid Stimulation Treatment was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & reciprocated the treatment across the slotted liner located at: 10387 - 11124' MD (Zl) Ref. Log: CDR 3/17/93. Pumped: a) 63 bbls 15% HCI w/10% Xylene @ 1.5 bpm & Nitrogen @ 600 scf/min, followed by b) 60 bbls 1% KCI Water & Nitrogen @ 2000 scf/min, followed by c) Shutdown. POOH w/CT while displacing w/Meth Water. Rigged down. Returned well to production w/gaslift & obtained a valid production test. RECEIVED J U ~ 5 0 ~995 Alaska Oil & Gas Cons. (.;orr~missiu, Anchorage Date: 5- ! 1-93 File Code: Transmittal 93051 Sonya Wallace (907) 263-4310 Co-Owner Distribution Subject: From/Location: Telephone: To/Loca'tion: I inadvertently made two errors on this transmittal. 1. The correct API# for the 3-20A logs are 50-029-20980-01. 2. The correct API# for the 9-35A logs are 50-029-21314-01. I'm sorry for any trouble that these omissions might have caused. ARCO Alaska, Inc. is a Subsidiary of Atlan~cRichfieldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-29-93 REFERENCE: ARCO ~INALS -20A ~ 3-20A \3-20A /3-25A ~/ 3-25A k 3-~5A N3-25A 2SA 28A ~ ~28A ~ ~28A ~28A -3lA ~-35A / ~-3~a ~35a k ~35A a ~35A ~36A ~36A N ~36A MI-IA ~GI-5 ~-lO ~GI- 10 4-13-93 SSTVD Run 1, l"&2' 4-13-93 DLL/GR/SP Run 1, 2'&5' 4-13-93 BHCA/GR Run 1, 2'&5' 4-13-93 CNL/GR Run 1, 2"&5' 3-23-93 SSTVD Run 1, 3-23-93 DLL/GR/SP Run 1, 2~&5" 3-23-93 - BHCA/GR Run 1, 3-23-93 CNL/GR Run 1, 2"&5" 3-23-93 BH Profile Run 1, 5~ 3-31-93 DLL (Simultaneous) Run 1, 2~&5" 3-31-93 BHCS/SSTVD Run 1, 5'' 3-31-93 BHC8 Run 1, 2"&5' 3-31-93 CNL Run 1, 2'&5' 3/26-31/93 MWD: DPR/GR Runs 1-3, 3/26-31/93 MWD: DPR/GR Runs 1-3, 2"&5'~rVD 4-17-93 SSTVD Run 1, 1'&2~ 4-17-93 DLL/GR Run 1, 2'&5~ 4-17-93 ZDL/CNL/GR Run 1, 2'&5" 3/13-18/93 LWD: CDN Mad Pass Composite, 2'&5' 3/13-17/93 LWD: CDN Drilling Pass Composite, 2"&5' 3/13-18/93 LWD: CDR Mad Pass Composite, 2"&5" 3/13-17/93 LWD: CDR Drilling Pass Composite, 2"&5" 3/13-18/93 LWD: CDN N/F Mad Pass Composite, 2"&5" 3/13-17/93 LWD: CDN N/F Drilling Pass Composite, 2"&5' 3/13-18/93 LWD: CDN Mad Pass TVD Composite, 3/13-17/93 LWD: CDN Drilling Pass TVD Composite, IF'&5 3/13-18/93 LWD: CDR Mad Pass TVD Composite, 3/13-17/93 LWD: CDR Drilling Pass TVD Composite, 2'&5' 4-6-93 SSTVD Run 1, 1'&2~ 4-6-93 DLL/GR Run 1, 2'&5' 4-6-93 BHCA/GR Run 1, 2"&5" 4-6-93 CNL/GR Run 1, 2'&5' 4-6-93 4 Arm CAl/GR (BH Profile) Run 1, 5" 3-19-93 ~Induction Electrolog Run 1, 2"&5" 3-20-93 CNL/GR Run 1, 2'&5" 4-20-93 DLL/MLL/GR/SP/CAl Run 1, 2~&,5' 4-20-93 BHCA/GR Run 1, 2'&5" 4-20-93 BH Profile Run 1, 5" 3-28-93 SSTVD Run 1, 3-28-93 DLL/MLL/GR/Cal Run 1, 2'&5" 3-28-93 BHCA/GR Run 1, 2'&5' 3-28-93 BH Profile Run 1, 5" Please sign and return ~/e attach~d~_copy as receipt of data. RECEIVED BY__~ Have l Nice Day[ ~ Sonya Wallace 93051 ATO-1529 ~]~PPROVED # C~ON e D · M ~ Oil & Gas Cons.-',~ ~c~c~ - - u~nch0m'e t ~o~ , MOB~ ~ T~CO * The lo~s for iht, well ail say field, but are actually finals. Atlas Atla~ Atla~ Atla~ Atlas Atlas Atla~ Atla~ Atla~ ach ach ach ach Teleco Teleco Atlas Atla~ Atla~ ach ach ach ach ach ach ach ach ach ach Atlas Atla~ Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION WELL COMPLETION OR RECOMP LETION REPOI r AND LOG 1, Status of Well ...~ Classificalio ell OIL~ GAS I"I SUSPENDED D ABANDONED I-I SERVICE I-I l'/i~//t/x/~'/'-- / 2. Name of Operalor 7. Permit Number - r ~ L ARCO Alaska,/nc. 93-31 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-21314-01 4. Location of well at surface -~ 9. Unit or Lease Name 1822' NSL, 1048'WEL, SEC. 2, TION, R15E, UM ':':";i'- ' ~.'~: ': ; ............... ~- Prudhoe Bay Unit ' 9 -35A 2590'NSL, 2658'WEL, SEC. 2, T I ON, R15E,,5¢¢~-,¢~'- ~--~j_: ...... ~.~.'/.. 11. Field and Pool At Total Depth *-- ~ ~ Prudhoe Bay Field/Prudhoe Bay Pool 434' NSL, 3357' WEL, SEC. 35, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. KBE = 52' I ADL 28324 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore J16. No. of Completions I 3/10/93 3/17/93 3/27/93 N/A feet MSL J One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set J21. Thickness of Permafrost I 11170'MD/9002' TVD 11129'MD/9002434' YES [] NO [] 2165'feet MD I 1900'(Approx.) 22. Type Electric or Other Logs Run RES/NEU TRON/L WD 23. CASING, LINER AND CEMENTING F:I~-CO~ SE3-rlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTIh~ RECORD AMOUNT PULLED 20" 91.5# -H-40 Surface 111" 30" 1810# Poleset 13-3/8" 68#/72# K-55/L-80 Surface 2526' 17-1/2" 2500 sx CS 111/400 sx CS II 9-5/8" 47# L-80 Surface 7700' 12-1/4" 500 sx Class "G"/300 sx PF "C" 7" 29# 13-CR 7555' 10387' 8-1/2" 526 sx Class "G" 4-1/2" 12.24# 13-CR 10282' 11170' 6" 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 (MDI None -Slotted Liner 4-1/2" x 3-1/2" 9530' 9409' 26. ACID, FRACTURE, CEMENT SQUEF'/F. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Well freeze protected w/140 bbls diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 4/3/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BB.L GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ~,nchoracjo Form 10-407 .- Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GE(~OGIC MARKERS , _,-[MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9580' 8649' Zone 3 9678' 8723' Zone 2 9 725' 8758' Zone 1 10076' 8949' 81. LIST OF ATTACHMENTS 8~, I hereby cerlily lhal lhe lotegoing is true and correc! Io lhe best ol my knowledge Signed ' - I..~ // Title Drilling EngineerSuoervisor Date .- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), sostate in item 16, and in item 24 show the producing intervals for only the interval reported' in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-35A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/03/93 05:00 SPUD: 03/07/93 02:00 RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 03/03/93 (1) TD: 0 PB: 0 PULL BPV WITH LUBRICATOR MW: 8.8 WBM ACCEPT RIG AT 05:00 HRS. TAKE ON SEAWATER, RU LUBRICATOR TO PULL BPV. 03/04/93 (2) TD: 0 PB: 0 POH AND L/D 3.5 13% CR TDS TUG MW: 8.5 Seawater RU AND PUMP DOWN ANNULUS.SET TWC. ND TREE NU AND TEST BOP. POH LAYING DOWN 3.5 13% CR TDS TUBING. 03/05/93 (3) TD: 9369 PB: 9369 03/06/93 (4) TD: 9369 PB: 9369 03/07/93 (5) TD: 7590 PB: 0 03/08/93 (6) TD: 7970' ( 0) 03/09/93 (7) TD: 8253'( 283) 03/10/93 (8) TD: 8859' ( 606) 03/11/93 (9) TD: 9145' ( 286) MU SECTION MILLING BHA MW: 9.8 KCl CONTINUE TO LAY DOWN 3.5" 13% CR TDS TUBING. BLEED OFF OUTER ANNULUS. MU 9-5/8" BRIDGE PLUG AND RIH PICKING UP DRILL PIPE. MU BHA #1o POH SECTION MILL MW: 9.8 KC1 CONTINUT TO RIH. CKEARED UP 1500 STROKES AFTER SWEEP PASSED SECTION MILL WHILE WORKING PIPE. CINTINUE MILLING. CUT AND SLIP DRILL LINE. TESTING BOP MW: 9.8 KCl SLIP DRILL LINE. POH, L/D COLLARS AND MILL. MU AND RIH WITH MULE SHOE, BREAK CIRCULATION, PU KELLY, CIRCULATE HOLE. SQUEEZE CEMENT, PUMP PILL AND BLOW DOWN LINES. POH WITH MULE SHOE, FLUSH STACK. TEST BOP'S. DRILLING @7970 MW: 9.7 VIS: 54 TEST BOPS. RIH TO 4130 BREAK CIRCULATIONN, CUT AND SLIP DRILL LINE. RIH, PU KELLY BREAK CIRCULATION, WASH. RIH W/ BHA #3 MW: 9.7 VIS: 54 POH TO WINDOW. SLIP AND CUT 395 OF DRILL LINE. RIH, CHANGE OUT SWAB ON MP #1. POH, RETRIEVE SURVEY. RIH W/ BHA #3. DRLG 8.5" HOLE MW: 9.7 VIS: 60 RIH BREAK CIRC @ 4106 & 7700. WASH & REAM 8175 TO 8246. :- DRLG. SLIDING & SURVEYS F/ 8246 TO 8859. DRLG MW: 9.7 VIS: 0 DRLG TO 8971. CIRC. SHORT TRIP TO SHOE. DRLG TO 9145' NOTE: COMPUTER DOWN° DAILY COST ESTIMATED. WELL : DS 9-35A OPERATION: RIG : NABORS 2ES PAGE: 2 03/12/93 (10) TD: 9290' ( 145) 03/13/93 (11) TD: 9588'( 298) SLIDING & SURVEYS MW: 9.7 VIS: 80 DRLG. & SLIDING TO 9180. CIRC HOLE CLEAN, DROP SINGLE SHOT & P.O.H. RIH, SLIP DRLG LINE, RIH. WASH TO BOTTOM. SLIDING TO 9290. POOH. DRLG TO 9588'. CIRC. POOH. MW: 9.8 VIS: 68 03/14/93 (12) TD: 9780' ( 192) 03/15/93 (13) TD: 9843'( 63) 03/16/93 (14) TD:10025' ( 182) 03/17/93 (15) TD:10387' ( 362) 03/18/93 (16) TD:10387' ( 0) 03/19/93 (17) TD:10387' ( 0) 03/20/93 (18) TD:10387' ( 0) 03/21/93 (19) TD:10447' ( 60) POOH. CHANGE BIT. RIH. REAM F/ 9513'-9588' 9588'-9780'. CBU. POOH. MW: 9.7 VIS: 56 DRLG F/ POOH. MW: 9.7 VIS: 55 POOH. CHANGE BHA, BIT. TEST BOPE. RIH. MAD LOG RUN F/ 9545'-9780'. DRLG F/ 9780'-9843' POOH. DRLG. MW: 9.7 VIS: 55 POOH. CHANGE BHA. RIH. REAM F/ 9748'-9843'. DRLG F/ 9843' -10025' . DRLG 8.5" HOLE TO TD MW: 9.7 VIS: 63 CONTINUE DRILLING FROM 10025' SLIDING AND ROTATING TO 10068. CONTINUE SLIDING AND ROTATING TO BUILD TO 90 DEGREE. ROTATED TO 10164 TO 10292. LWD MAD RUN MW: 9.7 VIS: 64 TD 8-1/2" HOLE AT 10387'MD, 9001' TVD. POOH W. BHA #7. LD 20 JTS DP AT WINDOW. LD BHA #7. MU AND RIH W/ BHA #8 FOR RESISTIVITY, NUETRON LWD. RIH W/ 7" LINER MW: 9.7 VIS: 70 CONTINUE TO MAD RUN TO TD. SHORT TRIP TO 8956' POOH, NO EXCESS DRAG THROUGH OH. LD BHA #8. DOWNLOAD LWD. RU NCS. MU LINER RUNNING TOOL TO 4-1/2" DP, RIH, FILL EVERY 10 STDS. DRLG THRU CEMENT PLUG MW: 9.7 VIS: 73 CONTINUE TO RIH W/ 4-1/2" DP. TAG BTM @10387. POOH, LD 109 JTS DP, LD RUNNING TOOL. CHG TOP RAMS TO VARIABLES. RU TO TEST BOP'S, TEST BOP'S & SURP EQUIP. PU & MU BHA #9. SHALLOW HOLE TEST. RIH W/ BHA #9, FILL PIPE. PU KELLY WASH F/ 10224' DRLG 6" HOLE MW: 9.1 VIS: 54 TAG LC @ 10305". TEST LINER. TAG FC @ 10347, DRILL OUT SAME. DRILL F? 10387" - 10397". RU TO DISP WELL. POOH FOR MWD_FAILURE. ~. RIH W/ BHA #10. PU KELLY, WASH F/ 10301'-i0397'. 10447' AT REPORT TIME. Anchorage WELL : DS 9-35A OPERATION: RIG : NABORS 2ES PAGE: 3 03/22/93 (20) TD:10866' ( 419) 03/23/93 (21) TD:ll017' ( 151) 03/24/93 (22) TD:lll70' ( 153) 03/25/93 (23) TD:lll70 PB:lll70 03/26/93 (24) TD:lll70 PB:lll70 SHORT TRIP TO SHOE MW: 9.2 VIS: 68 DRLG F/ 10397-10634. SURVEY EACH KELLY. CONT DRIL. TRIP TO SHOE 6 STANDS AT REPORT TIME. DRILING 6" HOLE MW: 9.3 VIS: 64 DRLG. ROT F/ 10866-10877. BD & SB KELLY, POOH F/ MWD FAILURE SHORT TRIP 12 STDS. SLIP DRILLING LINE 40' RU OTIS SLICKLINE F/ MWD, RIH W/ OVERSHOT, POOH, NO MWD, RD OTIS. POOH F/ MWD. RIH W/ BHA #11. PU KELLY WASH 10858-10930, NO FILLo RIH W/ 6" HO & 7" SCRAPER MW: 9.2 VIS: 61 POH TO SHOE. CHANGE SWIVEL PACKING. RIH. CIRC 3 OH VOLUMES, POH TO SHOE. FINISH CBU ROT & RECIP. POH F/ 6" HO & 7" SCRAPER. L/D BHA #11 & PICK UP BHA #12 6" HO & 7" SCRAPER. RIH. RIH W/ 4.5" SLOTTED LINER 13CR MW: 9.8 KC1 RUN W/ HO & SCRAPER. CUT DRLG LINE. FINISH RIH. REAM F/ 10390 TO 11170 W/ 6" HO. CBU. WIPER TRIP TO SHOE. POH TO RUN 4.5 " SLOTTED LINER. L/D BHA #12. RIG UP CASING EQUIPMENT & RUN 4.5" SLOTTED LINER. RIH W/ LINER ON DP. DRIFT 3.5" DP WHILE RIH. MW: 9.8 KC1 03/27/93 (25) TD:lll70 PB:ll129 03/27/93 (26) TD:lll70 PB:ll129 03/28/93 (27) TD:lll70 PB:ll129 ATTEMPTING TO GET OVER POLLISR MW: 9.8 FINISH RIH. W/ 4.5" SLOTTED LINER TO 1170' PULL 9 STDS. DP. CIRC WELL W/ SEAWATER. POH L/D/ RUNNING TOOL. MAKE UP OVERSHOT ASSY. & RIH. TAG TOP OF POLLISHED RISER & ATTEMPT TO SWALLOW SAME. RUNNING 4.5" TBG MW: 9.8 KC1 POH. SLIP DRLG. LINE--ADJUST BRAKES & TIGHTEN PAD NUTS. POH & LAY DOWN OVER SHOT RUNNING TOOL. RIH W/ 3.5' & 4.5" DP & POH LAYING DOWN DP. RUNNING 3.5" & 4.5" 13CR TBG. M/U TORQUE 2560 & 4000. RIG RELEASED MW: 9.8 KC1 P/U & MU -- SSSV CAMCO & TEST SAME TO 5000#. FINISH RUNNING TBG. RILDS RIG UP & REVERSE CIRC. DROP BALL & ND BOPE--NU TREE. RIG UP LUBRICATOR & PULL BPV. RIG DN LUBRICATOR. FREEZE PROTECT WELL W/ 140 .BBL. DIESEL. SET BpV. -' KC1 S I GNATURE: (drilling superintendent) DATE: WELL HF_,AD LOCATI~: LAT(N/-S) O,.~D AZI~ITH ~ E~ARY TABLE TD TARF:~ IS TIE IN F1]INT(TIF') : )IEASURED D~TH TR~ UE~,~ DEFIH INCLINATIO~ AZIKdTH LATIIqJI)E(hL/-S) DEP~URI~(£/-W) 7700.00 .~79,00 37,27 ~9,70 2102,00 -158.5.00 D1]F'(£/-I~) ~q3.92 0,00 Date Alaska. Oil & Gas Corls. Cornrr~issiOr~ Anchorage I)S 9-35A SL~,~J~' CAI~-q. ILATI 0~ ****~* MINII~Jq CLE'VAI~JR~ tEl"HOD **.**** TA~q;ET ~A?ION AZI~ITH L~?ITUDE SECTI~ INCLN. N/-S ft de9 d~ ft ~4,78 39,27 ~9,7C 2102,~ ~10,~ ~.45 3~.17 ~12,53 27~,~ ~,42 ~7,~ ~.~ W35,21 21,2I ~'.70 2745,69 19,43 DEF'AR~RE DISPLACEI~EN? at ~IM.F~H DLS £/-W deo/ ft ft de~ IOOft -1585,00 2632.61 322.98 0,00 -1643,~? 2756.45 323.~? 6.01 -1649,27 2769,]8 323,45 6.97 -1653.76 2780.98 3'23.51 7,46 -1657,24 2791,06 323,58 6,38 80&%78 8092,67 81~,4I 8154,76 8185,39 3t.8 7194,07 ~1,9 7224,~ ~,7 7254.16 ~1,3 7284,E~ 3O,6 7314.56 2755,72 . 17.81 343.49 2255.48 2764,91 16,43 2~7,7~ 2264.57 2_772.81 I4.69 353,26 2272,69 2~9,80 13,08 ~8,0~ 2280,18 2785,49 10,~. 2,58 2286,53 -16~.0.,26 2600.65 -1662,60 28~.36 323,71 -1663.98 2~16.72 ~3.79 -1664,56 282~.12 323.87 -1&64,55 2828,24 ~3,'.-75 5.33 5,86 7.40 6.32 7,85 82!7,20 8248,~6 8279,91 8311.~ 8342,24 ~1.8 7345,89 31,7 73.77,19 Si,O 7407,~4 31.4 7439,05 ~,9 7469.72 2790,10 9,19 12,74 2292,00 2793.59 8,18 21,77 2296,56 2796,15 7,70 32,44 2300,~ 2798.35' 7.54 30,42 2303,92 2800,58 7,58 32,~ 2307,.39 -16~3.85 2832.26 324,02 -1~2.$5 2635,I3 324,10 -1660,53 2837,08 324,[8 -16~,~ 2838.69 ~4,~ -1656,24 2840,28 324,~3 7.63 5,35 4.98 0.~ 0.82 8374,02 8405,04 8436,63 8~68,07 8498.44 31.8 7501,22 · ~1,0 ~31,97 31,6 7~.3,28 31.4 7594.44 [-',0.47624,56 2802.86 7.60 2~'.63 2310.99 28YJ5_.,12 7,66 31,~ ~14,53 2807,38 7,&3 31.17 2316.12 2E)9.67 7,58 29,7~ 2321.70 2811.89 7,26 28.99 23~.12 -1654,.~, 2641,~4 ~4,41 -165],98 2843,60 324,48 -1649,79 2~5.25 324,% -1647,68 2846,95 ~4.64 -16~5.~ 2848.6.3 ~4.71 1.12 0.89 0.21 0.61 1.11 8529,89 8592,69 8623.59 6655,28 31,4 7655.76 31,5 7687,0D ~1.3 7718.10 30.9 7748.77 S1,7 7780,22 2814.15 7,00 28,~ 2326,54 2816,~ 7.00 ~.16 2331.91 2818,56 7,00 28,2~ 2335.26 2820,79 6.99 26,~7 2336,59 2823,12 6.93 26,:7 2342,03 -1643,86 2850.34 324,78 -1642,03 2852.03 ~4.85 -1640,20 2853.71 32.4,92 -16~.46 2855,45 ~4.98 -1636,75 2857.28 325,05 0,86. 0,33 0,37 0.55 0,~ 8.A86,71 6719.58 8751.04 8782,52 8B]4.14 31.4 7811,43 ~,9 7844,07 31,5 7875..,~ ~1.5 7906.~ 31,6 7&37,f~ 2825,39 6,~ 27.93 2345,39 2827,58 6,52 30,3~' 2348.74 2829,52 6,54 31,51 2351,81 2831.42 6,75 33.5~ 2354.88 2833,28 7.07 35,58 2'~_~,.01 -1635,03 285%05 325,12 -1633,16 28~.74 32~. t9 -! ..ol,32 2862,21 325.25 -162'7.36 2863.61 3~,32 0,69 1,40 0.41 1,02 1.27 6845,46 88.77.~ 8906,32 8940,92_ 8971,78 31.3 7969.C7 31,9 8000.76 z.,9 6029.47 34,~ 8063.83 ~0,9 6094,47 2635.08 7.02 36.51 2361,12 2836,92 7,00 ~.87 2364.26 2838,~ 6,91 33,45 2~J7,18 2840.71 6.~ 34,59 2370.60 2842,48 7,13 36,&3 2373,64 -1624.94 2866.24 325,~6 -1622.67 2667,56 325,~ -1620.70 2868.83 325.60 -1618.~ 2670.35 ~5.~. -1616,21 2871,63 3~,75 0.3-7 0.63 0.68 0,50 1,38 9003,55, 9O34,33 9066,13 9O96,33 9127.71 31,8 8125,59 ~0,8 8156,29 31,8 8187,51 30,2 8216.99 31,4 8247,37 2844.50 8,71 ~..21 2377,16 2846,77 10,13 37.81 238!,18 2849,40 11,68 3~..17 23~5,92 2852.30 13,55 37,6~ 235'1.12 2855,94 15,4~ 35,05 2397,45 -1613,61 2873,0B ~5,63 -1610,~7 2874,71 325,93 -1606.87 2876,56 ~6,.D4 -1602,81 2878.62 326,l. 7 -1598.16 2~1,~ ~6.31 4,98 4.66 4,89 6.20 6,42 PA~ NO, DI~H 9159,0< 31,3 8277.41 9190,94 31.9 ~D7,70 9~,73 31,8 ~7,60 ~54,34 3~.6 9285,~ 3Z,2 ~,70 SL~VEY C~LD_iLA??CNS ***~-~ MINION CUDJATURE MET-IOD TA~.~T STATION AZt$]II~ LATITLrQE SECTION INC. LN, N/-S ft d~ deg ft 2~0,53 17,48 ~.73 24~.92 2~,28 19,03 26,9~ 2413.67 2873.~ ~.79 19.78 24~,60 2~1,~ ~,44 14,41 24~.73 289~ ,65 ~.~ 7.3~ 24~,79 DS 9-35A ])~F'AE'~URE DISPLACEMD~T at ~-W ft ft -1593.36 2_~4,~ -15~,~ 2889.52 -1584.29 ~'~ -15~.89 29.02,95 '15'-78,59 2911,83 AZZFUTN deo 326,47 326,65 32,.7,00 5~.7.]7 DLS lOOft 7,56 6,09 9,47 8,14 10,13 9316,06 9346,79 9379,08 9410,09 9441,32 ~0,5 8423.~ ~,,7 84~,93 S2+3 8479,46 31,0 85~.47 31,2 8533.37 2~2,53 25,60 3,72 2459,50 2914.~ 27,07 358.95 2473,12 2~8.51 28,~ 355,52 2488.21 2942.~. ~.12 351,58 2503.34 2958.18 30,~ 346,~ 2518,~ -I57'/,38 29.21.86 327,33 -1577,07 ?~3.17 327,47 -1577.81 2946.30 327,62 -1579,54 2960.01 327,~ -1582.56 ~74,80 327,86 7.36 8.38 7,20 7.65 8,65 9472.37 9503,84 9523,47 9554.21 9584.~ 31.1 8~9.~ 31.5 8586.49 ]9,6 8602,~ 30.7 ~28,12 30.1 8652,~ 2974.04 31,62 342.13 2534,44 2990.76 33,03 ~8,:~ 2550.25 · 3,'YO1,SB ~.~) 336,16 25~).24 3019,~ 35.50 ~5.7C 25576,24 ::K)37,01 37,~ 3;~.69 25~?.51 -1.565.92 2-79'0,27 ~7,95 -1592,64 3006.71 328,02 -I596.85 ~17.41 328.05 -1604,00 30-.34.77 328.09 -1611,53 ~)52.~5 ~8.13 7,66 8.14 7.42 4.~ 7.07 %15.53 9646..I~. 9678,55 97O8.96 9742.16 31.2 P.676,69 31,2 8700,20 31,9 87."3.49 ~3,4 8745.14 ~,2 87~,29 30~.49 ~,75 ~4~ 2610.0~ :3076,c/~ 42.21 3~.~5 262&.45 30'?8.68 43,92 334.Z'~ 2648,02 3120.02 45,26 33~,E. 2 2667,36 3143.81 46,32 ~5,18 2./.89,00 -1619,92 3071,92 328.17 -1628.84. L~F'J.24 328.~1 -1635.38 3113,89 328.25 -1647,42 3135,~ 328.~P -I657.33 3158.71 328.35 7,12 7.96 5,43 5.38 3,~ 9~3.32 9818.69 9850.46 9881,25 9913.~ 31.2 8789,60 45.4 8.8t9.82 31.8 86~g,26 30,8 8859,05 32.1 3166.54 47,40 ~5_,60 2709.67 32C.0,37 49,07 :~3.,.'N.' 2740,19 3224.69 50.85 3~.50 2761.94 ~49.07 53,89 ~3,65 2783.77 3'275.~ ~.~, 332,~4 2807,26 -I.%6.79 3181,27 328.40 -1681.40 3214.92 328.47 -16~.2-I' 3239.16 328.50 -1703.14 .'3263.44 328.54 -1714.97 3289.67 328,58 3.59 5.28 5.62 9.86 7,97 9I'44,65 9975,54 10004.72 100~.01 10070.64 ~1.3 8894,12 ~).9 8909,35, ~,2 8922.47 ~.3 8936.32 31,6 8947 3301,86 59,06 332.4S 2830,80 3328,72 61,87 331,63 2854,54 3354,75 64,69 :330,~ 2877,30 3386,05 67,66 330.7~ 2904.57 3415+~ 70,55 :3:31,~ 293~)',~ -1727,12 3316,08 328.61 -1739.73 3342.91 328..M -1752,42 3368,95 328,66 -1767,91 3400.30 328,~7 -1782.20 34~.82 328,69 8.67 9.37 10,75 8.84 9,40 10101,05 10132,92 10164.46 10196.03 10227,39' El,9 8965,58 31,5 8972.67 31,6 8978,82 31,4 89~,29 3444,41 73.16 330.59 2955o71 3475.09 75,83 331,~ 2982.54 3505,77 78,17 3~.79 30~'.39 ~36.68 79.37 33(}.~ 3036,4C ~7,51 60,57 377,87 30~,22 -1796.19 3458.6? 328,71 -1811,15 3489,38 326,73 -1826,08 3520.08 328.75. -184:,22 3551,03 328,77 -1856,54 3581,90 ~,78 9.02 7,48 3,80 4,55 10259,17 10291,26 10319,74 10425.90 1~78,50 31,8 8989,~ 32,I 28,5 8-796,80 106,2 9001.49 52,6 9001,13 3598,82 81,51 330,3~ 309'0,43 3630,55 82,59 330.59 3118,10 3658,80 84,&3 330,24 3142,71 3764,65 90.10 331.00 3'K~.09 3817,23 90,70 ~4,'~ 3281,~ -1872,17 3613.28 326,79 -1887.83 3645,06 ~8.81 -I901,80 3673,34 328.G2 -I953,82 3779.31 ~8.87 -1977,73 3831.77 328,93 3,36 3.41 7,97 5,02 7,50 P~]~ ND, " · J 9-35A ltP..JqS~D INTE~JVAC V~..'FICA]. Dt~F~ DSPTF ft ft ft 1~20,i0 4~,6 10~0.40 ~,3 9~,53 ~89,70 39.3 10621,60 31,9 10653,~ ~1.6 8999,64 SLRU~Y CA~ULATI[rtS-. *****~ MINIMUN CL~.~ATUR£ K~D ******** TA~ ~ATIC~N AZIML'TH LATITUDE SB'CI'I[~' INCi.N, N/-S ft deo d~ ft 38~,80 90,20 330,~ 3318,83 3889,04 90,80 330.20 3345, I2 3928.26 90,60 330,7C 3379,31 3960,i0 90.30 330,.40 3407,0~ 39'9'1.64 90,30 330,"C 3434,521 D~'~TUR]~ DISP~CB~I~!~T at )~/-W ft ft -1996.90 3873.27 -2011.96 T¢03,57 -2031.34 3942.85 -2047,03 3974.74 -2062.71 4006,33 AZIM_O~H dec. 326.97 328, ?7 328,99 329,01 DLS deo/ logit 11,36 1,95 1.37 1.32 0,~ IOE84.20 10714.80 10737,20 10768.30 10810,70 3!,0 89~',2.6 EO.6 8998,59 22.4 8~8.04 El.1 8997,47 42,4 8~'7,84 ~22,~7 91,10 330.20 3461,40 4~3.11 91,40 331.2~ 348~.08 4075,48, 91.40 330.90 3507,68 4106,54 90,70 331.*: 4146.90 &~.~ 331.10 3572,23 -2078.14 ~37.32 329,02 -2093,!1 4067.90 3~¢.03 -2!03.~ ~90,28 329,~ -2118,83 4121,35 329,06 -21:39,~. 4163.71 329,~¢ 2.60 3.41 1,33 3,92 5,97 10832,20 10~.6,2C, 10895,70 10~2Z,70 1~5B.50 21,5 8998,5~ 34,0 29,5 ?000,63 32.0 9~I,3D EO,8 '-7001.97 4170,~ 88,00 330,~ 3591,00 4204,30 87,90 332,00 ~20,80 4233.74 88,70 329,5~ 3~6.58 426~,70 88,90 332,80 36.74,65 42~6,45 88,60 329.5C 3701,62 -2149,53 4185,18 329,10 -2165,84 4219.14 329,11 -21~.16 4248,61 32~,113 -2195.50 4280,~ 329.14 -~10,35 4311,34 3~,16 2,71 4,12 7,61 9,08 10,76 I0.~,20 11028,80 11~,40 11094.00 111~20 31,7 ~J,6 31,6 9003.69 ~3.6 9003,3,-4. 15,2 90,03,13 4~8,10 ~,40 332.90 3729,39 4266,65 89,20 329.7C 3763,23 4~8,22 90,50 ~:.50 3791.02 4431,81 90.70 ~4,~; 3821,18 -2225.62 4~3.01 329,17 10.74 -2244,!5 4381.56 32.9,t9 8.~ -:~--'~9.18 ~13,13 32~,21 12.71 -2273.98 4446,62 3~,24 2,17 -22,B0,98 44~.,1,79 329.25 21,09 ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE 1-9 3-29-93 1-11 -~'7-~7 4-2-93 1-19 3-22-93 1-22 ~--I-]~ 4-6-93 1-29 4-6-93 1-33 ~~ 4-4-93 2;8 3-27-93 2-~1 ~% 4-~-93 3-8 3-28-93 3-10 3~--~k 3-28-93 4-2 3-20-93 4-29 ~' ~-~?-3-26-93 4-33 3-25-93 5-11 '~7--~C) 3-29-93 6-3 4-5-93 6-9 7'~/''-7~ 4-5-93 6-18 3-30-93 6-2~ ~-~ s-26-98 -4A ~-4A 3-22-93 4-3-93 '--9-35A 4-1-93 ~11-13A 4-9-93 14-15 ~t~q 3-S0-93 ~~4-22A 4-2-93 4-22A 4-2-93 16-30 ~-~ 3-21-93 ~7-20 4-3-93 ~8-26 3-24-93 Leak Detect Run 1, 1",5"&25" Sch Production Run 1, ~' Sch Production Run 1, ~' Sch Perf Record Run 1, [~' Sch Production Run 1, [~' Sch Perf Record Run 1, 5" Sch lnJ Profile Run 1, ~' Sch Perf Record Run 1. 1~' Sch Production Run 1, [~' Sch Tubing Puncher Run 1, 1~' Sch CNL Run 1, i~' Sch Static Pressure Run I, 5" Sch Preas/Temp/Spin Run 1, 2"&5" Sch Static Pressure Run 1, 1~' Sch Production/Gas Entry Run 1, I~' Sch Perf Record Run 1, I~' 8ch Leak Detect Run 1, l"&5" Sch Production Run 1,/P' Sch Perf Record Run 1, I~' Sch Perf Record Run 1, 1~' Sch Static Pressure Run 1, ~' Sch Perf Record Run 1, l~' Sch Production Run 1, I~' Sch Perf Record Run 1, 5" Sch Production Run 1, 5~' Sch PITS Run 1, 5, Sch Perf Record Run 1, 1~' Sch Perf Record Run 1, ~' Sch Perf Record Run 1, ~' Sch Perf Record Run 1, 1~' Sch Static Pressure Run 1. ~' Sch GR/CCL Run 1, I~' Sch Static Pressure Run 1, ~' Sch GR/CCL Run 1, ~' Sch Please sign and return th~ attached copy as receipt ,of data. RECEIVED BY___ ._~.~:./~_~_ ~ _~~./~ Have A Nice Dayi SonyaWallace ~.~..~ ~.~, ~/,-/_. APPROVED ATO-1529 ~--.. Trans# 93050 # CLINT CHAPMAN ~. #HPX # EXXDN '<.~/~ # STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 16, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 9-35A ARCO Alaska, Inc. Permit No. 93-31 Sur. Loc. 1822'NSL, 1048'WEL, Sec. 2, T10N, R15E UM Btmnhole Loc. 777'SNL, 3275'WEL, Sec. 2, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (ROPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) printed on recycled paper b y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillEIIlb. Type of well. ExploratoryF1 Stratigraphic Test I-] Development OilEI Re-Entry [] Deepen!'31 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE ---55 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. o. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28327 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 20 AAC 25.025) 1822' NS/_, 1048' WEL, SEC. 2, TION, R15E Prudhoe Bay Unit At t. co,~,4.of,~oductive interval 8. Well number Number 5094'N~_, 2631' WEL, SEC. 2, TION, R15E 9-35A U-630610 At t_ot.al .cl. epth 9. Approximate spud date Amount 777'&~gf_, 3275 WEL, SEC,. 2, TION, R15E 2/17/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 28328-2003' feet No Close Approach feet 2560 11420' MD/9001' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.O35 (,,)(2)) Kickoff depth 77oofegt Maximum hole an~]le 9o o Maximum surface 3330psig At total depth (TVD) 18. Casing program Setting Depth s~ze Specifications Top Bottom Qu~mtity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 8-1/2" 7" 29# 13CR80 NSCC 2690' 7550' 6743' 10420' 8806' 581 cu ft Class "G" 8-1/2" 4-1/2" 12.67/ 13CR FL4S 1000' 1042.0' 8806' 11420' 9001' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ~.. ~_i~ ~ ~!. Total depth: measured 10320'feet Plugs (measured) ..... ,;,.,..'\r,'O ......... ., o ~,. true vertical 9100feet ;5];~..~[:;~ 0It ,;.~ ('ii:3.'3 c,,-. .... Effective depth' measured 10247feet jUnk (measured) true vertical 8971 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20" 1810 # Poleset 111' 111' Surface 2471' 13-3/8" 2500 sx CS III & 2526' 2526' Intermediate 400 sx CS il P rod uction 812' 9-5/8" 500 sx "G" 10320' 9100' Liner 936' 5" 125sx ARC 10281' 9016' Perforation depth: measured 10206'-10228' true vertical 8898'-9015' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certify ~hat t_he/foregoing is true a. nd correct to the best of my knowledge Signedf"/l ~- Title Drilling EnEineer Supervisor Date L,' .~ Commission Use Only Permit Number ~ {APl number {Approval date {See cover letter /s0-o ¢,-.z/z/p- o/ I ,¢,~' i ~ "~-~ {for other requirements Conditions of approval Samples required [] Yes J~No Mud Icg required []Yes Hydrogen sulfide measures [] Yes ]~ No Directional survey required ~E~ Yes [] NO Required working pressure for BOPE F-I2M; 1-13M; ~5M; F-I10M; I-I15M; Other: Original Signed By by order of Approved by David W. Johr'lstof~ Commissioner zne commission Date~--// Form 10-401 Rev. 12-1-85 Submit in triplicate Objective' The primary objective of the DS 9-35A redrill is to convert the well into a horizontal, basal Romeo producer to recover reserves from the basal sands that have not been able to compete with more permeable lower Romeo sands. Scope' The scope of the DS 9-35A redrill is as follows: Plug and abandon the original perforations and pull the existing 3-1/2" tubing completion. Mill a 50' section in the 9-5/8" casing starting at 7700' MD. Lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to the horizontal target within 5' of the basal sands at about 8946' ss. Run and cement a 7" 29# L-80 / 13Cr liner. Drill approximately 1000' of 6" horizontal section. Recomplete with a 4-1/2" 13 Cr slotted liner arm 4-1/2" x 3-1/2" 13 Cr tubing. Open hole logging will be accomplished with GR / Res./Neutron / Density LWD tools in the 8-1/2" hole section and GR onlY in the 6" hole section. Timing' This project is presently scheduled for Nabors Rig 2ES upon completion of activity on DS 16 in mid - late February, 1993.. The reddll should take approximately 22 days. SUMMARY PROCEDURE' , , , 4. 5. 6. 7. ! o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Freeze protect and set a BPV. Test intermediate casing pack-off to 3500 psi. Move in workover rig. Test 9-5/8" intermediate casing pack-off i: not done during pre-rig work. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and tree test plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 3-1/2" tubing. Run 9-5/8" casing corrosion log (Schlumberger USIT) only if intermediate casing integrity is suspect. Spot a 18 ppg pill on bottom and cut a 50' section in the 9-5/8" casing from about 7700' to 7750' MD. Spot a balanced cement kick-off plug (180 cubic feet minimum) from 100' below the base of the section to 200' above the top of the section. Replace the 9-5/8" casing pack-off as needed. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Ki'ckoff and-directionally drill to the target as per the ~ttaChed directional plan. - Run a 7" 29 Cf L-80 / 13Cr liner'assembly to bottom in the 8-1/2" hole, Space +.he liner hanger and top isolation packer about 150' up inside the 9-5/8" cas;r;~. Cement the liner in place with the total cement volume based upon 40 % open-hole enlargement plus the shoe volume, lap volume and 200' excess on top cf the liner with drillpipe in the hole. Re-test BOP's as needed. Run in with 6" steerable drilling assembly with directional/GR MWD on 4-1/2' x 3-1/2" drillpipe. Drill out float shoe and 10' of new hole. Displace well with non-damaging (Xanvis polymer) drilling fluid. See MI Drilling Fluids recomended displacement procedure. Drill approximately 1000' of 6" hole to TD as per Geologist / Operations Engineer onsite. Make a conditioning trip with a 6" hole-opener for the open hole section and a 7" casing scraper spaced to clean the liner. Install a 4-1/2" 13CR slotted liner with 7" packer and PBR. Circulate well clean with filtered sea water. Retest 9-5/8" wellhead packoff and replace as needed. Run in with 3-1-/2"13Cr completion assemb;y and locate packer PBR: Circulate corrosion inhibitor down the annulus. Run a 4-1/2"/3-1/2" 13CR completion string and 7" packer. Space out, land completion. Test tubing by casing annulus to 3500 psi. Set two-way cileck valve. Remove BOP's. Install and test the production tree to 5000 psi with diesel. Pull the two w&y check valve, Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release workover rig. Complete appropriate documentation and hand-over to Production DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE. KOP 9.7 10 10 5 7 6 0 5 Water to to to to to to to to to Base BASE 9.8 16 18 15 15 4 0 7 Mud HORIZ. 9.0 6 1 5 1 0 1 5+ 5 0 4 Water SECTION to to to to to to to Base TD. 9.2 1 0 20 1 5 8 0 6 Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.7 ppg. Est. Pore Press. Sadlerochit: 3450 psi/8800' ss TVD 7.54 ppg EMW (est.) Overbalance Top SadleroChit: 650 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 3820 psi at 8700' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 2950 psi based upon a gas column to surface from 8700' TVDss. Fluids incidental to the drilling of the well will be removed by truck and disposed into well CC-2A. LINER DETAILS' CASING 7" 29# 13-Cr80 NSCC 4-1/2" 12.6# 13CR FL4S DEPTH .. BURST OOLLARSE TENSILE 7550'- 10420' MD 8160 psi 7030 psi 718 klbs 10420'- 11420' MD (Slotted) in the Horizontal Section PRELIMINARY WELL PLAN WELL: AP! ..No.' LOCATION' EST. START: EST. TIME' CONTRACTOR' ,P!RECTIONAL' WELLBORE: 9-35A Redrill PBU 50-029-21314-00 (on the original 9-35 well) Surface' 1822' FSL, 1048' FEL, Sec. 2, T10N, R15E Target: 5094' FSL, 2631' FEL, Sec. 2, T10N, R15E @ 8645' TVD BHL: 777' FSL, 3275' FEL, Sec. 2, T10N, R15E @ 8645' TVD 17 February, 1993 22 DAYS Nabors Rig #2ES Kickoff at 7700' MD. Drop angle at 6°/100 from 39° to 5.5° @ 8265' MD.' Hold tangent to 9013'MD then build 6°/100' to 90°. See directional details for moCe information. Item TVD(BKB) .MD(BK.B) Mud Wt. 13-3/8" SHOE 2526' 2526' N/A KOP1 2650' 2650' N/A KOP2 6879' 7700' 9.7 TOP SADLEROCHIT 8637' 9557' 9.8 TOTAL DEPTH 9001' 11420' 9.8 LOGGING PROGRAM: 8-1/2" Hole: MWD Conveyed Gamma Ray / Resistivity / Neutron / Density. Horizontal section: MWD Conveyed Gamma Ray / Resistivity MUD PROC RAM' The milling / d;i!!ing fluid program wi!! consist of a 9.7 - 9.8 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. Mud weigl~t will be reduced to 9.0 - 9.2 ppg in the 6" hole section. CEMENT 7" LINER: CALCULATIONS' Measured Depth' Basis' Total Cement Vol' 7550' (Hanger)- 10420' (Shoe) 40% open hole excess, 40' shoe joints, 150' liner lap and 150' excess above liner with DP. 581 cuft or 493 sxs of Class G blend @ 1.18 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13-Cr80 TDS 3-1/2" 9.3#, 13-Cr80 (Surface - 5950' MD X-over) (5950' MD- 9780' MD) NABORS RIG NO. 2ES MUD SOLIDS CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 H P FlaSh Mixer Agitator 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console FRI3["I I.jREI:-i !LHhi.i_.~ U I h".' UN .I. LL 1 .. G~_.£ LAND DIRECTIONAL DRILLING, INu. Corporate Office 1111 East 80th Avenue Anchorage, A~ 995!8 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING well ......... : DS 9-35A (P2) Field ........ : PRUDHOE BAY DRILL SITE 9 Computation..: MINIMUM CURVATURE Prepared ..... : 12/09/92 Section at...: 344.34 KB elevation,: 55.00 LEGAL DESCRIPTION Surface ...... : 1822 FSL 1048 FRL $02 T10N R15E UM Tie~in ....... : 3923 FEL 2531FEL S02 TION R15E UM Target ....... ~ 5094 PSL 188 FEL ~O~ T!ON R15E UM BML .......... : 777 FSL 3275 FEL S35 T!IN R15E UM X ASP ZONE 4 Y 717319,43 5943260.11 715675.!3 5945315.23 715265.00 5946475.00 714967.59 5947429.71 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN / KOP 6/100 END OF CURVE #! K-10 K-5 BOO ,W2 BUILD 6/100 LCU SD~LEROCMiT Z4/45 TEAD Z4A/X-RAY TSAD Z3 TSAD Z2/2C TSAD Z2B/TANGO TSAD Z2A/ROI~O TSAD Z1B/LR SHerLE END OF OUR~-E ~2 TARGET TD F~_VIK MEA$ INCLN DEPTH ANGLE 7700 39.27 7800 33.28 7900 27.29 8000 21.30 8100 15.32 8200 9.38 8291 5.55 ESSO 5.55 90!3 5.55 9557 38.23 9557 38.23 95S7 40.01 9681 45.66 9740 49.2! 9824 54.2~ Ol~ 65.50 10245 79.50 10313 10420 10420 90.00 11420 90.00 VERT-DEPTH$ SECT BKB SUB-S DiST 6879 6824 2451 6960 6905 2509 7046 6991 2558 7137 7082 2598 7232 7177 262E 7330 7275 2649 7395 7340 2658 7420 7365 2660 8006 7951 2717 S!38 8083 2730 8637 8582 2931 8637 8582 2931 ~660 8605 2949 8729 8674 3013 @769 8714 3057 SS21 8766 ~123 8915 8E60 32~5 89~5 8930 3607 8995 ~940 3574 9001 39~ ~ ~6~1 9001 8946 3651 9001 8946 4681 9019 8964 DIRECTION ]{EL-COORDINATES DL/ AZIMUTH PROM-WELLHEAD 100 329.70 2102 N 1585 W <TiE 330,18 2152 N 1614 W 6.0 330.84 2197 N 1639 W 6.0 331.54 2233 N 1659 W 6.0 333.57 2261 N 1673 W 6.0 337.43 2280 If 1682 W 6,0 344.34 2268 N 1685 W 6.0 244,34 2290 N 1686 W 0.0 344.34 2345 N 1701 W 0.0 344.34 2358 N 1705 W 0.0 344.34 2550 N 1759 W 6.0 344.34 2:'30 N 1759 W 6.0 344.34 2538 N 1764 344,34 2630 N 1781 W 6.0 34~.34 2672 N 1793 W 6.0 344.34 2735 N !$!1 W 6.0 344.34 2891 N 1854 W 6.0 344.34 3105 N 1914 W 6.0 344.34 3170 N 1932 W 6.0 344,34 3273 N 1961 W 6.0 344.34 3273 N 1961 W 6.0 344.34 4236 N 2231 W 0.0 (GLDD (c)92 DS955A 1~1.36 9:19 AM 2) PRODH'OE imm m .... i BAY BRILLING Honker Ident;¢ication NO BKB SECTN INCLN A) TIE-IN / KOP 6/JO0 7700 6879 245J 39.27 B) END OF CL~VE #t 8265 7395 2658 5.55 C] BOC 12 BOILO 6/~00 90t3 8~3B 2?30 5,55 D] ENO Of CURVE ~2 10420 900i 368] 90.00 E] IARGET I0420 900! 368! 90.00 FI TO 11420 900! 46D] 90.00 iOOdO 2400 DS 9-35A (P2) VERTICAL SECTION VIEW ,, Sect:ion st: 344.34 ,vD S~e.' ~ ~ Oep Scale.' ~ inch : 400 feet '%, ' i , , ' , , ', .... ii ,t : Dr wn ~2/09/92 ...... , i.' ~.' , , ~ .' I ! -?~[,:!:;/c: t] ~ J , ' j J I ; i i '-' ' i i ' "'- ~'.... ._x.~,,[', ,, , ,: , ' ' Great LandDirectJonal'B~lYling ~il ~l,. .... t · .. ............. , % t i , . .~_,~. ~_ , . _~. I , , ~ , ~ . ~-' ~- .~ '~ _ _.: . , ~ , , ~ . ~ . , .... r-¢ ', I i [ I ...... I ' ' I ' i ' .... . - · . , : ..... .: I , , ', , : I. '~~.l ' ,' .' .... ' cL~I: ;; ~I , I ~ : ~,! I ; : I I , : i :. 'F-y'~I Il ....... [[z- ~ __I ; l~ ] / ~ I : i I . il i i i ~ i I ; [~tI ''7-] , :; ! ~: i, k i: i ~ I !~ I ;l i I i~ i; :_[.. _~ [.L_._ ;I ' ' . : . ' ' ~ ~ ' ' i ' ' ; I : ' · I : ~.L.i._~.~._z.H~ ,,,,, , [ ....... ~ ...... I: ~, ,. ,:_ . .. . .... I i : ! i :~ : . t i i -['Ll';;]]T%%%z I ~_ i ;. : : , i :: , ~--~--~./--- ' 1 '~/ f / ~ ` ~ ~ I :' ~ ~1 : ! i i ~ i ~r]'~ i'~". !,: .: : ' .-..~ ! .I ! i- : :' ' ! ~ ' ' ! ; I : i : ~~.?..~,'=----~..--a----.mb**~l.l~~----.Z~ I ~'l--f--T" : . ' L I I I ' I ' I : ~ '~ ~2~ ~?' '¢' = ......... ' ........... r I . ' ' "~' ' . ~~- ~ ~ ..... r-,.- ..... ~-.,~-.-.-.m .... l_ ._~ ................................... ~._,__ : . : :; ;I : : , I I ::: :: I l,. :!. l~:i l:l' · -, ~,F . t ..... .~ . , ....... -%'~ -'t'i ~ , , ! ' '" ...... ~ ...... I ' ~ ' :. i i i ..... I ~ . ; :'' i ...... %' ' · i t ' ; I · ~ .... . . , .... ,._L ,. , I / :~;~:~!: ..... ,:.F,,t,.. ..... . . , : .... ~ ._J.,.., .I : ,. '" '~ ' -'~ I i : ' ' ; ' ' ~ I I i ' ~ ] II L ~ ' 'I : ~ I -- ' ] '"; ~':'~'"'I~-'t I:i: .... t 'T-'~ ' i I . --r ~ i i : , ~ : , : . : . : ....... ; : : , , I I ~ ' ' ' I " 4 260D 2800 3000 32_00 3~00 3600 3800 4000 4200 4400 4600 4B60 5000 5200 Section Departure mm .-. I 1, .l_ DEC-O9-19'32 O9:-''~.--_~ FROM GREAT LAND PFIUIDHOF BAY OBILLING 8) ENO ~ CUnVE ,~ 8~85 228B N PL AN V T C) BOC ~2 BUILD 6/~00 90~3 2358 N ~705 W D) ENO OF CURVE ~2 ~04~ 3a73 N ~g&t ~~ .... ' ........ E) TARGET 304a0 3a73 N ~96~ ~ CLOSURE · 4787 fL aL Azimuth 33~,~ F) TO ~0~~ ~36 N ~3i ~ DECLINATION.' 30.23 E ...... "' "~ '~'"~S ~ po ~)~s~,~. SCALE ' ~ inch : 800 feet ~',,~,,, DRAWN ' 12/09/92 '~', --"~'~ Great Land OJnectiona] Ori]]~ng ...... _ ~ -J ~ ', ~ ~ I I I I i-i t i ~ ', , , ~ ,' ~ ~ ~ i' "j ', ', ~ , ~ , ; ~. i 4000. , I I , I I , ~ , I , ~ , . , I , , ~t ~ ~ ~ --'t .... !.. ~ ' ' '' ~J ' ~J --!" ''-T-~:- ' ' ' ' ....... : ~.L, J ~ ~ ~ , , , r , : q ~ , . ,~. ' ; i ~ , i : '~-'j'~:"' [ ~ [ i ~ F-~-~ ! i ! J ! ~ J I I ', i i I i ~ ', I I i ~ I J I ~ i ! ~ i i ~ ~ i ~ J :~: i iI ~ I : I i ~ ~ ] ; , ! ~ , ~ '~1~ i' i ili ...... ~ ; t ~ i I i i ~ ~ ~ ,, i ~ ~ I ~ ~' ti M I' ~ I J ~ r ~ ' ~ -"~, ~ - ' ' ' ' ~ ' ' ., , , . .J ~ : ! · , .... ,. ,, Il I~'~ :t~. ! ,. .... ~.: J, ,, ,, ,, ,. I,.J.~oo I ' ' ~ -*F~l .......~ ~ ~ ...... I ! ~ , :, ::1 l: , I I.~. I ! I ; [ i ~ I ~ ~ ._i__t [ . . ......... ~ .~.. - . .. ~*-.i" i;F~ ; ~j ~i~ :.}: -! : / ~ i. ! I I I ! ~ i-' ~..i ~ .... ~ , ~ ~ ..... , I i ., , , , :.. , , q , I , , ~ , . .~xJ I ~ ~,~ ; . ~ - ,~t, i:, .,,!!, ,~ Ltl -~:i~ I~ ~ ~ : ~,t~ ~ I ~ , ~ : 5~0 ~BO0 ~400 4060 3600 3RoO 8~00 ~400 ~oDo ~600 ]200 800 400 0 400 <- WEST' E~ST-> TOTAL F'.04 .0' NABORS 2ES 13 5/8" 5,000 psi Stack KB TO BF DRIP PAN 4.95' 4.37' 4.85' 1.68' 1.88' 1.50' 2.17' !' I HYDRIL I I 12.19' PIPE RAM BLIND RAM I, MUD CROSS PIPE RAM i,, MUD CROSS TBG SPOOL 1.42' GROUND LEVEL ASE FLG ~ / iFIO R 16.37' 18.25' 22.20' 68' 26.85' 28 25' NABORS 2ES MUD PIT SYSTEM Trip Tank 55 BBLS PIT #1 170 BBLS PIT #2 175 BBLS PIT #3 180 BBLS Pill Tank 60 BBLS State: Field:. S tare Permit ~ ~nglneer: V/ork Sheet: Dale: N. N/ndef £emet'# Vok ,,mc. (;alc~#a#o; 2/16'/$3 Casing T Casirg Size -I:~hes Ca~ing Lench- Feet Hole Diamete~ -Inche.s ,_.amen, Sacks Cement- Ybld Cement- Cubic [{ r -~, Cubic ft Cement- Sacks ~2 Cement-Yield Cement-Cubic ii ~2 Cement-Cubic it ~2 Cement- Sacks C~ment- Yield Cemen~ - Cubic k Cement r,,~;~, f~ ~3 Cement-- Cubic It /Vol Eemen~ - Fill Eonduc(o~ 0.000 0.000 0.000 0.0~ O. O00 0.000 0.000 O. OOO 0.000 0.000 0.000 0.000 :i:I:DIV/O! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 0.000 ~DiV/O! Lir:e~ 7.000 2,690.000 8.500 0.000 0.000 0.000 58! .OOO 0.000 O. OOO O.OOO 0.000 581.000 I. 7('13 Casing Type Casing Size -Inches Casing Depth - Fee( Hole Diamet. er -Inches C:ement- Sacks Cement-Yield 1:II Cement-Cubic !I.$11 Cement- Cubic It Cement-Sacks ~12 Cement-Yield ~2 Cement- Cubic it~2 Cement-Cubic ft ~2 Cement-Sacks .~3 Cement-Yield :!:i3 Cement- Cubic fi. :1:I3 Cement- Cubic It:1:i3 Cement-Cubic tt /Vol Cement. Interval ft Top of Cement- Fee(' Intermediate 0000 0.000 0.000 0.00 0.00 0.00 0.00 0.~ 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 0.00 q:DiV/O! Intermediate ~12 0.000 0.000 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 O. O0 0.00 0.00 ~DIV/O! ~DIV/O! P.~odu'ction 0.000 0000 0.000 0.00 0.00 0.00 O. O0 0.00 0.00 O. O0 0.00 0.00 0,00 0.00 O. O0 O. O0 .State: Alaska Borough: Weft: D-Sg~-85A Field: Prudhoe Bay Date 2716193 Engr: M. Minder r"" "'3 ~.. '-. ,JSS-oS&XL.~ Casing Interval Interval Size Bottom Top Length iA 7 8806 6743 2690 2A 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Tension Lbs Grade Thread Lbs 29 13CR-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IB 2B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Wieght Gradient Gradient ppg p$i/ff psi/ft 9.8 0.510 0.410 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0. 100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.1 O0 0.0 0.000 -0.I O0 0.0 0.000 -0.100 0,0 0.000 -0.100 Maximum Minimum Pressure psi 33,30 0 0 0 0 0 0 0 0 0 Yield psi BDF 8'I 60 0 #DIV/0! o #DrW0! o 0 #DiV/0! 0 #DIV/0! 0 ~D~i0! 0 ~DIV/O! 0 ~D~i0~ 0 ~D~IO~ 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength F/Lbs 78.01 0 0 0 0 0 0 0 0 0 K/Lbs T-IDF 676 8.67 0 #DIVJO! 0 #DIVt0! 0 0 #OiV/0! 0 0 #DIV!O! 0 #DiV/O! 0 #DIV/O! 0 Collapse Collapse Pr-Dot-Psi 3607 0 0 0 0 0 0 0 0 0 Resisi. CDF 7020 1.946 0 #DlVl0! 0 tlDIVIO! 0 #DlViO! 0 #DlVi0! 0 #DIVIO.I 0 #DivlO! 0 #DlviO.~ 0 #DiVIO! fJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend__ Operation Shutdown__ Re-enter suspended well__ Alter casing __ Repair well __ Plugging x Time extension ~ Stimulate Change approved program ~ Pull tubing ~ Variance__ Perforate X Other X __ Plugback for Reddll 2. Name of Operator ARCO Alaska, inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1822' FSL, 1048' FEL, Section 2, TION, R15E, UM At top of productive interval 344' FNL, 2136' FWL, Section 2, TION, R15E, UM At effective depth 136' FNL, 2133' FWL, Section 2, TION, R15E, UM At total depth 115' FNL, 2132' FWL, Section 2, TION, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5. Type of Well: Development X Exploratory __ Stral~graphic __ Service 10320 feet Plugs (measured) 9100 feet 10247 feet Junk (measured) 8971 feet Length Size Cemented 80' 20" 1810# Poleset 2471' 13-3/8" 2500sx CSIil & 400sx 9754' 9-5/8" 500 sx Cl G 6. Datum elevation (DF or KB) RKB = 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 9-35 9. Permit number 85-52 10. APl number 50- 029-21314 11. Field/Pool Prudhoe Bay Field~Oil Pool Measured deptl~ ___ True vertical depth 9786' ~wo 8620' 812' 7" measured 10206'-10228' 300 sx C1 G/125 sx ARC true vertical 8898~9018' Tubing (size, grade, and measured depth) 3-1/2" 13 Cr-80 Fox & TDS @ 9401' 9100' ECEI VED Alaska Oil & Gas Cons, Commissi0~ 'Anchorage. Packers and SSSV (type and measured depth) Baker "D" Packer @ 9296;' Camco "TRDP-2a-SSA" SSSV @ 2116' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 2/10/93 16. If proposal was verbally approved Oil X Gas ~ Suspended ~ Name of approver /, Date approved Service 17. I hereby certify that}he foregoir/g is true and correct to the best of my knowledge. / Signed ~.~~ TitleDril/ingEngineerSupervisor Date ¢'" -~_,/ '~ FOR COMMISSION USE ONLY Conditions of approval: Notif" Cy~;~mission so representative may witness I Approval No. Plug integrity BOP Test__ Location clearance~ ~'L') I 2,-._72 ~ CC,' Mechanical Integrity Test ~ Subsequent form required 10-~/'t) ? i")lr-/° ~c,,~)°~~ ~.... ~ 0 "~'..~ Origlnal Signed By ¢..¢. ,- Approved by order of the Commission David W. doiqnston Commissioner Date ~--~---/~ - Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ** I TEN APPROVE DATE [ 2 thru · '1~9 thru [ 10 & 13] [14 thru 22] (5) BOPE '~,~/:'~.~ ~-)~-' ~,~ [23 thru 28] Company .~K<-~), 1. Is 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 & is wellbore plat included ................... ~< . 7. Is operator the only affected party .................................. .~. 8. Can permit be approved before 15-day wait ............................ _~ 1 10. 11. 12. 13. 14. 15. Lease & Well YES NO 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 lease nLFnber appropriate .......................................... Does well have a unique name & number ................................ I s conductor st r i ng provided ......................................... Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~-Od)d> psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS FOP ~ '/'7Od) / (6) Other ~[[~2F~ thru 31] (7) Contact ~1_ ~/2~~ (8) Addl ~ ~...~2~' geology' engineerinq' DWJ~-'-~ MTM¥?-~.. RAD~i~ Z-1L~ LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLmber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM ~< MER I D I AN' SM .TYPE' Exp D~.v~>~ Inj. Redr i I 1 Rev · , O -rz ~O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. , ALASKA COMPUTING CENTER , ****************************** ****************************** COMPANY NAME ~ ARco ALASKA, INC, WELL NAME : D.S. 9-35A FIELD NA~E : PRUDHOE BAY BOROUGH ~ NOETH SLOP~ STATE : ALASKA AP! NUMBER : 50-029-2].314-01 PEFERENCE NO : 93130 RECEIVED FEB 1 7 1~Y~4 ICiIOFILME ' ; =hlumberqer AlasKa ComoutJ. nq Center 20-JAN-t994 14:36 **** REEL HEADER 6ERVICE NAME : DATE : 94/0~/90 ORI~I~ : ~D~C REEL NAME : ~3130 CONTINUATION ~ PREVIOUS REEL COMMENT : ARCO ALASKA, INC.,PRUDHO~ BAY, D,S. 9-35A,50-0~9-21314-01 SERVICE NA~E : EDIT DATF : ~4/01./~0 O~I~IN : FL!C TAP~ ~AME : 93~30 CONTINUATION # : ~ P~EVIOUS TAPE : COMMENT : ARC{] ALASKA, INC,,PRUDWOE BAY, D,$, 9-35A,50-029-2~314-01 T~PF P~UDHOE BAY ~WD/MAD LOGS # WELT., APl NUMBER: OPErATOr: LOGGING COMPANY: TAPE CREATION DAT~: jOB DATA I,OGGING ENGINEER: # SURFACE LOCATION SECTION: R~NGE: FNL: ESL: FEI~: ELEVATION(FT FROM ESL 0) KELLY BUSHING: DERRICK FLOOF: ~ROUND LEVEL: WFLY, CASING RFCORD STRING STRIWG STRI~G 5 292131401 ARCO ALASKA, INC_, SCNb. UMBERGMR WELL SERVICES ~9-JAN-94 BIT RUN I BIT RUN 2 BIT RUN 93130 931.30 93130 ST.~MOU~ ST,AMOUR PERRY 2 1ON 1822 1049 52 62 51i62 22 61 OPEN HOI[,E CASING DRILLERS BIT STZ~ fiN) SIZE {IN) DEPTH (FTi 8.500 9.625 7700'0 PAGE: IS Tame 'Ver~flcation I,lstlnq 20-JAN-l. 994 14:36 Chlumberg~er AlasKa ComputlnO Center ~ROD!ICTION *TRINC GR TO BIT 38.2' RES TO BIT 27 8' DEN Tf~ BIT Q4.6' NEUT TO BIT {01.6' D~ISLF~D I~TERVAL: 9587 - 9780 MT CDR/C~I~_~ - R/T CDR ************************** 2******************* GR TO BIT 3~.3' PE$ TO BIT 27 q' DEN T~') BIT 94,7 NEUT TS BIT D~ILLED INTERVAL: 97~0 - 9843 MT CDR/CDN - R/T CDR WASMDOWN INTERVAL: 9550 - 9780 FT CDR/CQN - ~/T CDR GR TO BIT 37.9' RES TO BIT 27,4' DRILLING RES-GR ONLY 984~ - 10387 FT CDR R/T (NO CDN-TOOL ,.,AID DO N DUE TO D~ILLING CO~DITIO~S, DATA COLLECTED DURING MAD PASS. ) ************************ 4******************* GR TO BIT 53.7' RES TO BIT 4~ 3' WASHDDV~N ]NTE~ Ab: 9715 - 1038 CDR/CD~ - (NO R/T) ' ~ '~ '. DOWNH[~bE $O.~1. WARE V4 0C SLIDING INDICATOR SHOWN IN DEPTH TRACK CDR SAMPLE RATE = 20 SEC CD~ SAM~[,~ RATE = 20 SEC LIS FORe, AT DATA PAGE: 2 **** FYLM HEADER **** FTL~ NA~E : EDIT .001 SERVICE : PL/C VERSION : 00~CO1 DAT~ : 94/01/~0 ~AX REC SIZE : 10~4 FILE TYPE bAST FILE : FTLF HblADFR EDITED ~g~GEO me,th sh~fted a~d cl~poed curves~ all bit runs merged, DEPTH 1NCREMENT~ 0.5000 FILE S~iM~ARY Y..DWG TOOL CODE START DEPTH SIOP DEP?H rD''~''''''''''' '''''''''''9587.0 ''''''''''{0387.0 Tame Verificat,ton ~,istlnq ChlUmberq'er AlasKa Comput~n~ Center 20-JAN-1994 14:36 CON 9587.0 $ # BASELTNE CURVE FOR SHIFTS: CURVE $~;IFT DATa (~MASURED DEPT~) BASELINE DEPTH MERGED DATA SOURCE ~,DWG TOO[, CODE CDR CD~ CD~ CDW CDN $ REN~RKS: 984~.0 .......... ~QUIVALENT UN,SHIFTED OEPTH---------- RUN NO, MERGE TOp MERGE BASE 9587.0 9780.0 9780.0 984~.0 9~43,0 10387 0 9587.0 9780~0 9780,0 9843.0 THERE IS NO DEPTH SHIFTING ON THIS WELL AS PER BOB OCANA$ (ARCO) VIA &COTT LEVAD (ANADRILh). 1/12/94 THE CDN WAS RUN Y~ A DEPTH OF 9843 FT AND WAS THEN LAID DOWN DUE TO HOLE CONDITIONS. ONLY THE CDR WAS RUN T~ TD. THIS FILE CONTAINS THE LWD GR FRO~ THE DRILLING RUNS R. WD).AS ~Ebb AS A GA~A NADRTb~,'M SLIM~R bOG $ b?$ FORMAT DATA PAGE: 3 ** nATA FORe, AT SPECTFTCATION RECO~D ** ** SET TYPE - 64F~B ** E EPR CODE ~LUE i 66 0 2 66 0 3 73 6O 4 66 ~ 5 66 6 73 7 65 8 68 0.5 11 66 17 1~ 68 Tape Verlflcatlon Listlnq chlumberger Alaska Compute. hq Center 20-JAN-1994 14:36 TY COPE V 1 66 0 !4 65 15 66 68 ,16 66 0 66 0 PAGE: 4 ** SET TYPE - CF{AN ** N S RV UNIT ICE A API APl APl FILE NUMB NUMB SIZE R .R PROCE ID ORDER ~ hOG TYPE CLASS ~OD NUMB SA~{P ~LEM CODE (HEX) DEPT RWOm NPHI R~ DER GW NCNT F~T GRSL FT 619054 O0 aO0 O0 0 1 I 1 4 68 0000000000 G/C3 610054 O0 000 O0 0 1 ! t 4 68 0000000000 G/C3 61Q054 O0 OOO O0 0 1 1 1 4 68 0000000000 BN/E 619054 O0 000 O0 0 I 1 ~ 4 68 0000000000 IN 619054 O0 ©O0 O0 0 1 1 1 4 68 0000000000 PU-S 619054 O0 nO0 O0 0 1 1 ~ 4 68 0000000000 OHM~ 610054 O0 000 O0 0 1 1 1 4 68 0000000000 OHM~ 619054 O0 000 O0 0 1 1 ~ 4 68 0000000000 O~M~ 619054 O0 000 O0 0 1 1 I 4 68 0000000000 FPHR 61~054 O~ 000 O0 0 ~ ! 1. 4 68 0000000000 GAPY 610054 O0 000 O0 0 1 1 1 4 68 0000000000 C~S 619054 O0 aO0 O0 0 1 1 ~ 4 68 0000000000 CPS 610054 O0 o00 O0 0 1 I 1 4 68 0000000000 HR ~19054 O0 000 O0 0 ! 1 ~ 4 ,68 0000000000 GAPI 61~054 O0 000 O0 0 I I ~ 4 68 0000000000 DFPT. 11170.000 RHOB,~WD -999 ~50 DRHO.MWD -999.25(3 PEF,MWD -999,250 CaLM ~WD -9q9'250 MP~I,MWD -999~50 ~A.MWD -999.~50 RP,MWD -999,250 DE~WD -999'250 ROP,~WD -999 ~50 GR,MWD -999'~0 NCNT.MWD -999,~0 FCNT.,W9 -999,2~L} F~T,MWD -999~ ~50 GRSL,MWD -999.250 DFPT 11000.0~0 R!tOB.MWD -999 250 DR~O,MWD -999.~50 PEF MWD -999,250 C~LN'~D -999,2~0 NPHI,~WD -999~50 RA,MWD -999,~50 RP~MWD -999,~0 DE~PWD -909.2~0 ROP,MWD -999,250 GR.MWD -999,250 NCNT,MW~ -999,250 FCNT,~WD -999.25U FET'~wD -999,~50 GRSL,MWD -999.~50 DMpm 10500,000 R?(OB.MWD -999,250 DRHO,MWD -999 ~50 PEF.MWD -999~50 C~LN:~D -999.25u NPNI.MwD -999,250 ~A,MWD -999:~50 RP,MWO -999,~50 DEP,~D -999,2~0 RO~.M~D -999,~50 GR,M:4D -999.~50 NCNT,~W~ -999,250 FCNT.~WD -9~9,250 FET,~wD -999,~50 GRSL,M~O D~pT 10000,000 ~HOB.f~WO -999,~50 DRHO.MWD -999.~50 PEF,MWD -999 250 CabN[~wr~ -9q9,2~o ~PHI.M~i~O -999,250 ~A,~WD 36,604 RP,MWD 43:852 ~E~ ~W~ -999 250 ROP,MWD 44.677 GR,~WD 2],682 NCNT.~WD -999,250 FCNT~.n -999[250 FFT,bit,~5 1,759 ~RSL,MWD -999,~50 IS Tape Ver~.flcatlon histin~ chlumberger AlasKa Comput.~nq Center 20-JAN-1994 14:]6 PAGE: 5 DEPT. 9500 ~0 127 -999 250 5.505 CALN.MWD -~99 ~250 NPMI.MWD PEP. ~WD -999,259 ROP. MWD T O 6,030 ~T.MWD FCN . ~W " ** END OF DATA ** 999,250 DRHO,MWD :999.~50 RA,MWD -999. 250 GR.MWD -99~,~50 GRSL,MWD :999.250 PEF.MWD 999'250 RP.~WD -999 250 NCNT -999~50 ' " 3',304 '999,250 251',875 -9 ,250 -999,250 **** FILE TRAIDE~ **** FILM NA~E : EDIT ,001 SERVICE ! FL?C VERSION ! O01C01 DaT~ : 94/01/~0 MAX REC SIZE FILF TYPE : LO LAST FILE **** FILE ~EADER FIb~ NA~E : EDIT ,002 S~RVICE : ~LIC V~RSION : nO,COl DAT~ ~ 94/0~/20 MAX REC $IZ~ : ~024 FILF TYPE : LO L~ST FIbE : FIDF WKaDMR Fib? N!~BER: 2 EDITED ~ERGED MAD Depth shifted and cl{pmed curves; all bit runs merged. DFPTH INCREMENT: 0.5000 FIbm SUMMARY [.DWG TOOL CODE START DEPT~! STOP DEPTH C{)~ 9545 0. 10185,0 CD~ 9545.0 10385.0 CURVE SHIFT DATA (~ASURED DEPTH) .......... ~IIIVALENT UM~HIFTED OMPTH--- ....... :S Ta~e verification ~ist~n~ :hlUmber~er AlasKa Computln~ Center 20-JAN-1994 14:36 BASELINE DEPTH $ MKR~ED DATA I,DWG TOOL CODE CDR CDR CD~ CDN BIT RUN NO. MERGE TOP MERGE BASE l 9780,0 95., 45.0 ~ 10385,0 9715.0 ! 9780,0 9545.0 2 ~.0385,0 9715,0 TWERE IS P40 DEPTH SNIFT!NG ON TNIS WELb AS PE~, BOB OCANA$ (ARCO) VIA SCOTT LEVAI (ANADRILL) 1/12/94 $ bis FORMAT DATA PAGEt ** DATA FORMAT ~PECIFICATIO~ RECORD ** 2 66 3 73 56 4 66 5 66 5 73 7 65 8 68 0,5 9 65 FT 11 66 18 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 mmmmmmmmmmmmmmmmm~mmmmmmmmm##m ** SET TYPE - CWAN ** '''NA~ .... ;~''V .......... UNIT SE~V~ .... API''''~A ........ ¥ API ';~''''''''''''''~'~''~i~''~FIt, E NUMB EPR ..... ''''''PROCESS .... ID ORDER ~ BOG TYPE CbASS ~OD NUmB SAMP Eb~M CODE (HEX) DEPT FT 61~054 O0 000 O0 0 2 1 1 4 68 0000000000 R~OB ~AD G/C3 61oo54 O0 000 O0 0 2 ! 1 4 68 O000OO0000 DRHO ~AO G/C3 61o0~4 O0 ()nO O0 0 2 I 1 4 68 0000000000 PFF ~A~ BM/E 61oU54 O0 000 O0 0 ~ i 1 4 68 0000000000 IS Tare Ver~.f~,catJ. on T,£stino :blumber~er AlasKa Computtn~ Center 20-JAN-1.994 14:36 PAGE~ 7 ''''''''''NAMF SMRV .... U ~'''''''~IT SER V .......... M ADI Ap ~''.~''~.~,~''''FILE ...... NUM ~"'~''~'''''''''~~'''., REPR ID f~RDER ~ bOG TYPE CLASS MOD NUMB SA~P EI~EM CODE (HEX) CALN M~D IN 619054 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI UAD PU-S 619054 O0 000 O0 0 2 1 I 4 68 0000000000 R~ ~AD OMM~ 6~0054 O0 000 O0 0 2 I 1 4 68 0000000000 RP ~AO OHMU ~10054 O0 000 O0 0 2 i I 4 68 0000000000 DER ~AD O~M~ 619054 O0 000 O0 0 ~ 1 1 4 68 0000000000 ROP ~AD FPH~ 619054 O0 000 O0 0 2 1 I 4 68 0000000000 GR ~AD GIPI 619054 O0 000 O0 0 2 I 1 4 6~ 0000000000 NCMT UAD CPS 619054 O0 000 O0 0 2 I 1 4 68 O000OO0000 FCNT ~AD CPS 619054 O0 000 O0 0 ~ 1 1 4 68 O000OO0000 F~T ~AD HR 61~054 O0 000 O0 0 ~ I 1 4 68 0000000000 ** D~TA ** DEPT. CALN.~AD -999,250 DE,.MAD -999,250 FCNT.~AD -999.2~0 DMPT. 10000.000 C~b~.MAD 10.156 DE~,~AD FCNT.~AD 8.4vl 9500,000 D~PT'~AD 10 C~bW..~ . DE~.~AD -999,250 FCN?.WAD 5,163 DMPT. CaLM.~AD -999.250 DER.~AD -999,250 FCN~,vA~ 6.030 ** g~b OF mAmA ** RHOB~MAD '999,~50 DRMO,MAD -999,250 PEF,MAD NPHI,MAD '999,250 RA.MAD -999.~50 RP,MAD ROP'MAD ' 59.800 GR'MAD -999.250 NCNT'MAD FET.MAD 999,~50 RHOB,MAD ~ 355 DRHO,MAD '0.010 PEF.NAD NPHI.MAD 2~:900 RA,MAD 35,686 RP'MAD ROP,MAD . 69.371 GR,MAD 29.274 NCNT,MAD F~T,MAD 9991~50 RHOB',MAD 2 ~04 DRHO.MAD 0 026 PEF.MAD NPHI:MAO 3~1.00~ RA.MAD i999:~50 RP.MAD ROP,MAD -999.250 GR.MAD -999.~50 NCNT,MAD FET.MAD -999,~50 RHOB.M~D -999.~50 DRHO.MAD -999.~50 PEF.MAD NPHI.MAD -999.250 RA.MAD -999.~50 RP,MAD ROP,MAD -999.~50 GR,MAD -999,~50 NCNT,MAD FET,MAD -999.~50 -999'~$0 ~999,250 -999,250 3,02! 22,625 303,500 3,326 -999,250 249,000 99 250 -99 250 **** FILM FILE NA~E SFRVICE DaTF M~X REC SIZM FIL~ TY~M D~Sm FILE mRgI[,gP **** EDIT .002 rblC 001C01 q4/01/20 1074 T,O ES Tame ver!ficat.~..on ~,istlnq :hIumberger AlasKa ComputinQ Center ~O-jAN-I994 14:~6 PAGEt 8 **** FILE HEADER **** FILM MAnE : EDIT .003 SERVICE : VERSION : 00~COi ~aX REC SIZE : ~0~4 FILE TYPE : LO LAS? FILE FILE MEnDeR FILE NUMBER 3 RAW MWD Curves and lo~ header data for each bit run tn separate BIT RUN NUMBER: DEPTH INCREMENT: 0.5000 FIbF LDWG TOOL CODE START DEPT}~ ;';'''''''''''D ' .... ~=..~87 ~;'''' CDN 9587,0 $ ~OG ~EADER DATA DATE bOGGED: SDWTWAmE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE ¢~EMOR¥ or R~AL-TIME): TD DRILLER mop LOG INTERVAL (FT): ~OTTOM LOG INTERVAL BIT ROTATING SPEED ~OLE INCLINATION (9EG) ~TNTMUM ANGLE: MAXTM'~ ANGLE~ TOOL ST~ING (TOP ?O BOTTOM) VENDO~ TOOL C~DE TOOL TYPE CDR RESISTIVITY CQN NEUTRON/POROSITY $ ~OREHObE AND CASI~ DATA DRILLE~S CASIN~ DEPT~ MUD TYPE: ~iUD DENSITY STOP DEPTH 9780.0 9780,0 tS-MAR-93 FAST 2.BE V4,0C MEMORY 10387 0 10387.0 37.5 85.0 TOOL NUMBER RGS04] NDS055 8 5n0 7~00 .o ECL PO,Y~ER 9.80 40,00 IS Tame verification blstino chlumberger AlasKa Comp,It!nO Center 20-JAN-1994 14:]6 MUO ~UD CgLORIOES (PPg): FLUID bOSS ~XIMUM R~CORDED TEMPERATURE (DEGF): PESTSTIVITY COHEN) ~T TEMPERATURE CDEGF): ~UD AT ~EASU~ED TE~PERkTItRE gUD AT MAX CIRCULATING TEMPERATURE : ~UD FILTRATE AT ~UD CAKE Aw M~TRI× DENSITY: HObM CORRECTION # R~M~RKS: TO06 STANDOFW (IN): MWR FREQUENCY 9.00 32000 158.0 1,920 1.720 SANDSTONE 2.65 1,000 T~ERE WERE 4 BIT ~U~S IN THE MOLE IN WHIC~ TNERE ~ERE 3 DIFFERENT CDR TOObS RUN IN BOTN D~IbLING ~ND WASHDOWN ~ODE AS WELL AS 3 OF T~E RUNS ~AD CD~ IN THE CLIENT REQUESTED THAT THE WASHDOWN AND PASSES BE P~ESE~TED AS SEPARATE LOGS. G~ TO BIT 38.2' RES TO BIT 27.8' DEN TO ~!T c4,6' NEUT TO BIT 101.6' D~ILL;~D I~TERVAL: 9587 - 9780 FT' $ LIS FORMAT DATA 61.0 9 ** ~ATA FORMAT SPECIFICATIO~ ~ECOWD ** SET TYPE - 64EB · YPC RFP~ CODE VALUE I 66 0 2 66 0 3 73 64 5 66 6 73 7 65 1~ 66 ~6 12 68 13 66 0 14 ~5 FT [8 ?ape Verification nisting :blumberger AlasKa Computino Center 20-JAN-1994 14:36 PAGE~ 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl API API API ~ILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CLASS ~OD NUMB SAMP ELMS CODE (HEX) DEPT FT 619054 O0 000 00 0 ] 1 1 4 68 RMO~ LW] G/C3 619054 O0 000 00 0 3 1 1 4 68 DPHI LW] Pt) 619054 00 000 00 0 3 I I 4 68 D~HO hM3 G/C3 619054 00 000 00 0 3 1 1 4 68 P~F LW] BN/E 619054 00 000 00 0 3 1. 1 4 68 DCAL LW3 IN 619054 00 000 00 0 3 1 1 4 68 TNP~ LW3 PU 619054 00 000 00 0 3 1 1 4 68 ATR LW~ ONM~ 619054 O0 000 00 0 3 I I 4 68 PSR Lw3 O~M~ 619Q54 00 000 00 0 3 1 1 4 68 DER LW3 OMM~ 619054 O0 000 O0 0 3 1 1 4 68 ROPE LW3 F/H~ 61~054 00 000 O0 0 3 I 1 4 68 GR LW] GAPI 619054 00 000 O0 0 ] 1 I 4 68 H~NA L~] CPS 619054 00 000 00 0 ] 1 1 4 68 HEFI LW] CPS 619054 00 000 00 0 ~ I I 4 68 TAB bW3 HR 619054 00 000 00 0 ] I 1 4 68 TABD LW] HR 619054 00 000 O0 0 ] 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 #m~m~-mmmmmmmmmmMm-#m~mmmm~mmmmm-mm-~-~mmm-~mm~mmm~mmmm,#~-#m~#--~-~mm-m~-m~-~mmm'' DEPT. 9779,000 RHOO.LW3 -999,250 OPNI.hW3 PEr bw] -999,250 OCAL.bw3 -999.250 TNPH.bW3 PS~LW3 -999,250 DER LW3 -999,250 ROPE'LW~ H~N~' L~3 -999,250 ~EFAiLW3 -999,~50 TAB,LW3 DEPT. g500.0n0 RHOB.bW3 2,439 DPHI,bW3 PEr LW3 3.304 DCRb. Lw3 0.25~ TNPH,bw3 PS~:LW3 -9~9.250 DER.bW3 -999.~50 ROPE.LW3 HEN~iLW] 251,875 NEFA.LW3 5.505 TAB.LW3 DEPT. 9489.0o0 RHOB.bW3 -999.250 DPHI.bW3 PEr. LW3 -999,250 DCAb'Lw3 -999,250 TNPH,bW3 DSP.LW3 -999.250 DER,LW3 -999.~50 ROPE.bW3 H~N~.Lw3 -9~9.250 HEFA.LW3 5,880 TAB,bW3 -999.250 DRHO,L. W3 '999.250 ATR.LW] 74 381 GR.LW3 -999:250 TABD.bW3 12.800 DRHO.LW] 36.900 ATR.LW3 -999 250 GR,bW3 '999~250 TABD.LW3 :999.250 DRHO.LW3 999.250 ATR bW3 -999.250 GRiLW3 -999.250 TABD.L~3 - ' so -999'250 -999,250 0 008 -999 250 -999 250 -999 250 -999"250 :999.250 999-250 '999.250 ** END Ow DATA ** IS Tape veri, ficatlon I,istlnq chlumberger AlasKa Computlnq Center 20-JAN-1994 i4:36 PAGE~ !1, **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : F~?C VKRSION : O01CO1 D~T~ : 94./01/~0 ~X REC $IZ~ ~ 10~4 F~L~ TYPE : LO FIL~ NA~E : EDIT .004 SERVICE : FLIC V~RSIO~ : O0~.COi D~T~ : g4/01/~0 M~X REC S~Z~ : ~024 FILF TYPE : LO LaST FILE : FILR NUgBER 4 Curves and log header data for each bit run ~n separate BIT RUN NUMBER: 2 DEPTH I,C~E~ENT: 0.5000 # FILF SO,NARY [,DWG TOOL CODE START DEPTH CDR 978, 0.0 CDN 9780.0 LOG H~ADER DATA DATE bOGGED: SOFTWARE: SURFACE SOFT~ARE VERSION: DOwNHOLE SOFTWARE VERSInN: DATA TYPE (M~MORY or REAL-TIME): TD DRILLFg (FT): TOP !,OG INTERVAL (PT): POTTOM LOG INTERVAL mit ~OTATING SPE~D ~OLE I~CLI~{ATION (PEG) ~IN!M!!$ ANGLE: TOOL ST~ING (TOP TO BOTTOg) ........ . ....... C~R TY STOP DEPTH 9843,0 ~EUTRON/PORO$ITY I8-MAR-93 FAST 2.3E V4.0C MEMORY 10387.0 9550.0 10387.0 37.5 85.0 TOOL N;;M~ER ~GS043 ~DS055 files. Tape vertflcatt, on l.,istl, nq :hlumber~er AlasKa Computlno Center 20-JAN-1994 14:36 ~DREHOLE AND CASING DATA DRILLERS CASING DEPT~! (FT): BO~ENO~,E CONDITIOHS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) ~:UD PM: MUD CgDORID~S (PPIS) FLUID LOSS {C3): ~AX!~UM RKCORDED TE~PERATUR~ (OEGW): R~TSISTIVITY (O~M) AT TEMPERATURE (PELF): ~UD AT ~'~EAS~r~ED ~UD ~T ~AX CIRCULATING ~UD FILTRATE AT ~U9 CA~E AT NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # RMMARKS: TOOL STANDOFF (IN): KWR FREQUENCY (HZ): RN~SO00 8 5.O0 KCL POLYMER 9.80 40.00 9 O0 32600 158.0 1.920 1,720 SANDSTONE ~.65 1,000 TNE~E WERE 4 MIT RUNS IN THE HOLE IN WHICH THERE WERE 3 DIFFERMNT CDR TOOLS RUN IN DRII, LING AND WASHDOWN MODE AS WEbb AS 3 OF THE RUNS HAD CON IN THE C~,IENT REOUESTED THAT THE W~MRDOWN' AND MAD PASSES gE PRESENTED AS SEPARATE bOGS. *********************U, 2******************* GR TO BIT 38,3' RES TO BIT 27.9' DEN TO BlT 94.7 MEUT TO BIT D~ILL~D INTERVAL: 9780 - 9843 FT LIS FORWAT DATA 83.0 61.0 ** ~ATA FORMAT SPECTFICATION RECORD ** ** SET TYPE - 64Eg ** TYPE REPR CODE VALUE I 66 0 2 66 0 Tame Verlflcatton bistln~ =hlumberGer AlasKa Comput].n~ Center 20-JAM-1994 14:36 PAGE: 13 3 73 64 4 66 1 5 66 6 7] 7 65 8 68 0,5 9 65 WT 11 66 16 1~, 68 1~ 66 0 14 65 FT 19 66 68 !6 66 1 0 66 1 NAME SERV UNIT $ERVTCE AP1 AP! AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # hOG TYPE C~ASS ~OD gUMB $~MP ~EM CODE (HEX) DEP~ F? 619054 nO 000 O0 0 4 1 I 4 68 RMOB LW4 G/C3 619054 O0 000 O0 0 4 1 1 4 68 DPH! [,W4 PU 619054 O0 000 O0 0 4 i 1 4 68 DRHO LW4 G/C3 61~054 O0 000 O0 0 4 1 1 4 68 P~F LW4 BN/~ 6~9054 O0 OOO O0 0 4 I I 4 68 DCAL LW4 I~ 619054 O0 000 O0 0 4 1 1 4 68 T~P~ LN4 PU 619054 O0 000 O0 0 4 1 I 4 68 A~R LW4 OgM~ 619054 O0 000 O0 0 4 1 1 4 68 PSR LW~ O~M~ 610054 O0 000 O0 0 4 I I 4 68 DER l.,W4 OHM~ 619054 O0 000 O0 0 4 1 1 4 68 ROP~ I, W4 F/H~ 619054 O0 OhO O0 0 4 1 1 4 68 G~ LW4 GAP! 619054 O0 000 O0 0 4 1 i 4 68 HFNa LW4 CPS 619054 O0 000 O0 0 4 I 1 4 68 HEFA LW4 CPS 619054 O0 000 O0 0 4 I I 4 68 T~B LW4 HR 619054 O0 000 O0 0 4 1 I 4 68 T~BD LW4 H~ 61~054 O0 000 Oo 0 4 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DEPT. 9845.000 RHO6,LW4 -99q.~50 DPHI.LW4 -999.250 DRHO.LW4 PEW,LW4 -999.250 DCAb,Lw4 -999,250 TNPH.~W4 -999.~50 PS~.LW4 -999.250 DER,LW4 -999.250 ROPE,Lw4 53,716 GR.I, W4 H~N~.LW4 -999.250 gEFA.LW4 -999,?50 TAB.LW4 -999.~50 TABD.LW4 ~pT 9500.000 RHOB,LW4 ~,404 DpHI,LW4 14 900 DpEW~I.,W~ 3.326 DC~L,LW4 0'307 TNPH,Lw4 39~000 ATR,LW4 PSP.LW~ -9g9.250 DFR,LW4 -999,250 ROPE,bW4 999 250 GR.LW4 HFN~ Lw4 249 000 gE~A LW~ 5 163 TAB .~ ,. LW4 . , 99.250 TABDo -999,250 -999,250 -999,250 0.026 -999,250 -999,250 -999.250 IS Tape Verification Listing chlUmberger AlasKa Computing Center 20-JAN-1994 14136 PAGE~ 14 D~PT. 9454,000 ~HOB,LW4 -q99o250 DPHi,,LW4 -999.250 DRHO.LW4 -999,250 PEW.LW4 -999,250 DCfiL.LW4 999.250 TNPH LW~ -999 ~.50 ATR LW4 ~999'250 PS~,LW4 -999,250 DER,LW4 ~999,250 ~OPE' ' ' LW4 -999 ~50 GR,LW4 999'250 .H~N~.LW4 -9q9.2~0 HEFA.LW4 6.030 T~B' ~ ~ .. .b~4 -999~50 TABD.LW4 999.250 END OF DATA F~L~ MA~E : EDIT .004 SERVICE : FLIC VERSION : O0~COI DATE : 94/01/70 M~X R~C STZ~ : 102~ FILE TYPE : LO LaST FILE : **** FILE gEADER **** FILM NA~E : EDIT ,005 SERVICE : VLIC DAT? : 94/01/20 MAX REC SIZE : FIL~ TYPE : LO L~S~ FILE : FILM HE~DMR FILE NUNBER 5 RAW MWD Curves and log header data for each bit run in separate BIT RUN NUMBERJ 3 DEPTH INC~EWEMT: 0.~000 # LDWG TO0~. CODE START DEPTW 984~.0 LOG HEADER DATA DATE bOGGED: SUFTWAmE: SURFACE SOFT~ARE VEPS~ON: DO~NHOLE SOFTWARE VERSIqN: nATA TYPE (MEMORY or REAL-TIME): TD DRILLER mOP LOG INTERVAL (FT): BGTTO~ LOG STOP DEPTH ~0387.0 fAST 2,3E V4,0C ~E~O~Y 9550.0 10387.0 files. IS Tame Verification Listlno chlumberger Al, asEa Computlno Center 2D-JAN-1994 14:36 BIT ROTATIMG SPE~O ~O[,E IMCLINf~TION (DEG) MINI~UM ANGLE: ~ ~XI~UM ANGI,E: TOOL ST~iMG (TOP TO VENDO~ TOOL CODE TOOL TYPE ...... CD RESIS~I BO~EHOLE AND C~SING DATA ODE~,~ HOLE ~!T SIZE D~IL~,ERS CASING DE~TH BO~EHObE CONDITIO,~S'~ MUD TYPE: DENSITY (LB/G): MUD VISCOSITY' (S)~ MUD PM: MUD CHLORIDES (pPM): ~.AX~UM R~CORDgD TB,.P R~TURE Rg$~STIVITY (OH~N) AT T~N~RATURB MUD AT ~ASUPED TE~PERA, TURE r~U~ AT MAX CIRCULATI~G TE~1PERATURE ~UD FILTRATE AT MUD CAKE AT MEUTRO~ M~T~IX: MATRI~ HOb~ CORRECTION (IN) TO~L 8TANDOF~ (IN) ~W~ WREOI~E~CY lMM) ~EMaRKS: 37.5 85.0 8 5OO 7 oo.o KCL POLYMER 9,80 40,00 9 00 ~5~.0 ~,920 SANDSTONE 2.65 t.000 T~{EPE WERE 4 BIT RUNS IN THE MOLE IN WHICH TWERE wERE ] DIFFERENT CDR TO0[,,S ~UN IN BOTH D~ILLING AND wASHDOWN MODE AS WELL AS 3 OF T~4E RUNS HAD CDN IN CLIENT ~EOUESTED THAT TEE WASMDOWN AND MAD PASSES BE PRESENTED AS SEPARATE bOGS. *********************U, 3****************** GP TO B~T 37.9' RES TO BIT 27.4' DRILLING RES-GR O~LY 9843 - 10387 FT THE CD~ wAS NOT RUN IN THIS DRILLING RUN. $ LIS FORMAT DATA 83.0 61.0 chlu~berger A],es~e Compu~lne Center 20-JAN-J994 14:36 ** DATA FORMAT SPECIFICATION RECOPD ** ** SET TYPE - 64EB ** TYPE R PR CODE YALUE · I 66 0 2 66 0 3 73 64 4 66 5 66 7 65 8 68 0~5 9 65 !1 66 16 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE -~---------------------------:---------:------------~--~---~----------------~-~~---~F $~RV UNI ER~ICK A APl AP API ~IbE U~ B SIZE REPR ID ORD&~ # LOG ~Y~.K CSASS MOD NUmB SA~D ES'EM CODE (HEX) DRPT FT 619054 O0 000 O0 0 5 1 1 4 68 RMOB LW5 G/C3 619054 O0 000 O0 0 5 1 I 4 68 DPH! LW5 PU 619054 O0 000 O0 0 5 1 I 4 68 DRHO L~5 G/C3 619054 O0 000 O0 0 5 I 1 4 68 PKF LW5 BN/K 619054 O0 000 O0 0 5 1 1 4 68 DCA[, L~5 IN 619054 O0 000 O0 0 5 1 1 4 68 TNPw LW5 p!.l 619054 O0 000 O0 0 5 1 I 4 68 ATR I, W5 OHM~ 619054 O0 000 O0 0 5 1 I 4 68 PSR LW5 OHM~ 610054 O0 000 O0 0 5 ! I 4 68 D~R LW5 OHM~ 6i~054 O0 000 O0 0 5 I ! 4 68 R~P~ LW$ F/H~ 619054 O0 000 O0 0 5 1 I 4 68 G~ ~,W5 GAPI 619054 O0 000 O0 0 5 1 1 4 68 H~N~ LW5 C~$ 6]9054 O0 000 O0 0 5 1 1 4 68 H~Fa I~5 CPS 619054 O0 000 O0 0 5 1 I 4 68 T~B LW5 HR 619054 O0 000 O0 0 5 1 1 4 68 TABD L~ HR 61~054 ~0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmm~mm~mmm~mmmmmm~m-mmm#mm~m~mm~mmm~m~mmmmmmmmmmmmmmmmmmmmmmmmmm~mmmm~mmmm~mmmmmmmm ** DATA ** DEPT. 10387.0n~ RHOB.LW5 -99Q.~50 DPHI,bW5 PEr.[,w5 -9o9.250 DCAb,LW5 -999.250 TNPH,LW5 P$~.LW5 -~Q~,2KO DER.bW5 -999.250 ROPE,LW5 HFNa.I, W5 -999.250 NEFA.LW5 -099.~50 ~AB.I,W5 -999.250 DRHO.LN5 -999.250 ATR.bW5 52.973 GR.LW5 -999.~50 TABD.LW5 -999.250 -999,250 -999.250 -999.250 KS Taloe YerI~,c~t~on Listino :hlum~erger laska Co~put no Center 20-JAN-1994 14:36 D~PT 10000.000 RHOB LW5 -999.250 DPHI.LW5 PE., :LW5 909 250 DCAL LW5 999,250 TNPH.I~w5 PS~.L~5 4.3'852 DER.bW5 42,,876 ROPE,LW5 H~A L~5 0999 250 ~EF~ L~ °999.250 TA~,~W5 D~PT 9500,000 ~HOB..LW5 2,439 DPMI.Lw5 ~EW~LW5 3,304 DCAb,SW5 0.~5~ TNPH,LW5 PSP.,LW5 -999,250 DER.LW5 -999,~50 ROPE.,SW5 ,~.L~'5 251,875 ~EF~' bW5 5.505 TAB.LW5 DEF.LW5 -999,250 DCAL,LW§ 999:~50 TNPH,SW5 ~$~.LW5 -999,250 DER,LW5 -999 50 ROPE.bW5 H~Na.LW5 -999.250 MEFA.hW5 6,030 TAB,LW5 END OF DATA -999.~50 DRHD.LW5 -999.250 ATR,LW5 44.677 G~.LW5 1.789 TABD.LW5 12'800 DRHO.bW5 36.900 ATR'LW5 -999..250 GR.bW5 -999.250 TABD,LW5 -999.,250 DRHO LW5 -999.250 ~TR:LW5 -999.250 GR,LW5 -999.250 TABD.LW5 -999'~250 36.604 23,692 '999~250 0 008 -999:250 ~50 -999 ~50 -999 ~999, 0 -999'250 -999,250 **** FIL~ TRAILER FIG~ ~A~E : EDI? .005 SERVICE : FLIC YER~ION : O01COI DATE : 94/0t/20 MIX REC SIZE : 1024 FILE TYPE : LO LASH FILE **** FILE READER FILE NA~E ! EDIT .006 SERVICE : FLIC VERSION : O01. COl DAT~ ! 94/01/20 M~X REC SIZE : 1024 FILW TYPE : LO LAS~ WILE FILE HEADER FTbF HUMBER 6 MAD Curves and loq header data tot each bit run tn separate BIT RUN NUMRE~: DEP?H INC~E~ENT: FIL~ SUmmARY ~.I)WG TOOL CODE 2 0. 5000 START DEPTH .... 9545.0 STOP DEPTH 9780. 9780,0 files. Tame Verlficatlon Listinc~ :blum~erger Alaska Computing Center 20-JAN-1994 I4:]6 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWMHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~E}: TD D~ILLER TOP LOG INTERVAL (MT): BOTTOM LOG INTERVAL BIT ROTATING SPEED ~OLE INCLINATION (mEG) MINIMUM ~AXI~UM A~GLE: .. ...... .... .... CDR CDR NEUTRON/DENSITY $ BO~EHOLE AND CA&ING DATA DRILLERS CASING DEPTH (FT): m{JREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): ~UD VISCOSITY ($): ~UD SUD CHLORIDFS FLUID LOSS ~X~IM RFCORDED TE~PERAT~RE RESISTIVITY (OH~M) AT TEMPEEATURE (DEGF): ~UD ~T ~£ASUPED TEmPERaTURE ~Un ~T MAX. CIRCULATING TEMPERATURE ~UD FILTRATE AT (MT): ~UD CAKE AT (MT): NEUTRON TOOL M~TRIX: MATRIX HOL~ COPRMCTION {IN); # RFMARK6 ~ 18-~AR-93 FAST V4,0C MEMORY ~0387.0 9550.0 ~0387.0 37.5 85,0 NUMBER 00.0 KCL POLyNER 10,00 40,00 O0 !58.0 83.0 1,720 61.0 SANDSTONE TOOL STAL~DOFF (IN): FWP FRFUUENCY (HZ)~ 1,000 TWERE WFRE 4 BIT RUNS IN THE HOI, E IN WHICH TNEPE ~ERE 3 DIFFERFNT CD~ TOOLS RUN IN BOTH DRIbLI~G AND WASHDOW~ MODF~ AS WELL AS ~ OF ~H~ Ru~S HAD CDR IN THE LIENT REOUMSTED THAT THE ~SHDOWN AND MAD PASSES BE PRESENTED AS SEPARATE ~OGS. IS TaDe Verlflcation Listinq chlumberger AlasKa Computing Center 20-JAN-t994 14:36 DEN TO BIT 9% 7' NEUT TO BIT ~0 WASNDOI4N INTE~¥AL: 9550 - 9780 $ # LIS FORMAT DATA PAGE ** PATA F~!RMAT SPECIFICATION RECO~D ** SET TYPE - 64ED ** T PE REPR CODE 1 66 0 2 66 0 3 73 64 4 66 ~ 5 66 6 73 7 65 8 68 0 5 1~. 66 16 l~ 68 13 66 0 i4 65 FT 15 66 68 16 66 1 0 66 ~ ** SET TYPE - CHAN ** ...... ' ....... "'"'"'"i' ..... '"'""""'"','""'""'"'"",'"""'""'" F S~RV UNIT S~RVICE AP AP1 APl API FILE U~B NUMB SIZE R PR PROCESS ID ORDE~ # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ~;~.~~~~"~~~~~~~~"~~~""~~~"~~.~~`P~ FT 619054 O0 000 O0 0 6 1 I 4 68 0000000000 RHO~ DPHI L~I D~HO !,~1 DCAb LWl TNP~ Dwl ATR PSR DFR G~ [,Wi HFFa G/C3 619054 O0 PU 619054 O0 G/C3 619054 O0 BN/E 61Q054 O0 IN 619054 OO P!~ 619054 O~M~ 619054 O0 0~ 6Iq054 O0 OMM~ 619054 O0 F/H~ 619054 O0 GAPI 619{)54 O0 CPS 619054 O0 CPS 619054 O0 000 O0 0 6 1 1 4 68 000 O0 0 6 I I 4 68 OhO O0 0 6 1 I 4 68 000 O0 0 6 I 1 4 68 000 O0 0 6 1 I 4 68 000 O0 0 6 ! I 4 68 000 o0 0 6 1 1 4 68 CO0 O0 0 6 1 I 4 68 OhO on o 6 1 I 4 68 000 oO 0 6 1 1 4 68 000 O0 0 6 1 1 4 68 000 O0 0 6 1 I 4 68 Dan O0 0 6 I 1 4 6~ 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tape Verification Listing chlumberger Alaska Computin~ Center 20-JAN-t, 994 14:36 2O '''''''''NAMF SERV ...... UN~''SERVI~' ...... AP1 '''''''''''''''''''''''''''''''''''''''''''''''''''''''API API F NUMB SIZE ID ORDER # bOG TYP~ CLASS mOD NUMB SAMP EbEM CODE {HEX) ...... . .... ..... kB LW1 H~ 19054 0 000 0 6 1 I 4 6. 000 0000 TABD'LWl H~ 6!g054 O0 000 OD 0 6 ! i 4 68 0000000000 DATA ** DFPT. 10384.000 RHOB.Lwl -999.~50 DPHI.bW1 PEF.LW'~ -999.250 DCAL.LWI ~999.~50 TNPH..SW1 PS~,LW~ -999.25{) DER.LW1 999.250 ROPE.LWI HENA.LW1 -999.250 HEFA.Lwl -999.250 TAB.SW! DEPT 9454.000 ~HOB.LW1 -999.~50 DPMI.{uWl PEFiLW, -999.250 DCAbiLW1 -999.~50 TNPH.SW~ PS" [,W, -999.2~0 DER LWl -999'9,50 .OPE,bWl ,~N, LW! -999.250 ,EFA LWl 6.030 TAB.,Wl END OF DATA ** -999.:~50 DRHO.LW1 59.800 GR.SWI 999,~50 TABD.LWl 17.900 DRH 24.900 ATR 69'371 GR 999,~50 TABD 14.900 DRHO'LW! 39,000 ATR.LW! -999,250 GR.LW! -999.~50 99.~50 ATR.bW! 99..250 99.250 TABD,LWl '999. 0 '999, 0 !o O~ O. 6 '999,~0 '999.250 '999.~50 999' 999.~50 **** FILE TRSILER FILE NA~E = EDIT .006 SERVICE t FL!C V~RSION = 00!C01 D~T~ : 94/0~/70 M~X EEC SIZ~ FILF TYPE = LO L~ST FI!,E **** FILE NEADER FILE NAME ~ EDIT .007 S~RVICE : FLIC VERSION : O0~CO1 D~TF : 94/0~/20 MaX R~C S~Z~ : FILF TYP~ : LAST FI[,E : IS Tape Verification Listing chlumberger AlasKa Computing Center 20-JAN-1994 14:36 PAGE: FILE HEADER RAW MAD Curves and log header data for each bit run i,n separate BIT RI~N NUMBER: 3 DEPTH INCPEMENT: 0.5000 FIL~ SUmmARY LDWG TOOL CODE START DEPTH 9715.0 6DO HEADER DATA DATE LOGGED~ SOFTWARE: SURFACE $OFT'~A~E VERSION DOWNHOLE SOFTWARE VERSIOn: DATA TYPE (MEMORY or REAL-TIME)~ TD DPI~L~R (FT)I TOP LO.. INTERVAL ~OTTOM LOG INTERVAL HIT ROTATING SPEED HOLE INCLINATION (DEG) MTNTMUN ANGLE: MAXIMUM TOOL STRING CT[]P TO BOTTOM) V~NDO~ TOOL CODE TOOL TYPE COR RESISTIVITY CON NEUTRON/DENSITY BO~EHO[,E AND CASING DATA OPEN HOLE BIT $IZ~ (IN): QRTLLERS CASIN~ DEPTH ~OREHOLE CONDITIONS MUD TYPF: MUD DENSITY (LB/G): MUD VISCOSITY ~UD FLUID LOSS (C3): ~AX!M!,)M RECORDED TEMPFRATURE (DEGF): RFSTSTIVITY (OHWH) AT TEMPERATURE MUD AT MEASURED TEMPERATURE ~UD AT MAX CIRCULATING TEMPERATURE ~UD FILTPATK AT (MT): .UD CAKE AT ~EUTRON TOOL STOP DEPTH 10385,0 10385,0 18-MAR-g3 FAST 2.3E V4,0C MEMORY 10307.0 _9550,0 10387,0 37.5 85.0 000.0 KCL POLYMER ~0,00 4~,00 00 26oo 1,9~0 1,7~0 SANDSTONE files. 83.0 61.0 IS Tame Verlflcat~on Listing chlumberger Alaska Computtnq Center 20-JAN-1994 14:36 # i~T~I× DENSITY; HOLE CORRECTIO~ (IN): TOOL STANDOFF EWR FREOUE~C¥ 2.65 1,000 THE~E WERE 4 BI~ RUNS IN THE HOLE IN WHICH TMEPE ~ERE 3 DIFFERENT CDR TODLS RUN IN BOTH D~ILLING AND WASHDOWN MOD~ AS WELL AS 3 OF TME RUNS HAD CD~ IN THE BMA. CLIENT ~EOUESTED THAT THE WASHDOWN AND MAD P~SSES BE PRESENTED AS SEPARATE LOGS *********************U* GR T[~ BIT 53.7' ~ES TO DEN TO 8I~ 70.6' NEUT WAS~DONN INTE~ AL:V 97i5 - ~0387 FT l~IS FORe, AT DATA PAGE~ 22 ** DATA FORMAT SP~CTFTCATION RECORD ** ** SET TYPE - 64EB '~;i .... ' ......R~P~ CODE''''''''''~'VA 2 66 0 3 73 64 4 66 5 66 6 73 7 65 ~ 65 11 66 16 1~ 68 1~ 66 0 14 65 !5 66 6B 16 66 ! 0 66 ,, s~? ~ - c.A. ** ..... ""; ......... ~i~";~"; ........ ' ';"'"" ~ ~ ~ ....... "~;~~"' .~.~ s~ ~ u.~ ~, p~ ~ ~ ~ ~ ~ ..... "'" mmmmm~~m~~m~mm~~~m~mm~mm~m~~m~mmmm~~m~~m~mmmm~m~~m~~mm~~m~~m~m~mm~mmmm~~m~m~m~mmmm~~m~m D~P~ FT 61 q054 O0 000 O0 0 7 1 1 4 68 0000000000 R"O~ L~ G/C] ~19054 O0 00o O0 0 7 1 ! 4 68 0000000000 DPH? I,w? PU 610054 O0 000 O0 0 7 1 1 4 68 0000000000 Tare VerlfIcatlom Ltstlnq chlumber~er AlasKa ComputinO Center 20-JAN-1994 14:35 PAGE: 23 ID ORDER # LOG TYPE CbAS$ MOD NUMB. SA~zp ~LEM CODE (HEX) D~HO L~9 G/C3 619054 O0 000 O0 0 7 ! 1 4 68 PEF ~W9 BN/E 619054 O0 000 O0 0 7 1 1 4 68 DCAL LW~ lN 619054 O0 000 O0 0 7 I l 4 68 TNP~ LW~ PU 619054 O0 000 O0 0 7 1 1 4 68 ATR LN~ O~{MM 619054 O0 000 O0 0 7 i I 4 68 PSR I~W~ OHM~ 619054 O0 000 O0 0 7 1 1 4 68 DER LW2 OMM~ 619054 O0 000 O0 0 7 1 I 4 68 ROPF LW2 F/HD 61.9054 O0 000 O0 0 7 I i 4 68 GR LW? GAP! 619054 00 000 00 0 7 I i 4 6~ H~N~ LW~ CPS 61.9054 O0 000 O0 0 7 1 ! 4 68 ~EF~ LW~ CPS 6190~4 O0 000 OO 0 7 i I 4 68 T~B LW~ H~ 619054 O0 000 O0 0 7 1 1 4 68 TABD LW~ },IR 619054 O0 OOO O0 0 7 i I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 g* DAT~ PEFiL~2 PS~ LW2 I0384,000 ~HOB,bw2 -999.250 DPHI,LW2 999.250 DRHO,LW2 -999.250 DC~L.LW2 -999 ~50 TNPH.LW2 ~999.~50 ATReLW2 -999.250 DER,LW~ -999~250 ROPE'LW2 59.800 GR.LW9 -999.250 ~EFA.LW2 -999 950' TAB,bW2 '999,~50 TABD,LW~ ~0000,000 ~HOS.LW2 9,355 DPHi. SW2 17,900 DRHO,LW9 3,021 DCAL.LW2 0.281 TNPH,bW2 24.900 ATR.LW2 ~2.695 DER'LW2 25.0~8 ROP~ 5W2 69'37! GR.LW2 303.500 HEFA.LW2 8.471 TA :LW2 -999.950 TABD.LW2 9637.500 RHOB LW2 2 ~72 DPNI,LW2 -],350 DRHO.LW~ 3.245 DCAL:LW2 0:~9~ TNPH.bW2 22.850 ATR.LW2 7.173 DER.LW2 7.440 ROPE.LW2 82.475 GR LW2 2~2.875 NEFA.LW2 7.907 TAB.LW2 -999,250 TABDiLW~ DEPT. PEF.LW2 PSRoLW2 HENa.L~2 D~PT. PEF.Lw2 PS~.LW2 HEN~.LW2 END OF DATA '999'250 ~999~]50 -999,250 -999'250 -0,010 5,686 ~?~ 94,188 -~99,250 FIb~ N~E : EDIT .007 SERVICE : FLIC VERSION : OO1COI DATF : 94/0!/20 MaX REC SIZ~ : 1024 FTLF TYPE : bO L~$T ~ILE : ,IS Tape Vertflcatlon ~chlUmberqer AlasKa Compt.{tinc~ Center 20-JAN-1994 14:)6 PAGE** 24 **** FILE ~EADER SERVICE : FLIC VERSION : O0~CO! ~AX R~C S?Z~ : FTLF TYPE : LO L~ST ~ILC MWD Depth s~.~ted and cl]~p~ed curves; all bit runs merged. DEPTH INCRE~ENT: 0.5000 ILF SIj ~ 5iA R ~.. I,~WG TOOL CODE START DEPTH STOP DEPTH 10300'0 11700.0 ~AS~I,~INE CURVE FO~ CURVE $~IWT DATA (~EASURED DEPTH) -~--------- MUU I VALENT UMSHIFTED ~ASELINE DEPTH RF~R~S: T~IS DATA WAS PROVIDED BY ANADRIbL/SCMLUMBE~GER FPOM AN SLIM ~ GR (~WD) RUN CONDUCTED AS PER MEMO DATED 6/3/9~. THE FOLLOWING DATA IS PROVIDED~ TVD.DAT - (FT) TR~I~ VERTICAL ROP.DAT - (FT/HR) RATE OF PENETRATION FT/}~R) RATE OF PENETRATION OVER 5 FT SWOB.DAT - (KL~3S) SURFAC~ WMI~HT ON BIT RP~.DAT - SURFACE REVOLUTIONS PER MINUTE A~P.D~T - (AMPS) ROTAR~ TABLE POWER IN AMPS SPM.DaT - TOTAL PU~P STROKES PER MINUTE SPP~.DAT - fPSI) ~U"P PRESSURE ~EASURED AT STANDPIPE STOR. PAT - (KFT-LBS) SURFACE TO~UE ~FLO.DAT - TOTAL FbO~ IN AS C~LCULATED ~Y PU~P OUTPUT TIMES TOT GR.DAT - GA~ ~AY IN COUNTS PER SECOND C~R.DAT - GAMMA RAY C~R~ECTED FOR HOLM SIZE, MUD WE!GET AND COLLAR SIZE. L~S FOR.AT DA~A cblum%eroer AlasKa Computln.6 Center 20-JAN-1994 14:36 1 66 0 2 66 0 3 73 52 4, 66 5 66 7 65 8 68 0 5 9 65 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET ~YPE - CMAN ** '-------------,,--,,,,,,,--- .... . ..... ,---.----.,...---,............................... N~MR SRRV U ? AP1 API A I IP! FI E NUM NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE C[,~SS MOD NUMB SA~P ~LEM CODE (HEX) DEPT FT 619054 O0 000 O0 0 8 ! I 4 68 0000000000 TVD DAT 61~054 O0 000 O0 0 ROP DAT 619054 O0 000 O0 0 8 ROP5 DAT 619054 ~0 SWO~ DAT 6~9054 O0 000 O0 0 RPM DAT 61Q054 O0 000 O0 0 A~p DA? 619054 O0 000 O0 S~M DAT 61~054 O0 000 O0 0 8~P~ DAT 619054 O0 000 O0 0 STO~ DAW 619054 O0 000 O0 0 TFLO DAT 610054 O0 000 O0 0 GR DA~ 1 i 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 6B 0000000000 1 I 4 68 0000000000 1 I 4 65 0000000000 1 1 4 68 0000000000 ! 1 4 68 0000000000 1 1 4 68 0000000000 ** DAT~ DFPT. 11170.000 TVD.,DhT 9001,500 ROP.DAT SWO~.DAT ~7.100 RPM.DAT 83.000 AMP.DAT S~PP.DAT -999.250 STOR.DAT 29.600 TFLO,DAT CG~.DA? -909.250 17.200 ROPS.DAT 124.000 SPM.DAT 2596.000 GP.DAT 16'600 24,000 '999.250 Tape Verification Llstlno ~chlumberger AlasKa Computing'Center 20-JAM-1994 14:36 PAGE{ 26 DEPT 11000.000 TVO.DAT SWOP]OAT "' 16.900 RPM.DAT SPPP.DAT -999,250 STOR.D~T CG~,DAT -999.250 D~PT 10500,000 TVD.DAT SWOB'DAT ~5,700 RPM*DAT SPpp:DAT -999.250 STOR.DAT CG~.~AT 2.800 D~PT. 10300.000 TVD,DAT SWO~.,DAT 18.1(}0 RP~,DAT SPP~.DAT -999'250 STORiDAT CG~.DA? -9~9.250 ** END OF DATA 9003.000 ROP,OAT 83.000 AMP.OAT 20,180 TFbO.DAT 9001.801 ROP.DAT 77.000 8.420 TFLO.DAT 8994.701 ROP.OAT 158.000 A~P,DAT 103,520 TFLO'DAT 51 500 1151000 280.000 68.700 4 .000 16.100 2.000 4156'000 ROPL.DAT SPM.DAT GR.DAT ROP5.DAT SPM,DAT GR.DAT ROP$.DAT SPM.DAT G~.DAT 24, 0 '999,250 l'loo 23.000 28,000 ,ooo 46,00'0 '999,250 **** FILE TRAILER **** FIbE NA~E : MOlT .008 S~RVICE t ~LIC VERSION : O01CO1 D~TF : 94/01/20 M~X R~C SIZE : 1024 FILF TYPE : LO L~ST FILE : **** TAPE TRAILER **** D~T~ ~ 94/01120 ORIGIN : FblC TRPE ~!A~E : g3130 CONTINUATION # PREVIOUS TAPE CO~EMT : ARCO ALASKA, **** REEL TRAILER **** SMRVICE N~MM : EDIT DaTE : 94/01/~0 ORIGIN : FLTC CONTINUATION # : P~EVIOUS REEL : COMMENT : ARCO ALASKA, iMC.,PRUDHOE BAY, IMC.,PRUDHOM BAY, 9-351,50-029-21314-01 9-35A,50-029-21314-01